L-11-082, Submittal of Inservice Testing Programs

Submittal of Inservice Testing Programs

ML110880355
Person / Time
Site:	Perry
Issue date:	03/25/2011
From:	Bezilla M B FirstEnergy Nuclear Operating Co
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
L-11-082
Download: ML110880355 (339)

Text

FENOC Perry Nuclear Power Plant"f-t10 Center Road FirstEnergy Nuclear Operating Company Perry, Ohio 44081 Mark B. Bezilla 440-280-5382 Vice President Fax: 440-280-8029 March 25, 2011 L-1 1-082 ASME OM Code ISTA-3200(a)

ATTN: Document Control Desk U.S. Nuclear Regulatory Commission Washington, DC 20555-0001

SUBJECT:

Perry Nuclear Power Plant Docket Number 50-440; License Number NPF-58 Submittal of Perry Nuclear Power Plant Inservice Testing Programs The American Society of Mechanical Engineers Operations and Maintenance (OM)Code, Subsection ISTA, "General Requirements," establishes requirements for inservice testing and examination of pumps, valves, pressure relief devices, and dynamic restraints (snubbers).

ISTA-3100, "Test and Examination Program," requires preparation of test plans for these components, and ISTA-3200, "Administrative Requirements," requires the test plans to be filed with the regulatory authorities having jurisdiction at the plant site.The Perry Nuclear Power Plant (PNPP) inservice testing program (ISTP) for pumps, valves, and pressure relief devices for the current 120-month interval is provided in Enclosure A, for information.

The PNPP snubber test and examination program is maintained separately, and is provided in Enclosure B.There are no regulatory commitments contained in this submittal.

If there are any questions or if additional information is required, please contact Mr. Thomas A. Lentz, Manager- Fleet Licensing, at 330-761-6071.

Sincerely, Mark B. Bezilla

Enclosures:

A. Perry Nuclear Power Plant Inservice Testing Program B. Perry Nuclear Power Plant Snubber Program cc: NRC Region III Administrator NRC Resident Inspector Office A ----NRC Project Manager r)(L-Enclosure A to Letter L-1 1-082 Perry Nuclear Power Plant Inservice Testing Program (296 pages follow)

ISTP Page: Rev. : i 13 PERRY OPERATIONS MANUAL TITLE: PUMP AND VALVE INSERVICE TESTING PROGRAM PLAN REVISION: 13 EFFECTIVE DATE: 8-31-10 PREPARER:

Bryan L. Andrie 8-16-10/ Date APPROVER:

Scott Seman 8-19-10/ Date ISTP Page: ii Rev.: 13 Pump and Valve Inservice Testing Program Plan Table of Contents Section Title Page Preface i through ix

1.0 INTRODUCTION

1-1 1.1 Purpose 1-1 1.2 Scope 1-1 1.3 Compliance 1-2 2.0 PUMP INSERVICE TESTING PROGRAM 2.1-1 2.1 General Information 2.1-1 2.1.1 Applicable Code 2.1-1 2.1.2 Pump Groups 2.1-1 2.1.3 Pump Program Tables 2.1-4 2.1.4 Measurement of Test Parameters 2.1-5 2.1.5 Allowable Ranges of Test Parameters 2.1-6 2.1.6 Instrument Accuracy 2.1-6 2.1.7 Pump Test Descriptions 2.1-6 2.1.8 Pump Surveillance Test Review 2.1-7 2.2 Relief Requests for the Pump Inservice Testing Program 2.2-1 2.3 Pump Testing System Index and Test Tables 2.3-1 2.3.1 Pump Testing System Index 2.3-1 2.3.2 Pump Test Table Nomenclature 2.3-2 2.3.3 Pump Test Table 2.3-3 2.4 Hydraulic Circuits, Test Methods, and Instrumentation 2.4-1 3.0 INSERVICE TESTING PROGRAM FOR VALVES 3.1-1 3.1 General Information 3.1-1 3.1.1 Applicable Code 3.1-1 3.1.2 Valve Program Tables 3.1-1 3.1.3 Measurement of Test Quantities 3.1-4 3.1.4 Allowable Ranges of Test Quantities 3.1-10 3.1.5 Instrument Accuracy 3.1-12 3.1.6 Post-Maintenance Testing 3.1-12 3.2 Cold Shutdown Justifications, Refueling Outage Justifications and Relief Requests for Inservice Valve Testing Program 3.2-1 3.3 Valve Testing Index 3.3-1 3.4 Valve Test Table 3.4-1 3.5 Valve Test Table Notes 3.5-1 ISTP Page: Rev.: iii 13 Submittal History L-08-347 L-08-353 L-09-117 Revision No. 11 Revision No. 11 Revision No. 11 Revision No. 11 Revision No. 11 Revision No. 11 Revision No. 11 Inservice Testing Program (ISTP)Plan for pump and valve testing submitted relief request for the 3rd Interval dated November 18, 2008. Relief Requests PR-I and 2, VR-I, 2, 3, 4, 5 and 6.Inservice Testing Program (ISTP)Plan for pump and valve testing submitted relief request for the 3rd Interval dated February 18, 2009. Relief Request PR-3.Inservice Testing Program (ISTP)Plan for pump and valve testing response to request for additional information for the 3rd Interval dated May 28, 2009.Relief Requests PR-I, VR-3, 4, 5 and 6. Including re-submittal of VR-4 and withdrawal of VR-5.Inservice Testing Program (ISTP)Plan for pump and valve testing response to request for additional information for the 3rd Interval dated June 9, 2009.Relief Request PR-3.Withdrawal of VR-4 dated August 3, 2009.Approved Safety Evaluation Report for Relief request PR-3 dated October 8, 2009.Approved Safety Evaluation Report for Relief Requests PR-I, 2, 2, 3 and 6 dated October 22, 2009.L-09-160 L-09-19 R-09-242 R-09-250 VR-I, ISTP Page: Rev. : iv 13 SCOPE OF REVISION: Rev. 13 -Page 1-2 Page 2.4-1 Thru 2.4.15 Page 3.4-33 Page 3.4-37 Page 3.4-39 Eliminated Commitments L01940 and L02466 and added L02424.(Notification 600628763) (CR CA 10-79344-01)

Added the flow rate and differential pressure reference values based on MS-C-I0-06-13, Engineering, ASME Audit.QFO FLT12010138.

These values were added to the Hydraulic Circuits, Test Methods and Instrumentation table, for each pump listed. (Notification 600625199) 1E12-F011A stroke times show an average delta of -0.90 seconds closed and -0.43 open. In 2007 the stroke times showed average delta of -0.10 seconds closed and 0.38 open. Through the evaluation it was discovered that Order 200007544 (closed 4/15/09) removed the valve operator, valve bonnet, lubricated the stem and reinstalled the valve operator, which provided the current stroke time closed and open reference values of (29.20 seconds closed)and (29.90 seconds open). The IST Program Engineer will accept the closed and open stroke times of (29.20 seconds closed) and (29.90 seconds open) obtained on 4/11/09 as a new baseline reference values for the close and open direction.

SVI-E12-T2001 procedure change request has been submitted to update the procedure (refer to Ops Notification 600625333).

Accepting this value will change the average deltas to -0.08 seconds closed and -0.36 seconds open, which will eliminate this valve from the concern list. (Notification 600625479) 1E12-F004A stroke time closed shows an average delta of -2.66 seconds. In 2007 the stroke time closed and open showed average deltas of -1.72 seconds. Through the evaluation it was discovered that Order 200264931 (closed 4/15/09) removed the valve operator, refurbished the operator and reinstalled the valve operator, with the post maintenance test being performed within Order 200315867, which provided the current stroke time closed and open reference values of (112.50 seconds closed) and (115.50 seconds open). The IST Program Engineer will accept the closed and open stroke times of (112.50 seconds closed)and (115.50 seconds open) obtained on 4/11/09 as a new baseline reference values for the close and open direction.

SVI-E12-T2001 procedure change request has been submitted to update the procedure (refer to Ops Notification 600625333).

Accepting this value will change the average delta to 0.06 seconds closed and 0.04 seconds open, which will eliminate this valve from the concern list. (Notification 600625479) 1E12-F023 stroke time closed and stroke time open shows an average delta of -3.40 seconds and -2.90 seconds respectively.

In 2007 the stroke time closed and open showed average deltas of 0.40 seconds and -0.60 seconds respectively.

Through the evaluation it was discovered that Order 200002286 (closed 4/15/09) removed the valve operator, change stem lubrication, installed and calibrated strain gauge and reinstalled the valve ISTP Page: Rev. : V 13 Page 3.4-40 Page 3.4-56 operator, which provided the current stroke time closed and open reference values of (30.60 seconds closed) and (32.10 seconds open). The IST Program Engineer will accept the closed stroke and open times of (30.60 seconds closed) and (32.10 seconds open) obtained on 4/12/09 as a new baseline reference values for the close and open direction.

SVI-E12-T2004A procedure change request has been submitted to update the procedure (refer to Ops Notification 600625167).

Accepting this value will change the average delta to 0.00 seconds closed and open, which will eliminate this valve from the concern list.(Notification 600625479) 1E12-F037A stroke times show an average delta of -1.00 seconds closed and -1.05 open. In 2007 the stroke times showed average delta of -0.30 seconds closed and -0.30 open. Through the evaluation it was discovered that Order 200002324 (closed 4/14/09) removed the valve operator, lubricated the stem, installed/calibrated a strain gauge and reinstalled the valve operator, which provided the current stroke time closed and open reference values of (58.30 seconds closed) and (58.40 seconds open). The IST Program Engineer will accept the closed and open stroke times of (58.30 seconds closed) and (58.40 seconds open)obtained on 4/12/09 as a new baseline reference values for the close direction.

SVI-E12-T2004A procedure change request has been submitted to update the procedure (refer to Ops Notification 600625167).

Accepting this value will change the average deltas to 0.00 seconds closed and 0.00 seconds open, which will eliminate this valve from the concern list. (Notification 600625479) 1E51-F068 stroke time closed and stroke time open shows an average delta of -1.34 respectively.

In 2007 showed average deltas respectively.

In 2006 showed average deltas respectively.

In 2005 showed average deltas respectively.

In 2004 showed average deltas respectively.

In 2003 showed average deltas seconds and -2.12 seconds the stroke time closed and open of -2.90 seconds and -3.25 seconds the stroke time closed and open of -2.60 seconds and -2.67 seconds the stroke time closed and open of -3.13 seconds and -3.20 seconds the stroke time closed and open of -2.75 seconds and -3.00 seconds the stroke time closed and open of -2.52 and -2.75 seconds and in 2002 the stroke time closed and open showed average deltas of -1.9 seconds and N/A (not stroked open until late 2002). Through the evaluation it was discovered that Order 200328428 (closed 5/18/09) removed the valve operator, repaired valve disk due to Local Leak Rate Test (LLRT)failure and reinstalled the valve operator, which provided the current stroke time closed and open reference values of (39.60 seconds closed) and (40.10 seconds open). The IST Program Engineer will accept the closed stroke time of (39.60 seconds closed) and (40.10 seconds open) obtained on 5/12/09 as a new baseline reference values for the close and open direction.

SVI-E51-T2001 and SVI-E51-T1272 procedure change requests have been submitted to update ISTP Page: Rev. : vi 13 Page 3.4-64 Page 3.4-90 the procedures (refer to Ops Notification 600625364).

Accepting this value will change the average delta to 0.57 seconds closed and -0.47. seconds open, which will eliminate this valve from the concern list. (Notification 600625479) 1G33-F039 stroke time closed shows an average delta of -0.83 seconds. In 2007 the stroke time closed showed an average delta of -0.10 seconds. Through the evaluation it was discovered that Order 200360838 (closed 5/11/09)removed the valve operator, repaired valve disk due to Local Leak Rate Test (LLRT) failure and reinstalled the valve operator, which provided the current stroke time closed reference value of (20.70 seconds closed). The IST Program Engineer will accept the closed stroke time of (20.70 seconds closed) obtained on 4/23/09 as a new baseline reference value for the close direction.

SVI-G33-T2003 procedure change request has been submitted to update the procedure (refer to Ops Notification 600625365).

Accepting this value will change the average delta to 0.00 seconds closed, which will eliminate this valve from the concern list. (Notification 600625479) 1G33-F040 stroke time closed shows an average delta of -0.70 seconds. In 2007 the stroke time closed showed an average delta of -0.10 seconds. Through the evaluation it was discovered that Order 200360835 (closed 5/11/09)removed the valve operator, repaired valve disk due to Local Leak Rate Test (LLRT) failure and reinstalled the valve operator, which provided the current stroke time closed reference value of (20.50 seconds closed). The IST Program Engineer will accept the closed stroke time of (20.50 seconds closed) obtained on 4/21/09 as a new baseline reference value for the close direction.

SVI-G33-T2003 procedure change request has been submitted to update the procedure (refer to Ops Notification 600625365).

Accepting this value will change the average delta to 0.00 seconds closed, which will eliminate this valve from the concern list. (Notification 600625479) lPll-F060 stroke times show an average delta of -1.10 seconds closed and -0.01 open. In 2007 the stroke times showed average delta of -0.76 seconds closed and 0.62 open. Through the evaluation it was discovered that Order 200323587 (closed 4/9/09) removed the valve operator, replaced valve disk seal, installed a refurbished valve operator, with the post maintenance test being performed per Order 200342634, which provided the current stroke time closed and open reference values of (28.10 seconds closed) and (28.70 seconds open). The IST Program Engineer will accept the closed and open stroke times of (28.10 seconds closed) and (28.70 seconds open) obtained on 4/13/09 as a new baseline reference values for the close and open direction.

SVI-PII-T2002 procedure change request has been submitted to update the procedure (refer to Ops Notification 600625369).

Accepting this value will change the average deltas to 0.08 seconds closed and 0.12 ISTP Page: Rev. : vii 13 Page 3.4-94 Page 3.4-97 seconds open, which will eliminate this valve from the concern list. (Notification 600625479) lPll-F080 stroke times show an average delta of -0.53 seconds closed and -0.61 open. In 2007 the stroke times showed average delta of 0.18 seconds closed and 0.10 open.Through the evaluation it was discovered that Order 200194357 (closed 4/14/09) removed the valve operator, installed a refurbished valve operator, which provided the current stroke time closed and open reference values of (27.90 seconds closed) and (27.90 seconds open). The IST Program Engineer will accept the closed and open stroke times of (27.90 seconds closed) and (27.90 seconds open)obtained on 4/13/09 as a new baseline reference values for the close direction.

SVI-Pll-T2002 procedure change request has been submitted to update the procedure (refer to Ops Notification 600625369).

Accepting this value will change the average deltas to 00.07 seconds closed and -0.12 seconds open, which will eliminate this valve from the concern list. (Notification 600625479) 0P42-F255B stroke time closed shows an average delta of -0.70 seconds. In 2007 the stroke time closed showed an average delta of 1.82 seconds. Through the evaluation it was discovered that Order 200292547 (closed 3/11/09)removed the valve operator, replaced the valve and the valve operator, which provided the current stroke time closed reference value of (29.30 seconds closed). The IST Program Engineer will accept the closed stroke time of (29.30 seconds closed) obtained on 3/5/09 as a new baseline reference value for the close direction.

SVI-P42-T2002 procedure change request has been submitted to update the procedure (refer to Ops Notification 600625332).

Accepting this value will change the average delta to 0.00 seconds closed, which will eliminate this valve from the concern list. (Notification 600625479) 1P43-F055 stroke time closed shows an average delta of -1.30 seconds. In 2007 the stroke time closed showed an average delta of 0.20 seconds. Through the evaluation it was discovered that Order 200173854 (closed 4/1/09)removed the valve operator, replaced motor and reinstalled the valve operator, with the post maintenance retest being performed per Order 200261982, which provided the current stroke time closed reference value of (28.60 seconds closed). The IST Program Engineer will accept the closed stroke time of (28.60 seconds closed) obtained on 4/13/09 as a new baseline reference value for the close direction.

SVI-P43-T2001 procedure change request has been submitted to update the procedure (refer to Ops Notification 600625366).

Accepting this value will change the average delta to 0.00 seconds closed, which will eliminate this valve from the concern list. (Notification 600625479) 1P43-F140 stroke time closed shows an average delta of -1.50 seconds. In 2007 the stroke time closed showed an average delta of 0.00 seconds. Through the evaluation it was discovered that Order 200188423 (closed 4/3/09)removed the valve operator, replaced motor and reinstalled ISTP Page: Rev. : viii 13 Page 3.4-98 Page 3.4-106 the valve operator, with the post maintenance retest being performed per Order 200262062, which provided the current stroke time closed reference value of (27.90 seconds closed). The IST Program Engineer will accept the closed stroke time of (27.90 seconds closed) obtained on 4/13/09 as a new baseline reference value for the close direction.

SVI-P43-T2001 procedure change request has been submitted to update the procedure (refer to Ops Notification 600625366).

Accepting this value will change the average delta to 0.00 seconds closed, which will eliminate this valve from the concern list. (Notification 600625479) 1P43-F215 stroke time closed shows an average delta of -0.80 seconds. In 2007 the stroke time closed showed an average delta of 0.10 seconds. Through the evaluation it was discovered that Order 200187071 (closed 4/1/09)removed the valve operator, replaced motor and reinstalled the valve operator, with the post maintenance retest being performed per Order 200261981, which provided the current stroke time closed reference value of (28.10 seconds closed). The IST Program Engineer will accept the closed stroke time of (28.10 seconds closed) obtained on 4/13/09 as a new baseline reference value for the close direction.

SVI-P43-T2001 procedure change request has been submitted to update the procedure (refer to Ops Notification 600625366).

Accepting this value will change the average delta to 0.00 seconds closed, which will eliminate this valve from the concern list. (Notification 600625479) 1P45-F140 stroke time closed and stroke time open shows an average delta of 2.35 seconds and 2.23 seconds respectively.

In 2007 the stroke time closed and open showed average deltas of 1.22 seconds and 1.10 seconds respectively.

Through the evaluation it was discovered that Order 200327144 (closed 3/30/09) removed the valve operator, replaced valve disk due to leakage and reinstalled the valve operator, which provided the current stroke time closed and open reference values of (29.90 seconds closed) and (29.80 seconds open). The IST Program Engineer will accept the closed stroke time of (29.90 seconds closed) and (29.80 seconds open) obtained on 3/27/09 as a new baseline reference values for the close and open direction.

SVI-P45-T2003 procedure change request has been submitted to update the procedure (refer to Ops Notification 600625367).

Accepting this value will change the average delta to -0.02 seconds closed and-0.05 seconds open, which will eliminate this valve from the concern list. (Notification 600625479) 1P51-F150 stroke time closed shows an average delta of 0.81 seconds. In 2007 the stroke time closed showed an average delta of 0.04 seconds. Through the evaluation it was discovered that Order 200267408 (closed 3/24/09)refurbished the air operated valve actuator, which provided the current stroke time closed reference value of (9.70 seconds closed). The IST Program Engineer will accept the closed stroke time of (9.70 seconds closed)obtained on 4/15/09 as a new baseline reference value for ISTP Page: Rev.: ix 13 the close direction.

SVI-P51-T2001 procedure change request has been submitted to update the procedure (refer to Ops Notification 600625368).

Accepting this value will change the average delta to -0.28 seconds closed, which will eliminate this valve from the concern list.(Notification 600625479)

Removed all reference to NUREG-1482, as NUREG-1946 is currently out for draft comment and will totally replace NUREG-1482, Revision 1, that was in use at Perry.Page -Various

1.0 INTRODUCTION

1.1 Purpose

This Inservice Testing Program (ISTP) plan identifies the pumps, valves, and pressure relief devices that are included in the IST Program. The ISTP plan identifies the inservice tests to be performed on the components in the program in order to verify their operational readiness.

1.2 Scope

The IST Program applies to those Inservice Inspection (ISI) Safety Class 1, 2, 3, MC and Optional pumps and valves required to bring the reactor to a safe shutdown condition, maintain the safe shutdown condition and mitigate the consequences of an accident.

The program also applies to overpressure protection devices for systems or portions of systems that perform one or more of these functions.

The ISI boundary classifications are determined in accordance with the Inservice Examination Program (ISEP) plan. The ISEP plan identifies the applicable ISI Safety Classifications on the ISI -305 series drawings.

The IST program was developed using the ISI safety classification boundaries and the following documents:

Title 10, Code of Federal Regulations, Part 50, Paragraph 50.55a(f) and (g).American Society of Mechanical Engineers (ASME) OM Code-2001 Edition, Code of Operation and Maintenance of Nuclear Plants, with Addenda through OMb-2003.ASME OM Code-2001 Edition through OMb-2003 Addenda, Appendix I, Inservice Testing of Pressure Relief Devices in Light Water Reactor Nuclear Power Plants.ASME OM Code-2001 Edition through OMb-2003 Addenda, Appendix II, Check Valve Condition Monitoring Program.Generic Letter 89-04, "Guidance on Developing Acceptable Inservice Testing Programs" and "Minutes of the Public Meetings on Generic Letter 89-04".NRR Safety Evaluations and their associated TER's.Technical Specifications, Perry Nuclear Power Plant.Updated Safety Analysis Report, Perry Nuclear Power Plant.1-1 Rev. 13 The satisfactory testing of individual components (pumps/valves) in accordance with the plan shall verify operational readiness of each component's safety function(s).

A failure to meet the scheduled surveillance frequency or acceptance criteria shall place the component in an inoperable status. Further consideration must be given to verify the system or subsystem status and Limiting Condition of Operation.

Components placed in an inoperable status because of exceeding an acceptance criteria must undergo a repair, replacement, or corrective maintenance and be satisfactorily retested, or have an evaluation of acceptability performed.

Components placed in an inoperable status because of exceeding the scheduled surveillance frequency must be satisfactorily tested to return the component to an operable status. Component operability based on analysis shall have the results of the analysis recorded in the record of tests.1.3 Compliance The Perry Nuclear Power Plant (PNPP) ISTP Plan for the 3 rd 120 month inspection interval will be in effect from 18 May, 2009 through 17 May 2019 and will be updated in accordance with the requirements of lOCFR50.55a(f) and Technical Specification 5.5.6.This document outlines the inservice testing program based on the requirements of the ASME OM Code-2001 Edition, with Addenda through OMb-2003.If this revised Inservice Testing (IST) Program Plan for the site conflicts with site technical specifications a technical specification amendment shall be submitted to conform the technical specification to the revised IST program [10CFR50.55a(f)

(5) (ii)].Until approval of the technical specification amendment the most limiting requirement shall be met.When performing 120 month update all Measuring and Test Equipment specification sheets shall be verified to meet current code requirements for range and accuracy (reference CR 04-03936).

The Code of record for the Third 10-year interval has a change for required instrument accuracy.

Instruments used for measuring pressure must have a minimum required instrument accuracy of +/- 0.5%when performing the biennial Comprehensive pump test or when testing to the alternative requirements specified in Code Case OMN-18 as requested per relief request PR-3, subsequent to NRC approval.Commitments:

L02424 1-2 Rev. 13 2.0 PUMP INSERVICE TESTING PROGRAM 2.1 General Information

2.1.1 Applicable

Code This testing program for ISI Class 1, 2, 3 and Optional pumps meets the requirements of the ASME OM Code-2001 Edition/2003 Addenda, Subsection ISTA, General Requirements, and Subsection ISTB, Inservice Testing of Pumps in Light-Water Reactor Nuclear Power Plants. Where these requirements are determined to be impractical, specific requests for relief have been written and included in Section 2.2.2.1.2 Pump Groups Group A Pumps The ASME OM Code defines Group A pumps as those pumps that are operated continuously or routinely during normal operation, cold shutdown, or refueling operations.

PNPP considers the following pumps as being categorized as Group A as well as justification for grouping.

Justification does not necessarily consider all safety related functions.

• Residual Heat Removal Pumps A and B (lEI2-CO02A, B)The RHR Pumps operate within the A(B) RHR Loops to provide four main functions.

The Residual Heat Removal (Shutdown Cooling) mode operates in a closed loop to remove decay and sensible heat from the reactor primary system. In the Low Pressure Coolant Injection (LPCI) mode, the RHR Pumps provide water from the Suppression Pool to the reactor vessel to cover the core. The Suppression Pool Cooling and Containment Spray Cooling modes are part of the Containment Heat Removal System and function to prevent excessive containment pressures and temperatures during post accident conditions." Residual Heat Removal Waterleg Pump (IE12-C003)

This waterleg pump maintains the discharge piping of RHR Pumps B and C full to reduce the time lag from pump start to actual injection of water and to eliminate the possibility of water hammer on pump start. 1E12-C003 also provides a water source for the Feedwater Leakage Control System.* Low Pressure Core Spray Waterleg Pump (IE21-C002)

This waterleg pump maintain the discharge piping of RHR Pump A and the LPCS pumps full to reduce the time lag from pump start to actual injection of water and to eliminate the possibility of water hammer on pump start. 1E21-C002 also provides a water source for the Feedwater Leakage Control System.2.1-1 Rev. 13

• High Pressure Core Spray Waterleg Pump (1E22-C003)

This waterleg pump provides the keepfill function for the HPCS Pump by maintaining the discharge piping full to reduce the time lag from pump start to actual injection of water and to eliminate the possibility of water hammer on pump start.Reactor Core Isolation Cooling Waterleg Pump (IE51-C003)

This waterleg pump provides the keepfill function for the RCIC Pump by maintaining the discharge piping full to reduce the time lag from pump start to actual injection of water and to eliminate the possibility of water hammer on pump start.* Fuel Pool Cooling and Cleanup Pumps (0G41-CO03A, B)The Fuel Pool Cooling and Cleanup Pumps remove decay heat from the stored fuel assemblies, thereby maintaining the pool at the required temperature, maintaining pool water level, and the removal of radioactive materials from the pool.* Emergency Closed Cooling Water Pumps (IP42-CO01A, B)The ECC Pumps provide a reliable source of cooling water to safety-related components required for certain modes of normal reactor operation, as well as for accident conditions and loss of normal auxiliary power.* Emergency Service Water Pumps (IP45-C001A, B)The ESW Pumps A(B) provide a reliable source of cooling water to the A(B) RHR, A(B) Diesel Generator, A(B) ECC, and Fuel Pool Cooling (via Unit 2 ECC) heat exchangers." Control Complex Chilled Water Pumps (0P47-CO01A, B)The CCCW Pumps provide mechanically chilled water to the cooling coils of the air handling units serving the control complex during normal operation and post-accident conditions.

2.1-2 Rev. 13 Group AB Pumps The ASME OM Code defines Group B pumps as those pumps in standby systems that are not operated routinely except for testing. PNPP considers the following pumps as meeting categorization requirements as Group B as well as justification for grouping.

However, the following pumps have been categorized as Group AB to impose Group A testing requirements commensurate with Code Case OMN-18 as addressed per relief request PR-3, pending NRC approval.* Standby Liquid Control Pumps (IC41-CO01A, B)The Standby Liquid Control (SLC) Pumps provide a backup means of reactivity control by injecting a neutron absorbing solution (sodium pentaborate) into the reactor vessel." Residual Heat Removal Pump C (1E12-CO02C)

RHR Pump C operates within the C RHR Loop to provide the Low Pressure Coolant Injection (LPCI) function only. In the LPCI mode, RHR Pump C provides water from the Suppression Pool to the reactor vessel to cover the core.* Low Pressure Core Spray Pump (E21-CO01)

The LPCS Pump delivers water over the core at relatively low reactor pressures.

The LPCS Pump provides inventory makeup and spray cooling following a large break or inventory makeup following a small break and ADS initiation." High Pressure Core Spray Pump (E22-CO01)

The HPCS Pump delivers water to the core over the entire range of system operating pressures.

The HPCS Pump provides inventory makeup following a small break or inventory makeup and spray cooling following a large break." Reactor Core Isolation Cooling Pump (1E51-CO01 The RCIC pump assures that sufficient reactor water inventory is maintained in the reactor vessel to permit adequate core cooling to take place under isolated reactor vessel and/or loss of feedwater conditions

• HPCS Emergency Service Water Pump (IP45-C002)

The HPCS ESW Pump provides a reliable source of cooling water to the HPCS Diesel Generator heat exchanger and the HPCS room cooler. The pump has only one (1) mode of operation and that is to support the HPCS (Division 3)2.1-3 Rev. 13 Diesel Generator Hx and HPCS Pump Room Cooler. Therefore, the pump is only started and ran for testing of itself, as a support system to the diesel testing, and as a support system for HPCS pump testing.Diesel Fuel Oil Transfer Pumps Div. 1, 2 & 3 (IR45-CO01A, B, C and IR45-CO02A, B & C)The purpose of the Fuel Oil Transfer Pumps is to transfer fuel oil from the main storage tanks to the day tanks to support long term engine operation during accident conditions.

NOTE: PNPP has requested the use of Code Case OMN-18 via Relief Request PR-3. If approved, those pumps that can be tested to within +/- 20% of design flow during the quarterly pump tests will not receive a biennial Comprehensive Pump Test (CPT). The pumps will continue to be tested on a quarterly frequency using instrumentation that satisfies the accuracy requirements for Comprehensive or Preservice pump testing as specified in Table ISTB-3500-1.

Pumps that otherwise satisfy the requirements for Group B classification shall be tested commensurate with Group A test requirements and categorized as Group AB pumps. A biennial Comprehensive test shall not be performed.

2.1.3 Pump Program Tables The tables in Section 2.3 list all pumps included in the PNPP IST Program. Data contained in these tables identifies those pumps subject to inservice testing, the inservice test quantities to be measured, the inservice testing frequency, and any applicable remarks. The column headings are listed and explained below: PUMP IDENTIFICATION

1. SYSTEM/GROUP:

The system of which the pump is a component and the Group category of the pump(s).2. PUMP NUMBER: The pump SAP Functional Location number.3. TEST INST. NO.: The Surveillance Instruction (SVI) or Periodic Test Instruction (PTI) number in which the Inservice Pump Test is accomplished.

4. ISI CLASS: The ISI safety classification (i.e., 1, 2, 3 or Optional) of the pump.5. FREQ.: The frequency is the periodicity in which pump test must be accomplished.

6. MEASURED PARAMETERS:

The parameters to be measured during the Quarterly and CPT Inservice Pump Tests.2.1-4 Rev. 13 IST REQUIREMENTS

-PUMP SPEED, DIFFERENTIAL PRESSURE, DISCHARGE PRESSURE, FLOW RATE, VIBRATION:

When the symbol "X" appears in a particular measured parameter column, that quantity will be measured during inservice testing in accordance with the OM Code. If a modified test is planned or a test is being waived, a number, which refers to a Pump Test Table Note (Section 2.3.3), shall appear in the measured parameter column. Requests for relief are identified with the letter "PR" under the measured parameter column in the test tables.2.1.4 Measurement of Test Parameters SPEED: Per ISTB-5121(a), 5122(a) and 5123(a), the pump shall be operated at nominal motor speed for constant speed drives and at a speed adjusted to the reference point (+/-1%) for variable speed drives.DIFFERENTIAL PRESSURE:

Per ISTB-3520(b), differential pressure will be determined by calculating the difference between suction and discharge pressure measurements or by direct differential pressure measurement.

Where differential is not directly determined (i.e., suction pressure or suction lift calculated from suction bay level), the method is described in Section 2.4.DISCHARGE PRESSURE:

Per Table ISTB-5300-2, discharge pressure will be measured in lieu of differential pressure for positive displacement pumps. Per Table ISTB-5300-2, discharge pressure is not required to be measured for positive displacement pumps during the Group B pump test.FLOW RATE: Per ISTB-3550, flow rate will be measured using a flow rate meter installed in or on the hydraulic circuit.Where flow rate is not directly measured (i.e., flow rate calculated from flow orifice dP measurement), the method is described in Section 2.4. External recirculated flow is not required to be measured if it is not practical to isolate, has a fixed resistance, and has been evaluated to not have a substantial effect on the results of the test.NOTE: Per Tables ISTB-5100-1, 5200-1 and 5300-2, vibration measurement is not required during the Group B pump test, but is required during the Group A test and Comprehensive pump test.VIBRATION:

Pump vibration will be measured at the locations described below, dependent upon the type of pump. Pump vibration measurements will be in units of velocity (inches per second), unless otherwise noted in the table. The vibration measurement locations are permanently marked on the pump/motor with a "V", "Vlf ....H ....HI", "A" or "Al".2.1-5 Rev. 13 Centrifugal Pumps: Per ISTB-3540(a), measurements shall be taken in a plane approximately perpendicular to the rotating shaft in two approximately orthogonal directions on each accessible pump bearing housing, and in the axial direction on each accessible pump thrust bearing housing.Vertical Line Shaft Pumps: Per ISTB-3540(b), measurements shall be taken on the upper motor bearing housing in three approximately orthogonal directions, one of which is the axial direction.

Reciprocating Pumps: Per ISTB-3540(c), measurements shall be taken on the bearing housing of the crankshaft, approximately perpendicular to both the crankshaft and the line of plunger travel.2.1.5 Allowable Ranges for Test Parameters The allowable ranges specified in Tables ISTB-5100-1, 5200-1 or 5300-2, as appropriate, will be used. Should a measured test quantity fall outside the allowable range, action will be taken in accordance with ISTB-6200.

2.1.6 Instrument

Accuracy Allowable instrument accuracies are given in Table ISTB-3500-1, Required Instrument Accuracy.

If the accuracies of the plant installed instruments are not acceptable, temporary instruments meeting the requirements of Table ISTB-3500-1 will be used.When determining differential pressure by calculating the difference between individual suction and discharge pressure measurements, the range and accuracy of an individual instrument may be greater than allowed as long as the overall determination of differential pressure can be shown to be better than the Code required accuracy.

Digital instruments may be selected such that the reference value does not exceed 90% of the calibrated range per Code Case OMN-6 (Refer to relief request PR-2).2.1.7 Pump Test Descriptions Descriptions of pump testing hydraulic circuits, testing methods, and specific instrumentation are given in Section 2.4.The descriptions state which measured parameter is the fixed reference value (flow rate, differential pressure, or discharge pressure) and its value. Calculation methods for any parameters not determined directly are also included.

Any cases where individual pressure instruments do not meet accuracy requirements, but the overall differential pressure determination is acceptable, are justified within the instrumentation descriptions.

2.1-6 Rev. 13 2.1.8 Pump Surveillance Test Review All test data shall be analyzed within a reasonable period of time after completion of test. This analysis is satisfied by the Unit Supervisor's signature on the Perry Plant Work Order Surveillance Sheet or the Data Package Cover Sheet upon completion of the pump surveillance test. This analysis is acceptable since all required acceptance criteria is available within each individual pump surveillance test. Further analysis will be performed by the Inservice Test Program Owner or his alternate within a reasonable time following the Unit Supervisor review, generally within 5 to 7 working days.2.1-7 Rev. 13

2.2 Relief

Requests for the Pump Inservice Testinq Proqram Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number PR-I, Rev 0 Page 1 of 2 Proposed Alternative in Accordance with 10 CFR 50.55a(a)(3)(i)

--Alternative Provides Acceptable Level of Quality and Safety--1. ASME Code Component(s)

Affected IE12-C003, RHR Waterleg Pump (Class 2)IE21-C002, LPCS Waterleg Pump (Class 2)IE22-C003, HPCS Waterleg Pump (Class 2)1E51-C003, RCIC Waterleg Pump (Class 2)Waterleg pumps maintain the discharge piping of safety-related systems full to expedite flow during initiation, and minimize the likelihood of system damage due to water hammer.2. Applicable Code Edition and Addenda ASME OM Code-2001, with Addenda through OMb-2003 3. Applicable Code Requirements ISTB-3400; Frequency of Inservice Tests. An inservice test shall be run on each pump as specified in Table ISTB-3400-1.

Table ISTB-03400-1 specifies that a Group A pump test shall be performed on a quarterly frequency.

ISTB-3300(e)

(2); Reference values shall be established within +/- 20% of pump design flow for a Group A test, if practicable.

If not practicable, the reference point flow rate shall be established at the highest practical flow rate.4. Reason for Request The waterleg pumps are designed to remain in service during operation at power to ensure the emergency standby systems are maintained pressurized to reduce the likelihood of water hammer. The waterleg pumps run continuously, with flow established through a recirculation line, in order to provide enough head to keep the applicable systems discharge piping full to the highest elevation.

During safety-related pump testing, the waterleg pump normal discharge path must be redirected through drain lines to provide enough flow to establish the selected code reference values. This requires taking the system out of service and racking out safety-related pump breakers for the Residual Heat Removal (RHR) system, the Low Pressure Core Spray (LPCS)system, and the High Pressure Core Spray (HPCS) system, or isolating the Reactor Core Isolation Cooling (RCIC) system pump to prevent system damage due to water hammer or cavitation upon receipt of an auto actuation signal.2.2-1 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number PR-l, Rev 0 Page 2 of 2 Quarterly full flow testing of the listed safety-related waterleg pumps would result in the inoperability of its associated Emergency Core Cooling System without a compensating increase in the level of quality or safety.5. Proposed Alternative and Basis for Use The waterleg pumps shall be monitored on a quarterly basis by observing pump discharge pressure and bearing vibration.

These parameters will be evaluated to adequately assess the pump's performance.

The pumps will be full flow tested each refueling outage in conjunction with the comprehensive pump test performed in accordance with the requirements specified in ISTB-5123 Comprehensive Test Procedure.

All of these pumps have adequate margin beyond the capacity required for them to fulfill their function.

Using the provisions of this relief request as an alternative to the requirements of ISTB-3400 and ISTB-3300(e)

(2) provides a reasonable alternative to the code requirements.

The proposed alternative provides an acceptable level of quality and safety for monitoring the pumps and assuring that the pumps are capable of performing their safety function.6. Duration of Proposed Alternative The proposed alternative identified in this relief request shall be utilized during the Third Ten-Year IST Interval.7. Precedent Perry Nuclear Power Plant, Docket No. 50-440, Safety Evaluation Report (SER) dated August 9, 1999, "Safety Evaluation of the Inservice Testing Program Second Ten-Year Interval for Pumps and Valves -Perry Nuclear Power Plant, (TAC No. MA3328)." Previously approved as PR-2 in the aforementioned SER. Refer to Attachment 2, Technical Evaluation Report, Section 2.2.8. Reference Generic Letter 89-04, "Guidance on Developing Acceptable Inservice Testing Programs," Attachment 1, Position 9, "Pump Testing using Minimum-flow Return Line With or Without Flow Measuring Devices." 2.2-2 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number PR-2, Rev 0 Page 1 of 2 Proposed Alternative in Accordance with 10 CFR 50.55a(a)

(3) (i)--Alternative Provides Acceptable Level of Quality and Safety--1.ASME Code Component(s)

Affected IC41-C001A

& B, Standby Liquid Control Pumps (Class 2)1E12-C002A, B & C, Residual Heat Removal Pumps (RHR) (Class 2)1E12-C003, RHR Waterleg Pump (Class 2)IE21-C001, Low Pressure Core Spray Pump (LPCS) (Class 2)1E21-C002, LPCS Waterleg Pump (Class 2)1E22-C001, High Pressure Core Spray Pump (HPCS) (Class 2)IE22-C003, HPCS Waterleg Pump (Class 2)1E51-C001, Reactor Core Isolation Cooling Pump (RCIC) (Class 2)1E51-C003, RCIC Waterleg Pump (Class 2)G41-C003A

& B, Fuel Pool Cooling and Cleanup Pumps (Class 3)1P42-C001A

& B, Emergency Closed Cooling Pumps Class 3)1P45-C001A

& B and C002, Emergency Service Water Pumps (Class 3)P47-CO01A

& B, Control Complex Chilled Water Pumps (Class 3)1R45-C001A, B, C & C002A, B, C, Standby Diesel Generator Fuel Oil Pumps (Class 3)2.Applicable Code Edition and Addenda ASME OM Code-2001, with Addenda through OMb-2003 3.Avvlicable Code Requirements ISTA-3130, "Application of Code Cases," ISTA-3130(b) states, Code Cases shall be applicable to the edition and addenda specified in the test plan.ISTB-3510(b)

(2); Digital Instruments shall be selected such that the reference value does not exceed 70% of the calibrated range of the instrument.

2.2-3 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number PR-2, Rev 0 Page 2 of 2 4.Reason for Request The ASME Code committees have approved Code Case OMN-6, "Alternative Rules for Digital Instruments," which was included in the OMa-1999.The Nuclear Regulatory Commission has unconditionally approved the use of this code case as reflected in Regulatory Guide 1.192, "Operation and Maintenance Code Case Acceptability, ASME OM Code," June 2003.This code case allows owners to use digital instruments such that the reference value does not exceed 90% of the calibrated range of the instrument.

The Code of record for the Third Ten-Year Inservice Testing (IST) interval is OM Code-2001 Edition with Addenda through OMb-2003.

As stated in Regulatory Guide (RG) 1.192, the applicable Code for Code Case OMN-6 is OMa-1999.

Perry Nuclear Power Plant (PNPP) is requesting the use of Code Case OMN-6 because the applicable edition of the code is other than the code edition/addenda specified as the code of record for the Third Ten-Year Interval.5. Proposed Alternative and Basis for Use In lieu of the digital instruments requirements specified in ISTB-3510(b)

(2), PNPP proposes to utilize the alternative rules for digital instruments specified in Code Case OMN-6. Whereas, digital instruments shall be selected such that the reference value does not exceed 90% the calibrated range of the instrument.

Using the provisions of this relief request as an alternative to the requirements of ISTB-3510(b)

(2) provides a reasonable alternative to the code requirements based on the determination that the proposed alternative provides an acceptable level of quality and safety as recognized by RG 1.192.6. Duration of Proposed Alternative The proposed alternative identified in this relief request shall be utilized during the Third Ten-Year IST Interval.7. Precedent Perry Nuclear Power Plant, Docket No. 50-440, Safety Evaluation Report (SER) dated March 31, 1999, Safety Evaluation of the Inservice Testing Program Relief Requests for the Second Ten-Year Interval -Perry Nuclear Power Plant, (TAC No. MA3328). Previously approved as PR-6 in the aforementioned SEP.Regulatory Guide 1.192, "Operation and Maintenance Code Case Acceptability, ASME OM Code", June 2003, Table 1, "Acceptable OM Code Cases." 8. Reference Code Case OMN-6, Alternative Rules for Digital Instruments.

2.2-4 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number PR-3, Rev 0 Page 1 of 3 Proposed Alternative in Accordance with 10 CFR 50.55a(a)

(3) (i)--Alternative Provides Acceptable Level of Quality and Safety--1. ASME Code Component(s)

Affected Pumps Code Class 1C41-C001A

& B, Standby Liquid Control 2 1E12-C002A, B, & C, Residual Heat Removal 2 IE21-CO01, Low Pressure Core Spray 2 IE22-CO01, High Pressure Core Spray (HPCS) 2 1E51-C001, Reactor Core Isolation Cooling 2 G41-C003A

& B, Fuel Pool Cooling and Cleanup 3 1P42-C001A

& B, Emergency Closed Cooling Water 3 1P45-C001A

& B, Emergency Service Water 3 1P45-C002, HPCS Emergency Service Water 3 P47-CO01A

& B, Control Complex Chilled Water 3 1R45-C001A, B, & C, Fuel Oil Transfer #1 3 1R45-C002A, B, & C, Fuel Oil Transfer #2 3 2. Applicable Code Edition and Addenda ASME OM Code-2001, with Addenda through OMb-2003 3. Applicable Code Requirements ISTB-2000 defines operating criteria for designating Group A and Group B pumps.ISTB-3000, "General Testing Requirements" and Table ISTB-3000-1,"Inservice Test Parameters," define and compare parameters (e.g., pressure, flow rate, vibration) measured during Group A, Group B, and Comprehensive Tests.ISTB-3400, "Frequency of Inservice Tests," states that an inservice test shall be run on each pump as specified in Table ISTB-3400-1.

This table requires a Group A or Group B Test to be performed quarterly and a Comprehensive Test to be performed biennially.

Table ISTB-3500-1 defines the required instrument accuracy for Group A, Group B, and Comprehensive Tests.Table ISTB-5100-1 defines the required acceptance criteria for Group A, Group B, and Comprehensive Tests (Centrifugal Pumps).Table ISTB-5200-1 defines the required acceptance criteria for Group A, Group B, and Comprehensive Tests (Vertical Line Shaft Pumps).Table ISTB-5300-2 defines the required acceptance criteria for Group A, Group B, and Comprehensive Tests (Reciprocating Positive Displacement Pumps).2.2-5 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number PR-3, Rev 0 Page 2 of 3 4. Reason for Request The ASME OM Code Committee has established Code Case OMN-18,"Alternate Testing Requirements for Pumps Tested Quarterly within+/- 20% of Design Flow." This code case has not yet been approved for use in Regulatory Guide (RG) 1.192, "Operation and Maintenance Code Case Acceptability, ASME OM Code," June 2003. Although Code Case OMN-18 has not been approved for use, FENOC is proposing this alternative for Group A (and Group B re-classified as Group A) pumps.The increased requirements imposed by the proposed alternative on the parameters to be monitored during every quarterly pump test and the more accurate instruments that must consistently be used during quarterly testing of pumps classified as Group A (and Group B pumps that are re-classified as Group A pumps), allows FENOC to perform better trending of pump performance data due to the more consistent requirements for each of the quarterly tests.Due to the increased requirements on the parameters imposed by the proposed alternative during all quarterly tests there is no added value in performing the biennial Comprehensive Test.5. Proposed Alternative and Basis for Use FENOC proposes that in lieu of the requirements of ISTB-3400, Group A tests will be performed quarterly within +/-20 percent of the pump design flow rate, with instrumentation meeting the instrument accuracy requirements of Table ISTB-3500-1 for the biennial Comprehensive Test, and the Comprehensive Test would not be required.Specifically, a. Pumps tested quarterly using this alternative must be tested within+/-20 percent of pump design flow, as is required for the biennial Comprehensive Test in ISTB-3300(e) and (f).b. The proposed alternative requires the accuracy of instruments used during quarterly Group A tests to meet the more accurate pressure and differential pressure requirements listed for the Comprehensive Test in Table ISTB-3500-1 (an accuracy improvement from +/- 2 percent to +/- 1/2 percent).

Consistent use of these more accurate instruments during each quarterly test provides for improved Group A pump performance trend data evaluation.

c. Pumps that would normally be categorized as Group B pumps, but are re-categorized as Group A, may be tested according to the provisions of this alternative.

As a result of this re-categorization from Group B to Group A, per Table ISTB-3000-1, additional data must be obtained quarterly rather than once every two years on the test parameters of Discharge pressure (for the Standby Liquid Control positive displacement pumps), and Vibration (for all the affected pumps).2.2-6 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number PR-3, Rev 0 Page 3 of 3 d. Use of this alternative provides for consistent acceptance criteria for pump flow and differential pressure tests. FENOC will consistently utilize the Group A Test acceptance criteria in Tables ISTB-5100-1, ISTB-5200-1, and ISTB-5300-2 for pump tests rather than having to utilize the Comprehensive Test criterion for one biennial test.The provisions of this request, as an alternative to the requirements of ISTB-3400, provide a reasonable alternative to the code requirements.

The proposed alternative provides an acceptable level of quality and safety for monitoring the pumps and ensures they are capable of performing their safety function.6. Duration of Proposed Alternative The proposed alternative identified in this request shall be utilized during the Third Ten-Year IST Interval beginning May 18, 2009, or until the NRC publishes a new revision of RG 1.192 that approves Code Case OMN-18, whichever comes first.7. Precedence None 8. Reference Code Case OMN-18, "Alternate Testing Requirements for Pumps Tested Quarterly within +/- 20% of Design Flow" 2.2-7 Rev. 13 2.3 Pump Testing System Index and Test Tables 2.3.1 Pump Testing System Index System Dwg. No.Standby Liquid Control D-302-691 (C41)Standby Liquid Control D-302-692 Transfer (C41)Residual Heat Removal D-302-641 (E12) D-302-643 Low Pressure Core Spray (E21)High Pressure Core Spray (E22)Reactor Core Isolation Cooling (E51)Fuel Pool Cooling and Cleanup (G41)Emergency Closed Cooling Water (P42)Emergency Service Water (P45)Control Complex Chilled Water (P47)ESW Screen Wash (P49)Standby D.G. Fuel Oil (R45)D-302-705 D-302-701 D-302-631 D-302-654 D-302-621 D-302-791 D-913-001 D-302-214 D-302-352 D-302-356 Pump MPL IC41-C001A 1C41-C001B C41-C002A C41-C002B 1E12-C002A 1E12-C002B 1E12-C002C 1E12-C003 1E21-C001 1E21-C002 1E22-C001 1E22-C003 IE51-C001 IE51-C0O03 G41-C003A G41-CO03B 1P42-C001A 1P42-C001B 1P45-C001A 1P45-C001B 1P45-C002 P47-CO01A P47-CO01B P49-CO02A P49-CO02B 1R45-C001A 1R45-C002A IR45-C001B 1R45-C002B 1R45-C001C 1R45-C002C Coordinate D-8 G-8 F-7 F-9 K-5 J-12 H-12 G-10 G-5 F-9 F-12 H-10 C-4 F-5 G-12 H-12 E-12 G-12 G-14 G-I1 G-9 B-5 G-5 C-12 G-12 F-il F-9 F-5 F-3 F-5 F-4 2.3-1 Rev. 13 2.3.2 Pump Test Table Nomenclature The following abbreviations have been used in the Pump Test Table.N = Rotative Speed Pdiff = Differential Pressure Across Pump Pdisch = Pump Discharge Pressure PR = Relief Request Q = Quarterly.

2Y = 2 Years (Biennially)

Qf = Flow Rate RO = Refueling Outage V = Vibration Velocity (unless otherwise noted)X = Measurement/Observation Per OM Code ISTB 2.3-2 Rev. 13 2.3.3 Pump Test Table Quarterly Group A, Group B and Group AB Pump Tests PUMP LISTING MEASURED PARAMETERS SYSTEM PUMP MPL Group INST. NO. CLASS FREQ. N Pdif Pdisch Qf V I f Standby Liquid Control Standby Liquid Control Transfer (1)Residual Heat Removal Low Pressure Core Spray High Pressure Core Spray Reactor Core Isolation Cooling Fuel Pool Cooling and Cleanup Emergency Closed Cooling Water Emergency Service Water 1C41-C001A 1C41-C001B C41-CO02A C41-CO02B 1E12-C002A 1E12-C002B 1E12-C002C 1E12-C003 IE21-CO01 1E21-C002 1E22-C001 1E22-C003 1E51-C001 1E51-C003 G41-C003A G41-C003B 1P42-C001A IP42-CO01B 1P45-C001A 1P45-C001B 1P45-C002 AB SVI-C41-T2001A AB SVI-C41-T2001B N/A PTI-C41-POO01 N/A PTI-C41-POO01 A A AB A AB A AB A SVI-E12-T2001 SVI-E12-T2002 SVI-E12-T2003 SVI-GEN-T2002 SVI-E21-T2001 SVI-GEN-T2002 SVI-E22-T2001 SVI-GEN-T2002 2 2 03 03 2 2 2 2 2 2 2 2 2 2 3 3 3 3 3 3 3 Q Q 24M (1)24M (1)Q Q Q Q (2)Q Q (2)Q Q (2)Q Q (2)Q Q Q Q Q Q Q (1)(1)(1)(1)X(3) (4)X(3) (4)x x X (4)X (4)X (4)X(4)X(4)x x x x x x x x x x x (1)(1)x x x x x x x x x x x x x x x x x AB SVI-E51-T2001 A SVI-GEN-T2002 X X(4)X (5)A A A A A A AB SVI-G41-T2001 SVI-G41-T2001 SVI-P42-T2001A SVI-P42-T2001B SVI-P45-T2001 SVI-P45-T2002 SVI-P45-T2003 X (4)X (4)X (4)X (4)X (4)X (4)X (4)x x x x x x x 2.3-3 Rev. 13 2.3.3 Pump Test Table (Continued)

Quarterly Group A, Group B and Group AB Pump Tests PUMP LISTING MEASURED PARAMETERS SYSTEM PUMP MPL Group INST. NO. CLASS FREQ. N Pdiff Pdisch Qf V Control Complex Chilled P47-CO01A A SVI-P47-T2001A 3 Q X(4) X X Water P47-COOIB A SVI-P47-T2001B 3 Q X(4) X X Emergency Service Water P49-CO02A N/A PTI-P49-P0001 03 18M (1) (1) (1) (1)Screen Wash (1) P49-CO02B N/A PTI-P49-POO01 03 18M (1) (1) (1) (1)Standby Diesel Generator lR45-C001A AB SVI-R45-T2001 3 Q X(4) X X Fuel Oil 1R45-C002A AB SVI-R45-T2001 3 Q X(4) X X lR45-C001B AB SVI-R45-T2002 3 Q X(4) X X lR45-C002B AB SVI-R45-T2002 3 Q X(4) X X 1R45-C001C AB SVI-R45-T2003 3 Q X(4) X X IR45-CO02C AB SVI-R45-T2003 3 Q X(4) X X Biennnnial Comprehensive Pump Tests PUMP LISTING MEASURED PARAMETERS SYSTEM PUMP MPL Group INST. NO. CLASS FREQ. N Pdiff Pdisch Qf V Residual Heat Removal Water Leg Pump Low Pressure Core Spray Water Leg Pump High Pressure Core Spray Water Leg Pump Reactor Core Isolation Cooling Water Leg Pump IE12-C003 1E21-C002 1E22-C003 1E51-C003 A SVI-El2-T2023 A SVI-E21-T2004 A SVI-E22-T2002 A SVI-E51-T2003 2 RO (2)2 RO (2)2 RO (2)2 RO (2)X X X X X X X X x x x X 2.3-4 Rev. 13 2.3.3 Pump Test Table (Continued)

NOTE 1: The SLC Transfer pumps and ESW Screen Wash pumps are tested to satisfy requirements other than Technical Specification 5.5.6, "Inservice Testing Program." Where the requirements of the OM Code are determined to be impractical for these pumps, alternatives may be employed without prior approval.

In addition, a Comprehensive pump test will not be performed.

NOTE 2: Full flow Inservice testing of the waterleg pumps will be performed in conjunction with the Comprehensive pump test during refueling outages in accordance with PR-i. These pumps shall have their discharge pressure and vibration monitored quarterly (SVI-GEN-T2002).

NOTE 3: When performing the quarterly Group AB test on the SLC pumps, discharge pressure is the fixed parameter.

It is not identified in Table ISTB-5300-2 as a measured parameter.

NOTE 4: Measurements shall be acquired to satisfy the alternative test requirements of Code Case OMN-18 as addressed by relief request PR-3, pending NRC approval.NOTE 5: 1E51-CO01

'Reactor Core Isolation Cooling Pump' circuit has external recirculation flow through its lube oil cooler. Per ISTB-3550 the following has been evaluated:

1) This line is not practical to isolate due to the need for cooling water flow to the lube oil cooler. 2) This line contains a restricting orifice (IE51-D0012) with a fixed minimum flow rate of 16 gpm per calculation E51-25. and 3) This flow does not have a substantial effect on the test results as it equates to only 2.29% of the flow (16 gpm/700 gpm) X 100).2.3-5 Rev. 13

2.4 Hydraulic

Circuits, Test Methods, and Instrumentation Standby Liquid Control (SLC) Injection Pumps (Pump Group: AB)MPL Nos.: IC41-C001A, 1C41-C001B Pump Type: reciprocating-type positive displacement Hydraulic Circuit and Test Procedure:

The hydraulic circuits for inservice testing of the SLC pumps have a suction from the common suction line off of the SLC Test Tank, IC41-A002.

Pump discharges are directed through a common test return line back to the test tank. Reference conditions are established by throttling a valve in the common test return line. Discharge pressure is set to 1220 psig with flow rate being the variable parameter.

Vibration velocity measurements (pump speed < 600 rpm) are taken in the vertical direction (crankshaft and plunger travel direction are in the horizontal plane) on the inboard and outboard pump bearings.Instrumentation:

The instrumentation used is common to both pump tests.Discharge pressure is measured with a temporary M&TE gauge installed on the common discharge line. A permanently mounted flow meter located in the common discharge line is used to measure flow.1C41-CO01A and IC41-CO01B:

Parameter Flow Rate Discharge Pressure MPL No. I1C41-R700 Temporary Location C-654-265 C-654-265 Elevation NA 655 Reference Values 43 gpm (variable) 1220 psig (fixed)2.4-1 Rev. 13 Standby Liquid Control (SLC) Transfer Pumps (Pump Group N/A)MPL Nos.: C41-CO02A, C41-CO02B Pump Type: centrifugal Hydraulic Circuit and Test Procedure:

The test loops for both pumps take a suction off of a common suction line from the Auxiliary Mixing Tank, C41-A003.

The pump discharges are directed back to the Auxiliary Mixing Tank through a common return line. Valves in the return line are used to throttle flow until the pump dP is 33 psid. Flow is then measured with a temporary flowmeter.

Vibration velocity measurements are taken in the horizontal, vertical and axial directions on the pump bearing housing. Since these pumps are outside the scope on the OM Code, a Comprehensive pump test will not be performed.

The pumps are tested as Augmented components.

Instrumentation:

Pump differential pressure is determined with individual pump suction and discharge pressure measurements.

A temporary M&TE gauge on the common suction line is used to measure suction pressure for both pump tests. Temporary M&TE gauges are installed at the discharge of each pump to measure discharge pressure.

Flow is measured with an external clamp-on flowmeter located on the common portion of the return line.C41-C002A and C41-C002B:

Parameter Flow Rate Suct. Press. Disch. Press.MPL No. Temporary Temporary Temporary Location IBI/05-620 IBI/06-620 IBI/05-620 Elevation NA 624 624 Reference Value 41.1 A -gpm (variable) 33 psid (fixed)41.9 B -gpm (variable) 33 psid (fixed)2.4-2 Rev. 13 Residual Heat Removal (RHR) Pumps (Pump Group A (CO02A&B), AB (C002C))MPL Nos.: lEI2-CO02A, 1E12-C002B, 1E12-C002C Pump Type: vertical line shaft IST Hydraulic Circuit and Test Procedure:

The suction paths for the RHR pump hydraulic circuits are through individual suction lines from the suppression pool.The return paths for inservice testing of 1E12-C002A and 1E12-C002B are through their respective heat exchangers and test lines back to the suppression pool. Heat exchanger outlet valves are used to throttle flow for these two pumps. The pump discharge for IE12-C002C is routed directly back to the suppression pool through its test line. In this case a valve in the test line is used to throttle flow. Flow rate is set at 7100 to 7110 gpm (3.84 to 3.844 VDC) for all three pumps.Vibration velocity readings are taken in three orthogonal directions on the upper motor bearing housing.Instrumentation:

Instrumentation for the three test circuits is similar.Differential pressure is determined by calculating the difference between suction and discharge pressure.

Temporary M&TE gauges are installed to measure the suction and discharge pressures.

Flow rate is monitored using permanent plant flow instrumentation and the integrated computer system (ICS).1E12-CO02A:

Parameter Flow Rate

• Suct. Press. Disch. Press.MPL No. E12EA005 Temporary Temporary Location ICS AXC/07-574 AXC/07-574 Elevation NA 571 571 Reference Value 7100 gpm (fixed) 152.8 psid (Var)* -E12EA005 is averaged for use of smoothed point E12S0005.A DMM may be used in lieu of ICS point if unavailable.

1E12-C002B:

Parameter Flow Rate

• Suct. Press. Disch. Press.MPL No. E12EA006 Temporary Temporary Location ICS AXC/03-574 AXC/03-574 Elevation NA 571 571 Reference Value 7100 gpm (fixed) 148.2 psid (Var)* -E12EA006 is averaged for use of smoothed point E12S0006.A DMM may be used in lieu of ICS point if unavailable.

IE12-C002C:

Parameter Flow Rate

• Suct. Press. Disch. Press.MPL No. E12EA007 Temporary Temporary Location ICS AXC/05-574 AXC/05-574 Elevation NA 571 571 Reference Value 7100 gpm (fixed) 142.45 psid (Var)* -E12EA007 is averaged for use of smoothed point E12S0007.A DMM may be used in lieu of ICS point if unavailable.

2.4-3 Rev. 13 Low Pressure Core Spray (LPCS) Pump (Pump Group AB)MPL No.: 1E21-CO01 Pump Type: vertical line shaft IST Hydraulic Circuit and Test Procedure:

The LPCS pump test loop suction path is from the suppression pool. The pump discharge is returned to the suppression pool through a test line. A valve in the test line is used to throttle flow until pump differential pressure is equal to 311 +/-1 psid (3.522 VDC). Flow rate and vibration measurements are then taken after stabilization.

Vibration velocity readings are taken in three orthogonal directions on the upper motor bearing housing.Instrumentation:

Differential pressure is determined from individual suction and discharge pressure measurements.

Temporary M&TE gauges are installed to measure suction and discharge pressures.

Flow rate is monitored using permanent plant flow instrumentation and the integrated computer system (ICS).1E21-CO01:

Parameter Flow Rate

• Suct. Press. Disch. Press.MPL No. E21EA001 Temporary Temporary Location ICS AXC/08-568 AXC/08-568 Elevation NA 572 572 I Reference* -A DMM Value may be 6305 gpm (Var)used in lieu of 311 psid (Fixed)unavailable.

11 ICS point if 2.4-4 Rev. 13 HiQh Pressure Core Sprav (HPCS) Pump (Pump Group AB)MPL No.: 1E22-C001 Pump Type: vertical line shaft IST Hydraulic Circuit and Test Procedure:

The hydraulic circuit for HPCS pump testing has a suction from either the suppression pool or the condensate storage tank.Pump discharge is routed back to the suction source through test lines. Valves in the test lines are used to vary system resistance.

Flow rate is set at 6110 to 6140 gpm (3.444 to 3.456 VDC). Vibration velocity readings are taken in three orthogonal directions on the upper motor bearing housing.Instrumentation:

Differential pressure is determined from individual suction and discharge pressure measurements.

Temporary M&TE gauges are installed to measure suction and discharge pressures.

Flow rate is monitored using permanent plant flow instrumentation and the integrated computer system (ICS).1522-CO0l:

IE22-C001:

Parameter Flow Rate

• Suct. Press. Disch. Press.MPL No. E22EA001 Temporary Temporary Location ICS AXC/02-574 AXC/03-568 Elevation NA 572 572 Reference Value 6110 gpm (Fixed) 517.7 psid (Var)I* -E22EA001 is averaged for use A DMM may be used in lieu of of smoothed point E22EF001.ICS point if unavailable.

2.4-5 Rev. 13 Reactor Core Isolation Cooling (RCIC) Pump (Pump Group AB)MPL No.: 1E51-C001 Pump Type: centrifugal with variable speed drive (steam turbine)IST Hydraulic Circuit and Test Procedure:

The RCIC pump suction for inservice testing is from the condensate storage tank. Pump discharge is routed back to the condensate storage tank through a test line. Flow is throttled with a valve in the test line to obtain 700 +5-0 gpm @4400 +/-10 rpm. Vibration velocity is measured in the horizontal and vertical directions on the inboard bearing and outboard pump bearings, and in the axial direction on the outboard (thrust) bearing.Instrumentation:

Differential pressure is determined by calculating the difference between suction and discharge pressures.

Suction pressure is measured with a temporary M&TE gauge. Discharge pressure and flow rate are monitored using permanent plant instrumentation and the integrated computer system (ICS).Turbine (pump) speed is also monitored with permanent plant instrumentation, with readings taken from an indicator on a control room panel.1E51-C001:

Parameter Flow Rate Suct. Press. Disch. Press. Pump Speed *MPL No. E51EA004 Temporary Temporary IE51-R607 Location ICS AXB/05-574 AXB/05-574 1H13-P601 Elevation NA 572 572 NA Reference Value 700 gpm 1211 psid 4400 rpm (Fixed) (Var) (Fixed)* A calibrated strobe light is used in conjunction with IE51-R607.

2.4-6 Rev. 13 Waterleq Pumps (Pump Group A)MPL Nos.: lE12-C003, lE21-C002, lE22-C003, lE51-C003 Pump Type: centrifugal IST Hydraulic Circuit and Test Procedure:

The waterleg pumps take a suction off of the main suction line for their associated ECCS pump. Approximately 10 gpm is returned to the main pump suction through a recirculation line.In order to create enough additional flow to achieve the IST reference values for each pump, flow is directed through temporary hoses from vents, drains, and test connections.

This requires the main pump breakers to be opened (RHR, LPCS, and HPCS) or the pump discharge to be isolated (RCIC) since the pump discharge headers are no longer assured to be full. Flow rate is measured in the waterleg pump suction line such that recirculation flow is included in the measured flow rate.Flow through the temporary hoses is throttled until the reference flow rate is set as follows: IE12-C003:

37.2 gpm (2.80 to 2.81 VDC)IE21-C002:

41.0 gpm (3.10 to 3.11 VDC)IE22-C003:

32.4 gpm (2.32 to 2.33 VDC)1E51-C003:

41.5 gpm (3.15 to 3.16 VDC)Vibration velocity measurements are then taken in the horizontal, vertical and axial directions on the pump housing.Testing as described above is performed during refueling outages in conjunction with the Comprehensive Pump Test (CPT).Discharge pressure and vibration measurements are taken during the quarterly Group A test with the pumps in normal operation (approximately 10 gpm of recirculation flow) in accordance with relief request PR-l.Instrumentation:

Differential pressure is determined by calculating the difference between the suction and discharge pressures.

Suction and discharge pressures are measured using temporary M&TE gauges as described below. Flow rates are determined by measuring the dP across an orifice in the waterleg pump suction line with a temporary dP transmitter, then converting the dP to flow.2.4-7 Rev. 13 Waterleq Pumps (Cont.)1E12-C003:

Parameter Flow Rate Suct. Press. Disch. Press.MPL No. Temp. dP Xmtr

• Temporary Temporary Location AXB/02-574 AXB/04-574 AXB/04-574 Elevation NA 574 574 Reference Value 37.2 gpm (Fixed) 33 psid (Var)* -With resistor box and DMM 1E21-C002:

Parameter Flow Rate Suct. Press. Disch. Press.MPL No. Temp. dP Xmtr

• Temporary Temporary Location AXC/07-574 AXC/07-574 AXC/07-574 Elevation NA 574 574 Reference Value 41.0 gpm (Fixed) 35 psid (Var)* -With resistor box and DMM 1E22-C003:

Parameter Flow Rate Suct. Press. Disch. Press.MPL No. Temp. dP Xmtr

• Temporary Temporary Location AXC/02-574 AXC/02-574 AXC/02-574 Elevation NA 576 576 Reference Value 32.4 gpm (Fixed) 33.5 psid (Var)* -With resistor box and DMM 1E51-C003:

Parameter Flow Rate Suct. Press. Disch. Press.MPL No. Temp. dP Xmtr

• Temporary Temporary Location AXB/06-574 AXB/06-574 AXB/06-574 Elevation NA 576 576 Reference Value 41.5 gpm (Fixed) 33 psid (Var)* -With resistor box and DMM I 2.4-8 Rev. 13 Fuel Pool Cooling and Cleanup Pumps (Pump Group A)MPL Nos.: G41-C003A, G41-C003B Pump Type: centrifugal IST Hydraulic Circuit and Test Procedure:

The normal suction and discharge lines are used for inservice testing of the fuel pool cooling and cleanup pumps. For testing purposes the filter/demineralizers are bypassed and the full test flow rate goes through the filter/demineralizer bypass line. The flow rate is set at 1400-1410 gpm (4.733 to 4.760) by using a valve in the bypass line. Vibration velocity is measured in the horizontal and vertical directions for the inboard and outboard pump bearings, and in the axial direction for the outboard (thrust) bearing.Instrumentation:

Pump differential pressure is determined using individual suction and discharge pressure gauges. Suction pressures are measured with temporary M&TE gauges installed on each pump's suction line. Discharge pressure measurements utilize permanent plant instrumentation on the pump discharge lines.Flow rate is determined by measuring a voltage in the instrument loop for filter/demineralizer bypass flow, then converting the voltage to a flow rate.G41-C003A(B):

Parameter Flow Rate

• Suction Discharge Pressure Pressure MPL No. IG41-N076/K020 Temporary Temporary Location 1H13-P969B IBH/07-574 IBH/07-574 Elevation NA 577 577 Reference Value 1400 gpm -A (fixed) 119.4 psid (Var)1 1400 gpm -B (Fixed) 118.0 psid (Var)* Listed instruments with DMM 2.4-9 Rev. 13 Emergency Closed Cooling Water (ECC) Pumps (Pump Group A)MPL Nos.: lP42-C0O01A, 1P42-C001B Pump Type: centrifugal IST Hydraulic Circuit and Test Procedure:

The hydraulic circuit for inservice testing of the ECC pumps uses the normal closed loop with the control complex chillers bypassed.

A valve in the bypass line is used to establish the reference flow rate of 2000 gpm (4.20 VDC). Vibration velocity measurements are taken in the horizontal and vertical planes on the inboard and outboard pump bearings.

Vibration velocity is also measured in the axial direction for the outboard (thrust)bearing.Instrumentation:

Differential pressure is the variable parameter and is determined with individual suction and discharge pressure gauges. Suction pressure measurements utilize permanent plant instrumentation on the pump suction lines. Discharge pressures are measured with temporary M&TE gauges installed on each pump's discharge line. Flow rate is monitored using permanent plant flow instrumentation and the integrated computer system (ICS).1P42-C0O01A:

Parameter Flow Rate Suction Discharge Pressure Pressure MPL No. P42EA001

• Temporary Temporary Location ICS CCB/03-574 CCD/03-574 Elevation NA 576 577 Reference Value 2000 gpm (Fixed) 64.5 psid (Var)* -A DMM may be used in lieu of ICS point if unavailable.

1P42-CO01B:

Parameter Flow Rate Suction Discharge Pressure Pressure MPL No. P42EA004

• Temporary Temporary Location ICS CCE/03-574 CCD/04-574 Elevation NA 576 577 Reference Value 2000 gpm (Fixed) 1 65.0 psid (Var)* -A DMM may be used in lieu of ICS point if unavailable.

2.4-10 Rev. 13 Emerqency Service Water (ESW) Pumps (Pump Group A (1P45-CO01A&B), AB (1P45-C002)

MPL Nos.: 1P45-C001A, 1P45-C001B, 1P45-C002 Pump Type: vertical line shaft IST Hydraulic Circuit and Test Procedure:

The test loops for all three pumps establish flow through all of their associated heat exchangers (with the exception of the fuel pool cooling heat exchangers where the flow is through the bypass line), with suction from Lake Erie. The differential pressure is set at 96 psid for 1P45-CO01A&B and 90 psid for 1P45-C002 by throttling the pump discharge valves.Differential pressure is determined by first measuring the suction bay water level as a distance beneath the ESW Pumphouse floor. That distance is used to calculate the elevation difference between the water level and the discharge pressure gauge (suction lift distance) in feet, which is then converted to pressure.

A test discharge pressure is determined by subtracting the suction lift from the required pump dP.Throttling flow to establish the calculated test discharge pressure thus sets the differential pressure across the submerged pump impeller to the required value. Once the pump differential pressure is established, total pump flow is determined by summing the measured flows in each of the branch lines. Vibration velocity readings are then taken in three orthogonal directions on the upper motor bearing housing.Instrumentation:

Bay level measurements are taken to the nearest i inch using a dipstick or tape measure with the floor to water surface measurement expected to be between 14'6" and 14'11". Discharge pressure is measured with a temporary M&TE gauge. Flow measurements through the RHR heat exchangers, ECC heat exchangers, and standby diesel generator heat exchangers are obtained with permanent plant flow instrumentation and the integrated computer system (ICS). Flow rates through the fuel pool heat exchanger bypass lines (through the Unit 2 ECC System) and the HPCS room cooler are determined by measuring flow element dP with temporary M&TE dP gauges, then converting the dP to a flow rate.IP45-CO01A:

Parameter RHR Hx Unit 1 ECC DG Hx Unit 2 ECC Suction Bay Discharge.

Flow

• Flow

• Flow

• Flow ** Level Pressure MPL No. E12EA008 P45EA002 P45EA003 Temporary Physical Temporary dP Gauge Meas.Location ICS ICS ICS CCD/06-574 EWC/01-586 EWC/05-586 Elevation NA NA NA NA NA 590 Reference Total 10482 gpm 96 psid Value Flow (Var) (Fixed)* -A DMM may be used in lieu of ICS point if unavailable.

• • -A Controlotron ultrasonic flowmeter may be used if restricting orifice is unavailable.

2.4-11 Rev. 13 Emerqency Service Water (ESW) Pumps (Continued)

IP45CO01B:

Parameter RHR Hx Unit 1 ECC DG Hx Unit 2 ECC Suction Bay Discharge Flow

• Flow

• Flow

• Flow ** Level Pressure MPL No. E12EA009 P45EA007 P45EA006 Temporary Physical Temporary dP Gauge Measurement Location ICS ICS ICS CCD/06-574 EWC/01-586 EWC/05-586 Elevation NA NA NA NA NA 590 Reference Total 10941.6 96 psid Value Flow gpm (Var) (Fixed)* -A DMM may be used in lieu of ICS point if unavailable.

S* -A Controlotron ultrasonic flowmeter may be used if restricting orifice is unavailable.

1P45-C002:

Parameter HPCS DG Hx HPCS Room Suction Bay Discharge Flow

• Cooler Flow Level Pressure MPL No. P42EA004 Temporary dP Physical Temporary Gauge Measurement Location ICS EWC/03-568 EWC/01-586 EWC/01-586 Elevation NA NA NA 588 Reference Total Flow 906.4 gpm (Var) 90.0 psid Value (Fixed)S- A DMM may be used in lieu of ICS point if unavailable.

2.4-12 Rev. 13 Control Complex Chilled Water (CCCW) Pumps (Pump Group A)MPL Nos.: P47-CO01A, P47-CO01B Pump Type: centrifugal IST Hydraulic Circuit and Test Procedure:

The normal closed loops of the CCCW system are used as the hydraulic circuits for inservice testing of the CCCW pumps.The control complex chiller outlet isolation valves are used to throttle flow until the reference value of 1400 gpm is established.

Vibration velocity measurements are taken in the horizontal and vertical planes on the inboard and outboard pump bearings.

Vibration velocity is also measured in the axial direction for the outboard (thrust) bearing.Instrumentation:

Pump differential pressure is determined from the difference between individual suction and discharge pressure readings.Suction and discharge pressures are measured with temporary M&TE gauges. Flow rate readings are from a permanent local flow indicator.

P47-C0O01A(B):

Parameter Flow Rate Suction Discharge Pressure Pressure MPL No. P47-NI41A(B)

Temporary Temporary Location CCD/02-574 CCD/02-574 CCD/02-574 Elevation NA 578 576 Reference value 1400 gpm (Fixed) 61 psid (Var)for A and B for A and B 2.4-13 Rev. 13 Emergency Service Water Screen Wash Pumps (Pump Group N/A)MPL Nos.: P49-CO02A, P49-C002B Pump Type: vertical line shaft IST Hydraulic Circuit and Test Procedure:

These pumps take suction from Lake Erie and discharge through screen and trough wash nozzles. In order to achieve the reference values for differential pressure, flow is also directed through strainer drain valves. The trough wash and strainer drain valves are used to adjust flow until the required dP is established.

Pump differential pressure is calculated by first recording suction bay water level in feet of elevation.

The suction pressure is then determined by calculating the height of the water column above the pump impeller and converting it to pressure.

A test discharge pressure is calculated by adding the suction pressure to the required pump dP and subtracting the pressure equivalent of the elevation difference between the pump impeller and the discharge pressure gauge. Once the test discharge pressure is established, flow rate is measured with a temporary flow meter on the pump discharge line. Vibration velocity readings are then taken in three orthogonal directions on the upper motor bearing housing. Since these pumps are outside the scope on the OM Code, a Comprehensive pump test will not be performed.

The pumps are tested as Augmented components.

Instrumentation:

Suction bay level is read from a permanent local indicator.

Temporary M&TE gauges are installed to measure discharge pressure.

Flow rate is measured with an external clamp-on flow meter.P49-C002A(B):

Parameter Flow Rate Suction Bay Discharge Pressure Level MPL No. Temporary 0P45-R240 Temporary Location EWA/04-586 EWC/01-586 EWB/01-586 Elevation NA NA 593 eference Value 368 gpm A (Var) 120 psid -A (Fixed)1 381 gpm B (Var) 119 psid -B (Fixed)2.4-14 Rev. 13 Standby Diesel Generator Fuel Oil Transfer Pumps (Pump Group AB)MPL Nos.: IR45-C001A, IR45-C002A, 1R45-CO01B, 1R45-C002B, IR45-CO01C, 1R45-C002C Pump Type: centrifugal IST Hydraulic Circuit and Test Procedure:

The hydraulic circuits for fuel oil transfer pump testing use the normal flow paths for filling the fuel oil day tanks. The pump suction is from the day tank and the discharge goes through an eductor in the main storage tank. The increased flow then returns to the day tank. When the fuel oil transfer pumps are tested, they are run long enough to fill the day tank to the overflow point (which is directed back to the main storage tank), thus creating a repeatable condition.

Once conditions are stable, the pump discharge valve is throttled to set the pump differential pressure to the desired value. The reference dP is 70 psid for 1R45-C001A, 1R45-C002A, 1R45-C001B, 1R45-C002B, 72.7 psid for 1R45-C001C, and 71.1 psid for IR45-CO02C.

After the pump dP is set, flow rate is measured with a temporary flow meter on the pump suction line.Vibration velocity readings are then taken in the horizontal and vertical directions on the inboard and outboard pump bearings.Instrumentation:

Pump differential pressure is determined using individual suction and discharge pressure gauges. Both gauges are temporary M&TE. Flow rate is measured with an external clamp-on flow meter.IR45-C0O01A, 1R45-C002A, 1R45-C001B, 1R45-C002B:

Parameter Flow Rate Suction Discharge Pressure Pressure MPL No. Temporary Temporary Temporary Location DGD/01-620 DGD/01-620 DGD/01-620 Elevation NA 621 623 Reference 92.0 gpm -1A (Var) 70 psid (Fixed) for Value 96.7 gpm -2A (Var) all 4 pumps 98.9 gpm -lB (Var)84.8 gpm -2B (Var)IR45-C001C, 1R45-C002C:

Parameter Flow Rate Suction Discharge Pressure Pressure MPL No. Temporary Temporary Temporary Location DGD/01-620 DGD/01-620 DGD/01-620 Elevation NA 621 623 Reference 83.0 gpm -IC (Var) 72.7 psid -1C (Fixed)Value 87.5 gpm -2C (Var) 71.1 psid -2C (Fixed)2.4-15 Rev. 13

3.0 INSERVICE

TESTING PROGRAM FOR VALVES 3.1 General Information

3.1.1 Applicable

Code The valve testing program for ISI Class 1, 2, 3, MC and Optional valves meets the requirements of ASME OM Code-2001 Edition with Addenda through OMb-2003.

Where these requirements are determined to be impractical, specific requests for relief have been written and included in Section 3.2. In addition, cold shutdown and refueling outage justifications are included in Section 3.2 for those requirements that have been determined to be impractical to meet at the stated test frequencies.

3.1.2 Valve

Program Tables The tables in Section 3.4 list the ISI Class 1, 2, 3, MC and Optional valves and pressure relief devices included in the PNPP IST program. Information provided for each valve or pressure relief device is as follows: VALVE/DEVICE IDENTIFICATION AND IST REQUIREMENTS SYSTEM P&ID: The system and MPL are located in the top left hand corner of the program table and in the top right hand corner is the drawing number (DWG. No.). This identifies the valves associated system and P&ID.VALVE/DEVICE:

The valve or pressure relief device Master Parts List (MPL)number.ISI CLASS: The ISI safety classification of the valve or pressure relief device.P&ID COOR.: The coordinates on P&ID at which the valve or pressure relief device is located.ACTIVE: Valves which are required to change obturator position to accomplish a specific function.PASSIVE: Valves which maintain obturator position and are not required to change position to accomplish a specific function.3.1-1 Rev. 13 VALVE CATEGORY: The category assigned to the valve based on the definitions provided in ISTC. Four (4) separate categories are defined in this standard exist.CATEGORY A -CATEGORY B -CATEGORY C -CATEGORY D -and any combination of these categories may Valves for which seat leakage is limited to a specific maximum amount in the closed position for fulfillment of their required function.Valves for which seat leakage in the closed position is inconsequential for fulfillment of their required function.Valves which are self-actuating in response to some system characteristic, such as pressure (pressure relief devices) or flow direction (check valves) for fulfillment of their required function.Valves which are actuated by an energy source capable of only one operation, such as rupture disks or explosively-actuated valves.SIZE: The nominal pipe size of the valve in inches.VALVE TYPE: The type of valve/device abbreviations:

is indicated by the following BALL BUTTERFLY CHECK DIAPHRAGM GATE GLOBE RELIEF RUPTURE DISK SAFETY POWER ACTUATED SAFETY/RELIEF SET PRESSURE DEVICE STOP CHECK THREE WAY BA BF CH DI GT GL RE RU SV SR/AO SD SC TW 3.1-2 Rev. 13 ACTUATOR TYPE: The type of valve/device actuator is indicated by the following abbreviations:

MOTOR OPERATOR MO AIR OPERATOR AO SOLENOID OPERATOR SO HYDRAULIC OPERATOR HO MANUAL MA SELF-ACTUATED SE NORMAL POSITION: The position of the valve/device during normal plant operation, specified as follows: Normally Open 0 Normally Closed C Throttled TH Locked Open LO Locked Closed LC Locked Throttled LTH TEST REQUIREMENTS:

The test(s) that will be performed to fulfill the requirements of the OM Code. The test descriptions and abbreviations used are identified in Table 3.1-1.TEST FREQUENCY:

The frequency at which the above mentioned tests will be performed to fulfill the requirements of OM Code and augmented requirements are defined in Table 3.1-2.SURVEILLANCE (SVI) NO.: The surveillance instruction in which the valve or device is tested.STROKE TIME: The stroke time is the reference value assigned, in tenth of seconds, for power operated Category A or B valves.SEAT LEAKAGE: The limiting maximum value of seat leakage, in gpm or sccm, for Category A and AC valves.3.1-3 Rev. 13 SET PRESSURE: The pressure relief device set pressure (psi) is provided for safety valve, relief valve, safety relief valve, power actuated pressure relief valve, rupture disk device, vacuum relief device and set pressure relief device with deviations noted in the Remarks Section.RELIEF REQUEST: The reference to a relief request in Section 3.2 for valve and pressure relief device testing. Requests for relief are identified as VR-XX.COLD SHUTDOWN JUSTIFICATION:

The reference to a Cold Shutdown Justification in Section 3.2 for valve testing. This justification provides the mechanism for documenting the bases for performing a specific test during a cold shutdown.

Cold Shutdown Justifications are identified as CS-XX and comply with the rules of the OM Code.REFUEL OUTAGE JUSTIFICATION:

The reference to a Refueling Outage Justification in Section 3.2 for valve testing. This justification provides the mechanism for documenting the bases for performing a specific test during a refueling outage. Refueling Outage Justifications are identified as RO-XX and comply with the rules of the OM Code.REMARKS: Remarks in the valve test table are to clarify any special requirement due to design or identify other documents affecting testing requirements.

3.1.3 Measurement

of Test Quantities STROKE TIME: Stroke time is that time interval from initiation of the actuating signal to the end of the actuating cycle. Stroke time reference values for each power operated valve are specified in the valve test table for the open or closed direction.

Stroke time for all power operated valves is measured to the nearest one-tenth of a second.POSITION INDICATION:

Valve disk movement is determined by exercising the valve while observing an appropriate indicator that signals the required change of disk position.

Actual valve movement or observing indirect evidence, such as changes in system pressure, flow rate, level or temperature, which reflect stem or disk position will be used to verify that remote valve position indicators agree with valve travel direction, if practicable.

3.1-4 Rev. 13 SEAT LEAKAGE: Seat leakage is measured by one of the following methods: a) measuring leakage through a downstream telltale connection while maintaining test pressure on one side of the valve, or b) measuring the feed rate required to maintain test pressure in the test volume or between two seats of a gate valve, provided the total apparent leakage rate is charged to the valve or gate valve seat being tested, and that the conditions required by ISTC-3630(b) are satisfied; or c) determining leakage by measuring pressure decay in the test volume, provided the total apparent leakage rate is charged to the valve or valve combination or gate valve seat being tested, and that the conditions required by ISTC-3630(b) are satisfied.

CHECK VALVE EXERCISE: a) During exercise testing with flow, the necessary obturator movement shall be demonstrated by performing both an open and a close test. [ISTC-5221(a)]

(1) Check valves that have a safety function in both the open and close directions shall be exercised by initiating flow and observing that the obturator has traveled to either the full open position or the position required to perform its intended function(s) and verify that on cessation or reversal of flow, the obturator has traveled to its seat.(2) Check valves that have a safety function in only the open direction shall be exercised by initiating flow and observing that the obturator has traveled to either the full open position or the position required to perform its intended function(s) and verify closure.(3) Check valves that have a safety function in only the close direction shall be exercised by initiating flow and observing that the obturator has traveled at least to the partially open position (normal or expected system flow), and verify that on cessation of reversal of flow, the obturator has traveled to the seat.3.1-5 Rev. 13 Observations shall be made by observing a direct indicator (e.g., position indicating device) or other positive means (e.g., changes in system pressure, flow rate, level, temperature, seat leakage testing, or non-intrusive testing results.b) If a mechanical exerciser is used to exercise a valve, the force or torque required to move the obturator and fulfill its safety function(s) shall meet the acceptance criteria specified by PNPP [ISTC-5221(b)].

If practicable, the force(s) or torque(s) required to move the obturator and fulfill any non-safety function should be evaluated to detect abnormality or erratic action for corrective action. The following shall be considered when determining acceptance criteria for mechanical exercising:

(1) Exercise test(s) shall detect a missing obturator, sticking (closed or open), binding (throughout obturator movement), and the loss of any weight(s).

Both an open and closed test may not be required.(2) Acceptance criteria shall consider the specific design, application, and historical performance.

(3) If impracticable to detect a missing obturator or the loss or movement of any weight(s) using a mechanical exerciser, other positive means may be used (e.g., seat leakage tests and visual observations to detect obturator loss and the loss or movement of external weight(s), respectively).

c) Per ISTC-5221(c);

If the test methods in ISTC-5221(a)(flow exercising) and ISTC-5221(b) (mechanical exercising) are impractical for certain check valves, or if sufficient flow cannot be achieved or verified, a sample disassembly and inspection program shall be used to verify obturator movement.

If maintenance is performed on one of these valves that could affect its performance, the post-maintenance testing shall be conducted in accordance with ISTC-5221(c)

(4).Check valves that will be disassembled and inspected shall be grouped by similar design, application, and service condition and require a periodic examination of one valve from group each refueling outage. The details and bases of the sampling program shall be documented and recorded 3.1-6 Rev. 13 in the test plan. The following shall be considered when implementing a sample disassembly and inspection program: 1) Grouping of check valves for the sample disassembly and inspection program shall be technically justified and shall consider, as a minimum, valve manufacturer, design, service, size, materials of construction, and orientation.

[ISTC-5221(c)

(1)]Maintenance and modification history should be considered in the grouping process. Valve groupings should also consider potential flow instabilities, required degree of disassembly, and the need for tolerance or critical dimension checks.(2) During the disassembly process, the full stroke motion of the obturator shall be verified.

Full stroke motion of the obturator shall be verified immediately prior to completing reassembly.

Check valves that have their obturator disturbed before full stroke motion is verified shall be examined to determine if a condition exists that could prevent full opening or reclosure of the obturator.

Examples of valves that could have their obturators disturbed prior to verifying full stroke motion include; spring loaded check valves or check valves with the obturator supported from the bonnet.[ISTC-5221(c)

(2)](3) At least one valve from each group shall be disassembled and inspected each refueling outage; and all valves in the group be disassembled and inspected at least once every 8 years. [ISTC-5221(c)

(3)](4) Before return to service, valves that were disassembled for inspection or that received maintenance that could affect their performance, shall be exercised full- or part-stroke, if practicable, with flow in accordance with ISTC-3520.

Those valves shall also be tested for other requirements (e.g., closure verification or leak rate testing) before returning them to service.[ISTC-5221 (c) (4)]SERIES VALVES IN PAIRS: If two check valves are in a series configuration without provisions to verify individual reverse flow closure 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.3.1-7 Rev. 13 CHECK VALVE CONDITION MONITORING:

As an alternative to the requirements of paragraphs ISTC-3510, ISTC-3520, ISTC-3530, ISTC-3550, and ISTC-5221, PNPP may establish a Check Valve Condition Monitoring (CVCM) Program per ISTC-5222.

The purpose of this 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. PNPP may implement this program on a valve or a group of similar valves basis.a) Examples of candidates for (a) improved valve performance are check valves that: (1) have an unusually high failure rate during inservice testing or operations (2) cannot be exercised under normal operating conditions or during shutdown (3) exhibit unusual, abnormal, or unexpected behavior during exercising or operation (4) the Owner elects to monitor for improved valve performance b) Examples of candidates for (b) optimization of testing, examination, and preventive maintenance activities are check valves with documented acceptable performance that: (1) have had their performance improved under the Check Valve Condition Monitoring Program (2) cannot be exercised or are not readily exercised during normal operating conditions or during shutdowns (3) can only be disassembled and examined (4) 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 OMb-2003 Addenda. a site administrative procedure, and site implementing procedures which perform the specified tests identified in the individual Check Valve Condition Monitoring (CVCM) Program Plans.If the Appendix II CVCM Program for a valve or group of valves is discontinued then the requirements of ISTC-3510, ISTC-3520, ISTC-3530, ISTC-3550, and ISTC-5221 shall be implemented.

3.1-8 Rev. 13 SET PRESSURE: Set pressure testing for relief devices is measured by one of the following methods: a) Pressure Relief Valves -valves requiring a set pressure measurement may be tested in place or removed for bench testing. Valves designed to operate on steam shall be set pressure tested using saturated steam. Valves on systems using other compressible fluids shall be tested with the normal operating fluid. Valves used on liquid service systems shall be tested with the normal system operating fluid for which they were designed.

Alternative test media may be used provided the requirements contained in Appendix I of the OM Code are met.b) Reclosing Relief Devices (i.e., Vacuum Relief or Set Pressure)

-shall be actuated to verify open and close capability, set pressure, and performance of any pressure and position sensing accessories.

NOTE: Non-Reclosing pressure relief devices used in BWR Scram accumulators are exempt from the requirements of the OM Code. (OMb-2003, ISTC-1200) c) Non-Reclosing Rupture Disks -Devices are visually inspected upon receipt, functional testing is not required.

Devices are periodically replaced as provided for in Appendix I of the OM Code.MANUAL VALVES: Although ISTC-3540 permits manual valves to be full-stroke exercised at least once every 5 years; pursuant to 10 CFR 50.55a(b)

(3) (vi), manual valves within the IST program scope that perform an active safety function shall be exercised through a complete cycle at least once every 2 years. Exercise testing shall be considered acceptable if valve stem travel exhibits unrestricted movement with no abnormal resistance or binding through one complete cycle. Where practical, process parameters may be utilized to verify obturator movement.However, where process parameters are utilized to verify obturator movement it is not necessary to be performed simultaneous to manual exercising.

If a valve fails to exhibit the required change of obturator position, the valve shall immediately declared inoperable.

The use of a valve persuader (cheater) for additional mechanical advantage will not invalidate the test, as it is recognized that larger valves may exhibit increased packing friction and/or increased friction associated with the disk to seat interface.

In addition, a valve persuader may be used for personnel safety depending on a valve's service application (i.e., main steam). Must receive Senior Reactor Operator permission to use mechanical advantage devices.3.1-9 Rev. 13 SKID-MOUNTED COMPONENTS:

Skid-mounted valves are exempt perr Subsection ISTC-1200, provided they are tested as part of the major component and are justified by PNPP to be adequately tested. Skid-Mounted pumps and valves are those which are integral to or that support operation of major components, even though these pumps and valves may not be located on the skid. In general, these valves are supplied by the manufacturer of the major component.

Examples include: air start valves associated with the emergency diesel generators, and solenoid operated pilot valves used to control air operated valves and ADS/Safety Relief valves. Valves considered as skid-mounted shall be included in the valve test tables with "skid-mounted" specified in the Remarks column.3.1.4 Allowable Ranges of Test Quantities STROKE TIME: Stroke times shall be compared to the initial reference values established per the OM Code. Stroke times shall meet the criteria listed below. Valves not meeting this criteria shall be immediately retested or declared inoperable.

Valves declared inoperable may be repaired, replaced, or the data may be analyzed to determine the cause of the deviation and the valve shown to be operating acceptably.

Valve operability based on analysis shall have the results of the analysis recorded in the record of tests.a) Electric motor operated valves with reference stroke times greater than 10 sec. shall exhibit no more than +/-15%change in stroke time when compared to the reference value.b) Other power operated valves with reference stroke times greater than 10 sec. shall exhibit no more than +/-25%change in stroke time when compared to the reference value.NOTE: As an alternative to the requirements of paragraph ISTC-5120 of the ASME OM Code-2001 through OMb-2003, Code Case OMN-I "Alternative Rules for Preservice and Inservice Testing of Certain Electric Motor-Operated Valve Assemblies in LWR Power Plants" provides an alternative to MOV stroke time testing.PNPP shall adopt the alternative test requirements specified in ASME OM Code Case OMN-I in lieu of stroke timing certain motor operated valves (MOVs) in accordance with the requirements specified in paragraph ISTC-5120 and position indication testing in accordance with the requirements specified in paragraph ISTC-3700.

The PNPP MOV Program satisfies the criteria specified in ASME OM Code Case OMN-l and the 3.1-10 Rev. 13 conditional acceptance specified in Reg. Guide 1.192,"Operation and Maintenance Code Case Acceptability, ASME OM Code". Paragraph 3.6 of OMN-l requires MOVs to be full stroke exercised (not timed) to the position(s) required to fulfill their function(s) on an interval not to exceed one year or one refueling cycle (which ever is longer). Full stroke exercising is based on the practicality of exercising during power operation, cold shutdown, or refueling.

Justification for extended full stroke exercising of ASME OM Code Case OMN-I scoped MOVs beyond a quarterly frequency are provided in Section 3.2 of the PNPP IST Program. Also, refer to Valve Relief Request VR-3.c) Electric motor operated valves with stroke times less than or equal to 10 sec. shall exhibit no more than a +/-25% or+/-1 sec. change in stroke time, whichever is greater, when compared to the reference value.d) Other power operated valves with reference stroke times less than or equal to 10 sec. shall exhibit no more than+/-50% change in stroke time when compared to the reference value.e) Valves that stroke in less than 2 sec. may be exempted from (d) above. In such cases the maximum limiting stroke time shall be 2 sec.f) Valve stroke time shall not exceed either the values used to satisfy PNPP Technical Specifications or the owner's (CEI) established stroke times.NOTE: The most limiting action limit shall be used from Technical Specifications, USAR or Recommended Practice (if applicable).

POSITION INDICATION:

The valve travel direction (open/closed) will agree with remote position indicators.

SEAT LEAKAGE: Valve leakage rates shall not exceed either the value specified by Technical Specifications or the Owner's (CEI) established leakage rates.SET PRESSURE: Set pressure shall not exceed the greater of either the+/- tolerance limit of the Owner-established set pressure acceptance criteria or +/- 3% of the valves nameplate set pressure.3.1-11 Rev. 13

3.1.5 Instrument

Accuracy Instruments used to measure stroke times shall be capable of measurement to the nearest hundredth of a second.3.1.6 Post-Maintenance Testing During the inservice life of a valve, work may be required to restore the valve performance to within acceptable ranges.This work can be in the form of: routine servicing, maintenance (preventive/corrective), repair, and replacement.

The following work scope guidelines, test types to work scope required, steps to determine retest requirements, and retest flowpath (with examples) should be utilized in determining post-maintenance test requirements.

WORK SCOPE GUIDELINES

a. Routine -Performance of planned, preventive maintenance which does not require disassembly of the valve or replacement of parts such as greasing a bearing, stem lubrication, adjustment of stem packing and etc.b. Maintenance

-Performance of preventive or corrective maintenance which does require disassembly of the valve or replacement of consumable items to correct or prevent an abnormal or unsatisfactory condition.

Examples:

removal of bonnet, stem assembly or actuator, and disconnection of hydraulic or electrical lines.c. Repair -Performance of welding or grinding on a valve to correct a defect.d. Replacement

-Installation of a new valve, valve part, or a modification to the valve.3.1-12 Rev. 13 TEST TYPES TO WORK SCOPE REQUIRED Test Types Work Scope EC,EO,STC,STO,FS Routine servicing, maintenance, repair or replacement.

LJ Specified maintenance, repair or replacement.

Specified maintenance:

repacking, lowering of motor-operated valve closing torque switch setting, replacement of motor-operated valve torque switch mechanism, adjustment of motor-operated valves that close on limit switch, disassembly of valve internals, removal of the valve actuator or alteration to seating surface. MOVATS Data may be used as an alternative test to verify existing conditions have not degraded.LW Specified maintenance, repair or replacement.

Specified maintenance:

alteration to seating surface, lowering of motor-operated valve closing torque switch setting, replacement of motor-operated valve torque switch mechanism, adjustment of motor-operated valve closing unit switch for motor-operated valves that close on limit switch. MOVATS Data may be used as an alternative test to verify existing conditions have not degraded.LK Same as LW.LD Same as LW.PI Specified maintenance, repair or replacement.

Specified maintenance:

reconnection of the valve actuator, adjustment or disassembly of limit switch mechanism for remote position indicator, or terminating/reterminating wiring for the remote indicator circuitry.

Exception:

No retest for replacement of fuses or light bulbs. Lifting and landing a single lead requires no retest.3.1-13 Rev. 13 Test Types Work Scope RT Specified maintenance, repair or replacement.

Specified maintenance:

adjustment of setting, disassembly, internal gagging, remachining or cleaning of any critical part, lapping of seat and disc or any other operation which may affect the flow passage, capacity, function or pressure retaining integrity.

NOTE: Changing the blowdown setting and/or the nameplate set pressure for safety and safety relief valves requires testing by other than the bench test method.RD Maintenance, repair or replacement.

EX None (Manufacturer's Data acceptable).

STEPS TO DETERMINE RETEST REQUIREMENTS Step 1: Locate the valve or device by MPL number in the Valve Test Table (Section 3.4).Step 2: If the work scope is applicable to the test requirement then the surveillance located on the valve test table should be performed, however other documents may be used if ASME OM Code requirements are followed.Step 3: When the work scope is applicable to the test requirement, other means for documenting a retest may be used (i.e., Work Orders). When using other means for documentation of a retest, ensure all ASME OM Code requirements are being followed (i.e., all appropriate retests (EC, EO, STC, STO, PI etc.) are being performed).

Also any test conditions established within the applicable surveillance must be met (i.e., flowrate of 7100 GPM for stroke timing of valve). To establish surveillance test conditions within the RETEST document (Work Order) any approved PNPP instruction may be used (e.g., SVI, SOI, 101, etc.).This is accomplished by extracting the steps from the appropriate instruction (SVI, SOI, 101, etc.) and inserting them into the re-testing document (Work Order).3.1-14 Rev. 13 Step 4: If a valve test exists within the pump operability portion of a surveillance instruction, and the pump must be started to test this valve, only the set reference value for the pump need be established.

It is not required to perform entire pump data collection (e.g., if flow is set to 7100 GPM to establish conditions for pump data collection, then set flow to 7100 GPM and N/A all other data entries on pump data sheet).Retest Flowpath Verify valve MPL listed in Section 3.4, Valve Test Table.--NO -No retest required for operability.

I YES I Note all applicable test requirements for that valve.I YES I Identify Work Scope to be performed is applicable to the test requirements.

YES---NO ----Identify the SVI No. in the Section 3.4, Valve Test Table.I Y IES Perform appropriate steps of this SVI to satisfy retest requirements.

NO-Work Orders may be used for re-testing valves if conditions set in the SVI are met.3.1-15 Rev. 13 Examples: 1. 1B21-F028A requires the valve seating surface to be lapped per Work Order and the appropriate Surveillance Instructions be used for retest.Valve 1B21-F028A MPL is listed on Page 3.4-3 See Post NO -Maintenance Test Manual.I YES I Note Valve Test Reqts: PC, EC, STC, FS, LJ, PI I YES I Work Scope Performed requires:

EC, STC, FS, LJ, PI. NO NOTE: PE not required when performing FE NOTE: IS YI~S SVI Numbers: EC, FS,STC, PI;SVI-B21-T2001 PC ;SVI-C71-T0039 LJ ;SVI-B21-T9000 I YES I T F'he Local Leak Rate Pest (LJ) may require)oth Pre and Post Leak hate Testing Perform applicable steps of Section 4.0;Prerequisites and Section-O 5.0, Surveillance Instruction Work Orders not required, retest per-formed by Surveillance Instructions.

3.1-16 Rev. 13

2. 1E12-F025B requires the valve seating surface to be lapped per Work Order and the appropriate Surveillance Instructions be used for retest.Valve 1E12-F025B MPL is listed on Paqe 3.4-45-NO Y4s Note Valve Test Reqts: RT, LJ I YES I Work Scope Performed requires:

RT, LJ NO I YES I SVI Numbers: RT ; SVI-GEN-T2100 LJ ; SVI-E12-T9429 YES NOTE: The Local Leak Rate Test (LJ) may require both Pre and Post Leak Rate Testing NOTE: Lapping of a valve seating surface is within the scope of work which bench testing adequately verifies set points Perform applicable steps of Section 4.0; Prerequisites

_-and Section 5.0, Surveillance Instructions.

OR Work Orders not re-quired, retest per-formed by Surveillance Instructions.

3.1-17 Rev. 13

3. 1E12-F024A requires the stem packing to be adjusted to minimize leaking and the retest is to be performed within the Work Order Package.Valve IE12-F024A MPL is listed on Page 3.4-33 1 YES Note Valve Test Reqts: EC, EO, STC, STO, LW, PI I YES I Work Scope performed requires: EC. EO. STC. STO I YES SVI Numbers: EC, EO, STC, STO;SVI-E12-T2001 YES See Post NO Maintenance Test Manual.NO I Reviewed SVI Section 4.0 Work Order Prerequisites and Section follow SVI 5.0 Surveillance Instruc- OR use a Work ions for retest reqts. retest, it steps should format. To Order to may read:$1 1) Start RHR Pump A (SOI-E12).

2) Establish a flowrate of7100 GPM (SOI-E12).

3) Close 1E12-F024A while measuring and recording stroke time (SVI-E12-T2001).

3.1-18 Rev. 13 TABLE 3.1-1 INSERVICE TEST REQUIREMENTS TEST TEST NAME TEST DESCRIPTION LJ Containment Isolation Valve Containment leak tested Appendix J, detailed in isolation valves will be seat in accordance with 10CFR50, Option B, with exceptions as Technical Specification 5.5.12.LW LK LD EO Seal System Con-tainment Isolation Valve Pressure Isolation Valve Other Isolation Valves Exercise Open Exercise Closed Seal System -Containment isolation valves will be seat leak tested in accordance with 10CFR50, Appendix J, Type C Leak Test and PNPP Technical Specification requirements to ensure long term viability of a seal system.Pressure isolation valves will be seat leak tested in accordance with the OM Code.Other Category A valves requiring seat leakage tests per the OM Code.Exercise testing of (Check) valves from position.Exercise testing of (Check) valves from position.Category A, B or C the closed to open Category A, B or C the open to closed EC STO STC Stroke Time Open Stroke Time Closed Partial Stroke Open Stroke time is the measurement of the time required to exercise a power operated Category A or B valve from the closed to open position required for the valve to perform its function.Stroke time is the measurement of the time required to exercise a power operated Category A or B valve from the open to closed position required for the valve to perform its function.Partial stroke exercise testing will be performed to confirm partial stroke open capability for power operated Category A or B valves when full stroke exercise is impractical.

Partial stroke exercise will also be performed on Category C check valves subsequent to reassembly, if practicable.

PO 3.1-19 Rev. 13 TABLE 3.1-1 (Cont.)INSERVICE TEST REQUIREMENTS TEST PC RD RC RT TEST NAME Partial Stroke Closed Rupture Device Set Pressure Replacement Cycling Relief Valve Set Pressure Relief Device Set Pressure Explosive Charge Fail Safe Test Position Indicator Verification TEST DESCRIPTION Partial stroke exercise testing will be performed to confirm partial stroke closed capability for power operated Category A or B valves when full stroke exercise is impractical.

Device (i.e., rupture disk) actuation set point will be verified in accordance with Appendix I of the OM Code, Section 1-3340 or Technical Specification.

These devices will be replaced periodically to satisfy testing requirements.

This requirement does not apply to rupture discs associated with the scram accumulators.

Power actuated relief valve cycling following a replacement with a pre-tested valve.Valve (i.e., relief, safety, safety relief, or power actuated relief valve) set point will be verified in accordance with Appendix I of the OM Code or Technical Specifications.

Device (i.e., vacuum relief or set pressure relief) actuation set point will be verified in accordance with Appendix I of the OM Code, Section 1-3370 or Technical Specification.

These devices must open and close within a specific set pressure tolerance which differ them from check valves.Testing of explosive charges by firing, per ISTC-5260 of the OM Code, shall be with at least 20% of the charges in a batch fired every 2 years with no charge testing exceeding 10 years.Valves which change obturator position to perform the specific function by loss of valve actuating power to the actuator (e.g., air operated, spring loaded, solenoid operated and hydraulic operated).

Valves with remote position indicators will be verified to accurately reflect valve travel direction.

This is typically performed every 2 years. For certain MOVs the frequency will reflect that of OMN-1.SP EX FS PI 3.1-20 Rev. 13 TABLE 3.1-2 INSERVICE TESTS FREQUENCY TEST INTERVAL Weekly (W)Monthly (M)Quarterly (Q)OPERATIONAL MODE FREQUENCY DESCRIPTION Any Mode Any Mode Any Mode Cold Shutdown (CS)Refuel Outage (RO)Cold Shutdown Refueling Outage At least once every seven (7) days (T/S 5.5.6 states at least once every 92 days with an extension of 25% being permitted T/S SR 3.0.2)At least once every thirty-one (31)days (T/S 5.5.6 states at least once every 92 days with an extension of 25%being permitted T/S SR 3.0.2)At least once every three (3) months (T/S 5.5.6 states at least once every 92 days with an extension of 25% being permitted T/S SR 3.0.2)Testing which cannot be performed quarterly 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 power (e.g., it is not the intent to keep the plant in cold shutdown in order to complete cold shutdown testing).

For extended outages, testing need not be commenced in 48 hours5.555556e-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 prior to plant startup. Testing completed within the quarterly requirements need not be performed in subsequent cold shutdowns.

Testing which cannot be performed at cold shutdown shall be completed when the plant is shutdown for the purpose of replacing fuel (T/S 5.5.6 states at least once every 731 days with an extension of 25% being permitted T/S SR 3.0.2). For certain OMN-I MOVs, a maintenance plan will be used to representing the number of refueling outages or years between tests.Testing every two years (T/S 5.5.6 states at least once every 731 days with an extension of 25% being permitted T/S SR 3.0.2).2-Year (2Y)Any Mode 3.1-21 Rev. 13 TABLE 3.1-2 INSERVICE TESTS FREQUENCY TEST INTERVAL 2-Year Device (2YD)OPERATIONAL MODE Refueling Outage FREQUENCY DESCRIPTION 5-Year (5Y)5-Year Replacement (5YR)10-Year (10Y)Any Mode Any Mode Any Mode Testing at each refueling outage or every 2 years whichever is sooner, unless historical data requires more frequent testing (i.e., ISI Class 2, 3, MC and Optional Reclosing Devices).Testing every 5 years, with no maximum limit specified for the number of valves to be tested within each interval; however, a minimum of 20% of the valves from each valve group shall be tested within any 24 month interval.This 20% shall consist of valves that have not been tested during the current 5-year interval, if they exist. The interval for any individual valve shall not exceed 5 years (i.e., ISI Class 1 Pressure Relief Valves).Replacing every 5 years, unless historical data indicates a requirement for more frequent replacement (i.e., ISI Class 2, 3, and Optional Non-Reclosing Devices).Testing every 10 years, with no maximum limit specified for the number of valves to be tested during any single plant operating cycle; however, a minimum of 20% of the valves from each valve group shall be tested within any 48 months interval.

This 20% shall consist of valves that have not been tested during the current 10-year test interval, if they exist. The test interval for any individual valve shall not exceed 10 years (i.e., ISI Class 2, 3, and Optional Pressure Relief Valves).At least 20% of the charges shall be fired and replaced at least once every 2 years (T/S 5.5.6 states at least once every 731 days with an extension of 25%being permitted T/S SR 3.0.2) but in no case shall the service life exceed 10 years for a charge.10-Year Explosive (10YE)Refueling Mode 3.1-22 Rev. 13 TABLE 3.1-2 INSERVICE TESTS FREQUENCY TEST INTERVAL Performance Based (PB)OPERATIONAL MODE FREQUENCY DESCRIPTION Any Mode Condition Monitoring (CM)Periodic Verification (PV Refueling or On-line Refueling or On-Line Testing based on a valve's performance history and assigned an interval up to 5 years (an extension of 25% being permitted T/S SR 3.0.2).Test frequency specified in the applicable Check Valve Condition Monitoring Program Plan. The test interval for a single valve or Group of valves shall not exceed the test interval specified in the Plan.Test frequency specified in the valve test tables for certain motor operated valves reflects the frequency designated by the MOV Program.3.1-23 Rev. 13 3.2 Cold Shutdown Justifications, Refueling Outage Justifications and Relief Requests for Inservice Valve Testinq Proqram Cold Shutdown Justification CS-1 System: Feedwater (N27)Valves: 1B21-F065A, 1B21-FO65B Category:

A Class: 2 Function:

Main Feedwater Shutoff Valves Test Requirements:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.Exercising these valves during normal operation would require a significant reduction in power and stopping one line of feedwater flow. Isolation of one line of feedwater flow during normal operation introduces undesirable operational transients and could result in a reactor trip. Partial stroke testing cannot be performed since valves stroke fully on initiation and conformance with the quarterly requirements is impractical for the facility due to the potential for a reactor trip.This cold shutdown justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (Log No. PY-NRR/CEI-0989L).

Exercise valves during cold shutdown when plant conditions permit isolation of feedwater flow.Alternate Testing: 3.2-1 Rev. 13 Cold Shutdown Justification CS-2 System: Main Steam System (Nil)Valves: lNll-F020A, lNll-F020B, lNll-F020C, lNll-F020D Category:

B Class: 2 Function:

Main Steam Shutoff Valve Test Requirements:

Basis for Justification:

ISTC-3510, '"Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.Valves fully stroke on initiation of close signal making partial valve stroke impractical.

Full stroke exercising results in loss of steam flow from one main steam line to the turbine creating adverse transients and potential of valve damage due to steam erosion of valve seat. Also, the design of these 28 inch gate valves does not allow exercising against the magnitude of differential pressure encountered without valve damage. Therefore, conformance to the quarterly requirements is impractical for the facility due to the potential for a reactor scram and equipment damage.This cold shutdown justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L).

Exercise valves during cold shutdown when plant conditions permit isolation of Main Steam.Alternate Testing: 3.2-2 Rev. 13 Cold Shutdown Justification CS-3 System: Reactor Coolant Pressure Isolation Valves -Motor operated (e.g., RHR, LPCS, HPCS, and Feedwater Leakage Control).Valves: IE12-F008, 1E12-F009, 1E12-F023, 1E12-F042A, 1E12-F042B, 1E12-F042C, 1E12-F053A, 1E12-F053B, IE21-F005, IE22-F004, 1N27-F737, 1N27-F740 Category:

A Class: 1, 2 Function:

Provide pressure isolation from high pressure coolant systems (e.g., Rx. Coolant, Feedwater) to other safety-related systems containing low pressure designed components.

Test Requirements:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.These pressure isolation motor operated valves maintain one of the two high to low pressure barriers during plant operation.

Exercising these valves during plant operation would involve a loss of one isolation barrier. The probability of causing an internal loss of coolant accident is significantly increased by exercising these motor operated valves quarterly.

Therefore, conformance to the quarterly requirements is impractical for the facility due to the potential for equipment damage.This cold shutdown justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L).

Exercise valves during cold shutdown when reactor pressure has been reduced to below the design pressure of attached piping and components.

Alternate Testing: 3.2-3 Rev. 13 Cold Shutdown Justification CS-4 System: Reactor Core Isolation Cooling (E51)Valves: IE51-F013 Category:

A Class: 1 Function:

Provide primary containment isolation and isolation of the RCIC injection to reactor coolant system.Test Requirements:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.The RCIC motor operated injection isolation valve is normally closed and interlocked with the turbine steam supply valve to prevent inadvertent opening if the RCIC system is not in operation.

System design precluded the installation of a RCIC pump discharge check valve, thus the motor operated injection isolation valve provides a second isolation between high pressure and low pressure RCIC components.

Testing of the RCIC injection isolation valve during plant operation would require either defeating the safety interlock, increasing the likelihood of an internal loss of coolant accident, or using the RCIC system to inject into the reactor vessel, which would cause the undesirable effects of nozzle thermal stress cycling and moisture carry-over.

Therefore, conformance to the quarterly requirements is impractical for the facility due to the potential for equipment damage.This cold shutdown justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L).

Exercise valve during cold shutdown when system conditions permit opening the valve without the potential for equipment damage.Alternate Testing: 3.2-4 Rev. 13 Cold Shutdown Justification CS-5 System: Nuclear Boiler (B21)Valves: 1B21-F022A, 1B21-F022B, IB21-F022C, IB21-F022D, 1B21-FO28A, 1B21-F028B, 1B21-F028C, 1B21-F028D Category:

A Class: 1 Function:

Main Steam Isolation Valves Test Requirements:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.Full stroke exercising requires a reduction in power to approximately 80% due to the loss of steam flow from one main steam line to the turbine. Recent industry information indicates that closing these valves with high steam flow in the line may be a large contributing factor in observed seat degradation.

The valves are designed for and receive a partial stroke exercise quarterly to verify proper position indication, limit switch actuation and partial fail safe with full steam flow during plant operation.

Partial stroke exercising is accomplished by bleeding down the accumulator air supply to the operator.

Therefore, conformance to the quarterly requirements is impractical for the facility due to the potential for equipment damage.This cold shutdown justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L).

Exercise and fail safe test valves during cold shutdown when system conditions permit full closure of the MSIVs without the potential for equipment damage.Alternate Testing: 3.2-5 Rev. 13 Cold Shutdown Justification CS-6 System: Control Rod Drive Hydraulic (ClI)Valves: lCll-F083 Category:

A Class: 2 Function:

Condensate Water to Control Rod Drive Outboard Containment Isolation Valve.Test Requirements:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.Closing of this valve during plant operation would result in a loss of drive and cooling water to the control rods. This would inhibit normal operation of the control rods possibly resulting in a reactor shutdown and/or overheating of the control rods causing equipment damage. This valve fully strokes upon initiation and cannot be partial stroke tested.Therefore, conformance to the quarterly requirements is impractical for the facility due to the potential for equipment damage.This cold shutdown justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L).

Exercise valve during cold shutdown when system conditions permit isolation of drive and cooling water to the control rods without the potential for equipment damage.Alternate Testing: 3.2-6 Rev. 13 Cold Shutdown Justification CS-7 System: Reactor Coolant Pressure Isolation Check Valves (RHR, LPCS, and HPCS) of a testable nature.Valves: IEI2-FO41A, 1E12-FO41B, IEI2-FO41C, IE21-F006, IE22-F005, Category:

AC Class: 1 Function: Provide pressure isolation of the reactor coolant pressure boundary between the high pressure reactor coolant system and other safety-related systems containing low pressure designed components.

Test Requirement:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.These pressure isolation valves maintain one of the two high to low pressure barriers during plant operation.

To exercise these valves during plant operation would involve a loss of one isolation barrier. The possibility of an internal loss of coolant accident is significantly increased by exercising these valves quarterly.

Therefore, conformance to the quarterly exercise requirement is impractical for the facility due to the potential for equipment damage.The closed exercise will be satisfied the closed position indicating signal open exercise during cold shutdown.by obtaining following the This cold shutdown justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L) and FENOC response to an RAI dated February 26, 2001 (PY-CEI/NRR-2549L).

Perform valve exercising (open and close) during cold shutdown when reactor pressure has been reduced to below the design pressure of attached piping and components.

Alternate Testing: 3.2-7 Rev. 13 Cold Shutdown Justification CS-8 System: RHR Relief Line Discharge to Suppression Pool Valves: 1E12-F605A and F605B Category:

C Class: 2 Function:

Vacuum breakers ensure discharge lines equalize to the environment's pressure.Test Requirement:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.The RHR relief line to suppression pool discharge vacuum breakers provide a means for releasing a vacuum developed in the discharge line from condensing steam. The vacuum breakers are normally closed during plant operation.

The forward flow exercising of these valves can be verified manually.Exercising these valves during operation would require entry into the containment.

Also, there is no method to prevent actuation of the relief valves that discharge into these discharge lines, placing personnel at risk if exercising was performed.

Therefore, quarterly testing is impractical during power operations for personnel safety reasons.The closed exercise is satisfied by witnessing the valves return to the closed position after the valves have been manually open exercised.

This cold shutdown justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L).

Perform valve exercising (open, closed) during cold shutdown when containment entry is possible without concerns for personnel safety.Alternate Testing: 3.2-8 Rev. 13 Cold Shutdown Justification CS-9 System: Reactor Water Cleanup System (G33)Valves: 1G33-FOO1, IG33-F004, IG33-F039, IG33-F040, IG33-F053, IG33-F054 Category:

A Class: 1 Function:

To provide containment isolation of the Reactor Water Cleanup System.Test Requirements:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.The Reactor Water Cleanup System is inservice during normal plant operation and provides a backup function in post accident cleanup. This system ensures that reactor coolant pH, chlorides, conductivity, and activity are maintained within specified limits.These limits are to prevent the likelihood of exceeding 10CFR100 guidelines or allowing stress corrosion cracking of the stainless steel systems which is important since the facility is currently monitoring indicated feedwater nozzle cracks for size propagation.

A closure of any valve during surveillance testing would require the removal of the system from service causing prolonged system inoperability.

PNPP (BWR6) has "hot leg" RWCU pumps with pump seal run times greater than 5 years. The thermal transients placed on our RWCU CAN-6 pump seals during a shutdown from rated temperature and pressure significantly increases the chance of a RWCU pump seal failure. Seal failure results in an expensive and dose intensive work activity (approximately

$300,000.00 and 1.5 Rem). Therefore, quarterly testing is impractical due to unnecessary system equipment challenges.

This cold shutdown justification had been previously found to be acceptable as CS-10 in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L) and FENOC response to an RAI dated February 26, 2001 (PY-CEI/NRR-2549L).

Exercise valves during cold shutdown when plant conditions permit isolation of RWCU to preclude unnecessary system equipment challenges.

Alternate Testing: 3.2-9 Rev. 13 Cold Shutdown Justification CS-10 System: Containment Atmosphere Monitoring System Valves: 1D23-F010A, 1D23-F010B, 1D23-F020A, 1D23-F020B, 1D23-F030A, 1D23-F030B, 1D23-F040A, 1D23-F040B, 1D23-F050 Category:

A Class: 2 Function:

Provide instrumentation isolation in case of an instrument line failure to maintain containment integrity.

Test Requirements:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.The Containment Atmosphere Monitoring System provides highly reliable instrumentation for detecting abnormal conditions in the containment, drywell and the suppression pool, and for monitoring of these areas after postulated accidents.

These valves have a normal and accident position as open. Opening and closing of these valves will cause unanalyzed perturbations which may initiate the trip logic associated with the instrumentation being isolated, which could cause a plant shutdown to occur. These valves affect instrumentation for five (5) Emergency Safety Feature Systems and more than ten (10)Limiting Condition of Operation Technical Specifications.

Therefore, quarterly testing is impractical since testing could result in a plant trip.This cold shutdown justification had been previously found to be acceptable as CS-11 in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L).

Exercise valves during cold shutdown when plant conditions permit closure of these valves without the potential for a plant trip.Alternate Testing: 3.2-10 Rev. 13 Cold Shutdown Justification CS-lI Systems: Residual Heat Removal (RHR)Valves: IE12-F037A, 1E12-F037B Category:

A Class: 2 Function: These valves are used during refueling activities to provide an alternate mode of reactor vessel shutdown cooling when reduced turbulence and improved water clarity is necessary.

Test Requirements:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.These valves (IE12-F037A and 1E12-F037B) provide isolation between the RHR System and the Upper Containment Pool (UCP). A reactor pressure interlock is provided to prevent inadvertent valve opening above 135 psig. Overriding this interlock to test these valves will provide an alternate flow path that would divert flow from the reactor vessel if a LPCI initiation were to occur. Also testing would open an isolation boundary between the higher energy piping upstream of the interlocked valve and the lower energy piping downstream of the interlocked valve.Therefore, quarterly testing is impractical due to system design and the potential for equipment damage.This cold shutdown justification had been previously found to be acceptable as CS-12 in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L) and FENOC response to an RAI dated February 26, 2001 (PY-CEI/NRR-2549L).

Exercise valves during cold shutdown when reactor pressure has been reduced to a level that the potential for equipment damage is not a concern.Alternate Testing: 3.2-11 Rev. 13 Cold Shutdown Justification System: Valve: CS-12 Residual Heat Removal Head Spray Line (E12)1E12-F019 Category:

AC Class: 1 Function: Provide a flowpath for RHR spray to the reactor vessel dome to condense steam accumulated in the upper portion of the reactor vessel.Test Requirement:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.Basis of Justification:

This simple check valve is within the normal flowpath for RHR spray to the reactor vessel head. The simple check valve has no external means for exercising and must rely on system operation (i.e., change in flow)to ensure that the valve opens to the position required to fulfill its function.During plant operation this normally closed check valve performs a pressure isolation safety function.Its safety function prevents over-pressurization of the Residual Heat Removal Loop A low pressure piping from either 1) reactor vessel pressure or 2) RCIC operation when controlling RPV level and pressure.Therefore, system/component design makes compliance with the quarterly open exercise requirements impractical.

Each plant shutdown to cold conditions should allow RHR head spray to be periodically initiated.

Spraying the reactor vessel dome condenses steam accumulated in the upper portion of the reactor vessel. Initiation of head spray flow provides for a full-stroke exercise open of the check valve to fulfill its function.

The Integrated Operating Instruction (101) note's that if only one RHR loop is to be used for Shutdown Cooling, it is preferable to use RHR Loop A because only this loop is capable of head spray.This had been previously found to be acceptable, as a valve relief request, in a NRC Safety Evaluation dated April 5, 1993 (Log No. PY-NRR/CEI-0629L).

Perform valve open exercise during cold shutdowns when RHR Loop A is capable of initiating head spray.Alternate Testing: 3.2-12 Rev. 13 Cold Shutdown Justification CS-13 System: Reactor Core Isolation Cooling (E51)Valves: IE51-F065, 1E51-F066 Category:

AC Class: 1 Function: These check valves provide the normal flowpath for RHR spray to the reactor vessel head and RCIC operation controlling RPV level and pressure.Test Requirement:

Basis of Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.These simple check valves are within the normal flowpath for both 1) RHR spray to the reactor vessel head and 2) RCIC operation when controlling RPV level and pressure.

Both check valves have their own unique external exercising device. These valves satisfy the necessary open obturator movement by;relying on system operation (i.e., change in flow) or using the external exercising device.During plant operation, these normally closed check valves perform the reactor coolant system (RCS)pressure isolation safety function.

Their safety function is required to prevent over-pressurization of either the Residual Heat Removal A Loop and/or the RCIC System low pressure piping.Additionally, limitations exist for the external exerciser's use. Both exercisers will not properly function unless minimum resistance to obturator movement (i.e., low differential pressure) exists.Therefore, system/ valve design makes compliance with the quarterly open exercise requirements impractical.

Testing during plant shutdown to cold conditions could be accomplished by initiating RHR head spray.Spraying the reactor vessel dome condenses steam accumulated in the upper portion of the reactor vessel. Initiation of head spray flow provides the conditions to satisfy a full-stroke exercise open of both check valves to the position required to fulfill its function.

The Integrated Operating Instruction (101) note's that if only one RHR loop is to be used for Shutdown Cooling, it is preferable to use RHR Loop A because only this loop is capable of head spray.3.2-13 Rev. 13 Cold Shutdown Justification CS-13 (Continued)

Exercising the check valves open using the RCIC system, (i.e., during plant operation, for controlling RPV level and pressure) would be considered an Emergency Safety Feature (ESF)actuation.

If the initiation was caused by Level 2 in the reactor vessel or manual initiation it would trip the Main Turbine and Reactor Feed Pump Turbines.As such RCIC system operation would not be considered an option to satisfy the quarterly open exercise.Additionally, during plant cold shutdown conditions local access would be afforded for use of the check valve external exercisers.

However, the operation of these exercisers would still be limited by ALARA and test duration concerns.This had been previously found to be acceptable, as a valve relief request, in a NRC Safety Evaluation dated April 5, 1993 (Log No. PY-NRR/CEI-0629L).

Alternate Testing: Perform valve open exercise during cold shutdowns by either 1) RHR Loop A initiating head spray or 2) for 1E51-F065 by using the external exercisers as plant conditions would dictate.3.2-14 Rev. 13 Refueling Outage Justification RO-I System: Residual Heat Removal System Valves: 1E12-F558A, 1E12-F558B Category:

AC Class: 2 Function: These check valves are located in the RHR Heat Exchangers vent line back to containment and serve as Containment Isolation Valves.Test Requirement:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.These check valves are located in an open ended line leading from the RHR Heat Exchangers to the drywell suppression pool. To verify that these valves exercise to the closed position requires installation of test equipment inside containment and installation of a blank flange, also located in the containment.

This evolution would cause an open flowpath from the drywell to the containment during the time required for installation and removal of this flange. The verification that these valves exercise to the open position also requires test equipment to be installed inside the containment, increasing the exposure to radiation of those involved in the testing.Therefore, quarterly or cold shutdown testing is impractical due to system design and geometry as well as personnel radiation exposure.This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L)

As an alternative to the exercise requirements of the OM Code, these valve may be included in the Check Valve Condition Monitoring Program per ISTC-5222 and Appendix II.or Exercising to verify open and closed positions shall be performed on a refueling outage frequency when plant conditions allow a containment entry to facilitate the use of temporary test equipment without exposing personnel to excessive radiation.

Alternate Testing: 3.2-15 Rev. 13 Refueling Outage Justification RO-2 System: As applicable Valves: lE51-F030, IP45-F575, IE21-F501, 1E22-F007 Category:

C Class: 2 and 3 Function: These complex (IE51-F030, IP45-F575, iE21-F501)and simple (IE22-F007) check valves perform different system functions which are described within the Basis for Justification.

Test Requirement:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.The complex valves are of a unique design called Duo-Check.

The Duo-Check design is constructed as an integral unit permitting removal and installation in the same manner as an ordinary pipe orifice. The valve's removal for inspection and exercising is accomplished without any disassembly of the obturator or its actuating components.

The exercise of a Duo-Check valve is similar to other check valves such as vacuum breakers whose obturator is exposed to permit direct observation.

1E22-F007 is a simple check and serves as the inboard valve of a series pair in the discharge path of a safety related keep fill pump. It provides the high to low pressure interface to prevent over-pressurization of the low pressure piping.1E51-F030 1E51-F030 is a check valve located in the supply line from the suppression pool (backup source) for the RCIC system. The preferred source of water for the RCIC system is the condensate storage tank (CST).PNPP maintains the RCIC system as a "clean" system with minimal internal contamination by preferentially using the CST as the water supply during normal RCIC system operation including testing. Minimizing RCIC system contamination supports ALARA goals as well as reduces radwaste generation resulting from system flushes.3.2-16 Rev. 13 Refueling Outage Justification RO-2 (Continued)

These operational considerations preclude establishment of flow in the involved line during plant operation, cold shutdowns or refueling outages.The system would have to be substantially redesigned and modified to perform the code required testing.Valve removal and inspection with exercising to assess operational readiness provides a reasonable alternative to the Code test method.At a refueling frequency valve removal and manual exercising with closure verification ensures operational readiness.

Proper orientation of this valve is achieved through direct visual observation.

Visual verification of orientation upon reinstallation is sufficient to ensure operability and is the only practical method since initiation of flow through this line is undesirable.

1P45-F575 1P45-F575 is a check valve in a line providing an alternative emergency source of water from the Emergency Service Water (ESW) system (i.e., raw untreated water from Lake Erie) for the RHR system.This valve is one valve in a series of three normally closed valves. Flow through this line is extremely undesirable except under actual emergency conditions.

This emergency line-up is never expected to be used.These operational considerations preclude establishment of flow in the involved line during plant operation, cold shutdowns or refueling outages.The system would have to be substantially redesigned and modified to perform the code required testing.Valve removal and inspection with exercising to assess operational readiness provides a reasonable alternative to the Code test method.At a refueling frequency valve removal and manual exercising with closure verification ensures operational readiness.

Proper orientation of these valves is achieved through direct visual observation.

Visual verification of orientation upon reinstallation is sufficient to ensure operability and is the only practical method since initiation of flow through this~line is undesirable.

3.2-17 Rev. 13 Refueling Outage Justification RO-2 (Continued) 1E21-F501 1E21-F501 is a check valve in the LPCS minimum flow and test return to the suppression pool. This valve is exercised open quarterly by obtaining proper LPCS flow. The piping configuration does not include isolation capability downstream of the check valve, precluding closure verification without installation of a blind flange.Installation of the blind flange requires extensive preparation, equipment staging and would result in a significant period of inoperability of the LPCS (estimated 1 -2 days).Although the possibility exists to perform this reverse flow test during refueling outages, the test requires expenditure of significantly more resources than simply removing the valve for exercise testing.Also this valve is a TRW Mission Duo check valve, which when removed may be better assessed by visual inspection rather than by testing. When removed the check valves spring tangs and hinge pin may be inspected to ensure they have not failed or worn to the point of failure. Therefore, it is impractical to test when the disassembly, inspection and reassembly of the valve provides a superior assessment of the valves functionality.

At a refueling frequency valve removal and manual exercising including closure verification ensures operational readiness.

Visual verification of proper orientation during installation and verification of flow after installation ensures operability.

1E22-F007 System configuration does not include test connections, which precludes closure verification of the IE22-F007.

The system would have to be redesigned and modified to allow performance of the quarterly or cold shutdown Code required testing.Disassembly and inspection of this valve to assess its' closure capability will be performed in accordance with the Code at a refueling outage frequency.

3.2-18 Rev. 13 Refueling Outage Justification Alternate Testing: RO-2 (Continued)

This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328)(Log No. PY-NRR/CEI-0989L) and FENOC response to an RAI dated February 26, 2001 (PY-CEI/NRR-2549L).

As an alternative to the exercise requirements of the OM Code, these valve may be included in the Check Valve Condition Monitoring Program per ISTC-5222 and Appendix II.or At a refueling frequency each valve is removed and manually exercised including closure verification.

Visual verification of proper orientation is performed upon reinstallation.

3.2-19 Rev. 13 Refueling Outage Justification RO-3 System: Nuclear Closed Cooling Water System (P43)Valves: 1P43-F055, 1P43-F140, 1P43-F215, IP43-F355, 1P43-F400, 1P43-F410 Category:

A (IP43-F055, 1P43-F140, IP43-F215)

B (IP43-F355, 1P43-F400, 1P43-F410)

Class: 2 Function: Containment (i.e., drywell and primary) isolation valves for cooling water to the reactor recirculation coolant pumps and other safety-related systems.Test Requirements:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.These valves are the inlet and outlet isolation valves for nuclear closed cooling water. Closing these valves would result in a loss of cooling water to the reactor recirculation pumps and motors causing serious damage to the equipment.

The recirculation pumps are used during all modes of operation except for refueling to prevent reactor vessel water stratification.

Therefore, conformance to the quarterly and cold shutdown requirements are impractical for the facility due to the potential for equipment damage.This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L).

Exercise valves during each refueling outage when the reactor recirculation pumps can be removed from service.Alternate Testing: 3.2-20 Rev. 13 Refueling Outage Justification RO-4 System: Reactor Water Cleanup (G33)Valves: 1G33-F052A, 1G33-F052B Category:

C Class: 2 Function:

Normal return flow path for Reactor Water Cleanup (RWCU) water to the reactor vessel via feedwater.

Test Requirements:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.These simple check valves are within the normal flowpath for reactor water cleanup return to feedwater system. The RWCU returns to the Residual Heat Removal (RHR) shutdown cooling return line, which then returns to Feedwater (FW). The current test method requires access to the steam tunnel, which is inaccessible during power operations and a high radiation and highly contaminated area during cold shutdowns.

Also, testing requires the isolation and venting of the RWCU return line to the reactor vessel (via the FW system). The RWCU system is necessary for cleanup and chemistry control caused by transients (i.e., shutdowns) and loss of this capability could prolong any shutdown.

Therefore, quarterly or cold shutdown testing is impractical due to unnecessary removal of plant safety systems (Residual Heat Removal shutdown cooling and Feedwater) from service resulting in unnecessary cycling of safety related systems. Also testing would result in unnecessary personnel radiation exposure.This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L) and FENOC response to an RAI dated February 26, 2001 (PY-CEI/NRR-2549L).

Valve exercising to the opened and closed position shall be performed during refueling outages when RWCU can be removed from service and when the steam tunnel can be safely entered with out exposing personnel to excessive amounts of radiation.

Alternate Testing: 3.2-21 Rev. 13 Refueling Outage Justification RO-5 System: Nuclear Boiler Valves: 1B21-F036C, D, G, H, J, K, M, N, R, S IB21-FO36U, 1B21-F039A, B, E, F, L, P, T, V Category:

C Class: 3 Function:

To prevent depressurization of the non-ADS SRV's air accumulators on a loss of instrument air and the ADS SRV's air accumulators on a loss of Safety Related Instrument Air.Test Requirement:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.To perform the open and close exercise of these non-ADS and ADS accumulator supply check valves on a quarterly or cold shutdown frequency, access is required into the drywell for valve manipulations, test equipment installation and depressurization of the instrument air. Performance of these tests during operation would expose personnel to high neutron radiation.

During Cold Shutdowns, personnel would still experience unnecessary radiation exposure.

This testing would also make the Instrument Air System (which supplies engineered safety features systems) to the containment and drywell and the Safety Related Instrument Air System inoperative for an extended period of time.Therefore, quarterly or cold shutdown testing is impractical due to isolation of instrument air to safety-related systems and extensive test setup time.This refueling outage justification had bee previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L).

Perform valve exercising (open, closed) during refueling outages when the drywell can be safely entered without exposing personnel to excessive amounts of radiation.

Alternate Testing: 3.2-22 Rev. 13 Refueling Outage Justification RO- 6 System: Fire Service Carbon Dioxide (P54)Valve: 1P54-F1098 Category:

AC Class: 2 Function: This valve is the inboard containment isolation valve for the Recirculation Pump Carbon Dioxide System. Upon sensing a fire (heat) the C02 is designed to extinguish the fire by releasing a measured amount of carbon dioxide to the affected area.Test Requirement:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.To adequately exercise the carbon dioxide supply check valve in the open and closed direction requires isolation of the penetration, which in turn would require an alternate method of extinguishing a possible fire (local C02 fire extinguishers) being available.

Access to the drywell is not available during operation or during all normal cold shutdowns in order to stage the alternate method of fire extinguishment.

Therefore, quarterly or cold shutdown testing is impractical due to personnel and equipment safety.This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L).

As an alternative to the exercise requirements of the OM Code, these valve may be included in the Check Valve Condition Monitoring Program per ISTC-5222 and Appendix II.or Perform valve exercising in the open and closed directions during refueling outages when the drywell is accessible.

Alternate Testing: 3.2-23 Rev. 13 Refueling Outage Justification RO-7 Systems: As applicable Valves: 1E22-F039, IE51-F021, IE51-F040, 1E51-F090 Category:

AC Class: 2 Function:

These check valves serve various functions to allow for proper operation of the HPCS and RCIC systems. Each valve's function will be described briefly in the Basis for Justification.

Test Requirements:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.Basis for Justification:

RCIC Pump Minimum Flow Check Valve 1E51-F021 allows for pump minimum flow when operating in a shutoff head or low flow conditions and rapid penetration isolation on loss of pump prior to closure of the containment isolation valve.RCIC Turbine Exhaust Line Check Valve lE51-F040 allows for turbine exhaust steam to be transferred into the suppression pool as part of the heat cycle and rapid penetration isolation on loss of the turbine prior to closure of the containment isolation valve. Both of these check valves are located in the RHR "A" Heat Exchanger Room. Accessing the valves for testing requires entering a high radiation area during normal plant operation or cold shutdown when RHR "A" Loop is in the shutdown cooling mode of operation.

Verifying that these valves have been exercised to their closed seat position is performed utilizing standard seat leakage techniques which require significant test duration for valve lineups, equipment installation and removal.Check valve 1E22-F039 is located in the HPCS return line to the Condensate Storage Tank and serves as a thermal relief device to preclude an over pressure condition in this line. Opening of the valve is accomplished quarterly when the HPCS pump recircs back to the CST. However, verification of valve closure is performed using standard seat leakage techniques which require significant test duration for valve lineups, draining the main condensate return header, equipment installation and removal.3.2-24 Rev. 13 Refueling Outage Justification RO-7 (Continued)

Check valve 1E51-F090 is located in the RCIC return line to the Condensate Storage Tank and serves as a thermal relief device to preclude an over pressure condition in this line. Opening of the valve is accomplished quarterly when the RCIC pump recircs back to the CST. However, verification of valve closure is performed using standard seat leakage techniques which require significant test duration for valve lineups, draining the main condensate return header, equipment installation and removal.Therefore, quarterly and cold shutdown testing is impractical due to extended safety system unavailability as well as unnecessary personnel radiation exposure.This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L)

Alternate Testing: Verification of valve closure capability will be performed during refueling outages when system conditions permit sufficient time to perform seat leakage testing.or As an alternative to the exercise requirements of the OM Code, the 1E51-F040 valve may be included in the Check Valve Condition Monitoring Program per ISTC-5222 and Appendix II.3.2-25 Rev. 13 Refueling Outage Justification RO-8 System: Combustible Gas Control System Valves: IM51-F531A, 1M51-F531B, IM51-F532A, IM51-F532B, 1M51-F618A, 1M51-F618B Category:

C Class: 2 Function:

These sample line check valves allow automatic draining of condensate in sample lines and isolation to perform a localized sample.Test Requirements:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.Basis for Justification:

These sample line drain check valves are located inside the drywell and containment.

Access to the drywell is not available during plant operation or normal cold shutdowns.

Also, the erection of scaffolding over the suppression pool is not permitted during operation.

Performance of the open exercise requires passing air through the valves and monitoring the flowrate.

This task involves securing the hydrogen analyzer, installing blank flanges, hanging tags, erecting scaffolding inside containment over the suppression pool for test hookups and restoration after testing.Returning the Hydrogen Analyzer (CGC) to an operable status following testing will require a minimum of 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for temperature stabilization prior to declaring the system as operable.Ensuring that the valves have exercised to the closed position requires the Hydrogen Analyzer to be operating with access to each valve for installation of test equipment to allow measurement of the bypass flow. Since entry into the drywell is not always possible during each cold shutdown and scaffolding (or ladder) is required, establishing the test conditions places a significant impact on the plant by the extended duration for test setup.This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L) 3.2-26 Rev. 13 Refueling Outage Justification RO-8 (Continued)

Alternate Testing: Perform the open and close exercise tests during refueling outages when sufficient time exists for the installation of temporary test equipment and scaffolding.

3.2-27 Rev. 13 Refueling Outage Justification RO- 9 System: Residual Heat Removal System Valves: 1E12-F063A, 1E12-F063B, 1E12-F063C, 1E12-F086 Category:

C Class: 2 Function:

These "simple" check valves, 1E12-F063A, 1E12-F063B, 1E12-F063C, and 1E12-F086 provide a means for alternate keepfill of the RHR loop. These valves are also used for system filling and maintenance flush purposes when required.Test Requirements:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.These check valves must close to prevent gross diversion of LPCI injection flow during accident conditions.

The Residual Heat Removal (RHR) Systems lack the design provisions to allow Quarterly or Cold Shutdown testing of these check valves without extending system outages for the associated RHR loop.By design the valves must open slightly to provide sufficient flow to maintain RHR pressurized when used for Alternate Keepfill.

To maintain RHR pressurized per the USAR, takes approximately 1 gpm for each loop to account for all boundary valve leakage. This flowrate would require these 8 inch check valves to barely break away from their closed seats and may only open one of the two seats on these duo disk check valves. To establish a flow path to ensure the valves are opening sufficiently to verify closure would generate several hundreds of gallons of radwaste.

Based on the low flow rate for Alternate Keepfill and radwaste generation, non-intrusive testing would be impractical to verify valve closure.The only means of adequately verifying valve closure is to disassemble and exercise these check valves.Disassembly of these check valves again requires an extended period of inoperability for the associated RHR loop.3.2-28 Rev. 13 Refueling Outage Justification RO-9 (Continued)

The time involved would include tagging, draining, transport to test shop, test equipment setup, testing, transport back to field, tag removal, and filling and venting. Also only a single air operated butterfly valve exists for isolation from the remainder of the PII system. Failure of this butterfly to provide isolation for check valve removal would require inoperability of the P11 system. Therefore, quarterly and cold shutdown testing is impractical due to unnecessary challenges to safety systems, unnecessary personnel radiation exposure as well as limitations of system design (inability to perform in-situ leak testing).These check valves have no safety function to open.However, when open they must close if the associated system initiates to ensure bypassing of injection flow does not occur. The opening function of these valves is an operational convenience.

This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L) and FENOC response to an RAI dated February 26, 2001 (PY-CEI/NRR-2549L).

Alternate Testing: Perform valve exercising (open, closed) during refueling outages in conjunction with the check valve disassembly program and ISTC-5221(C).

or As an alternative to the OM Code requirements the valves may be included in the Check Valve Condition Monitoring Program per ISTC-5222 and Appendix II.3.2-29 Rev. 13 Refueling Outage Justification RO-10 System: Standby Liquid Control (C41)Valves: 1C41-F006, 1C41-F007 Category:

AC Class: 1 Function:

Standby Liquid Control Injection Check Valve Test Requirements:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.To verify that these check valves exercise to the open position during normal operation would require firing a squib valve and injecting water into the reactor vessel using the SLC pumps. Injecting water during operation could result in adverse plant conditions such as changes in reactivity, power transients, thermal shock induced cracking, a dramatic change in plant water chemistry, and a possible plant trip.Verification of closure capability of these valves will be satisfied by obtaining a satisfactory seat leakage measurement.

Verifying valve closure by any other means is not practical.

This testing method requires prolonged periods in the drywell for isolating and draining of the injection line, causing increased radiation exposure.

Therefore, quarterly and cold shutdown testing is impractical due to prolonged periods of SLC inoperability, increased exposure to radiation, and extensive test setup time.This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L).

Perform valve exercising (open, closed) during refueling outages when water can be injected into the vessel by SLC and a drywell entry can be made to perform seat leakage testing.Alternate Testing: 3.2-30 Rev. 13 Refueling Outage Justification RO-11 System: Residual Heat Removal Shutdown Cooling (E12)Valves: 1E12-F050A, 1E12-F050B Category:

AC Class: 2 Function:

Provide a flowpath for RHR water for shutdown cooling (e.g., using the feedwater nozzles).Test Requirement:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.These simple check valves are within the normal flowpath for shutdown cooling (e.g., using the feedwater nozzles).

The valves are normally closed during plant operation and require forward flow exercising.

Initiation of shutdown cooling is used to verify forward flow exercising.

Both loops of shutdown cooling may not be required during cold shutdown.

The initiation of a loop of shutdown cooling requires flushing of the system generating thousands of gallons of liquid radwaste that would have to be processed.

Therefore, compliance with the quarterly and cold shutdown requirements is impractical since the generation of massive amounts of liquid radwaste is undesirable.

Verification of valve closure capability will be satisfied by obtaining a satisfactory seat leakage measurement.

Verifying valve closure by any other means is not practical.

This test requires isolation of a loop of feedwater, reactor water cleanup, shutdown cooling, and involves entry into the drywell and steam tunnel (includes scaffolding).

Therefore, quarterly or cold shutdown testing is impractical due to causing prolonged losses of reactor vessel heat removal sources and loss of cleanup water source, and increased exposure to radiation.

This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L) and FENOC response to an RAI dated February 26, 2001 (PY-CEI/NRR-2549L).

3.2-31 Rev. 13 Refueling Outage Justification RO-Il (Continued)

Alternate Testing: Perform valve exercising (open and closed) during refueling outages when plant conditions permit forward exercising and the performance of seat leakage testing.3.2-32 Rev. 13 Refueling Outage Justification RO- 12 System: Valve: Category: Class: Function: Residual Heat Removal Head Spray Line (E12)1E12-F019 AC 1 Provide a pressure isolation safety function preventing over-pressurization of the Residual Heat Removal Loop A low pressure piping from either 1) reactor vessel pressure or 2) RCIC operation when controlling RPV level and pressure.Test Requirement:

Basis of Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.This simple check valve is within the normal flowpath for RHR spray to the reactor vessel head. The valve has no external means for exercising and must rely on system operation (i.e., cessation or reversal of flow) to ensure that the valve seats/closes.

During plant operation this normally closed check valve performs a pressure isolation safety function.Its safety function prevents over-pressurization of the Residual Heat Removal Loop A low pressure piping from either 1) reactor vessel pressure or 2) RCIC operation when controlling RPV level and pressure.Therefore, system/component design makes compliance with the quarterly exercise closed requirement, by observing that the obturator travels to the seat on cessation or reversal of flow, impractical.

Each plant shutdown to cold conditions could require RHR head spray to be periodically initiated providing for a full-stroke exercise open. The closure of the check valve on cessation of flow is unverifiable.

The RHR head spray line is design such that no system operation or instrumentation exists that would provide positive means for closure verification.

Check valve's with a safety function to provide pressure isolation are designated Category AC.Category AC valves shall be leakage tested in 3.2-33 Rev. 13 Refueling Outage Justification RO-12 (Continued) accordance with ISTC-3630, Leakage Rate for Other Than Containment Isolation Valves. The seat leakage testing is to verify the valve's seat leak-tight integrity.

Per ISTC-3630(a)

The tests are conducted at a frequency of at least once every 2 years, which would agree with refueling outages. Therefore since this check valve's closure is unverifiable, observation by an other indicator such as the seat leakage testing is an acceptable test.This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L) and FENOC response to an RAI dated February 26, 2001 (PY-CEI/NRR-2549L).

Alternate Testing: Perform valve closure exercise during refueling outage when is capable of being tested for seat leakage.3.2-34 Rev. 13 Refueling Outage Justification RO-13 System: Primary Containment Isolation Check Valves Valves: 1B21-F032A, 1B21-F032B, lCli-F122, IG41-F522, IN27-F559A, 1N27-F559B, 1P43-F721, 1P50-F539 Category:

AC Class: 1, 2 Function:

System check valves for systems penetrating primary containment.

Test Requirement:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.These check valves are the inboard and outboard primary containment isolation valves for systems that are inservice during plant operation.

These normally open check valves are required to be exercised to both the open and closed position.

The closed position exercise is verified by leakage testing while the open exercise is accomplished when the systems are placed back into service, generally following a refueling outage. The only exception to this is lCli-F122, which can only be exercised open by inserting a reactor scram. Attaining the desired system flow ensures that the valves have been exercised open while attaining a satisfactory leakage rate verifies the valves exercised closed.Therefore, quarterly or cold shutdown testing is impractical due to prolonged periods of component inoperability and increased exposure to radiation.

These valves are listed below with a description of the system needs during operation or cold shutdown.This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L) and FENOC response to an RAI dated February 26, 2001 (PY-CEI/NRR-2549L).

3.2-35 Rev. 13 Refueling Outage Justification RO-13 (Continued)

Alternate Testing: Perform valve lCli-F122 exercising in the open and closed directions during refueling outages. Valves 1B21-F032A, 1B21-F032B, IG41-F522, IN27-F559A, IN27-F559B, IP43-F721, and IP50-F539 will be exercised closed during refueling outages as well as verified open quarterly.

As an alternative to reverse exercising during each refueling outage, valves lCll-F122, 1G41-F522, IP43-F721, and IP50-F539 may be placed in the Check Valve Condition Monitoring Program and reverse exercised in conjunction with seat leakage testing at the Option B frequency.

With the exception of lCll-F122, these valves are open during normal plant operation and normally remain open during cold shutdown, therefore, imposing restrictions to exercise to the open and closed position to allow use of nonintrusive test techniques is not practical.

Valve No's.1B21-F032A, B IN27-F559A, B IC1l-F122 IG41-F522 System Description These valves are the feedwater inboard and outboard containment isolation valves. The Feedwater System is the normal method of level control for the reactor vessel. Testing of these valves can only be performed during prolonged shutdowns when other sources of level control are available and area radiation levels are reduced. Therefore, quarterly or cold shutdown testing is impractical due to prolonged system shutdowns and unnecessary exposure to radiation.

This valve is the inboard containment isolation valve for the Control Rod Drive System. The CRD System is required for normal rod motion and cooling of the control rod drive mechanisms.

Thus, testing of this valve can only be performed during prolonged shutdowns when a reactor scram can be inserted and rod movement and cooling is not required.

Therefore, quarterly or cold shutdown testing is impractical due to prolonged shutdowns, isolation of cooling water to the CRD's and unnecessary exposure to radiation.

This valve is the inboard containment isolation valve for the Fuel Pool Cooling and Clean-up System. The FPCC System is required to remove heat and maintain the purity, clarity, and level of water in the upper containment pools. Thus, testing of this valve can only be performed during prolonged shutdowns.

Therefore, quarterly or cold shutdown testing is impractical due to prolonged shutdowns and unnecessary exposure to radiation.

3.2-36 Rev. 13 Refueling Outage Justification RO-13 (Continued)

Valve No's.1P43-F721 1P50-F539 System Description This valve is the inboard containment isolation valve for the Nuclear Closed Cooling System. The NCC System is required to supply cooling water to numerous plant components which include: control complex chillers, fuel pool cooling and cleanup heat exchangers, air system compressors, reactor water cleanup pumps, CRD hydraulic pumps, drywell coolers, reactor recirculation pumps, and containment chillers.

Thus, testing of this valve can only be performed during prolonged shutdowns.

Therefore, quarterly or cold shutdown testing is impractical due to prolonged shutdowns and unnecessary exposure to radiation.

This valve is the inboard containment isolation valve for the Containment Vessel Chilled Water System. The CVCW System is required to maintain the containment environment acceptable for equipment qualification and personnel occupancy.

Thus, testing of this valve can only be performed during prolonged shutdowns.

Therefore, quarterly or cold shutdown testing is impractical due to prolonged shutdowns and unnecessary exposure to radiation.

3.2-37 Rev. 13 Refueling Outage Justification RO-14 Systems: Residual Heat Removal (RHR)Valves: 1E12-F550 Category:

AC Class: 1 Function:

Provides Pressure Isolation for the Reactor Coolant Pressure Boundary System and provides thermal relief for the shutdown cooling suction penetration.

Test Requirements:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.During cold shutdowns, technical specifications require that two modes of shutdown cooling and two ECCS systems be maintained operable unless the plant is in the refueling mode with the reactor vessel head removed and the cavity flooded. Open and closed exercising of this valve, which is located in the shutdown cooling supply line, is accomplished by performing leak rate testing. To perform this testing in any mode other than refueling, renders one or more ECCS and shutdown cooling modes inoperable, in violation of Technical Specifications.

Testing of this valve during the actual refueling outage ensures that adequate alternate means of decay heat removal exists and enhances system availability.

Therefore, performing the open and close exercising of the 1E12-F550 simple check valve quarterly or during cold shutdown is impractical due to prolonged system inoperability and an increased exposure to radiation.

This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L).

Perform valve open and closed exercising during refueling outages when plant conditions permit testing without violating Technical Specifications.

Alternate Testing: 3.2-38 Rev. 13 Refueling Outage Justification RO-15 System: Emergency Closed Cooling System (P42)Valves: P42-F260A, P42-F260B, P42-F265A, P42-F265B Category:

B Class: 3 Function:

These valves provide an alternate emergency cooling water supply to the fuel pool cooling and cleanup (FPCC) System Heat Exchangers upon loss of nuclear closed cooling (NCC) water due to a loss of coolant accident (LOCA) or system inoperability.

Test Requirement:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.The design of the FPCC system allows two methods of supplying cooling water to the FPCC Heat Exchangers.

The supply methods include: 1) normal closed cooling water supply using Unit 1, Nuclear Closed Cooling System, 1P43; 2) alternate emergency cooling water supply using Unit 1, Emergency Service Water (ESW)System, 1P45. Therefore, the alternate emergency cooling water supply (IP45) must be available within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> upon loss of the normal closed cooling water supply (IP43).The emergency service water spectacle flanges were removed due to the safety concern raised over the 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> duration required for flange rotation, thus making these P42 valves the new interface between the closed loop cooling and the open loop cooling system.This alternate emergency cooling water supply (IP45)should be used only as a last resort since this would adversely affect the water chemistry of the NCC system (IP43) and eliminates the closed loop barrier establishing a potential direct leakage path for radioactive water into an open loop system (1P45).3.2-39 Rev. 13 Refueling Outage Justification RO-15 (Continued)

Thus, these valves are to be exercised on a refueling outage frequency when the FPCC Hx can be removed from service to allow valve cycling and minimal intrusion of ESW water into the NCC system. Upon completion of the exercise the FPCC Hx and portions of the NCC System require numerous flushes to remove the lake water. Therefore, quarterly or cold shutdown testing is impractical due to the increased likelihood of lake water intrusion and prolonged periods of system inoperability.

This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L).

Alternate Testing: Exercise valves during refueling outage to minimize the intrusion of lake water into the NCC system and when sufficient time exists to perform flushing.3.2-40 Rev. 13 Refueling Outage Justification RO-16 System: Standby Liquid Control (C41)Valves: IC41-F033A and 1C41-F033B Category:

AC Class: 2 Function:

Standby Liquid Control Pump Discharge Check Valves Test Requirement:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.These check valves are exercised to the open position (verified open) on a quarterly basis when the SBLC pumps are operated.

However, ensuring the closure capability of these valves requires isolation of a train of the Standby Liquid Control System, draining of a portion of the system and removal of a relief valve to measure seat leakage. Therefore, quarterly or cold shutdown testing is impractical due to the prolonged period of system inoperability.

This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L).

Alternate Testing: Perform valve exercising to performing the seat leakage outages.the closed position when test during refueling 3.2-41 Rev. 13 Refueling Outage Justification RO-17 System: Penetration Pressurization (P53)Valves: 1P53-F601A, 1P53-F601B, 1P53-F602A, IP53-F602B, 1P53-F633A, 1P53-F633B Category:

A, AC Class: 2 Function: The check valves supply air to the drywell airlock air accumulator system for the drywell air lock door seals. The drywell air lock door equalizing ball valves allow for air lock pressure equalization during operation.

Test Requirement:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.These check valves are only opened to charge the seal accumulators following seal pressurization, verification of adequate seal pressure ensures that the valves exercised open. Leak testing of the seal accumulator system is only required by Technical Specifications every 24 months, which verifies that the valves exercised closed. Entry through the drywell airlock, to exercising the check valves open, may not occur during every cold shutdown.

When tested at a refueling outage frequency, failure of the check valves to open after using the airlock door would be identified by a limit switch indication that one or both doors are open (i.e., the unsafe condition).

The ball valves are only utilized to equalize pressure across the airlock when making a drywell entry, which for the most part is only done during a refueling outage prior to the equipment hatch being removed. Failure of the ball valves to exercise to the open position would be detected by the inability to equalize pressure across the airlock door during cycling. Drywell airlock leakage testing, which is only required every 24 months, verifies that these ball valves were exercised to the closed position.3.2-42 Rev. 13 Refueling Outage Justification RO-17 (Continued)

After having been opened the drywell air lock door would require testing prior to plant startup. This testing would require that the drywell airlock blast shields be unlocked, pulled back for access to the airlock, sufficient time for Health Physics to establish a boundary, and Site Safety must be present for opening an unknown atmosphere.

This testing also requires significant test duration for valve lineups, equipment installation, stabilization time and equipment removal. It would be impractical on a quarterly or cold shutdown frequency to force the plant to enter the drywell just to open the drywell airlock check valves and ball valves that are being maintained in their accident positions.

Also an existing technical specification requires testing at a specified frequency.

This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L) and FENOC response to an RAI dated February 26, 2001 (PY-CEI/NRR-2549L).

Alternate Testing: Perform valve exercising (open, closed) during refueling outages when the drywell airlock doors are most likely to be used. Additionally, this frequency is consistent with that required by Technical Specifications.

3.2-43 Rev. 13 Refueling Outage Justification RO-18 System: Safety Relief Valves (SRV) and Reactor Head Vent Valves: 1B21-F037A, B, C, D, E, F, G, H, J, K, L, M, N, P, R, S, T, U, V 1B21-F078A, B, C, D, E, F, G, H, J, K, L, M, N, P, R, S, T, U, V 1B21-F040 Category:

C Class: 2, 3 Function:

Vacuum breakers ensure that the steam exhausted into the discharge lines equalizes to the environment's pressure.Test Requirement:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.The SRV and reactor head vent discharge vacuum breakers provide a means for releasing a vacuum developed in the discharge lines from condensing steam. The vacuum breakers are normally closed during plant operation.

Exercising of these valves to the open position can be verified manually, however, this would require entry into the drywell which is not permitted during operation and not normally required during cold shutdowns.

Also, there is no method to prevent actuation or steam seat leakage into the discharge lines, placing personnel at risk if exercising was performed.

Therefore, quarterly or cold shutdown testing would be impractical due to personnel safety and increased exposure to radiation.

Verifying that these valves exercised to the closed position will be performed during the manual exercise by witnessing the valves return to the closed position.This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L.

Perform valve exercising (open, closed) during refueling outages when potential for steam pressure does not exist for personal safety concerns and when drywell entry can be made without exposing personal to excessive levels of radiation.

Alternate Testing: 3.2-44 Rev. 13 Refueling Outage Justification RO-19 Systems: Nuclear Boiler (B21) and Safety Related Instrument Air (P57)Valves: 1B21-F024A, B, C, D 1B21-F029A, B, C, D IP57-F572B 1P57-F574B Category:

AC Class: 3 Function: Prevent depressurization of air accumulators on a Loss of Instrument Air and supply air for the exercising of the Main Steam Isolation Valves (MSIV). The Safety Related Instrument Air valves supply air to the outboard MSIV's from the Instrument Air system and isolate the Instrument Air system from the Safety Related Instrument Air system if the Instrument Air system is lost.Test Requirements:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.To adequately exercise these check valves in the open and closed directions requires instrumentation hook ups and valve manipulations that would make the associated MSIV's inoperative.

Performance of these tests require entry into the drywell (IB21-F024A/B/C/D) and the steam tunnel, which would expose personnel to high neutron radiation in the drywell and high gamma radiation in the steam tunnel (IB21-F029A/B/C/D, IP57-F572B, and IP57-F574B).

Therefore, quarterly or cold shutdown testing is impractical due to the increased radiation exposure, and safety concerns created.This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L) and FENOC response to an RAI dated February 26, 2001 (PY-CEI/NRR-2549L).

Perform valve exercising (open, closed) during refueling outages when entry into the drywell and steam tunnel is possible without exposing personal to excessive levels of radiation.

Alternate Testing: 3.2-45 Rev. 13 Refueling Outage Justification RO-20 System: Nuclear Boiler (B21)Valves: IB21-R011A-F, 1B21-R011A-G, IB21-RO11B-F, 1B21-R011B-G, IB21-R011C-F, IB21-R011C-G, IB21-R011D-F, 1B21-R011D-G Category:

AC Class: 2 Function: These check valves provide the flowpath for CRD water to the RPV level sensing line reference leg, preventing the buildup of non-condensable gases.Test Requirement:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.These valves are the safety interface between the RPV level reference leg and the non-safety portion of the CRD system. The instrument reference leg purge system provides a continuous water flow of approximately 0.002 gpm up to 0.020 gpm to prevent creation of a non-conservative instrument error. The instrument error is attributed to gases coming out of solution during a rapid depressurization event.These check valves are located in the containment building and require instrumentation/equipment to be connected to confirm the open and closed exercising.

The safety significance of this system and the additional radiation exposure that would be incurred during testing precludes the justification for testing during normal plant operation.

Therefore, quarterly or cold shutdown testing is impractical due to inoperability of a safety significant system and unnecessary exposure to radiation.

This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L) and FENOC response to an RAI dated February 26, 2001 (PY-CEI/NRR-2549L).

Perform valve exercising (open, closed) during refueling outages when the interruption of CRD water to the RPV level reference leg is possible.Additionally, performing these tests during refueling outages minimizes test personal to radiation exposure.Alternate Testing: 3.2-46 Rev. 13 Refueling Outage Justification RO-21 System: Feedwater Leakage Control (N27)Valves: IN27-F739A, IN27-F739B, IN27-F742A, IN27-F742B Category:

AC Class: 2 Function:

These valves allow a flowpath to the feedwater system during feedwater leakage control operations and provide a pressure isolation from the feedwater system during normal power operations.

Test Requirements:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.To perform the open exercising of these valves would require opening upstream valves 1N27-F737 and IN27-F740.

These valves are interlocked (feedwater header pressure must be <35 psig) to prevent full stroke exercising during normal operation.

Performance of both the open and closed exercise requires valve manipulations and equipment to be installed which would prolong system down time. In addition, these valves are located in the steam tunnel and testing during operation or cold shutdown would result in increased radiation exposure.Therefore, quarterly or cold shutdown testing is impractical due to prolonged system down time and increased radiation exposure.This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L).

Perform valve exercising (open, closed) during refueling outages when feedwater pressure is at an acceptable level and to minimize radiation exposure to test personnel.

Alternate Testing: 3.2-47 Rev. 13 Refueling Outage Justification RO-22 System: Parallel Instrument Air (P52)Valves: 1P52-F550 Category:

AC Class: 2 Function:

Supplies instrument air to various components throughout the containment and drywell.Test Requirement:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.Performing the open and close exercising of this valve could lead to a loss of instrument air to the containment and drywell. Components that could be affected by this loss of air are the inboard MSIV accumulators, non ADS SRV accumulators, RWCU Filter/Demineralizers, CRD HCU's, Scram Discharge Volume valves, Reactor Protection Air and miscellaneous control valves (B33, G33, G36, G50, G61, M11, M14, M16, P43 and P50). Isolation of the containment would not allow the instrument air header to be monitored in the control room since there is no instrumentation or alarm functions on that portion of the instrument air system. As a result normal instrument air leakage/usage could lead to anomalous component position changes (ventilation dampers closing, scram outlet valves could start to open causing their associated control rods to drift in, and MSIV's' could close on a decreasing pressure).

Also several other systems such as containment vessel cooling (MIl), containment and drywell purge (M14)could be lost creating habitability concerns in the containment.

Therefore, quarterly or cold shutdown testing is impractical due to potential unnecessary challenges to plant systems.This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L) and FENOC response to an RAI dated February 26, 2001 (PY-CEI/NRR-2549L).

3.2-48 Rev. 13 Refueling Outage Justification RO-22 (Continued)

Alternate Testing: Perform valve exercising (open, closed) during refueling outages when plant conditions permit the isolation of instrument air to the containment and drywell.As an alternative to reverse exercising during each refueling outage, this valve may be placed in the Check Valve Condition Monitoring Program and reverse exercised in conjunction with seat leakage testing at the Option B frequency.

3.2-49 Rev. 13 Refueling Outage Justification RO-23 System: Safety Related Instrument Air (P57)Valves: 1P57-F524A and 1P57-F524B Category:

AC Class: 2 Function: These check valves are located in the supply piping from the Safety Related Instrument Air receivers to the eight ADS SRV accumulators and one non-ADS accumulator.

They also serve as containment isolation valves.Test Requirement:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.To adequately exercise these check valves in the open and closed directions requires equipment installation and valve manipulations inside the containment that could possibly make the associated SRV's inoperative.

Therefore, testing to verify open and closed capability quarterly and during cold shutdown is impractical due to the increased radiation exposure and due to the necessity for isolation of the ADS SRV accumulator air supply. Isolation of the containment and drywell would not allow the safety related instrument air system header pressure to monitored in the control room since there is no instrumentation or alarms associated with that portion of the safety related instrument air system. If pressure were to decrease below 150 psig without being monitored the Safety Relief Valves (SRV's) would be inoperable without control room knowledge.

Therefore, quarterly or cold shutdown testing is impractical due to potential unnecessary challenges to a safety system.This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L) and FENOC response to an RAI dated February 26, 2001 (PY-CEI/NRR-2549L).

I 3.2-50 Rev. 13 Refueling Outage Justification RO-23 (Continued)

Alternate Testing: As an alternative to reverse exercising during each refueling outage, these valves may be placed in the Check Valve Condition Monitoring Program and reverse exercised in conjunction with seat leakage testing at the Option B frequency.

or Perform valve exercising (open, closed) during refueling outages when unnecessary challenges to a safety system is not a concern and when test personnel are not exposed to excessive levels of radiation.

3.2-51 Rev. 13 Refueling Outage Justification RO-24 System: High Pressure Core Spray Valves: IE22-F621, 1E22-F622 Category:

C Class: 2 Function:

Relieve vacuum in the HPCS discharge line to the suppression pool.Test Requirements:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.IE22-F621 and 1E22-F622 allow the HPCS full flow test line, leading to the suppression pool, to drain in a timely manner after the HPCS pump is secured. This in turn minimizes the potential for a damaging water hammer to occur if the HPCS system were called upon to restart. Verification that these internal spring check valves are closed is accomplished quarterly during HPCS pump operation by verifying no leakage past the seating surface. Testing to verify the full open capability of these vacuum breakers would require a clearance to be hung, removal of the vacuum breaker, testing of the vacuum breaker, reinstallation of the vacuum breaker, and the clearance to be removed. These actions combined would result in extended out of service time for the High Pressure Core Spray System. Therefore, quarterly or cold shutdown testing is impractical due to the increased inoperability of the HPCS system.This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L).

Perform valve exercising in the open direction during refueling outages when plant conditions permit the HPCS system to be removed from service and sufficient time exists for removal, testing and reinstallation of the vacuum breakers.Alternate Testing: 3.2-52 Rev. 13 Refueling Outage Justification RO-25 System: Reactor Core Isolation Cooling (E51)Valves: lE51-F065, 1E51-F066 Category:

AC Class: 1 Function: These check valves are part of the normal flowpath for RHR spray to the reactor vessel head and RCIC operation when controlling RPV level and pressure.Test Requirement:

Basis of Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.These simple check valves are within the normal flowpath for both 1) RHR spray to the reactor vessel head and 2) RCIC operation when controlling RPV level and pressure.

Both check valves have their own unique external exercising device.During plant operation, these normally closed check valves perform the reactor coolant system (RCS)pressure isolation safety function, with 1E51-F066 additionally serving a primary containment isolation (PCI) safety function.

Their RCS safety function closed is to prevent over-pressurization of either the RHR Loop A and/or RCIC System low pressure piping. The failure consequences for valve closure could be a loss of coolant accident (LOCA) outside of containment, which is an unanalyzed accident.Limitations exist for the external exerciser's use.Both exercisers will not properly function unless minimum resistance to obturator movement (i.e., low differential pressure) exists. Additionally, the exercisers provide positive means to verify opening, but the ability to determine valve closure does not exist. Therefore, system/component design makes compliance with the quarterly exercise closed requirement, by observing that the obturator travels to the seat on cessation or reversal of flow, impractical.

3.2-53 Rev. 13 Refueling Outage Justification RO-25 (Continued)

During plant operation these normally closed check valves perform a pressure isolation safety function.Its safety function prevents over-pressurization of the Residual Heat Removal Loop A low pressure piping from either 1) reactor vessel pressure or 2) RCIC operation when controlling RPV level and pressure.Therefore, system/component design makes compliance with the quarterly exercise closed requirement impractical.

Each plant shutdown to cold conditions could require RHR head spray to be periodically initiated.

Spraying the reactor vessel dome condenses steam accumulated in the upper portion of the reactor vessel. Initiation of head spray flow demonstrates full-stroke exercise open capability of the check valve. The closure of the check valve on cessation of flow is currently unverifiable.

The RHR head spray line is designed such that no system operation or instrument exists that would provide positive means for closure verification.

Check Valve's with a safety function to provide RCS pressure isolation are designated Category AC.Category AC valves shall be leakage tested in accordance with ISTC-3630, Leakage Rate for Other Than Containment Isolation Valves. The seat leakage testing is to verify the valve's seat leak-tight integrity.

Per ISTC-3630(a) the tests are conducted at a frequency of at least once every 2 years, which coincide with refueling outages. Therefore since these check valves are unable to be verified closed by other means, observation by an indicator such as the seat leakage testing is an acceptable test.This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L) and FENOC response to an RAI dated February 26, 2001 (PY-CEI/NRR-2549L).

Alternate Testing: Perform valve closed exercise during a refueling outage when RHR Loop A Head Spray Line is capable of being seat leakage rate tested.3.2-54 Rev. 13 Refueling Outage Justification RO-26 System: Primary Containment Isolation Check Valves Valves: IPII-F545, IP22-F577, IP51-F530, 1P86-F528 Category:

AC Class: 2 Function:

System check valves for systems penetrating primary containment.

Test Requirement:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.These check valves are the inboard containment isolation valves for systems of limited use during plant operation.

These normally closed check valves are required to be exercised in both the open and closed direction.

The closed position exercise is verified by leakage testing while the open exercise is accomplished during refueling outages when these systems are utilized more extensively.

Attaining a desired system flow ensures the valves have exercised to the open position while attaining a satisfactory leakage rate verifies the valves exercised to the closed position.

To adequately exercise these check valves to the closed position requires equipment installation and valve manipulations inside the containment which would result in prolonged periods of exposure to radiation.

Therefore, quarterly or cold shutdown testing is impractical due to prolonged periods of exposure to radiation with little to no benefit.This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L).

As an alternative to reverse exercising during each refueling outage, these valves may be placed in the Check Valve Condition Monitoring Program and reverse exercised in conjunction with seat leakage testing at the Option B frequency.

Perform valve exercising to the open and closed position during refueling outages when plant conditions allow flow through the valves and sufficient time exists to perform seat leakage testing.Alternate Testing: 3.2-55 Rev. 13 Refueling Outage Justification RO-27 System: Safety Related Instrument Air Valves: IP57-F555A, 1P57-F555B, 1P57-F556A, 1P57-F556B Category:

AC Class: 3 Function: System check valves that isolate the Non-Safety portion of the Safety Related Instrument Air System from the Safety Class portion.Test Requirement:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.These check valves provide the boundary between the non safety and safety portions of the Safety Related Air System. These valves are normally closed but do periodically partially open to provide makeup air to the safety related accumulators.

To exercise these valves to the open position would require depressurizing the safety related instrument air system in order to develop the dp required to open the valves. To verify that these valves have exercised to the closed position would require isolating the makeup system and installing test equipment so a leakage rate test can be performed.

Since this system supplies the air to the ADS SRV's, depressurizing the system to allow for testing would render the ADS SRV's inoperable.

Therefore, quarterly or cold shutdown testing is impractical due to making the ADS SRV's inoperable.

This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L).

Perform valve exercising (open, closed) during refueling outages. Open exercising will be verified when the Safety Related air accumulators are filled following maintenance activities during a refueling outage. Verification that the valves have exercised to the closed position will be performed by leakage rate testing prior to plant startup.Alternate Testing: 3.2-56 Rev. 13 Refueling Outage Justification RO-28 System: Containment Vessel and Drywell Purge Valves: 1M14-F045, 1M14-F055A, 1M14-F055B, 1M14-F060A, 1M14-F060B, 1M14-F065, 1M14-F070, 1M14-F085 Category:

A and B Class: 2 Function:

To provide Containment and Drywell isolation for the Containment and Drywell Purge System.Test Requirement:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.Basis for Justification:

These large (24", 36" and 42") air operated butterfly valves are considered inoperable during plant operations and are administratively sealed with a keylock switch.Valves 1M14-F055A, 1M14-F055B, 1M14-F060A, and 1M14-F060B (24") are provided in the Drywell purge lines, which supply air from the containment to the drywell, primarily during refueling outages. In addition to being administratively sealed, (Technical Specifications does not permit these valves to be opened during Modes 1, 2 and 3) the piping between these valves is flooded during normal operation to serve as a radiation shield against streaming.

Stroking of these valves on a quarterly or cold shutdown frequency would require draining the piping, performing valve manipulations and restoring the piping to a water filled status, all of which would be done inside the containment in a radiation environment.

Therefore, quarterly or cold shutdown testing is impractical due to technical specification violations and increased exposure to radiation if the system were drained.Valves 1M14-F045, 1M14-F065, 1M14-F070 and 1M14-F085 (36" and 42") are provided in the purge supply line to containment and purge exhaust line from the drywell. Technical Specifications does not permit these valves to be operated during Modes 1, 2 and 3 so these valves are administratively sealed closed during plant operations.

In addition, the Technical Specifications state that leakage rate testing is required every time the 42" containment isolation 3.2-57 Rev. 13 Refueling Outage Justification RO-28 (Continued) valves are opened. This additional leakage rate testing that could occur involves valves to be manipulated in the annulus structure, test equipment to be installed, and many hours of leak testing to allow for this large test volume to stabilize prior to recording leak rate data. Therefore, quarterly or cold shutdown is impractical due to technical specification violations, increased exposure to radiation if the system were drained and prolonged test setup times.Also, in accordance with ISTC-3570, "valves in a system declared inoperable or not required to be operable, the exercising test schedule need not be followed".

This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L).

Alternate Testing: Perform valve exercising and stroke time testing during refueling outages when Technical Specifications allow the valves to be exercised.

3.2-58 Rev. 13 Refueling Outage Justification RO-29 System: Fuel Pool Cooling Valves: IG41-F597A, 1G41-F597B Category:

C Class: 3 Function:

Provide isolation between the Surge Tanks and the Fuel Transfer Tube Drain System.Test Requirement:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.These check valves are in the discharge flow path of the Fuel Transfer Tube Drain Pumps which transfer water from the drain tank to the surge tanks. This system is only used during refueling operations and is considered inoperable during all other plant modes. Testing of this system to prove operability, including check valves 1G41-F597A and 1G41-F597B for their exercise open and close capabilities, is performed each refuel prior to fuel movement.In accordance with ISTC-3570, "valves in a system declared inoperable or not required to be operable, the exercising test schedule need not be followed".

This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L).

Alternate Testing: Perform valve exercising to the open position prior to fuel movement.and closed 3.2-59 Rev. 13 Refueling Outage Justification RO-30 System: Penetration Pressurization (P53)Valves: IP53-F572A, IP53-F572B, IP53-F573A, IP53-F573B, IP53-F574, IP53-F587A, IP53-F587B, 1P53-F588A, 1P57-F588B Category:

AC Class: 2 Function: These check valves supply air to the upper and lower containment airlocks air accumulator systems for the air lock door seals.Test Requirement:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.These check valves are opened routinely to charge the seal accumulators following seal pressurization, which occurs each time the doors are opened and closed. Verification of adequate seal pressure ensures that the valves exercised open. However, verifying that these check valves have exercised to the closed position can only be accomplished by performing a leak test. vLeak testing of the seal accumulator system is only required by Technical Specifications every 24 months, which verifies that the valves have exercised to the closed position.Verifying that these valves have exercised to the closed position requires significant test duration for valve lineups, equipment installation, stabilization time and equipment removal. In addition, each time this testing is performed the affected air lock can not be used for egress or ingress for a minimum of 10 hours1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br />. Therefore, quarterly or cold shutdown testing is impractical due to an existing technical specification requiring testing at a specified frequency.

This refueling outage justification had been previously found to be acceptable in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L).

3.2-60 Rev. 13 Refueling Outage Justification RO-30 (Continued)

Alternate Testing: Seat leakage testing of valves will be by conducting a seal pneumatic system leak test per technical specifications which also will perform the closed position verification.

Additionally, valves 1P53-F572B, F573B and F574 are in a series configuration; however, only one valve is needed to close in this series configuration.

Therefore, they will be tested as a unit per ISTC-5223. (Ref.CR 99-2553)3.2-61 Rev. 13 Refueling Outage Justification RO-31 System: Control Rod Drive Hydraulic System (ClI)Valves: lCll-115 (Typical of 177)Category:

C Class: 2 Function:

Accumulator Supply Check.Test Requirements:

Basis for Relief: Alternate Testing: ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.Check valve lCll-115 Exercise Close is satisfied by performance of surveillance procedure SVI-Cll-T2001 at least once every 2 years. 1Cli-115, Accumulator supply check valve testing is performed by securing the operating Control Rod Drive pump, and verifying a no accumulator fault condition exists, or that there is only a minimal pressure drop observed.

This testing is also supplemented by operational rounds every 7 days, where, HCU pressures are verified to be 1520 psig per Technical Specification surveillance requirement.

The surveillance testing must be performed in operational Modes 4 or 5 due to the necessity to secure the Control Rod Drive pump.Securing the Control Rod Drive pumps would result in loss of charging water pressure, loss of Control Rod Drive Mechanism cooling water, loss of Reactor Pressure Vessel level instrument purge flow, and the loss of cooling water to the reactor recirculation pump seals. Performing this surveillance during power operation would be impractical due to the potential for equipment damage or reactor scram.Accumulator supply check valve testing shall be performed at least once every 2 years during a refueling outage when the Control Rod Drive pumps can be secured.3.2-62 Rev. 13 Refueling Outage Justification RO-32 Systems: ECCS Waterleg Pump Check Valves (RHR, LPCS, HPCS, AND RCIC)Valves: Category: Class: Function: 1E12-F084A, 1E12-F084B, 1E12-F084C, 1E12-F085A, IE12-F085B, IE12-F085C, 1E21-F033, 1E21-F034, IE22-F006, 1E22-F007, lE51-F061, IE51-F062 C 2 To provide keep fill water for Emergency Core Cooling System discharge piping preventing possible water hammer.Test Requirements:

Basis for Justification:

ISTC-3510, '"Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.Forward flow exercising of these check valves would require system alignment for a flow path and measurement of an established flow rate. The Waterleg pumps' Comprehensive pump testing accomplishes both items, therefore pump Relief Request PR-I is applicable to these valves. The waterleg pumps were designed to be inservice to maintain functional systems (discharge/

suction piping) pressurized.

The waterleg pump normal discharge path must be redirected to perform safety-related Comprehensive pump testing. This would require racking out of the ECCS main pump breakers (RHR, LPCS, and HPCS) or isolation of the pump (RCIC) to prevent system damage due to waterhammer or cavitation upon receipt of an actuation signal. Also, a fill and vent of each ECCS System would be required after testing, prolonging the time these systems are in a non-standby readiness mode. Therefore, conformance with the exercise requirements is impractical for the facility due to prolonged safety system inoperability.

The appropriate time to demonstrate check valve full stroke capability is in conjunction with the biennial Comprehensive pump testing.3.2-63 Rev. 13 Refueling Outage Justification RO-32 (Continued)

This justification had been previously found to be acceptable as CS-13 in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L) and FENOC response to an RAI dated February 26, 2001 (PY-CEI/NRR-2549L).

Since the biennial Comprehensive pump tests will be performed during refueling outages CS-13 was changed to a Refueling Outage test justification.

Alternate Testing: Perform valve exercising (open) during refueling outages, in conjunction with the waterleg keepfill pumps' Comprehensive pump tests.3.2-64 Rev. 13 Refueling Outage Justification RO-33 Systems: Division 1, 2, 3 Diesel Generator Fuel Oil Transfer Systems, Safety-related Keep Fill Systems, and Reactor Core Isolation Cooling exhaust vacuum breakers.Valves: 1E12-F084A, IE12-F084B, IE12-F084C, IE51-FO61, IE51-F079, IE51-F081, 1R45-F577A, lR45-F577B, IR45-F578A, IR45-F578B, IR45-F579A and lR45-F579B Category:

C Class: 2 and 3 Function:

lEI2-F084A, IE12-F084B, IE12-F084C, and lE51-F061 are Class 2 simple check valves that are used as in-line check valves for the safety-related keep fill pumps discharge lines, for the Low Pressure Core Spray, Residual Heat Removal and Reactor Core Isolation Cooling systems.IR45-F577A, IR45-F577B, 1R45-F578A, IR45-F578B, IR45-F579A, and 1R45-F579B are Class 3 simple lift check valves that serve to break the potential siphon between the Fuel Oil Day Tank and the Fuel Oil Storage Tank thereby, preventing the Fuel Oil Day Tank from siphoning back to the Fuel Oil Storage Tank.1E51-F079 and 1E51-F081 are Class 2 simple lift check valves that serve to break the vacuum on the RCIC exhaust line thereby, ensuring suppression pool water is not drawn into the RCIC system piping due to condensing steam following RCIC shutdown.Test Requirements:

Basis for Justification:

ISTC-3510, "Exercise Test Frequency";

Active Category A, Category B, and Category C check valves shall be tested nominally every 3 months.IEI2-F084A/B/C and 1E51-F061 These simple check valves are the outboard checks of a series pair for the safety-related keep fill pump discharge.

They provide the high to low pressure interface to prevent overpressurization of the low pressure portion of the system.3.2-65 Rev. 13 Refueling Outage Justification RO-33 (Continued)

Both the associated inboard and involved outboard check valves are in close proximity to each other.The valves being in such close proximity make non-intrusive testing an option that is not preferred due to the difficulty in analyzing the test data (e.g., with acoustics it is difficult to determine which valve closed). Also with the system configuration it is difficult to get reversal/cessation of flow to close the valve with sufficient force to test. During refueling outages these valves are exercised open by verifying proper keep fill system flow during the Comprehensive pump tests.The associated inboard stop check valves can be verified closed using the manual handwheel.

The system configuration does not include test connections between the involved outboard valves and their associated inboard stop check valves.Therefore, the closure of the outboard check valves cannot be individually verified.

The system would have to be redesigned and modified to perform the code required testing. Disassembly and inspection of these valves on a sampling basis to assess their closure capability provides reasonable assurance of the valves operational readiness.

IR45-F577A/B, IR45-F578A/B, and IR45-F579A/B IR45-F577A and F578A, Division 1 Standby Diesel Generator Fuel Oil Transfer pump siphon breakers, 1R45-F577B and F578B, Division 2 Standby Diesel Generator Fuel Oil Transfer pump siphon breakers, and IR45-F579A and F579B, Division 3 HPCS Diesel Generator Fuel Oil Transfer pump siphon breakers are simple lift check valves. These valves break the potential siphon between the Fuel Oil Day Tank and the Fuel Oil Storage Tank to prevent the Fuel Oil Day Tank from siphoning back to the Fuel Oil Storage Tank. An attempt was made to comply with the ASME Code required Exercise Closed (EC) by using both the Dynasonics and Controlotron non-intrusive ultrasonic flow meters. The Dynasonics was unable to accurately measure flow since it required suspended solids for proper indication of flow, which, clean Number 2 fuel oil does not have. The Controlotrons were unable to accurately measure flow since they need certain physical attributes (e.g., 15 pipe diameters from 3.2-66 Rev. 13 Refueling Outage Justification RO-33 (Continued) flow disturbance) to be met for proper indication of flow, which, could not be met by the piping systems.Also the Controlotrons could not be physically installed in an area of the piping system with laminar flow (upstream side of check) for all the check valves. Acoustical testing was considered but not attempted due to the size of the check valves, the orientation of the check valves and the lack of reverse flow to positively seat the check valve while testing. Disassembly and inspection of these valves on a sampling basis to assess their closure capability provides reasonable assurance of the valves operational readiness.

1E51-F079 and 1E51-F081 1E51-F079 and 1E51-F081 break the vacuum of the RCIC exhaust piping upon RCIC shutdown.

These simple check valves were evaluated by engineering and may not be treated as a series pair assembly, as both valves are needed to perform their function.

These check valves currently have no intermediate test connections to allow individual valve testing. The intended long term fix for these valves is to install an intermediate test connection to allow for testing individually.

However, in the interim period, sample disassembly and inspections will provide sufficient data to assess their closure capabilities and will provide reasonable assurance of the valves operational readiness.

Both the associated inboard and involved outboard check valves are in close proximity to each other. The valves being in such close proximity make non-intrusive testing an option that is not preferred due to the difficulty in analyzing the test data (e.g., with acoustics it is difficult to determine which valve closed). Also with the system configuration it is difficult to get reversal/cessation of flow to close the valve with sufficient force to test.This refueling outage justification had been previously found to be acceptable as relief request VR-4 in a NRC Safety Evaluation dated August 9, 1999 (TAC No. MA3328) (Log No. PY-NRR/CEI-0989L).

3.2-67 Rev. 13 Refueling Outage Justification RO-33 (Continued)

Alternate Testing: The valves will be disassembled and inspected on a sampling basis pursuant to the requirements ISTC-5221(c).

Due to the scope of the activity and system operating restrictions, these valve disassemblies will be performed during reactor refueling outages for the Safety-related Keep Fill System check valves and during on-line divisional diesel outages or reactor refueling outages for the Division 1, 2, 3 valves.The keep fill check valves are exercised open following their re-assembly by verifying proper keep fill pump flow. The siphon breaker check valves are exercised open following their re-assembly by verifying no reverse rotation of the applicable pump when secured.As an alternative to the OM Code requirements the valves may be included in the Check Valve Condition Monitoring Program per ISTC-5222 and Appendix II.3.2-68 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number VR-I, Revision 0 Page 1 of 3 Proposed Alternative in Accordance with 10 CFR 50.55a(a)

(3) (i)--Alternative Provides Acceptable Level of Quality and Safety--9. ASME Code Component(s)

Affected Category B Valves (Typical of 177)lC1-126, Scram Inlet Valve (Class 2)lC11-127, Scram Exhaust Valve (Class 2)Category C Valves (Typical of 177)lCI1-114, Scram Discharge Header Check Valve (Class 2)[OPEN direction only]1CI1-115, Charging Water Check Valve (Class 2)[OPEN direction only]These valves operate as an integral part of their respective hydraulic control unit to rapidly insert the control rods in support of a scram function.10. Applicable Code Edition and Addenda ASME OM Code-2001, with Addenda through OMb-2003 11. Applicable Code Requirements ISTC-3510, "Exercise Test Frequency," requires active Category B and Category C check valves to be exercised nominally every 3 months. If exercising every 3 months is not possible then exercising may be performed during cold shutdowns or refueling outages as permitted by ISTC-3520.

ISTC-5130, "Pneumatically Operated Valves," requires active valves to have their stroke times measured when exercised in accordance with ISTC-3500.

ISTC-5220, "Check Valves," requires that necessary valve obturator to be demonstrated by performing both an open and close test.12. Reason for Request These valves are not provided with position indication; therefore measuring their full stroke time in accordance with the code is impractical.

3.2-69 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number VR-I, Revision 0 Page 2 of 3 Exercising these valves at a frequency other than that specified by Technical Specifications could result in a plant trip, which is burdensome without a compensating increase in the level of quality and safety. Additionally, since the power operated valves are not provided with position indication, special test methods or test equipment would be required to determine valve position, which is also burdensome without a compensating increase in the level of quality and safety.13. Proposed Alternative and Basis for Use As discussed in NUREG-1482, Rev. 1, Section 4.4.6, the rod scram test frequency identified in the plant Technical Specifications may be used as the valve testing frequency to minimize rapid reactivity transients and unnecessary wear of the CRD mechanisms.

Verifying that the associated control rod meets the scram insertion time limits defined in the Technical Specifications can be an acceptable alternative method of detecting degradation of these valves in lieu of valve stroke measurement.

Technical Specification Surveillance Requirement (SR) 3.1.4.1 requires the scram time for all control rods to be verified within limits prior to thermal power exceeding 40% of rated thermal power after fuel movement, and prior to thermal power exceeding 40% of rated thermal power after each reactor shutdown 120 days. In addition, Technical Specification SR 3.1.4.2 requires testing of a representative sample of the control rods at least once per 120 days of operation in Mode 1.The Technical Specification SRs assure the necessary quality of the system and components are maintained, and that facility operation will be within the Safety Limits and the Limiting Condition of Operation will be met. Therefore, scram insertion timing per Technical Specification SR 3.1.4.1 shall be substituted for individual valve testing.Using the provisions of this relief request as an alternative to the requirements of ISTC-3510, 5130 and 5220 provides a reasonable alternative to the code requirements.

The proposed alternative method of detecting degradation provides reasonable assurance of the valves'operational readiness.

Therefore, the proposed alternative provides an acceptable level of quality and safety, and Perry Nuclear Power Plant (PNPP) requests that relief be granted pursuant to 10 CFR 50.55a(a)

(3) (i).14. Duration of Proposed Alternative The proposed alternative identified in this relief request shall be utilized during the Third Ten-Year IST Interval.15. Precedent Perry Nuclear Power Plant, Docket No. 50-440, Safety Evaluation Report (SER) dated August 9, 1999, "Safety Evaluation of the Inservice Testing Program Second Ten-Year Interval for Pumps and Valves -Perry Nuclear Power Plant, (TAC No. MA3328)." Previously approved as VR-l in the aforementioned SER.3.2-70 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number VR-I, Revision 0 Page 3 of 3 8. References

1. Technical Specification SR 3.1.4.1, Control Rod Scram Times.2. Technical Specification SR 3.1.4.2, Control Rod Scram Times.3. NUREG-1482, Guidelines for Inservice Testing at Nuclear Power Plants, Revision 1, January 2005, Section 4.4.6, Testing Individual Scram Valves for Control Rods in Boiling-Water Reactors.4. Refueling Outage Justification RO-31, Control Rod Drive Hydraulic System (C1I), Valve lCll-115.3.2-71 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number VR-2, Rev 0 Page 1 of 4 Proposed Alternative in Accordance with 10 CFR 50.55a(a)

(3) (i)--Alternative Provides Acceptable Level of Quality and Safety--1. ASME Code Component(s)

Affected IB21-FO41A, Dikkers Valve (ADS)1B21-FO41B, Dikkers Valve (ADS)1B21-FO41C, Dikkers Valve IB21-FO41D, Dikkers Valve IB21-F041E, Dikkers Valve (ADS)IB21-F041F, Dikkers Valve (ADS)1B21-F041G, Dikkers Valve IB21-F041K, Dikkers Valve IB21-F047B, Dikkers Valve 1B21-F047C, Dikkers Valve IB21-F047D, Dikkers Valve (ADS)IB21-F047F, Dikkers Valve (LLS)IB21-F047G, Dikkers Valve 1B21-FC47H, Dikkers Valve (ADS)1B21-FO51A, Dikkers Valve (LLS)IB21-FO51B, Dikkers Valve (LLS)1B21-FO51C, Dikkers Valve (ADS/LLS)IB21-FO51D, Dikkers Valve (LLS)IB21-F051G, Dikkers Valve (ADS/LLS)The Nuclear Boiler System provides Reactor Pressure Vessel (RPV)over pressurization protection by opening the Safety/Relief Valves (SRVs). The SRVs open at the high reactor pressure trip set point. In addition to overpressure protection, the SRVs provide RPV pressure relief by opening to release steam and decrease vessel pressure.

Pressure in the vessel is thereby maintained below the American Society of Mechanical Engineers (ASME) Code required limit.In addition to the above, the Automatic Depressurization System (ADS) and the individual SRVs shall be capable of being manually operated from the main Control Room. This provides the capability to manually depressurize the RPV in the event of the main condenser is not available as a heat sink.3.2-72 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number VR-2, Rev 0 Page 2 of 4 The Nuclear Boiler System ADS shall provide automatic depressurization of the RPV under certain small break Loss Of Coolant Accident (LOCA)conditions so that the low pressure Emergency Core Cooling Systems (ECCS) can adequately cool the core. Note that all of the SRVs, those used for ADS as well as those assigned purely for pressure relief, are used for overpressure protection.

All of the SRVs work together to ensure that the ASME Code limit is not exceeded.2. Applicable Code Edition and Addenda ASME OM Code-2001, with Addenda through OMb-2003 3. Applicable Code Requirements ASME OM Code, Appendix I (1995), Section 3410(d), requires that each valve that has been maintained or refurbished in place, removed for maintenance and testing, or both, and reinstalled, shall be remotely actuated at reduced or normal system pressure to verify open and close capability of the valve before resumption of electric power generation.

Set-pressure verification is not required.4. Reason for Request The nuclear industry experience as a whole has shown that repeated manual actuation of the SRVs and ADS valves can lead to valve seat leakage during plant operation.

This experience is substantiated within NUREG-0626, "Generic Evaluation of Feedwater Transients and Small Break Loss-of-Coolant Accidents in GE-Designed Operating Plants and Near Term Operating License Applications," and NUREG-0123,"Standard Technical Specifications for GE Boiling Water Reactors (BWR/5)," which recommend reducing the number of challenges to the ADS valves.5. Proposed Alternative and Basis for Use This relief request will allow testing of the SRVs to be performed in two separate stages. Stage 1 will be manual actuation of the valves at the qualified test facility.

This will verify the open and close function of the valve with the actuator coupled to the valve stem, and includes both solenoids and the air block valve. Each solenoid is energized, one at a time, resulting in two separate lifts of the SRV disk from the seat. Stage 2 will be manual actuation of the SRV actuators following installation into the plant with the actuator uncoupled from the valve stem. The plant installed testing will verify full operation of the electrical circuitry, manual actuation solenoid valve, block valve, and the actuator.

Therefore, all components associated with the SRVs will continue to be tested.3.2-73 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number VR-2, Rev 0 Page 3 of 4 This uncoupled test may also be performed following any maintenance activity that could affect the relief mode of the associated SRV.With this relief request the existing test method will also remain acceptable, i.e., full stroke exercise from the control room at adequate reactor steam pressure and flow.The proposed test alternative provides verification of proper control connections by requiring the pneumatic and electrical controls to cycle the actuator on each SRV following installation, without stroking the SRV disk. The plant installed testing will verify full operation of the electrical circuitry, manual actuation solenoid valve, block valve, and the actuator.

In addition, the test populations of SRVs removed each refuel outage for setpoint testing would also be tested in the relief mode during bench testing. This setpoint testing provides assurance that the SRV would perform as expected when control air pressure is applied to the actuator assembly.The proposed test alternative continues to demonstrate full functionality of the SRVs while minimizing the potential for creating valve seat leakage caused by cycling the valve unnecessarily.

Therefore, the proposed test alternative provides an acceptable level of quality and safety. Manual actuation of the valves at the qualified test facility will verify the open and close function of the valve with the actuator coupled to the valve stem. This actuation includes both solenoids and the air block valve, with each solenoid being energized, one at a time, and results in two separate lifts of the SRV disk from the seat.Upon re-installation, uncoupled manual actuation will verify the appropriate function of the electric circuit, both solenoid valves, air block valve, and the valve actuator.

This actuation includes both solenoids by lifting of the actuator with the first solenoid and maintaining the actuator open using the second solenoid, thereby, only lifting the actuator once.Using the provisions of this relief request as an alternative to ASME OM Code, Appendix I (1995), Section 3410(d), provides a reasonable alternative to the Code requirements, based on the determination that the proposed alternative provides an acceptable level of quality and safety. In addition, the method of uncoupled exercising is recognized as acceptable per OM Code-2004, 1-3410(d)whereas main disk movement is not required subsequent to installation after maintenance.

6. Duration of Proposed Alternative The proposed alternative identified in this relief request shall be utilized during the Third Ten-Year IST Interval.3.2-74 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number VR-2, Rev 0 Page 4 of 4 7. Precedents Perry Nuclear Power Plant, Docket No. 50-440, Safety Evaluation Report (SER) dated February 10, 2005, "Valve Relief Request VR-13, RE: Testing of Safety/Relief Valves (TAC No. MC2518)." Previously approved as VR-13 in the aforementioned SER.8. References

1. NUREG-0626, "Generic Evaluation of Feedwater Transients and Small Break Loss-of-Coolant Accidents in GE-Designed Operating Plants and Near Term Operating License Applications." 2. NUREG-0123, "Standard Technical Specifications for GE Boiling Water Reactors (BWR/5)." 3. OM Code-2004, Appendix I, Paragraph 1-3410(d).

3.2-75 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number VR-3, Rev 0 Page 1 of 2 Proposed Alternative in Accordance with 10 CFR 50.55a(a)

(3) (i)--Alternative Provides Acceptable Level of Quality and Safety--1. ASME Code Component(s)

Affected Certain motor-operated valve assemblies currently included in the Perry Nuclear Power Plant (PNPP) Motor-Operated Valve (MOV) Program 2. Applicable Code Edition and Addenda ASME OM Code-2001, with Addenda through OMb-2003 3. Applicable Code Requirements ISTA-3130, "Application of Codes Cases," ISTA-3130(b) states that code cases shall be applicable to the edition and addenda specified in the test plan.ISTC-5120, "Motor-Operated Valves," ISTC-5121(a) states that active valves shall have their stroke times measured when exercised in accordance with ISTC-3500.

ISTC-3700, "Position Verification Testing," states in part, that valves with remote position indicators shall be observed locally at least once every two (2) years to verify that valve position is accurately indicated.

4. Reason for Request Code Case OMN-I has been determined by the NRC to provide an acceptable level of quality and safety when implemented in conjunction with the conditions imposed in RG 1.192.Since the NRC staff recommends licensees implement ASME Code Case OMN-I, PNPP proposes to implement Code Case OMN-I, Revision 1 in lieu of the stroke-time provisions specified in ISTC-5120 for MOVs as well as the position verification testing in ISTC-3700.

3.2-76 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number VR-3, Rev 0 Page 2 of 2 5. Proposed Alternative and Basis for Use NUREG-1482, Revision 1, "Alternatives to Stroke-Time Testing," Section 4.2.5 states in part, that as an alternative to MOV stroke-time testing, ASME developed Code Case OMN-l, "Alternative Rules for Preservice and Inservice Testing of Certain Electric Motor-Operated Valve Assemblies in LWR Power Plants," which provides periodic exercising and diagnostic testing for use in assessing the operational readiness of MOVs. Section 4.2.5 further states that the NRC staff recommends licensees implement ASME Code Case OMN-l, as accepted by the NRC (with certain conditions) in the regulations, or Regulatory Guide (RG) 1.192, Revision 0, "Operation and Maintenance Code Case Acceptability, ASME OM Code," as alternatives to the stroke-time testing provisions in the ASME Code for MOV.RG 1.192 allows licensees with an applicable code of record to implement ASME Code Case OMN-l (in accordance with the provisions in the regulatory guide) as an alternative to the code provisions for MOV stroke-time testing, without submitting request for relief from their code of record. The code of record for PNPP Third 10-Year IST Interval is OM Code-2001 Edition with Addenda through OMb-2003 and the applicable Code for OMN-I, as stated in RG 1.192, is OMa-1999.Using the provisions of this relief request as an alternative to the MOV stroke-time testing requirements of ISTC-5120 and position indication verification of ISTC-3700 provides an acceptable level of quality for the determination of valve operational readiness.

Code Case OMN-l, Revision 1 should be considered acceptable for use with OM Code-2001 with OMb-2003 Addenda as the code of record.6. Duration of Proposed Alternative The proposed alternative identified in this relief request shall be utilized during the Third Ten-Year IST Interval.7. Precedents

1. NUREG-1482, Revision 1, Section 4.2.5, "Alternatives to Stroke-Time Testing." 2. Regulatory Guide 1.192, Revision 0, "Operation and Maintenance Code Case Acceptability, ASME OM Code," Table 2, "Conditionally Acceptable OM Code Cases." 8. Reference Code Case OMN-I, "Alternative Rules for Preservice and Inservice Testing of Certain Electric Motor-Operated Valve Assemblies in LWR Power Plants." 3.2-77 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number VR-4, Rev 0 Page 1 of 9 Proposed Alternative in Accordance with 10 CFR 50.55a(a)

(3) (i)--Alternative Provides Acceptable Level of Quality and Safety--WITHDRAWN DURING REQUEST FOR ADDITION INFORMATION REPONSES 3.2-78 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number VR-4, Rev 0 Page 2 of 9 WITHDRAWN.DURING REQUEST FOR ADDITION INFORMATION REPONSES 3.2-79 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number VR-4, Rev 0 Page 3 of 9 WITHDRAWN DURING REQUEST FOR ADDITION INFORMATION REPONSES 3.2-80 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number VR-4, Rev 0 Page 4 of 9 WITHDRAWN DURING REQUEST FOR ADDITION INFORMATION REPONSES 3.2-81 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number VR-4, Rev 0 Page 5 of 9 WITHDRAWN DURING REQUEST FOR ADDITION INFORMATION REPONSES 3.2-82 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number VR-4, Rev 0 Page 6 of 9 WITHDRAWN DURING REQUEST FOR ADDITION INFORMATION REPONSES 3.2-83 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number VR-4, Rev 0 Page 7 of 9 WITHDRAWN DURING REQUEST FOR ADDITION INFORMATION REPONSES 3.2-84 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number VR-4, Rev 0 Page 8 of 9 WITHDRAWN DURING REQUEST FOR ADDITION INFORMATION REPONSES 3.2-85 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number VR-4, Rev 0 Page 9 of 9 WITHDRAWN DURING REQUEST FOR ADDITION INFORMATION REPONSES 3.2-86 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number VR-5, Rev 0 Page 1 of 1 Proposed Alternative in Accordance with 10 CFR 50.55a(a)

(3) (i)--Alternative Provides Acceptable Level of Quality and Safety--WITHDRAWN DURING REQUEST FOR ADDITION INFORMATION REPONSES 3.2-87 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number VR-6, Rev 0 Page 1 of 3 Proposed Alternative in Accordance with 10 CFR 50.55a(a)

(3) (i)--Alternative Provides Acceptable Level of Quality and Safety--1. ASME Code Component(s)

Affected 1B21-FO4lA, 1B21-FC4lB, 1B21-FO4lC, 1B21-FO4lD, 1B21-FO4lE, 1B21-FO4lP, 1B21-FO4lG, 1E21-F04 lx, 1B21-F047B, 1B21-F047C, 1B21-F047D, 1B21-F04 7F, 1B21-F'047G, 1B21-F047H, lB21-FC5lA, 1B21-FO5lB, 1B21-F051C, lB21-FO5lD, lB21-FO51G, Dikkers Dikkers Dikkers Dikkers Dikkers Dikkers Dikkers Dikkers Dikkers Dikkers Dikkers Dikkers Dikkers Dikkers Dikkers Dikkers Dikkers Dikkers Dikkers Valve Valve Valve Valve Valve Valve Valve Valve Valve Valve Valve Valve Valve Valve Valve Valve Valve Valve Valve (ADS) (Class 1)(ADS) (Class 1)(Class 1)(Class 1)(ADS) (Class 1)(ADS) (Class 1)(Class 1)(Class 1)(Class 1)(Class 1)(ADS) (Class 1)(LLS) (Class 1)(Classl)(ADS) (Class 1)(LLS) (Class 1)(LLS) (Class 1)(ADS/LLS) (Class 1)(LLS) (Class 1)(ADS/LLS) (Class 1)The Nuclear Boiler System provides Reactor Pressure Vessel (RPV)overpressurization protection by opening the Safety/Relief Valves (SRVs). The SRVs open at their reactor pressure set point.addition to overpressure protection, the SRVs provide RPV pressure relief by opening to release steam and decrease vessel pressure.Pressure in the vessel is thereby maintained below the American Society of Mechanical Engineers (ASME) Code required limit.In In addition to the above, the Automatic Depressurization System (ADS)and the individual SRVs shall be capable of being manually operated from the main control room. This provides the capability to manually depressurize the RPV in the event the main condenser is not available as a heat sink.The Nuclear Boiler System ADS provides automatic depressurization of the RPV under certain small break Loss Of Coolant Accident (LOCA)conditions so that the low pressure Emergency Core Cooling Systems (ECCS) can adequately cool the core.Note that all of the SRVs, those used for ADS as well as those assigned purely for pressure relief, are used for overpressure protection.

2. Applicable Code Edition and Addenda ASME OM Code-2001, with Addenda through OMb-2003.3.2-88 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number VR-6, Rev 0 Page 2 of 3 3. Applicable Code Requirements Appendix I, Paragraph 1-1320(a), "5-Year Test Interval," specifies that Class 1 pressure relief valves shall be tested at least once every five (5) years, starting with initial electric power generation.

No maximum limit is specified for the number of valves to be tested within each interval; however, a minimum of 20% of the valves from each valve group shall be tested within any 24-month interval.

This 20% shall consist of valves that have not been tested during the current five 5-year interval, if they exist. The test interval for any individual valve shall not exceed 5 years.4. Reason for Request The Perry Nuclear Power Plant (PNPP) transitioned from an 18-month fuel cycle to a 24-month fuel cycle on August 29, 2000 via Amendment 115. Prior to transitioning to the 24-month fuel cycle, ASME Code requirements could be satisfied by removing and testing approximately one-third of the 19 SRVs each refueling outage in order to comply with the 5-year test interval requirements for Class 1 pressure relief valves imposed by the code of record during that time.Since transitioning to the 24-month fuel cycle, PNPP must remove at least one-half of the subject relief valves each refueling outage for off-site testing.The removal of half of the 19 valves versus a third of the valves each outage requires the removal of additional insulation, instrumentation, and other interferences.

This additional work also results in an undesirable increase in radiation exposure to maintenance personnel.

Therefore, PNPP proposes that each SRV be tested at least once every three refueling cycles (approximately six years) with a minimum of 20%of the valves tested within any 24-month interval.P 5. Proposed Alternative and Basis for Use As an alternative to the code required 5-year test interval per Appendix I, paragraph 1-1320(a), PNPP proposes that the subject Class 1 pressure relief valves be tested at least once every three refueling cycles (approximately six years) with a minimum of 20% of the valves tested within any 24-month interval.

This 20% would consist of valves that have not been tested during the current three cycle interval, if they exist. The test interval for any individual valve would not exceed three refueling cycles.To provide technical basis for the proposed request, the setpoint testing results were evaluated for the time period from initial operation to the present time (approximately 20 years, 150 data points). The evaluation showed that the average variance from the setpoint testing data is 0.91% and the calculated standard deviation from the average is 0.72 of the nominal setpoint values.3.2-89 Rev. 13 Perry Nuclear Power Plant Unit 1 10 CFR 50.55a Request Number VR-6, Rev 0 Page 3 of 3 Amendment 101, which was approved on March 3, 1999, changed the allowable SRV setpoint test range from +/-1% to +/-3%. As part of the evaluation of the setpoint testing data, it was identified that fifty-two (52) tests exceeded the Technical Specifications as-found value of +/-1%. There were four (4) failures where the as-found setpoint exceeded the +/-3%, with all 4 of the +/-3% failures occurring prior to the adoption of Amendment 101. Two (2) of the 4 failures had no as-found setpoint data obtained, due to severe seat leakage. The PNPP data indicates a slight tendency toward higher as-found setpoints, but this tendency is well within the PNPP Technical Specification required limits, which require current SRV setpoint deviations to be within +/-3%.The proposed alternative of increasing the test interval for the subject Class 1 pressure relief valves from five years to three fuel cycles (approximately six years) would continue to provide an acceptable level of quality and safety while restoring the operational and maintenance flexibility that was lost when the 24-month fuel cycle created the unintended consequences of more frequent testing. This proposed alternative will continue to provide assurance of the valves'operational readiness and provides an acceptable level of quality and safety pursuant to 10 CFR 50.55a(a)

(3) (i).6. Duration of Proposed Alternative The proposed alternative identified in this relief request shall be utilized during the Third Ten-Year IST Interval.7. Precedent Nine Mile Point Nuclear Station, Docket No. 50-410, Safety Evaluation Report (SER) dated April 17, 2001, "Safety Evaluation of the Alternative to ASME Code Regarding Inservice Testing of Main Steam Safety/Relief Valves, (TAC No. MB0290)." 8. References

1. SER dated August 29, 2000. Perry Nuclear Power Plant, Unit 1, Docket No. 50-440, "Issuance of Amendment RE: Revisions of Various Surveillance Requirements to Support a 24-Month Operating Cycle (TAC No. MA5930)." 2. SER dated March 3, 1999. Perry Nuclear Power Plant, Unit 1, Docket No. 50-440, Amendment 101 (SRVs 1% to 3%) to Facility Operating License No. NPF-58 Perry Nuclear Power Plant, Unit 1 (TAC No. MA2290).3.2-90 Rev. 13

3.3 Valve

Testing Index System Nuclear Boiler (B21)Reactor Water Recirculation (B33)Control Rod Drive Hydraulics (Cl)Standby Liquid Control (C41)Plant Radiation Monitoring (D17)Containment Atmosphere Monitoring (D23)Residual Heat Removal (E12)Low Pressure Core Spray (E21)High Pressure Core Spray (E22)Reactor Core Isolation Cooling (E51)Containment Integrated Leak Rate Testing (E61)Inclined Fuel Transfer Reactor Water Cleanup (G33)Fuel Pool Cooling and Cleanup (G41)Suppression Pool Cleanup (G42)Valve Testing Index Dwg. No.D-302-121 D-302-605 D-302-607 D-302-602 Page (s)3.4-1 3.4-2 through 3.4-19 3.4-20 3.4-21 D-302-871 D-302-872 D-302-691 D-302-692 D-806-004 D-806-007 D-302-881 D-302-641 D-302-642 D-302-643 D-302-705 D-302-701 D-302-631 D-302-632 D-302-811 D-302-970 D-302-671 D-302-672 D-302-651 D-302-654 D-302-655 D-302-681 3.4-22 3.4-23 3.4-25 3.4-27 3.4-29 3.4-30 3.4-31 3.4-33 3.4-37 3.4-45 3.4-49 through through through 3.4-24 3.4-26 3.4-28 through 3.4-32 through through through through 3.4-36 3.4-44 3.4-48 3.4-50 3.4-51 through 3.4-53 3.4-54 3.4-58 3.4-61 3.4-62 3.4-63 3.4-64 3.4-66 3.4-67 3.4-68 3.4-69 through 3.4-57 through 3.4-60 through 3.4-65 3.3-1 Rev. 13 Va System Suppression Pool Makeup (G43)Liquid Radwaste (G50)Liquid Radwaste Sumps (G61)Containment Vessel and Drywell Purge (M14)Drywell (M16) and Containment Vacuum Relief (M17)Combustible Gas Control (M51)Main Steam (N11)Main, Reheat, Extraction, and Misc., Drains (N22)Feedwater Leakage Control (N27)Condensate Transfer and Storage (P11)Mixed Bed Demin, and Distribution (P22)Service Water (P41)Emergency Closed Cooling Water (P42)Nuclear Closed Cooling (P43)Emergency Service Water (P45)Control Complex Chilled Water (P47)ESW Screen Wash (P49)Llve Testing Dwg. No.D-302-686 D-302-737 D-302-739 D-302-740 D-912-604 Index (Cont.)Page (s)3.4-70 through 3.4-71 3.4-72 3.4-73 3.4-74 3.4-75 through 3.4-77 D-912-606 3.4-78 through 3.4-80 D-302-831 D-302-832 D-302-011 D-302-121 3.4-81 3.4-82 3.4-86 3.4-87 through 3.4-85 D-302-082 D-302-971 D-302-102 D-302-713 D-302-212 D-302-621 D-352-621 D-302-622 D-302-613 D-302-791 D-302-792 D-913-001 D-913-002 D-302-214 3.4-88 3.4-89 3.4-90 3.4-91 3.4-92 3.4-93 3.4-94 3.4-96 3.4-97 3.4-98 3.4-101 3.4-102 3.4-103 3.4-104 through 3.4-95 through 3.4-100 3.3-2 Rev. 13 Valve Testing Index (Cont.)System Containment Vessel Chilled Water (P50)Service Air Distribution (P51)Instrument Air (P52)Penetration Pressurization (P53)Fire Service Water and CO 2 (P54)Safety-Related Instrument Air (P57)Nitrogen Supply (P86)Post Accident Sampling (P87)Standby Diesel Generator Starting Air (R44)HPCS Diesel Generator Air (E22A)Standby Diesel Generator Fuel Oil (R45)Standby Diesel Generator Jacket Water (R46)Standby Diesel Generator Lube Oil (R47)Dwg. No.D-913-008 D-302-242 D-302-243 D-302-244 D-302-761 D-302-762 D-914-003 D-914-005 D-302-271 D-302-950 D-302-431 D-302-351 Page (s)3.4-105 3.4-106 3.4-107 3.4-108 3.4-109 through 3.4-111 3.4-112 through 3.4-115 3.4-116 3.4-117 3.4-118 through 3.4-119 3.4-120 3.4-121 through 3.4-124 3.4-125 through 3.4-127 D-302-358 D-302-352 D-302-356 D-302-354 D-302-353 3.4-128 3.4-129 3.4-130 3.4-131 3.4-132 3.3-3 Rev. 13 SYSTEM: NUCLEAR BOILER (B21)DWG. NO. D-302-121 CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.EC -Q STC-Q LJ -PB PI -2Y SURV INST.NO.SVI-B21 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT (sccm or ppm)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 1B21-F016 1 A D-11 ACTIVE 3 GT MO 0 T2006 T2006 T9423 T2006 T2006 T2006 T9423 T2006 19.6 1000.0 VR-3 VR-3 VR-3 VR-3 VR-Pending 9186 1B21-F019 1 A D-10 ACTIVE 3 GT MO EC -Q 0 STC-Q LJ -PB PI -2Y 20.2 1000.0 SVI-B21-T2008 (PI) REMOTE S/D LOCAL BREAKER VR-Pending 16817 3.4-1 Rev. 13 SYSTEM: NUCLEAR BOILER (B21)DWG. NO. D-302-605 CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.PI -2Y SURV INST.NO.SVI-B21 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT (sccm or gpm)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 1B21-FD0l 1B21-FDD2 IB21-F005 1 B E-13 PASSIVE 2 MO GL C T2004 1 B 2 D-13 PASSIVE GL MO C PI -2Y T2004 1 B D-13 PASSIVE 2 MO GL 0 1B21-F022A 1 A 26 C-8 ACTIVE GL AO 0 1B21-F022B 1 A 26 E-9 ACTIVE GL AO 0 AO 0 PI -2Y PC -Q EC -CS STC-CS FS -CS LJ -2Y PI -2Y PC -Q EC -CS STC-CS FS -CS LJ -2Y PI -2Y PC -Q EC -CS STC-CS FS -CS LJ -2Y PI -2Y T0039(C71)

T2001 T2001 T2001 T9000 T2001 T0039(C71)

T2001 T2001 T2001 T9000 T2001 T0039(C71)

T2001 T2001 T2001 T9000 T2001 3.1 CS-5 CS-5 CS-5 SVI-C61-T1104 (PI) REMOTE S/D PANEL NOTE: 6 T2004 NOTE: 1 3.2 CS-5 CS-5 CS-5 SVI-C61-T1104 (PI) REMOTE S/D PANEL NOTE: 6 1B21-F022C 1 F-9 A ACTIVE 26 GL 3.2 CS-5 CS-5 CS-5 SVI-C61-T1104 (PI) REMOTE S/D PANEL NOTE: 6 3.4-2 Rev. 13 SYSTEM: NUCLEAR BOILER (B21)CLASS VALVE AND CATEGORY/VALVE/ DWG. ACTIVE OR DEVICE NO. COOR. PASSIVE 1B21-F022D 1 A F-9 ACTIVE DWG. NO. D-302-605 SIZE ACTUATOR TEST (in.)AND TYPE TYPE/NORMAL POSITION 26 GL 1B21-F024A 3 AC 1 B-8 ACTIVE CH 1B21-F024B 3 AC E-9 ACTIVE 1B21-F024C 3 AC F-9 ACTIVE 1 CH 1 CH AO 0 SE C SE C SE C SE C AO 0 REQ.AND FREQ.PC -Q EC -CS STC-CS FS -CS LJ -2Y PI -2Y SURV INST.NO.SVI-B21 STROKE TIME REFERENCE VALUE(sec)

LIMIT (sccm or 92m)LEAKAGE DEVICE T0039(C71)

T2001 T2001 T2001 T9000 T2001 T2009 T2200 T2200 3.0 CS-5 CS-5 CS-5 SVI-C61-T1D04 (PI) REMOTE S/D PANEL NOTE: 6 SET PRESS.REFERENCE VALUE(psi)

EO EC LD EO EC LD EO EC LD EO EC LD PC EC STC FS LJ PI-RO-RO-2Y-RO-RO-2Y-RO-RO-2Y-RO-RO-2Y-Q-CS-CS-CS-2Y-2Y 2,885.0 T2009 T2200 T2200 T2009 T2200 T2200 T2009 T2200 T2200 2,885.0 JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS RO-19 RO-19 RO-19 RO-19 RO-19 RO-19 RO-19 RO-19 INBD MSIV (F022A) ACCUM.NOTE: 3 INBD MSIV (F022B) ACCUM.NOTE: 3 INBD MSIV (F022C) ACCUM.NOTE: 3 INBD MSIV (F022D) ACCUM.NOTE: 3 2,885.0 1B21-F024D 3 AC 1 F-9 ACTIVE CH 2,885.0 1B21-F028A 1 A C-6 ACTIVE 26 GL T0039(C71)

T2001 T2001 T2001 T9000 T2001 3.3 CS-5 CS-5 CS-5 NOTE: 6 3.4-3 Rev. 13 SYSTEM: NUCLEAR BOILER (B21)DWG. NO. D-302-605 CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE 1B21-F028B 1 A E-8 ACTIVE 1B21-F028C 1 A F-8 ACTIVE SIZE (in.)AND TYPE 26 GL 26 GL ACTUATOR TYPE/NORMAL POSITION AO 0 AO 0 TEST REQ.AND FREQ.PC -Q EC -CS STC-CS FS -CS LJ -2Y PI -2Y PC -Q EC -CS STC-CS FS -CS LJ -2Y PI -2Y SURV INST.NO.SVI-B21 T0039(C71)

T2001 T2001 T2001 T9000 T2001 T0039(C71)

T2001 T2001 T2001 T9000 T2001 T0039(C71)

T2001 T2001 T2001 T9000 T2001 STROKE TIME REFERENCE VALUE (sec)3.2 4.5 LEAKAGE LIMIT (sccm or gpm)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS CS-5 CS-5 CS-5 NOTE: 6 CS-5 CS-5 CS-5 NOTE: 6 1B21-F028D 1 A F-8 ACTIVE 26 GL AD PC -Q 0 EC -CS STC-CS FS -CS LJ -2Y PI -2Y 3.9 CS-5 CS-5 CS-5 NOTE: 6 1B21-F029A 3 AC B-6 ACTIVE 1B21-F029B 3 AC E-8 ACTIVE I CH 1 CH SE C SE C EO EC LD EO EC LD-RO-RO-2Y-RO-RO-2Y T2009 T2201 T2201 T2009 T2201 T2201 1, 873.4 RO-19 RO-19 RO-19 RO-19 OUTBD MSIV (FO28A) ACCUM.NOTE: 4 OUTBD MSIV (F028B) ACCUM.NOTE: 4 1,873.4 3.4-4 Rev. 13 SYSTEM: NUCLEAR BOILER (B21)DWG. NO. D-302-605 CLASS AND VALVE/ DWG.DEVICE NO. COOR.1B21-F029C 3 F-8 1B21-F029D 3 F-8 VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-B21 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT (sccm or gpm)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS AC ACTIVE AC ACTIVE 1 CH 1 CH SE C SE C EO EC LD-RO-RO-2Y 1B21-F036C 3 C B-lI ACTIVE 1B21-F036D 3 C B-lI ACTIVE 1B21-F036G 3 C B-lI ACTIVE 1B21-F036H 3 C B-lI ACTIVE IB21-F036J 3 C B-lI ACTIVE 1B21-F036K 3 C B-lI ACTIVE 1B21-F036M 3 C B-Il ACTIVE 1B21-F036N 3 C B-i1 ACTIVE 1 SE CH C 1 CH 1 CH 1 CH 1 CH 1 CH 1 CH 1 CH SE C SE C SE C SE C SE C SE C SE C EO -RO EC -RO LD -2Y EO -RD EC -RO EO -RD EC -RO EO -RD EC -RO EO -RD EC -RO EO -RD EC -RO EO -RD EC -RO EO -RD EC -RO EO -RD EC -RO T2009 T2201 T2201 T2009 T2201 T2201 T2009 T2007 T2009 T2007 T2009 T2007 T2009 T2007 T2009 T2007 T2009 T2007 T2009 T2007 T2009 T2007 1, 873.4 RO-5 RO-5 RO-5 RO-5 RO-5 RO-5 RO-5 RO-5 RO-5 RO-5 RO-5 RO-5 RO-5 RO-5 RO-5 RO-5 1,873.4 RO-19 RO-19 RO-19 RO-19 OUTBD MSIV (FO28C) ACCUM.NOTE: 4 OUTBD MSIV (F028D) ACCUM.NOTE: 4 NON-ADS (F041C)ACCUM.NON-ADS (F041D)ACCUM.NON-ADS (F041G)ACCUM.NON-ADS (F041K)ACCUM.NON-ADS (F047B)ACCUM.NON-ADS (F047C)ACCUM.NON-ADS (F047F)ACCUM.NON-ADS (F047G)ACCUM.3.4-5 Rev. 13 SYSTEM: NUCLEAR BOILER (B21)DWG. NO. D-302-605 CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-B21 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT (sccm or gpm)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.1B21-F036R 3 C B-Il ACTIVE IB21-F036S 3 C B-lI ACTIVE 1 CH 1 CH 1 CH SE EO -RO C EC -RO SE C SE C IB21-F036U 3 A-3 C ACTIVE EO -RO EC -RO EO -RO EC -RO EO -RO EC -RO 1B21-F037A 3 C B-10 ACTIVE 1B21-F037B 3 C B-10 ACTIVE 1B21-F037C 3 C B-10 ACTIVE 1B21-F037D 3 C B-10 ACTIVE 1B21-F037E 3 C B-10 -ACTIVE 1B21-F037F 3 C B-10 ACTIVE IB21-F037G 3 C B-10 ACTIVE 1B21-F037H 3 C B-10 ACTIVE 6 SE CH C 6 CH 6 CH SE EO -RC C EC -RO SE C EO -RO EC -RO EO -RO EC -RO T2009 T2007 T2009 T2007 T2009 T2007 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 RO-5 RO-5 RO-5 RO-5 RO-5 RO-5 REMARKS NON-ADS (F051A)ACCUM.NON-ADS (FO51B)ACCUM.NON-ADS (FO51D)ACCUM.6 SE CH C RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RD-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 SRV (F041A)DOWNCOMER SRV (F041B)DOWNCOMER SRV (F041C)DOWNCOMER SRV (F041D)DOWNCOMER SRV (F041E)DOWNCOMER SRV (F041F)DOWNCOMER SRV (F041G)DOWNCOMER SRV (F041K)DOWNCOMER 6 CH 6 CH 6 CH SE EO -RO C EC -RO SE C SE C EO -RO EC -RO EO -RC EC -RO 6 SE EO -RO CH C EC -RO 3.4-6 Rev. 13 SYSTEM: NUCLEAR BOILER (B21)DWG. NO. D-302-605 CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE ACTUATOR TEST (in.)AND TYPE TYPE/NORMAL POSITION IB21-FD37J 3 C B-10 ACTIVE TB21-F037K 3 C B-10 ACTIVE IB21-F037L 3 C B-10 ACTIVE TB21-F037M 3 C B-10 ACTIVE IB21-F037N 3 C B-10 ACTIVE TB21-F037P 3 C B-10 ACTIVE TB21-F037R 3 C B-10 ACTIVE TB21-F037S 3 C B-10 ACTIVE TB21-F037T 3 C B-10 ACTIVE TB21-F037U 3 C B-2 ACTIVE TB21-F037V 3 C B-10 ACTIVE 6 CH 6 CH 6 CH 6 CH 6 CH 6 CH 6 CH 6 CH SE C SE C SE C SE C SE C SE C SE C SE C REQ.AND FREQ.EO -RD EC -RO EO -RD EC -RO EO -RD EC -RO EO -RD EC -RO EO -RD EC -RO EO -RD EC -RO EO -RD EC -RO EO -RD EC -RO EO -RD EC -RO SURV INST.NO.SVI-B21 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE DEVICE LIMIT SET PRESS.(sccm or REFERENCE gpm) VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 RD-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 R0-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 SRV (F047B)DOWNCOMER SRV (F047C)DOWNCOMER SRV (F047D)DOWNCOMER SRV (F047F)DOWNCOMER SRV (F047G)DOWNCOMER SRV (F047H)DOWNCOMER SRV (FO51A)DOWNCOMER SRV (FT51B)DOWNCOMER SRV (F051C)DOWNCOMER SRV (FO51D)DOWNCOMER SRV (F051G)DOWNCOMER 6 SE CH C 6 CH 6 CH SE EO -RD C EC -RO SE C EO -RD EC -RO 3.4-7 Rev. 13 SYSTEM: NUCLEAR BOILER (B21)DWG. NO. D-302-605 CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE 1B21-F039A 3 C D-10 ACTIVE IB21-F039B 3 C D-10 ACTIVE IB21-F039E 3 C D-10 ACTIVE IB21-F039F 3 C D-10 ACTIVE IB21-F039L 3 C D-10 ACTIVE IB21-F039P 3 C D-10 ACTIVE IB21-F039T 3 C D-10 ACTIVE IB21-F039V 3 C D-10 ACTIVE SIZE (in.)AND TYPE 1 CH 1 CH 1 CH ACTUATOR TYPE/NORMAL POSITION SE C SE C SE C TEST REQ.AND FREQ.EO -RD EC -RO EO -RD EC -RO EO -RD EC -RO SURV INST.NO.SVI-B21 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT (sccm or gpm)DEVICE SET PRESS.REFERENCE VALUE (psi)JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS T2009 T2007 T2009 T2007 T2009 T2007 T2009 T2007 T2009 T2007 1 CH 1 CH 1 CH SE EO -RD C EC -RO RD-5 R0-5 RD -5 RD-5 R0-5 R0-5 RD-5 R0-5 R0-5 R0-5 R0-5 R0-5 R0-5 R0-5 R0-5 R0-5 R0-5 SE C SE C EO -RD EC -RO EO -RD T2009 EC -RO T2007 ADS (F041A)ACCUM.ADS (F041B)ACCUM.ADS (F041E)ACCUM.ADS (F041F)ACCUM.ADS (F047D)ACCUM.ADS (F047H)ACCUM.ADS (F051C)ACCUM.ADS (FO51G)ACCUM.RX HEAD VENT LINE DIKKERS (ADS)VALVE DIKKERS (ADS)VALVE 1 SE EO -RD T2009 CH C EC -RO T2007 1 CH 2 CH SE C SE C IB21-F040 3 C F-13 ACTIVE EO -RD EC -RO EO -RD EC -RO RT -6Y RC -RD T2009 T2007 T2011 T2011 IB21-FD41A 1 C D-10 ACTIVE 1B21-F041B 1 C D-10 ACTIVE 10 SE SR/AO C T2100 T2012/T2005 T2100 T2012/T2005 1165.0 1123.0 1165.0 1123.0 RO-18 RO-18 VR- 6 VR-2 VR-6 VR-2 10 SE RT -6Y SR/AO C RC -R0 3.4-8 Rev. 13 SYSTEM: NUCLEAR BOILER (B21)DWG. NO. D-302-605 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1B21-F041C 1B21-F041D 1B21-F041E 1B21-F041F IB21-FD41G 1B21-F041K 1B21-F047B 1B21-F047C 1B21-F047D 1B21-F047F IB21-F047G 1 C C-10 ACTIVE 1 C C-10 ACTIVE 1 C D-10 ACTIVE 1 C D-10 ACTIVE 1 C C-10 ACTIVE 1 C C-10 ACTIVE 1 C C-10 ACTIVE 1 C C-10 ACTIVE 1 C D-10 ACTIVE 1 C C-10 ACTIVE 1 C C-10 ACTIVE 10 SE SR/AO C 10 SE SR/AO C 10 SE SR/AO C 10 SE SR/AO C 10 SE SR/AO C 10 SE SR/AO C 10 SE SR/AO C 10 SE SR/AO C 10 SE SR/AO C 10 SE SR/AO C 10 SE SR/AO C TEST REQ.AND FREQ.RT -6Y RC -RD RT -6Y RC -RD RT -6Y RC -RD RT -6Y RC -RO RT -6Y RC -RD RT -6Y RC -RD RT -6Y RC -RO RT -6Y RC -RO RT -6Y RC -RO RT -6Y RC -RO RT -6Y RC -RD SURV INST.NO.SVI-B21 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT (sccm or ppm)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS T2100 T2012/T2005 T2100 T2012/T2005 T2100 T2012/T2005 T2100 T2012/T2005 T2100 T2012/T2005 T2100 T2012/T2005 T2100 T2012/T2005 T2100 T2012/T2005 T2100 T2012/T2005 T2100 T2012/T2005 T2100 T2012/T2005 1165.0 1123.0 1165.0 1123.0 1165.0 1123.0 1165.0 1123.0 1165.0 1123.0 1165.0 1123.0 1180.0 1113.0 1180.0 1113.0 1180.0 1113.0 1180.0 1113.0 1180.0 1113.0 VR- 6 VR-2 VR- 6 VR-2 VR- 6 VR-2 VR- 6 VR-2 VR-6 VR-2 VR-6 VR-2 VR- 6 VR-2 VR-6 VR-2 VR-6 VR-2 VR-6 VR-2 VR-6 VR-2 DIKKERS VALVE DIKKERS VALVE DIKKERS (ADS)VALVE DIKKERS (ADS)VALVE DIKKERS VALVE DIKKERS VALVE DIKKERS VALVE DIKKERS VALVE DIKKERS (ADS)VALVE DIKKERS VALVE DIKKERS VALVE 3.4-9 Rev. 13 SYSTEM: NUCLEAR BOILER (B21)DWG. NO. D-302-605 CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION 1B21-F047H 1B21-F051A 1B21-F051B 1B21-F051C 1 C D-10 ACTIVE 1 C C-10 ACTIVE 1 C C-10 ACTIVE 1 C D-10 ACTIVE 10 SE SR/AO C 10 SE SR/AO C 10 SE SR/AO C 10 SE SR/AO C 10 SE SR/AO C 10 SE SR/AO C TEST REQ.AND FREQ.RT -6Y RC -R0 RT -6Y RC -R0 RT -6Y RC -RD RT -6Y RC -RD RT -6Y RC -RD RT -6Y RC -RD EO -RD EC -RO EO -RD EC -RO EO -RD EC -RO SURV INST.NO.SVI-B21 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT (sccm or gpm)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS T2100 T2012/T2005 T2100 T2012/T2005 T2100 T2012/T2005 T2100 T2012/T2005 T2100 T2012/T2005 T2100 T2012/T2005 1180.0 1113.0 1190.0 1113.0 1190.0 1113.0 1190.0 1113.0 1190.0 1103.0 1190.0 1113.0 1B21-F051D 1 C-2 C ACTIVE VR-6 VR-2 VR-6 VR-2 VR-6 VR-2 VR-6 VR-2 VR-6 VR-2 VR-6 VR-2 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 DIKKERS (ADS)VALVE DIKKERS VALVE DIKKERS VALVE DIKKERS (ADS)VALVE SVI-C61-T1104 (PI)DIKKERS (ADS)VALVE SVI-C61-T1104 (PI)DIKKERS (ADS)VALVE SVI-C61-T1104 (PI)IB21-FO51G 1B21-F078A 1B21-F078B 1 C D-10 ACTIVE 3 C B-10 ACTIVE 3 C B-10 ACTIVE 6 CH 6 CH SE C SE C T2011 T2011 T2011 T2011 T2011 T2011 SRV (F041A)DOWNCOMER SRV (F041B)DOWNCOMER SRV (F041C)DOWNCOMER 1B21-F078C 3 C B-10 ACTIVE 6 SE CH C 3.4-10 Rev. 13 SYSTEM: NUCLEAR BOILER (B21)DWG. NO. D-302-605 CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION 1B21-F078D 3 C B-10 ACTIVE IB21-F078E 3 C B-10 ACTIVE 1B21-F078F 3 C B-10 ACTIVE 1B21-F078G 3 C B-10 ACTIVE 1B21-F078H 3 C B-10 ACTIVE 1B21-FO78J 3 C B-10 ACTIVE 1B21-F078K 3 C B-10 ACTIVE 1B21-F078L 3 C B-10 ACTIVE 1B21-F078M 3 C B-10 ACTIVE 1B21-F078N 3 C B-10 ACTIVE 1B21-F078P 3 C B-10 ACTIVE 6 CH 6 CH 6 CH 6 CH 6 CH 6 CH SE C SE C SE C TEST REQ.AND FREQ.EO -RO EC -RO EO -RO EC -RO EO -RO EC -RO SURV INST.NO.SVI-B21 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT (sccm or gpm)DEVICE SET PRESS.REFERENCE VALUE (psi)JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS SE EO -RO C EC -RO SE C SE C EO -RO EC -RO EO -RD EC -RO T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 SRV (F041D)DOWNCOMER SRV (F041E)DOWNCOMER SRV (F041F)DOWNCOMER SRV (F041G)DOWNCOMER SRV (F041K)DOWNCOMER SRV (F047B)DOWNCOMER SRV (F047C)DOWNCOMER SRV (F047D)DOWNCOMER SRV (F047F)DOWNCOMER SRV (F047G)DOWNCOMER SRV (F047H)DOWNCOMER 6 SE EO -RO CH C EC -RO 6 CH 6 CH SE C SE C EO -RO EC -RO EO -RO EC -RO 6 SE EO -RO CH C EC -RO 6 CH SE EO -RO C EC -RO 3.4-11 Rev. 13 SYSTEM: NUCLEAR BOILER (B21)DWG. NO. D-302-605 CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE ACTUATOR TEST (in.)AND TYPE TYPE/NORMAL POSITION 1B21-F078R 3 C B-10 ACTIVE 1B21-F078S 3 C B-10 ACTIVE 1B21-F078T 3 C B-10 ACTIVE 6 CH 6 CH 6 CH 6 CH 6 CH 2 TW SE C SE C SE C REQ.AND FREQ.EO -RD EC -RO EO -RD EC -RO EO -RD EC -RO SURV INST.NO.SVI-B21 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE DEVICE LIMIT (sccm or gpm)SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 T2011 RD-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RO-18 RD-18 1B21-FD78U 3 B-2 C ACTIVE SE EO -RD C EC -RO SRV (FD51A)DOWNCOMER SRV (FD51B)DOWNCOMER SRV (FD51C)DOWNCOMER SRV (F051D)DOWNCOMER SRV (F051G)DOWNCOMER SRV (F041A)CONTROL VALVE Skid-Mounted Note 12 1B21-F078V 3 C B-10 ACTIVE 1B21-F410A 3 B D-11 ACTIVE SE C SO C EO -R0 EC -RO EQ -RO EC -RO STO-RO STC-RO FS -RO PI -RO 1B21-F410B 3 B D-11 ACTIVE 2 TW So EQ -RO C EC -RO STO-RO STC-RO FS -RO PI -RO T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 N/A N/A SRV (F041A)CONTROL VALVE N/A Skid-Mounted N/A Note 12 lB21-F411A 3 B D-11 ACTIVE 2 TW So C E0 -RO EC -RO STO-RO STC-RO FS -RO PI -RO SRV (F041B)CONTROL VALVE N/A Skid-Mounted N/A Note 12 3.4-12 Rev. 13 SYSTEM: NUCLEAR BOILER (B21)DWG. NO. D-302-605 CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-B21 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT (sccm or ppm)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS lB21-F411B 3 B D-11 ACTIVE 1B21-F412A 3 B B-lI ACTIVE 2 TW 2 TW SO C SO C E0 -RO EC -RO STO-RO STC-RO FS -RO PI -RD ED -RO EC -RD STO-RO STC-RO FS -RO PI -RO lB21-F412B 3 B B-lI ACTIVE 2 so E0 -RO TW C EC -RO STO-RO STC-RO FS -RO PI -RD T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 SRV (F041C)CONTROL VALVE Skid-Mounted Note 12 N/A N/A SRV (F041B)CONTROL VALVE Skid-Mounted Note 12 N/A N/A SRV (F041C)CONTROL VALVE N/A Skid-Mounted N/A Note 12 lB21-F413A 3 B B-lI ACTIVE lB21-F413B 3 B B-lI ACTIVE 2 TW 2 TW SO C SO C ED -RD EC -RO STO-RO STC-RO FS -RO PI -RO EQ -RO EC -RO STO-RO STC-RO FS -RO PI -RO SRV (F041D)CONTROL VALVE Skid-Mounted Note 12 N/A N/A SRV (F041D)CONTROL VALVE Skid-Mounted Note 12 N/A N/A 3.4-13 Rev. 13 SYSTEM: NUCLEAR BOILER (B21)DWG. NO. D-302-605 CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION 1B21-F414A 3 B D-11 ACTIVE 1B21-F414B 3 B D-11 ACTIVE IB21-F415A 3 B D-11 ACTIVE IB21-F415B 3 B D-11 ACTIVE 2 so TW C 2 TW 2 TW 2 TW So C SO C SO C TEST REQ.AND FREQ.E0 -RO EC -RO STO-RO STC-RO FS -RO PI -RO ED -RO EC -RO STO-RO STC-RO FS -RO PI -RO E0 -RO EC -RO STO-RD STC-RO FS -RO PI -RO E0 -RO EC -RO STO-RO STC-RO FS -RO PI -RO SURV INST.NO.SVI-B21 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT (sccm or gpm)DEVICE SET PRESS.REFERENCE VALUE(psi)

T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 SRV (F041E)CONTROL VALVE Skid-Mounted Note 12 N/A N/A JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS SRV (F041E)CONTROL VALVE Skid-Mounted Note 12 N/A N/A SRV (F041F)CONTROL VALVE Skid-Mounted Note 12 N/A N/A SRV (F041F)CONTROL VALVE Skid-Mounted Note 12 N/A N/A IB21-F416A 3 B B-lI ACTIVE 2 TW So ED -RO C EC -RO STO-RO STC-RO FS -RO PI -RO SRV (F041G)CONTROL VALVE N/A Skid-Mounted N/A Note 12 3.4-14 Rev. 13 SYSTEM: NUCLEAR BOILER (B21)DWG. NO. D-302-605 CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-B21 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT (sccm or gpm)DEVICE SET PRESS.REFERENCE VALUE (psi)JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 1B21-F416B 3 B B-il ACTIVE 2 TW So EC -RO C EC -RO STO-RO STC-RO FS -RO PI -RO lB21-F417A 3 B B-lI ACTIVE IB21-F417B 3 B B-lI ACTIVE 2 TW 2 TW SO C SO C E0 -RO EC -RO STO-RO STC-RO FS -RO PI -RO EO -RO EC -RO STO-RO STC-RO FS -RO PI -RO T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 SRV (F041G)CONTROL VALVE Skid-Mounted Note 12 N/A N/A SRV (F041K)CONTROL VALVE Skid-Mounted Note 12 N/A N/A SRV (F041K)CONTROL VALVE Skid-Mounted Note 12 N/A N/A 1B21-F420A 3 B B-lI ACTIVE 2 TW So EO -RO C EC -RO STO-RO STC-RO FS -RO PI -RO SRV (F047B)CONTROL VALVE Skid-Mounted Note 12 N/A N/A IB21-F420B 3 B B-lI ACTIVE 2 TW So C E0 -RO EC -RO STO-RO STC-RO FS -RO PI -RO SRV (F047B)CONTROL VALVE N/A Skid-Mounted N/A Note 12 3.4-15 Rev. 13 SYSTEM: NUCLEAR BOILER (B21)DWG. NO. D-302-605 CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION lB21-F421A 3 B B-lI ACTIVE IB21-F421B 3 B B-lI ACTIVE lB21-F422A 3 B D-11 ACTIVE 2 TW 2 TW 2 TW SO C So C SO C TEST REQ.AND FREQ.EO -RO EC -RO STO-RO STC-RO FS -RO PI -RO ED -RO EC -RO STO-RO STC-RO FS -RO PI -RO EO -RO EC -RO STO-RO STC-RO FS -RO PI -RO SURV INST.NO.SVI-B21 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT (sccm or gpm)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 REMARKS SRV (F047C)CONTROL VALVE Skid-Mounted Note 12 N/A N/A SRV (F047C)CONTROL VALVE Skid-Mounted Note 12 N/A N/A SRV (F047D)CONTROL VALVE Skid-Mounted Note 12 N/A N/A IB21-F422B 3 B D-lI ACTIVE 2 TW SO EO -RO C EC -RO STO-RO STC-RO FS -RO PI -RO SRV (F047D)CONTROL VALVE N/A Skid-Mounted N/A Note 12 lB21-F423A 3 B B-il ACTIVE 2 TW So C EO -RO EC -RO STO-RO STC-RO FS -RO PI -RO SRV (F047F)CONTROL VALVE N/A Skid-Mounted N/A Note 12 3.4-16 Rev. 13 SYSTEM: NUCLEAR BOILER (B21)DWG. NO. D-302-605 CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION IB21-F423B 3 B B-lI ACTIVE 2 TW SO C TEST REQ.AND FREQ.EQ -RO EC -RO STO-RO STC-RO FS -RO PI -RO SURV INST.NO.SVI-B21 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT (sccm or ppm)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS IB21-F424A 3 B B-li ACTIVE 2 TW SO EQ -RO C EC -RO STO-RO STC-RO FS -RO PI -RO IB21-F424B 3 B B-Il ACTIVE 2 TW So C EQ -RO EC -RO STO-RO STC-RO FS -RO PI -RO EQ -RO EC -RO STO-RO STC-RO FS -RO PI -RO T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 SRV (F047F)CONTROL VALVE N/A Skid-Mounted N/A Note 12 SRV (F047G)CONTROL VALVE N/A Skid-Mounted N/A Note 12 SRV (F047G)CONTROL VALVE N/A Skid-Mounted N/A Note 12 IB21-F425A 3 B D-Il ACTIVE 1B21-F425B 3 B D-11 ACTIVE 2 So TW C SRV (F047H)CONTROL VALVE Skid-Mounted Note 12 N/A N/A 2 TW So EQ -RO C EC -RO STO-RO STC-RO FS -RD PI -RO SRV (F047H)CONTROL VALVE Skid-Mounted Note 12 N/A N/A 3.4-17 Rev. 13 SYSTEM: NUCLEAR BOILER (B21)DWG. NO. D-302-605 CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-B21 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT (sccm or gpm)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 1B21-F440A 3 B B-Il ACTIVE IB21-F440B 3 B B-Il ACTIVE IB21-F441A 3 B B-Il ACTIVE 2 TW 2 TW 2 TW SO C So C SO C EQ -RO EC -RO STO-RO STC-RO FS -RO PI -RO EQ -RO EC -RO STO-RO STC-RO FS -RO PI -RO EQ -RO EC -RO STO-RO STC-RO FS -RO PI -RO T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 SRV (F051A)CONTROL VALVE Skid-Mounted Note 12 N/A N/A SRV (FO51A)CONTROL VALVE Skid-Mounted Note 12 N/A N/A SRV (F051B)CONTROL VALVE Skid-Mounted Note 12 N/A N/A IB21-F441B 3 B B-lI ACTIVE 2 TW 2 TW So E0 -RO C EC -RO STO-RO STC-RO FS -RO PI -RO So EQ -RO C EC -RO STO-RO STC-RO FS -RO PI -RO SRV (FO51B)CONTROL VALVE Skid-Mounted Note 12 N/A N/A IB21-F442A 3 B D-11 ACTIVE SRV (F051C)CONTROL VALVE Skid-Mounted Note 12 N/A N/A 3. 4-18 Rev. 13 SYSTEM: NUCLEAR BOILER (B21)DWG. NO. D-302-605 CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION IB21-F442B 3 B D-l1 ACTIVE IB21-F443A 3 B B-li ACTIVE 1B21-F443B 3 B B-lI ACTIVE IB21-F444A 3 B D-II ACTIVE IB21-F444B 3 B D-Il ACTIVE 2 TW 2 TW 2 TW SO C SO C So C TEST REQ.AND FREQ.EQ -RO EC -RO STO-RO STC-RO FS -RO PI -RO EQ -RO EC -RO STO-RO STC-RO FS -RO PI -RO EQ -RO EC -RO STO-RO STC-RO FS -RO PI -RO EQ -RO EC -RO STO-RO STC-RO FS -RO PI -RO EQ -RO EC -RO STO-RO STC-RO FS -RO PI -RO SURV INST.NO.SVI-B21 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT (sccm or gpm)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 T2012/T2005 REMARKS SRV (F051C)CONTROL VALVE Skid-Mounted Note 12 N/A N/A SRV (F051D)CONTROL VALVE Skid-Mounted Note 12 N/A N/A SRV (F051D)CONTROL VALVE Skid-Mounted Note 12 N/A N/A 2 so TW C SRV (F051G)CONTROL VALVE Skid-Mounted Note 12 N/A N/A 2 TW SO C SRV (F051G)CONTROL VALVE Skid-Mounted Note 12 N/A N/A 3.4-19 Rev. 13 SYSTEM: NUCLEAR BOILER (B21)DWG. NO. D-302-607 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-B21 VALVE/DEVICE NO.IB21-RO11A-F STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE (psi)JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 1B21-RO11A-G 2 C-3 2 C-4 2 F-3 2 F-4 AC ACTIVE AC ACTIVE AC ACTIVE AC ACTIVE IB21-RO11B-F IB21-RO11B-G 3/8 CH 3/8 CH 3/8 CH 3/8 CH 3/8 CH SE 0 SE EO 0 EC LD EO EC LD SE 0 SE 0 SE 0 IB21-RO11C-F IB21-RO11C-G IB21-RO11D-F IB21-R0lID-G 2 AC J-12 ACTIVE 2 AC J-13 ACTIVE 2 AC J-8 ACTIVE 2 AC J-9 ACTIVE EO EC LD EO EC LD EO EC LD E0 EC LD EO EC LD-RO-RO-2Y-RO-RO-2Y-RO-RO-2Y-RO-RO-2Y-RO-RO-2Y-RO-RO-2Y-RO-RO-2Y T2222 T2222 T2222 T2222 T2222 T2222 T2223 T2223 T2223 T2223 T2223 T2223 T2222 T2222 T2222 T2222 T2222 T2222 T2223 T2223 T2223 T2223 T2223 T2223 0.0 0.0 0.0 0.0 RO-20 RO-20 RO-20 RO-20 RO-20 RO-20 RO-20 RO-20 RO-20 RO-20 RO-20 RO-20 RO-20 RO-20 RO-20 RO-20 0.0 RX INSTRUMENT REFERENCE LEG FILL RX INSTRUMENT REFERENCE LEG FILL RX INSTRUMENT REFERENCE LEG FILL RX INSTRUMENT REFERENCE LEG FILL RX INSTRUMENT REFERENCE LEG FILL RX INSTRUMENT REFERENCE LEG FILL RX INSTRUMENT REFERENCE LEG FILL RX INSTRUMENT REFERENCE LEG FILL 3/8 SE CH 0 3/8 SE CH 0 3/8 SE CH 0 0.0 0.0 EQ -RO EC -RO LD -2Y 0.0 3.4-20 Rev. 13 SYSTEM: REACTOR WATER RECIRCULATION (B33)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1B33-F019 2 B B-6 ACTIVE 2 B B-4 ACTIVE 3/4 AO DI C 3/4 AO DI C TEST REQ.AND FREQ.EC -Q STC-Q FS -Q PI -2Y EC -Q STC-Q FS -Q PI -2Y SURV INST.NO.SVI-B33 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE (psi)DWG. NO. D-302-602 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 3.1*3.2*1B33-F020 3.4-21 Rev. 13 SYSTEM: CONTROL ROD DRIVE HYDRAULICS (Cll)DWG. NO. D-302-871 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.lCll-F010 lCll-F011 lCll-F083 2 B D-11 ACTIVE 2 B F-lI ACTIVE 2 A H-4 ACTIVE 1 AO GL 0 TEST REQ.AND FREQ.EC -Q STC-Q FS -Q PI -2Y EC -Q STC-Q FS -Q PI -2Y EC -CS STC-CS LJ -PB PI -2Y SURV INST.NO.SVI-Cll STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 2 GL AO 0 2 1/2 MO GT 0 T2004 T2004 T2004 T2004 T2004 T2004 T2004 T2004 T2002 T2002 T9204 T2002 T2004 T2004 T2004 T2004 T2004 T2004 T2004 T2004 12.7*19.4*SUPPLEMENTAL (PI) PTI-CIl-P0007 AND NOTE: 2 SUPPLEMENTAL (PI) PTI-CII-P0007 AND NOTE: 2 VR-Pendingl0296 CS-6 CS-6/VR--3 9.0*1,000.0 VR-3 lCIl-F180 2 B D-12 ACTIVE 1 AO EC -Q GL 0 STC-Q FS -Q PI -2Y 25.2*SUPPLEMENTAL (PI) PTI-Cll-P0007 AND NOTE: 2 SUPPLEMENTAL (PI) PTI-Cll-P0007 AND NOTE: 2 lCll-FI81 2 B F-12 ACTIVE 2 GL AO 0 EC -Q STC-Q FS -Q PI -2Y 26.1*3.4-22 Rev. 13 SYSTEM: CONTROL ROD DRIVE HYDRAULICS (ClI)DWG. NO. D-302-872 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-Cil STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.VALVE/DEVICE NO.lCli-F122 REMARKS 2 AC G-13 ACTIVE 2 1/2 SE EC -CVCM T9204 CH 0 EO -RO T1300-1 (ISI-B21)LJ-PB T9204 RO-13 RO-13 1,000.0 ASSEMBLY lCll-114 ASSEMBLY lCll-115 ASSEMBLY lCll-120 ASSEMBLY lCll-121 ASSEMBLY lCll-122 ASSEMBLY lCll-123 2 C C-4 ACTIVE 2 B D-10 ACTIVE 2 B C-7 ACTIVE 2 B C-6 ACTIVE 2 B C-6 ACTIVE 2 B C-7 ACTIVE 3/4 CH 3/4 CH 3/4 GT 3/4 GT 3/4 GT SE C SE C SO C SO C SO C EO -RO EC -RO EO -RO EC -RO T1006 N/A VR-I T1006 T2001 VR-1 RO-31 ED EC FS EO EC FS EO EC FS-W-W-W-W-W-W-W-W-W T1003A(B)T1003A (B)T1003A (B)T1003A(B)T1003A(B)T1003A(B)T1003A (B)T1003A (B)T1003A(B)T1003A(B)T1003A(B)T1003A (B)TYPICAL OF 177 HCUs, SCRAM INSERTION TIME Skid Mounted Note 14 TYPICAL OF 177 HCUs, SCRAM INSERTION TIME TYPICAL OF 177 HCUs, ROUTINE ROD NOTCH TYPICAL OF 177 HCUs, ROUTINE ROD NOTCH TYPICAL OF 177 HCUs, ROUTINE ROD NOTCH TYPICAL OF 177 HCUs, ROUTINE ROD NOTCH 3/4 so GT C EO -W EC -W FS -W 3.4-23 Rev. 13 SYSTEM: CONTROL ROD DRIVE HYDRAULICS (ClI)DWG. NO. D-302-872 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-ClI STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.VALVE/DEVICE NO.ASSEMBLY lCll-126 ASSEMBLY lCll-127 ASSEMBLY IClI-138 REMARKS 2 B C-9 ACTIVE 2 B B-5 ACTIVE 2 C D-8 ACTIVE 1/2 AO EO -RO GL C STO-RO FS -RO T1006 T1006 T1006 T1006 T1006 T1006 N/A N/A VR-1 VR-1 VR-l VR-1 VR-I VR-I 3/4 AO GL C 1/2 SE CH O EO -RO STO-RO FS -RO EC -Q EC -W TYPICAL OF 177 HCUs, SCRAM INSERTION TIME TYPICAL OF 177 HCUs, SCRAM INSERTION TIME TYPICAL OF 177 HCUs, ROUTINE ROD NOTCH T2001(GEN)

T1003A(B)3.4-24 Rev. 13 SYSTEM: STANDBY LIQUID CONTROL (C41)CLASS AND DWG.COOD.VALVE CATEGORY/ACTIVE OR PASSIVE VALVE/DEVICE NO.1C41-F001A IC41-F001B 1C41-F004A IC41-FO04B 1C41-F006 iC41-F007 2 B D-6 ACTIVE 2 B F-6 ACTIVE 2 D D-12 ACTIVE 2 D G-11 ACTIVE 1 AC F-13 ACTIVE 1 AC F-13 ACTIVE 2 C D-9 ACTIVE 2 C F-9 ACTIVE SIZE (in.)AND TYPE 4 GL 4 GL 1 1/2 SQ 1 1/2 SQ ACTUATOR TYPE/NORMAL POSITION MO C MO C EX C EX C TEST REQ.AND FREQ.EO -Q STO-Q PI -2Y EO -Q STO-Q PI -2Y SURV INST.NO.SVI-C41 T2001A T2001A T2001A T2001B T2001B T2001B STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-691 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS 15*VR-3 VR-3 VR-3 VR-3 VR-Pending 6276 VR-Pending 12650 16*EX -10YE T2002 EX -10YE T2002 1 1/2 SE CH C 1 1/2 SE CH C EO -RO EC -RD LK -2Y EO -RO EC -RO LK -2Y T2002 T2200 T2200 T2002 T2200 T2200 0.75 RO-10 RO-10 RO-10 RO-10 0.75 1C41-F029A 1C41-F029B 1 1/2 RE 1 1/2 RE SE C SE C RT -10Y T2100(GEN)

RT -10Y T2100(GEN) 1,400.0 1,400.0 5.0 psi BACK PRESSURE 5.0 psi BACK PRESSURE 3.4-25 Rev. 13 SYSTEM: STANDBY LIQUID CONTROL (C41)DWG. NO. D-302-691 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.VALVE/DEVICE NO.IC41-F033A IC41-FD33B 1C41-F036 2 AC D-10 ACTIVE 2 AC F-10 ACTIVE 1 B F-14 PASSIVE 1 1/2 SE CH C 1 1/2 SE CH C 1 1/2 MA GT LO EO -Q EC -RO LD -2Y EO -Q EC -RO LD -2Y PI -2Y SURV INST.NO.SVI-C41 T2001A T2201 T2201 T2001B T2201 T2201 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS RO-16 1.0 RO-16 1.0 T2200 MAINTENANCE ONLY 3.4-26 Rev. 13 SYSTEM: STANDBY LIQUID CONTROL TRANSFER (C41)DWG. NO. D-302-692 CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION C41-F511A C41-FS11B C41-Fý13A C41-Fý13B C41-FS14A C41-FS14B C41-FS15 C41-FS16A C41-F516B lC41-PS18 03 B F-6 ACTIVE 03 B F-9 ACTIVE 3/4 MA GL C 3/4 MA GL C 03 G-7 C ACTIVE 03 C G-9 ACTIVE 03 H-7 B ACTIVE 03 B H-9 ACTIVE 2 CH 2 CH 2 GL 2 GL 2 GL 2 GL 2 GL SE C SE C MA C MA C MA C MA C MA C TEST REQ.AND FREQ.ED -RO EC -RO EO -RO EC -RO EO -RO EC -RO EO -RO EC -RO EO -RO EC -RO EO -RO EC -RO EO -RO EC -RO EO -RO EC -RO EO -RO EC -RO N/A N/A LJ -PB SURV INST.NO.SVI-C41 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS P0001 (PTI)P0001 (PTI)P0001 (PTI)P0001 (PTI)P0001 (PTI)P0001 (PTI)*P0001 (PTI)P0001 (PTI)P0001 (PTI)P0001 (PTI)P0001 (PTI)P0001 (PTI)P0001 (PTI)P0001 (PTI)P0001 (PTI)P0001 (PTI)P0001 (PTI)P0001 (PTI)OPTIONAL (ISI)SYSTEM OPTIONAL (ISI)SYSTEM OPTIONAL (ISI)SYSTEM OPTIONAL (ISI)SYSTEM OPTIONAL (ISI)SYSTEM OPTIONAL (ISI)SYSTEM OPTIONAL (ISI)SYSTEM OPTIONAL (ISI)SYSTEM OPTIONAL (ISI)SYSTEM VERIFICATION OPEN PTI-C41-P0001 03 H-8 B ACTIVE 03 B G-6 ACTIVE 03 H-8 B ACTIVE 2 A 2 MA H-5 PASSIVE GL LC N/A N/A T9315 1,000.0 3.4-27 Rev. 13 SYSTEM: STANDBY LIQUID CONTROL TRANSFER (C41)DWG. NO. D-302-692 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-C41 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.VALVE/DEVICE NO.1C41-F520 REMARKS 2 AC 2 H-4 PASSIVE CH SE C EO -RO EC -PB LJ -PB T2005 (GEN)T9315 T9315 VERIFICATION OPEN PTI-C41-1,000.0 P0001 IC41-F527 C41-F529A C41-F529B 03 B J-6 ACTIVE 03 C G-7 ACTIVE 03 C G-10 ACTIVE 03 C D-5 ACTIVE 03 C D-8 ACTIVE GL C 2 MA EO -RO P0001 (PTI)1 SE RT -10Y T2100 (GEN)39.0 EC -RO P0001 (PTI)RE C OPTIONAL (ISI)SYSTEM OPTIONAL (ISI)SYSTEM OPTIONAL (ISI)SYSTEM 1 SE RT -10Y T2100 (GEN)RE C 39.0 C41-F542A C41-F542B 3/4 CH 3/4 CH SE C SE C N/A N/A N/A N/A N/A N/A N/A N/A VERIFICATION OPEN PTI-C41-P0001 VERIFICATION OPEN PTI-C41-P0001 3.4-28 Rev. 13 SYSTEM: PLANT RADIATION MONITORING (D17)DWG. NO. D-806-004 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1D17-F071A TEST REQ.AND FREQ.EC -Q STC-Q FS -Q LJ -PB PI -2Y SURV INST.NO.SVI-D17 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE (psi)JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 2 A 1 B-13 ACTIVE BA HO 0 T2001 T2001 T2001 T9201 T2001 2.0*SPRING TO CLOSE, ON LOSS OF POWER 1,000.0 1D17-F071B 1D17-F079A 2 A B-14 ACTIVE 2 A B-lI ACTIVE 1 BA 1 GL HO MO 0 0 EC -Q T2001 STC-Q T2001 FS -Q T2001 LJ -PB T9201 PI -2Y T2001 2.0*SPRING TO CLOSE, ON LOSS OF POWER 1,000.0 EC -Q STC-Q LJ -PB PI -2Y EC -Q STC-Q LJ -PB PI -2Y T2001 T2001 T9201 T9201/T2003 T2001 T2001 T9201 T9201/T2003 2.0*1,000.0 SOLENOID TO OPEN, SOLENOID TO CLOSE SOLENOID TO OPEN, SOLENOID TO CLOSE 1D17-F079B 2 A B-II ACTIVE 1 GL SO 0 2.0*1,000.0 3.4-29 Rev. 13 SYSTEM: PLANT RADIATION MONITORING (D17)DWG. NO. D-806-007 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-D17 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.VALVE/DEVICE NO.1D17-F081A 1D17-F081B REMARKS 2 A B-13 ACTIVE 2 A B-13 ACTIVE 1 BA 1 BA HO MO 0 HO 0 EC -Q T2001 STC-Q T2001 FS -Q T2001 LJ -PB T8317 PI -2Y T2001 EC -Q T2001 STC-Q T2001 FS -Q T2001 LJ -PB T8317 PI -2Y T2001 2.0*2.0*SPRING TO CLOSE, ON LOSS OF POWER 1,000.0 SPRING TO CLOSE, ON LOSS OF POWER 1,000.0 1D17-F089A 1D17-F089B 2 A B-11 ACTIVE 2 A B-10 ACTIVE 1 GL 1 GL SO 0 SO 0 EC -Q STC-Q LJ -PB PI -2Y EC -Q STC-Q LJ -PB PI -2Y T2001 T2001 T8317 T8317/T2003 T2001 T2001 T8317 T8317/T2003 2.0*1,000.0 SOLENOID TO OPEN, SOLENOID TO CLOSE SOLENOID TO OPEN, SOLENOID TO CLOSE 2.0*1,000.0 3.4-30 Rev. 13 SYSTEM: CONTAINMENT ATMOSPHERE MONITORING (D23)DWG. NO. D-302-881 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1D23-F010A 1D23-F010B 2 A B-4 ACTIVE 2 A B-lI ACTIVE 3/4 GL SO 0 3/4 so GL 0 TEST REQ.AND FREQ.EC -CS STC-CS FS -CS LD -2Y PI -2Y EC -CS STC-CS FS -CS LD -2Y PI -2Y EC -CS STC-CS FS -CS LD -2Y PI -2Y EC -CS STC-CS FS -CS LD -2Y PI -2Y EC -CS STC-CS FS -CS LD -2Y PI -2Y SURV INST.NO.SVI-D23 T2001 T2001 T2001 T2002A T2002A T2001 T2001 T2001 T2002B T2002B T2001 T2001 T2001 T2002A T2002A T2001 T2001 T2001 T2002B T2002B T2001 T2001 T2001 T2002A T2002A STROKE TIME REFERENCE VALUE(sec) 2.0*CS-10 CS-10 CS-10 LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.CONTAINMENT INSTRUMENT LINE 1,000.0 REMARKS 2.0*CS-10 CS-10 CS-10 CONTAINMENT INSTRUMENT LINE 1,000.0 ID23-F020A 1D23-F020B 2 A C-4 ACTIVE 2 A C-lI ACTIVE 3/4 so GL 0 3/4 so GL 0 2.0*CS-10 CS-10 CS-10 CONTAINMENT INSTRUMENT LINE 1,000.0 2.0*CS-10 CS-10 CS-10 CONTAINMENT INSTRUMENT LINE 1,000.0 1D23-F030A 2 A F-4 ACTIVE 3/4 so GL 0 2.0*CS-10 CS-10 CS-10 CONTAINMENT INSTRUMENT LINE 1,000.0 3.4-31 Rev. 13 SYSTEM: CONTAINMENT ATMOSPHERE MONITORING (D23)DWG. NO. D-302-881 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1D23-F030B 1D23-F040A 2 A F-lI ACTIVE 2 A F-4 ACTIVE 3/4 GL 3/4 GL SO 0 SO 0 TEST REQ.AND FREQ.EC -CS STC-CS FS -CS LD -2Y PI -2Y EC -CS STC-CS FS -CS LD -2Y PI -2Y EC -CS STC-CS FS -CS LD -2Y PI -2Y EC -CS STC-CS FS -CS LD -2Y PI -2Y SURV INST.NO.SVI-D23 T2001 T2001 T2001 T2002B T2002B T2001 T2001 T2001 T2002A T2002A T2001 T2001 T2001 T2002B T2002B T2001 T2001 T2001 T2002C T2002C STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 2.0*CS-10 CS-10 CS-1O CONTAINMENT INSTRUMENT LINE 1,000.0 2.0*CS-10 CS-10 CS-10 CONTAINMENT INSTRUMENT LINE 1,000.0 1D23-F040B 1D23-F050 2 A F-1i ACTIVE 3/4 GL 3/4 GL SO 0 SO 0 2.0*CS-10 CS-10 CS-10 CONTAINMENT INSTRUMENT LINE 1,000.0 2 B-4 A ACTIVE 2.0*CS-10 CS-10 CS-10 CONTAINMENT INSTRUMENT LINE 1,000.0 3.4-32 Rev. 13 SYSTEM: RESIDUAL HEAT REMOVAL (E12)DWG. NO. D-302-641 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1E12-F003A TEST REQ.AND FREQ.EO -Q EC -Q STO-Q STC-Q PI -2Y SURV INST.NO.SVI-E12 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 2 B D-12 ACTIVE 18 GL MO 0 1E12-F011A 2 A C-10 ACTIVE 4 MO EO -Q GL C EC -Q STO-Q STC-Q LW -PB PT -2Y T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T9105 T2001 T2001 T2001 T2001 T2001 T9105 T2001 56.0*55.6*VR-3 VR-3 VR-3 SVI-C61-T1201 REMOTE S/D PANEL VR-Pending 23104 SVI-C61-T1201 REMOTE S/D PANEL 29.9*29.2*5.0 1E12-F024A 1E12-F025A 2 F-4 2 C-5 A ACTIVE AC ACTIVE 18 GL 1 RE MO C SE C EO -Q EC -Q STO-Q STC-Q LW -PB PI -2Y SVI-C61-T1201 REMOTE S/D PANEL 96.0 95.0 VR-3 VR-3 VR-3 5.0 VR-Pending 40316 RT -10Y T2100 (GEN)LJ -PB T9107 485.0 1386.0 3.4-33 Rev. 13 SYSTEM: RESIDUAL HEAT REMOVAL (E12)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1E12-F031A 1E12-F040 2 C K-7 ACTIVE 18 SE CH C TEST REQ.AND FREQ.ED -Q EC -Q EO -Q EC -Q STO-Q STC-Q PI -2Y EO -Q EC -Q SURV INST.NO.SVI-E12 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)2 F-7 DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-641 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS B ACTIVE 8 GL MO C 1E12-F046A 1E12-F047A 2 C G-6 ACTIVE 2 B F-10 ACTIVE 6 CH SE C 18 MO EO -Q GT 0 EC -Q STO-Q STC-Q PI -2Y T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 SVI-C61-T1201 REMOTE S/D 85.0* PANEL 85.0*SVI-C61-TI201 REMOTE S/D 17.0* PANEL 17.0*IEI2-F048A 2 B E-7 ACTIVE 18 GL MO 0 ED -Q EC -Q STO-Q STC-Q PT -2Y 75.0*73.0*VR-3 VR-3 VR-3 SVI-C61-T1201 REMOTE S/D PANEL VR-Pending 26029 IEI2-F049 2 B E-7 ACTIVE 8 MO EO -Q GT C EC -Q STO-Q STC-Q PI -2Y 41.2*40.8*3.4-34 Rev. 13 SYSTEM: RESIDUAL HEAT REMOVAL (E12)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-EI2 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE (psi)DWG. NO. D-302-641 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS VALVE/DEVICE NO.1E12-F055A IE12-F060A 2 AC E-9 ACTIVE 2 B E-13 ACTIVE 4 RE 3/4 GL SE C SO C RT -10Y T2100 (GEN)LJ -PB T9107 485.0 1386.00 1E12-F064A 2 A H-6 ACTIVE 6 GT MO 0 EO -Q EC -Q STO-Q STC-Q FS-Q PI -2Y EO -Q EC -Q STO-Q STC-Q LW -PB PI -2Y EO -Q EC -Q STO-Q STC-Q LJ -2Y Pi -2Y T2001 T2001 T2001 T2001 T2001 T2017 2.0*2.0*T2001 T2001 T2001 T2001 T9105/T8105 T2001 SVI-C61-T1201 REMOTE S/D PANEL 12.0 12.0 VR-3 VR-3 VR-3 3.0 VR-Pending 46229 1E12-F073A 2 A F-9 ACTIVE 1 GL MO C T2001 T2001 T2001 T2001 T9118 T2001 T2001 T2001 T2001 T2001 T2001 9.0*9.0*1,000.0 1E12-F074A 2 B G-9 ACTIVE 1 MO EO -Q GL C EC -Q STO-Q STC-Q Pi -2Y 8.3 7.7 3.4-35 Rev. 13 SYSTEM: RESIDUAL HEAT REMOVAL (E12)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE VALVE/DEVICE NO.1E12-F075A 1E12-F084A 1E12-F085A 1E12-F552A 1E12-F609 1E12-F610 SIZE (in.)AND TYPE 3/4 GL ACTUATOR TYPE/NORMAL POSITION SO C 2 B E-14 ACTIVE TEST REQ.AND FREQ.EO -Q EC -Q STO-Q STC-Q FS -Q PI -2Y SURV INST.NO.SVI-E12 T2001 T2001 T2001 T2001 T2001 T2017 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-641 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS 2.0*2.0*2 J-7 C ACTIVE 1 1/2 SE CH C 1 1/2 SE SC C EO -CVCM T2004 (E21)EC -CVCM T2000 (GEN)EO -RO T2004 (E21)EC -Q T2001 RO-32 RO-33 RO-32 2 C J-7 ACTIVE 2 C-4 2 F-3 C ACTIVE A ACTIVE 10 SC 6 GT 6 GT SE EO -Q LC EC -Q MO EO -Q C EC -Q STO-Q STC-Q LW -PB PI -2Y T2002 (G42)T2002 (G42)CLOSED USING HANDWHEEL CLOSE USING HANDWHEEL SVI-C61-T1201 REMOTE S/D PANEL VR-Pending 22987 T2001 T2001 T2001 T2001 T9105 T2001 T2001 T2001 T2001 T2001 T9105 T2001 27.0*27.0*VR-3 VR-3 VR-3 5.0 2 A E-3 ACTIVE MO C EO -Q EC -Q STO-Q STC-Q LW -PB PI -2Y 27.0*27.0*VR-3 VR-3 VR-3 5.0 VR-Pending 12586 3.4-36 Rev. 13 SYSTEM: RESIDUAL HEAT REMOVAL (E12)DWG. NO. D-302-642 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1E12-F004A 1E12-F004B 2 A H-12 ACTIVE 24 GT 24 GT MO 0 MO 0 TEST REQ.AND FREQ.EO -Q EC -Q STO-Q STC-Q LW -PB PI -2Y EO -Q EC -Q STO-Q STC-Q LW -PB PI -2Y SURV INST.NO.SVI-E12 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS T2001 T2001 T2001 T2001 T9102 T2001 T2002 T2002 T2002 T2002 T9402 T2002 115.5*112.5*VR- 3 VR-3 VR-3 5.0 SVI-C61-T1201 REMOTE S/D PANEL VR-Pending 13650 SVI-C61-T1202 REMOTE SID LOCAL BREAKER 2 H-5 A ACTIVE 115.0*115.0*VR-3 VR-3 VR-3 5.0 VR-Pending 12816 1El2-F005 2 J-9 AC ACTIVE 1 RE 18 GT SE C RT -10Y T2100 LJ -PB T9429 (GEN)185.0 1386.0 1E12-F006A 2 B J-13 ACTIVE MO EO -Q C EC -Q STO-Q STC-Q PI -2Y T2001 T2001 T2001 T2001 T2001 T2002 T2002 T2002 T2002 T2002 SVI-C61-TI201 REMOTE S/D 84.1* PANEL 82.9*SVI-C61-T1200 REMOTE S/D 83.0* PANEL 83.0*1E12-F006B 2 B J-4 ACTIVE 18 GT MO C EO -Q EC -Q STO-Q STC-Q PI -2Y 3.4-37 Rev. 13 SYSTEM: RESIDUAL HEAT REMOVAL (E12)DWG. NO. D-302-642 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1E12-F008 1E12-F009 1 A G-12 ACTIVE 1 A G-10 ACTIVE 20 GT 20 GT MO C MO C TEST REQ.AND FREQ.EO -Q EC -Q STO-Q STC-Q LJ -PB LK -2Y PI -2Y EO -Q EC -Q STO-Q STC-Q LJ -PB LK -2Y PI -2Y SURV INST.NO.SVI-E12 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

T2022 T2022 T2022 T2022 T9421 T2200 T2022 T2022 T2022 T2022 T2022 T9421 T2200 T2022 JUSTIFI-CATIONS &RELIEF REQUEST NO.CS-3 CS-3 CS-3/VR-3 CS-3/VR-3 REMARKS 30.4*30.2*4159.0 5.0 VR-3 CS-3 CS-3 CS-3/VR-3 CS-3/VR-3 29.4*28.8*12,000.0 5.0 SVI-C61-T1201 REMOTE S/D PANEL INTERSYSTEM LEAKAGE LIMIT OF 0.3 GPM VR-Pending 16841 SVI-C61-T1200 REMOTE S/D PANEL INTERSYSTEM LEAKAGE LIMIT OF 0.3 GPM VR-Pending 16843 MAINTENANCE ONLY LOC PROGRAM LOC PROGRAM LOC PROGRAM VR-3 1E12-F010 1E12-F017A 1E12-F017B 1E12-F017C 1E12-F019 1 B 20 G-10 PASSIVE GT 2 C J-12 ACTIVE 2 H-4 2 G-4 C ACTIVE C ACTIVE 1 RE 1 RE 1 RE MA 0 SE C SE C SE C RT -10Y T2100 (GEN)RT -10Y T2100 (GEN)RT -10Y T2100 (GEN)EO -CS T2016 OR E51-T2010 EC -RO T2202 LK -2Y T2202 5 dpm 5 dpm 5 dpm PI -2Y T2200 200.0 200.0 200.0 1 AC B-13 ACTIVE 6 SE CH C CS-12 RO-12 3.0 3.4-38 Rev. 13 SYSTEM: RESIDUAL HEAT REMOVAL (E12)DWG. NO. D-302-642 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1E12-F023 1 A C-13 ACTIVE 6 GL MO C TEST REQ.AND FREQ.EO -CS EC -CS STO-CS STC-CS LJ -PB LK -2Y PI -2Y SURV INST.NO.SVI-E12 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE (psi)JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS T2004A T2004A T2004A T2004A T9123 (E51)T2202 T2004A CS-3 CS-3 CS-3 CS-3 SVI-C61-T1201 REMOTE S/D PANEL 32.1*30. 6*1386.0 3.0/0.036 NOTE 10 1E12-F025C 2 C-3 AC ACTIVE 1E12-F027A 1E12-F027B 2 A D-12 ACTIVE 2 A E-4 ACTIVE 1 RE 12 GT 12 GT SE C MO 0 MO 0 RT -10Y T2100 (GEN)LJ -PB T9429 485.0 1386.0 EO -Q EC -Q STO-Q STC-Q LJ -PB PI -2Y EO -Q EC -Q STO-Q STC-Q LJ -PB PI -2Y EO -Q EC -Q STO-Q STC-Q LJ -PB PI -2Y T2001 T2001 T2001 T2001 T9113 T2001 T2002 T2002 T2002 T2002 T9412 T2002 T2001 T2001 T2001 T2001 T9113 T2001 52. 9*51.7*VR-3 VR-3 VR-3 2773.0 SVI-C61-T1201 REMOTE S/D PANEL VR-Pending 10841 SVI-C61-T1202 REMOTE S/D LOCAL BREAKER 52.0*51.0*VR-3 VR-3 VR-3 2773.0 VR-Pending 16078 1E12-F028A 2 A 12 A-10 ACTIVE GT MO C 76.8*74 .7*VR-3 VR-3 VR-3 2773.0 SVI-C61-T1201 REMOTE S/D PANEL VR-Pending 16223 Rev. 13 3.4-39 SYSTEM: RESIDUAL HEAT REMOVAL (E12)DWG. NO. D-302-642 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1E12-F028B 1E12-F037A 2 A B-6 ACTIVE 2 A B-l1 ACTIVE 12 GT 12 GL MO C MO C TEST REQ.AND FREQ.EO -Q EC -Q STO-Q STC-Q LJ -PB PI -2Y EO -CS EC -CS STO-CS STC-CS LJ -PB PI -2Y EO -CS EC -CS STO-CS STC-CS LJ -PB PI -2Y SURV INST.NO.SVI-E12 T2002 T2002 T2002 T2002 T9412 T2002 T2004A T2004A T2004A T2004A T8113 T2004A T2004B T2004B T2004B T2004B T8412 T2004B STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 75.6*74.3*VR-3 VR-3 VR-3 2773.0 SVI-C61-T1202 REMOTE S/D LOCAL BREAKER VR-Pending 16102 SVI-C61-T1201 REMOTE S/D PANEL CS-iI CS-li CS-II CS-Il 58.4*58.3*2773.0 IEI2-F037B 2 A B-6 ACTIVE 12 GL MO C CS-il CS-il CS-II CS-lI SVI-C61-T1202 REMOTE S/D LOCAL BREAKER 58.0*58.0*2773.0 1E12-F039A IEl2-F039B IE12-F039C 1 D-9 B PASSIVE 1 B E-7 PASSIVE 1 B C-7 PASSIVE 12 MA GT 0 12 MA GT 0 12 MA GT 0 PI -2Y T2204 PI -2Y T2205 PI -2Y T2206 MAINTENANCE ONLY MAINTENANCE ONLY MAINTENANCE ONLY 3.4-40 Rev. 13 SYSTEM: RESIDUAL HEAT REMOVAL (E12)DWG. NO. D-302-642 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE ACTUATOR TEST VALVE/DEVICE NO.1E12-F041A 1E12-F041B (in.)AND TYPE TYPE/NORMAL POSITION REQ.AND FREQ.SURV INST.NO.SVI-E12 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 1 AC D-10 ACTIVE 1 AC E-6 ACTIVE 12 CH 12 CH SE/HO EO C EC LK PI SE/HO EO C EC LK PI SE/HO EO C EC LJ LK PI-CS-CS-2Y-2Y-CS-CS-2Y-2Y-CS-CS-PB-2Y-2Y T2003 T2003 T2204 T2003 T2003 T2003 T2205 T2003 T2003 T2003 T9411 T2206 T2003 (GEN)(GEN)(GEN)(GEN)(GEN)(GEN)(GEN)(GEN)(GEN)CS-7 CS-7 TESTABLE CHECK VALVE 5.0 CS-7 CS-7 TESTABLE CHECK VALVE 5.0 1E12-F041C 1 AC C-6 ACTIVE 12 CH CS-7 CS-7 TESTABLE CHECK VALVE 2,773.0 5.0 1E12-F042A 1 A D-11 ACTIVE 12 GT MO C EO -CS EC -CS STO-CS STC-CS LJ -PB LK -2Y PI -2Y EO -CS EC -CS STO-CS STC-CS LJ -PB LK -2Y PI -2Y T2004A T2004A T2004A T2004A T9113 T2204 T2004A T2004B T2004B T2004B T2004B T9412 T2205 T2004B CS-3 CS-3 CS-3/VR-3 CS-3/VR-3 SVI-C61-T1201 REMOTE S/D PANEL 28.0 27.0 2773.0 5.0 VR-3 1E12-F042B 1 A E-5 ACTIVE 12 GT MO C CS-3 CS-3 CS-3/VR-3 CS-3/VR-3 VR-Pending 9189 SVI-C61-T1202 REMOTE S/D LOCAL BREAKER 28.0 28.0 2773.0 5.0 VR-3 VR-Pending 39158 3.4-41 Rev. 13 SYSTEM: RESIDUAL HEAT REMOVAL (E12)DWG. NO. D-302-642 VALVE/DEVICE NO.1E12-F042C CLASS AND DWG.COOR.1 C-4 VALVE CATEGORY/ACTIVE OR PASSIVE A ACTIVE SIZE (in.)AND TYPE 12 GT ACTUATOR TYPE/NORMAL POSITION MO C TEST REQ.AND FREQ.EO -CS EC -CS STO-CS STC-CS LJ -PB LK -2Y PI -2Y 1E12-F050A 1E12-F050B 1E12-F053A 2 AC F-12 ACTIVE 2 F-4 AC ACTIVE 12 CH 12 CH 12 GL SE C SE C MO C EO EC LK EO EC LK-RO-RO-2Y-RO-RO-2Y SURV INST.NO.SVI-E12 T2004B T2004B T2004B T2004B T9411 T2206 T2004B T2016 T2210 T2210 T2021 T2211 T2211 T2004A T2004A T2004A T2004A T9121 T2210 T2004A T2004B T2004B T2004B T2004B T9414 T2211 T2004B VR-3 RO-11 RO-11 RO-11 RO-11 VR-Pending 22927 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS CS-3 CS-3 CS-3/VR-3 CS-3/VR-3 5.0 5.0 28.0 28.0 2773.0 5.0 2 A F-13 ACTIVE EO -CS EC -CS STO-CS STC-CS LJ -PB LK -2Y PI -2Y EO -CS EC -CS STO-CS STC-CS LJ -PB LK -2Y PI -2Y CS-3 CS-3 CS-3/VR-3 CS-3/VR-3 27.0*27.0*12,000.00 5.0 INTERSYS LEAK LIMIT = 0.163 GPM INTERSYS LEAK LIMIT = 0.163 GPM SVI-C61-T1201 REMOTE S/D PANEL, INTERSYS LEAK LIMIT = 0.163 GPM VR-Pending 17570 SVI-C61-T1202 REMOTE S/D LOCAL BREAKER, INTERSYS LEAK LIMIT = 0.163 GPM VR-Pending 44183 VR-3 1E12-F053B 2 F-3 A ACTIVE 12 GL MO C CS-3 CS-3 CS-3/VR-CS-3/VR-27.0*27.0*.3.3 12,000.00 5.0 VR-3 3.4-42 Rev. 13 SYSTEM: RESIDUAL HEAT REMOVAL (E12)DWG. NO. D-302-642 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-E12 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.VALVE/DEVICE NO.IE12-F063A 1EI2-F063B 1E12-F063C 1E12-F086 IE12-F105 REMARKS 2 C F-13 ACTIVE 2 C F-3 ACTIVE 2 D-4 C ACTIVE 8 CH 8 CH 8 CH 6 CH 24 GT SE C SE C SE C SE C MO 0 ED -RO T2000 (GEN)EC -RO T2000 (GEN)ED -RO T2000 (GEN)EC -RO T2000 (GEN)ED -RO T2000 (GEN)EC -RO T2000 (GEN)ED -RO T2000 (GEN)EC -RO T2000 (GEN)RO-9 RO-9 RO-9 RO-9 RO-9 RO-9 RO-9 RO-9 EO IS OPTIONAL LOC PROGRAM EO IS OPTIONAL LOC PROGRAM EO IS OPTIONAL LOC PROGRAM EO IS OPTIONAL LOC PROGRAM 2 C C-13 ACTIVE 2 H-5 A ACTIVE EO -Q EC -Q STO-Q STC-Q LW -PB PI -2Y EO -Q EC -Q STO-Q STC-Q PI -2Y T2003 T2003 T2003 T2003 T9403 T2003 T2001 T2001 T2001 T2001 T2001 114.0" 114. 0*VR-3 VR-3 VR-3 5.0 VR-Pending 16192 1E12-F537A 2 B A-9 ACTIVE 12 GT MO C 68.0*65.0*VR-3 VR-3 VR-3 VR-Pending 16106 3.4-43 Rev. 13 SYSTEM: RESIDUAL HEAT REMOVAL (El2)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1EI2-F537B IEI2-F550 1E12-F558A 1E12-F558B TEST REQ.AND FREQ.EO -Q EC -Q STO-Q STC-Q PI -2Y SURV INST.NO.SVI-El2 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-642 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS 2 B B-8 ACTIVE 2 AC G-10 ACTIVE 2 AC F-1I ACTIVE 12 GT MO C T2002 T2002 T2002 T2002 T2002 T2200 T2200 T9421 T2200 67. 0*64. 0*VR-3 VR-3 VR-3 RO-14 RO-14 3/4 SE CH C EO EC LJ LK-RO-RO-PB-2Y-CVCM-CVCM-PB VR-Pending 23212 FOR THERMAL EXPANSION, INTERSYSTEM LEAKAGE LIMIT OF 0.3 GPM 12,000.0 5.0 2 F-5 AC ACTIVE 1 CH 1 CH 6 CH 6 CH SE C SE C SE C SE C EO EC LJ T9118 T9118 T9118 T9431 T9431 T9431 1,000.0 EO -CVCM EC -CVCM LJ -PB 1,000.0 RO-i RO-I RO-I RO-I CS-8 CS-8 CS-8 CS-8 IEI2-F605A IEI2-F605B 2 C G-1I ACTIVE 2 C G-5 ACTIVE EO -CS T2004 (B21)EC -CS T2004 (B21)EO -CS T2004 (B21)EC -CS T2004 (B21)3.4-44 Rev. 13 SYSTEM: RESIDUAL HEAT REMOVAL (E12)DWG. NO. D-302-643 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-E12 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.VALVE/DEVICE NO.1E12-F003B REMARKS 2 B E-4 ACTIVE 18 GL MO EO -Q 0 EC -Q STO-Q STC-Q PI -2Y 1E12-FO11B 1E12-F021 2 D-6 A ACTIVE 4 GL MO C EO -Q EC -Q STO-Q STC-Q LW -PB PI -2Y 2 A C-14 ACTIVE 18 MO EO -Q GL C EC -Q STO-Q STC-Q LJ -PB PI -2Y T2002 T2002 T2002 T2002 T2002 T2002 T2002 T2002 T2002 T9407 T2002 T2003 T2003 T2003 T2003 T9408 T2003 T2002 T2002 T2002 T2002 T9407 T2002 58.2*58.4*30.0*30.0*5.0 VR-3 VR-3 VR-3 SVI-C61-T1202 REMOTE S/D LOCAL BREAKER VR-Pending 16268 SVI-C61-T1202 REMOTE S/D LOCAL BREAKER 73.2*73.9*VR-3 VR-3 VR-3 4159 1E12-F024B 2 A D-13 ACTIVE 18 GL MO EO -Q C EC -Q STO-Q STC-Q LW -PB PI -2Y VR-Pending 16297 SVI-C61-T1202 REMOTE S/D LOCAL BREAKER VR-Pending 24063 96.0 96.0 VR-3 VR-3 VR-3 5.0 1E12-F025B 2 AC D-11 ACTIVE 1 RE SE C RT -10Y T2100 (GEN)LJ -PB T9429 4R5 .0 1386.0 3.4-45 Rev. 13 SYSTEM: RESIDUAL HEAT REMOVAL (E12)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE VALVE/DEVICE NO.1E12-F031B 1E12-F031C 1E12-F046C 1E12-F047B SIZE (in.)AND TYPE 18 CH 18 CH ACTUATOR TYPE/NORMAL POSITION SE C SE C 2 C J-10 ACTIVE 2 C E-11 ACTIVE 2 C F-13 ACTIVE 6 SE CH C TEST REQ.AND FREQ.EO -Q EC -Q EO -Q EC -Q EO -Q EC -Q EO -Q EC -Q STO-Q STC-Q PI -2Y EO -Q EC -Q STO-Q STC-Q PI -2Y SURV INST.NO.SVI-E12 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi) 2 E-7 DWG. NO. D-302-643 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS B ACTIVE 18 GT MO 0 T2002 T2002 T2003 T2003 T2003 T2003 T2002 T2002 T2002 T2002 T2002 T2002 T2002 T2002 T2002 T2002 SVI-C61-T1202 REMOTE S/D 86.0* LOCAL BREAKER 85.0*1E12-F048B 2 B D-9 ACTIVE 18 GL MO 0 75.0*77.0*VR-3 VR-3 VR-3 SVI-C61-T1202 REMOTE S/D LOCAL BREAKER VR-Pending 16165 1E12-F055B 1E12-F060B 2 AC E-8 ACTIVE 2 B E-2 ACTIVE 4 RE 3/4 GL SE C SO C RT -10Y T2100 (GEN)LJ -PB T9429 485.0 1386.0 EO -Q EC -Q STO-Q STC-Q FS -Q PI -2Y T2002 T2002 T2002 T2002 T2002 T2020 2.0*2.0*3.4-46 Rev. 13 SYSTEM: RESIDUAL HEAT REMOVAL (E12)DWG. NO. D-302-643 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.IE12-F064B 2 A J-ll ACTIVE 6 MO GT 0 1E12-F064C 1E12-F073B 2 A F-12 ACTIVE 6 GT 1 GL MO 0 MO 0 TEST REQ.AND FREQ.EO -Q EC -Q STO-Q STC-Q LW -PB PI -2Y EO -Q EC -Q STO-Q STC-Q LW -PB PI -2Y EO -Q EC -Q STO-Q STC-Q LJ -2Y PI -2Y SURV INST.NO.SVI-E12 STROKE TIME REFERENCE VALUE(sec) 2 F-8 A ACTIVE T2002 T2002 T2002 T2002 T9407 T2002 T2003 T2003 T2003 T2003 T8408 T2003 T2002 T2002 T2002 T2002 T9431 T2002 T2002 T2002 T2002 T2002 T2002 T2002 T2002 T2002 T2002 T2002 T2020 13.0 12.0 3.0 LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 12.0 12.0 13.0*12.0*VR-3 VR-3 VR-3 3.0 VR-Pending 18129 VR-Pending 43093 VR-3 VR-3 VR-3 SVI-C61-T1202 REMOTE S/D LOCAL BREAKER VR-Pending 16169 VR-3 VR-3 VR-3 1,000.0 1E12-F074B 1E12-F075B 2 B G-8 ACTIVE 2 B E-I ACTIVE 1 MO EO -Q GL C EC -Q STO-Q STC-Q PI -2Y 6.8 6.9 2.0*2.0*3/4 GL SO C EO -Q EC -Q STO-Q STC-Q FS -Q PI -2Y 3.4-47 Rev. 13 SYSTEM: RESIDUAL HEAT REMOVAL (E12)VALVE/DEVICE NO.1E12-F084B IE12-FD84C IE12-FD85B lE12-F085C 1E12-F102 CLASS AND DWG.COOR.2 H-9 VALVE CATEGORY/ACTIVE OR PASSIVE C ACTIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-E12 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-643 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS 2 C E-10 ACTIVE 1 1/2 SE CH C 1 1/2 SE CH C 1 1/2 SE SC C 1 1/2 SE SC C EO -CVCM T2023 EC -CVCM T2000 (GEN)EO -CVCM T2023 EC -CVCM T2000 (GEN)RO-32 RO-33 RO-32 RO-33 RO-32 RO-32 2 H-9 C ACTIVE 2 C E-10 ACTIVE EO -RO EC -Q EO -RO EC -Q EO -N/A EC -N/A LJ -PB T2023 T2002 T2023 T2003 CLOSED USING HANDWHEEL CLOSED USING HANDWHEEL 2 E-9 A 1 1/2 MA PASSIVE GL LC NONE NONE T9115 (E51)1,000.0 3.4-48 Rev. 13 SYSTEM: LOW PRESSURE CORE SPRAY (E21)DWG. NO. D-302-705 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1E21-F001 1E21-F003 1E21-F005 2 A G-10 ACTIVE 24 GT 14 CH 12 GT MO 0 SE C MO C TEST REQ.AND FREQ.EC -Q STC-Q LW -PB PI -2Y EO -Q EC -Q EO -CS EC -CS STO-CS STC-CS LJ -PB LK -2Y PI -2Y SURV INST.NO.SVI-E21 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 2 C-6 1 C-9 C ACTIVE A ACTIVE T2001 T2001 T9103 T2001 T2001 T2001 T2004 T2004 T2004 T2004 T9112 T2200 T2004 113.0 5.0 VR-3 VR-3 CS-3 CS-3 CS-3/VR-3 CS-3/VR-3 VR-Pending 13735 VR-Pending 11500 27.0 28.0 2,773.0 5.0 VR-3 CS-7 CS-7 1E21-F006 1 AC C-12 ACTIVE 12 CH SE/HO EO -CS C EC -CS LJ LK PI-PB-2Y-2Y T2003 T2003 T9112 T2200 T2003 (GEN)(GEm)(GEm)TESTABLE CHECK VALVE 2,773.0 5.0 1E21-F007 1E21-F011 1 B 12 C-13 PASSIVE GT MA LO MO 0 2 E-6 A ACTIVE 4 GT EO -N/A EC -N/A PI -2Y EC -Q STO-Q STC-Q LW -PB PI -2Y NONE NONE T2200 T2001 T2001 T2001 T9105 T2001 MAINTENANCE ONLY 21.1 21.0 VR-3 VR-3 VR-3 (E12)5.0 VR-Pending 13738 3.4-49 Rev. 13 SYSTEM: LOW PRESSURE CORE SPRAY (E21)DWG. NO. D-302-705 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1E21-F012 TEST REQ.AND FREQ.EC -Q STC-Q LW -PB PI -2Y SURV INST.NO.SVI-E21 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 2 A D-8 ACTIVE 12 GL MO C T2001 T2001 T9105 (E12)T2001 59.0*5.0 VR-3 VR-3 VR-Pending 13761 1E21-F018 1E21-F031 1E21-F033 1E21-F034 IE21-F501 2 B-8 AC ACTIVE 1 1/2 SE RE C RT -10Y T2100 (GEN)LJ -PB T9107 (E12)RT -10Y T2100 (GEN)1,386.0 585.0 100.0 2 C H-8 ACTIVE 2 C F-7 ACTIVE 1 RE SE C 5 dpm LOC PROGRAM 1 1/2 SE CH C 1 1/2 SE SC C 2 F-7 C ACTIVE EO -RO EC -Q EO -RO EC -Q EO -Q T2004 T2001 T2004 T2001 T2001 RO-32 RO-32 CLOSED USING HANDWHEEL REFERENCE IEB: 83-03 2 C E-8 ACTIVE 12 CH SE C EC -CVCM T2000 (GEN)RO-2 3.4-50 Rev. 13 SYSTEM: HIGH PRESSURE CORE SPRAY (E22)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1E22-F001 TEST REQ.AND FREQ.EO -Q EC -Q STO-Q STC-Q PI -2Y SURV INST.NO.SVI-E22 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-701 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS 2 B H-13 ACTIVE 16 GT MO 0 1E22-F002 1E22-F004 2 C H-13 ACTIVE 1 A D-7 ACTIVE 16 CH 12 GT SE EO -Q C EC -Q T2001 T2001 T2001 T2001 T2001 T2001 T2004 T2002 T2002 T2002 T2002 T9410 T2200 T2002 68. 6*67. 0*VR-3 VR-3 VR-3 VR-Pending 16194 MO C EO -CS EC -CS STO-CS STC-CS LJ -PB LK -2Y PI -2Y CS-3 CS-3 CS-3/VR-3 CS-3/VR-3 13.4 14.1 2,773.0 5.0 VR-3 CS-7 CS-7 VR-Pending 16662 1E22-F005 1 AC D-5 ACTIVE 12 CH SE/HO EO C EC LJ LK PI-CS-CS-PB-2Y-2Y T2003 (GEN)T2003 (GEN)T9410 T2200 T2003 (GEN)TESTABLE CHECK VALVE 2,773.0 5.0 1E22-F006 1E22-F007 IE22-FO10 2 C G-10 ACTIVE 2 C G-10 ACTIVE 2 B C-9 ACTIVE 1 1/2 SE SC C 1 1/2 SE CH C EO -RO EC -Q T2002 RO-32 T2001 CLOSED USING HANDWHEEL EO -CVCM T2002 EC -CVCM T2000 (GEN)RO-32 RO-2 10 GL MO C EC -Q STC-Q PI -2Y T2001 T2001 T2001 46.0*VR-3 VR-3 VR-Pending 14427 3.4-51 Rev. 13 SYSTEM: HIGH PRESSURE CORE SPRAY (E22)DWG. NO. D-302-701 CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-E22 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 1E22-F011 1E22-F012 2 B C-1l ACTIVE 2 A D-10 ACTIVE 10 MO EC -Q GL C STC-Q PI -2Y 4 GT MO EC -Q C EO -Q STO-Q STC-Q LJ -PB PI -2Y T2001 T2001 T2001 T2001 T2001 T2001 T2001 T9409 T2001 48.0*VR-3 VR-3 VR-Pending 32717 7.3 7.1 VR-3 VR-3 VR-3 2,773.0 VR-Pending 8617 1E22-F014 1E22-F015 2 C H-II ACTIVE 2 A H-7 ACTIVE 1 RE 24 GT SE RT -10Y T2100 (GEN)C 5 dpm 100.0 LOC PROGRAM MO C EC -Q EO -Q STO-Q STC-Q LW -PB PI -2Y T2001 T2001 T2001 T2001 T9401 T2001 T2001 T2004 T2001 T2001 T9409 T2001 21.0*21.0*VR-3 VR-3 VR-3 5.0 VR-Pending 16200 1E22-F016 1E22-F023 2 C H-7 ACTIVE 2 A E-8 ACTIVE 24 CH 12 GL SE EO -Q C EC -Q MO C EC -Q STC-Q LJ -PB PI -2Y 53.0*2,773.0 VR-3 VR-3 VR-Pending 16197 3.4-52 Rev. 13 SYSTEM: HIGH PRESSURE CORE SPRAY (E22)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE VALVE/DEVICE NO.IE22-F024 IE22-F035 IE22-F036 SIZE (in.)AND TYPE 16 CH TYPE/NORMAL POSITION REQ.AND FREQ.EO -Q EC -Q ACTUATOR TEST SURV INST.NO.SVI-E22 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-701 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS 2 C D-10 ACTIVE SE C T2001 T2001 2 D-7 1 D-4 AC ACTIVE 1 1/2 SE RE C RT -10Y T2100 (GEN)LJ -PB T9409 1560.0 2,773.0 B 12 PASSIVE GT MA 0 SE C EO EC PI-N/A-N/A-2Y NONE NONE T2200 IE22-F039 IE22-F621 IE22-F622 2 C C-9 ACTIVE 2 C F-6 ACTIVE 2 C F-6 ACTIVE 1 CH EO -Q EC -RO T2001 T2005 (GEN) RO-7 1 SE EO -RO CH C EC -Q MAINTENANCE ONLY FOR THERMAL EXPANSION PTI-P0008(EC)

INTERNAL SPRING CHECK INTERNAL SPRING CHECK T2101 (GEN)T2001 T2101 (GEN)T2001 RO-24 1 CH SE EO -RO C EC -Q RO-24 3.4-53 Rev. 13 SYSTEM: REACTOR CORE ISOLATION COOLING (E51)DWG. NO. D-302-631 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.IE51-F010 TEST REQ.AND FREQ.EC -Q STO-Q STC-Q PI -2Y SURV INST.NO.SVI-E51 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 2 B F-6 ACTIVE 6 GT MO 0 T2001 T2001 T2001 T1272 T2001 T2001 24.2*25.0*VR-3 VR-3 VR-3 lE51-F011 1E51-F013 1E51-F017 2 C F-6 ACTIVE 1 A C-8 ACTIVE 2 C E-4 ACTIVE 2 A E-8 ACTIVE 2 C E-7 ACTIVE 6 CH 6 GT 1 RE 2 GL 2 CH SE EO -Q C EC -Q T1272 (EC, ST)DURING S/U SVI-C61-T1200 REMOTE S/D PAN VR-Pending 16666 T1272 (EO, EC)DURING S/U SVI-C61-T1200 REMOTE S/D PANEL NOTE 10 VR-Pending 15296 LOC PROGRAM MO C EO -CS EC -CS STO-CS STC-CS LJ -PB LK -2Y PI -2Y T2003 T2003 T2003 T2003 T9123 T2202 (E12)T2003 CS-4 CS-4 CS-4/VR-3 CS-4/VR-3 11.0 11.0 1,386.0 0.036 VR-3 SE RT -10Y T2100 (GEN)C 5 dpm 100.0 1E51-F019 1E51-F021 MO C SE C EO -Q EC -Q STO-Q STC-Q LJ -PB PI -2Y EO -Q EC -RO T2001 T2001 T2001 T2001 T9104 T1272 T2001 T2009 4.0 4.0 1,000.0 VR-3 VR-3 VR-3 RO-7 T1272 (EC, EO, ST)DURING S/U SVI-C61-T1200 REMOTE S/D PAN VR-Pending 19324 T1272 (EO)DURING S/U 3.4-54 Rev. 13 SYSTEM: REACTOR CORE ISOLATION COOLING (E51)DWG. NO. D-302-631 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1E51-F022 TEST REQ.AND FREQ.EC -Q STC-Q PI -2Y SURV INST.NO.SVI-E51 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE (psi)JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 2 B C-8 ACTIVE 4 GL MO C T2001 T2001 T1272 10.1*VR-3 VR-3 T1272 (EC, ST)DURING S/U SVI-C61-T1200 REMOTE S/D PAN VR-Pending 16812 1E51-F030 1E51-F031 2 C H-8 ACTIVE 2 A H-8 ACTIVE 6 CH 6 GT SE C EO -CVCM T2000 (GEN)EC -CVCM T2000 (GEN)MO EC -Q C STO-Q STC-Q LW -PB PI -2Y 1E51-F040 2 G-5 C ACTIVE 10 CH SE C EO -Q EC -CVCM LJ -PB T2001 T2001 T2001 T9101 T1272 T2001 T9106 T9106 T2001 T2001 T1272 16.9*17.0*3.0 RO-2 RO-2 VR-3 VR-3 VR-3 RO-7 T1272 (EC, ST)DURING S/U SVI-C61-T1200 REMOTE S/D PAN VR-Pending 19326 T1272 (EO)DURING S/U, REFERENCE IEB: 83-03 2773.0 1E51-F059 1E51-F061 2 B B-8 ACTIVE 4 GT MO C EC -Q STC-Q PI -2Y 10.9*VR-3 VR-3 T1272 (EC, ST)DURING S/U, SVI-C61-T1200 REMOTE S/D PAN VR-Pending 5296 2 E-4 C ACTIVE 1 1/2 SE CH C EO -CVCM T2003 EC -CVCM T2000 (GEN)RO-32 RO-33 3.4-55 Rev. 13 SYSTEM: REACTOR CORE ISOLATION COOLING (E51)DWG. NO. D-302-631 VALVE /DEVICE NO.lE51-F062 CLASS AND DWG.COOR.2 E-4 VALVE CATEGORY/ACTIVE OR PASSIVE C ACTIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.EO -RO EC -Q SURV INST.NO.SVI-E51 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE (psi)JUSTIFI-CATIONS &RELIEF REQUEST NO.RO-32 1 1/2 SE SC C T2003 T2001 REMARKS T1272 (EC)DURING S/U, CLOSED USING HANDWHEEL IE51-FO65 1 AC C-9 ACTIVE 1 AC C-II ACTIVE 6 CH 6 CH SE C EO EC LK 1E51-F066 SE/HO EO C EC LJ LK PT-CS-RO-2Y-CS-RO-PB-2Y-2Y T2010 T2202 (E12)T2202 (E12)3.0 CS-13 RO-25 CS-13 RO-25 MANUALLY TESTABLE T2010 T2201 T8123 T2201 T2010 T2001 T2001 T2001 T2001 T9106 T1272 TESTABLE CHECK VALVE 5,500.0 3.0 1E51-F068 2 G-7 A ACTIVE 12 GT MO 0 EO -Q EC -Q STO-Q STC-Q LJ -PB PI -2Y 40.1*39.6*VR-3 VR-3 VR-3 2,773.0 T1272 (EC, ST)DURING S/U, SVI-C61-T1200 REMOTE S/D PAN VR-Pending 19321 3.4-56 Rev. 13 SYSTEM: REACTOR CORE ISOLATION COOLING (E51)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-E51 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-631 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS VALVE/DEVICE NO.1E51-F079 1E51-F081 2 C E-7 ACTIVE 2 C E-8 ACTIVE 2 C C-8 ACTIVE 1 1/2 SE EO -CVCM T2000 (GEN)T2008 CH C EC -CVCM T2000 (GEN)1 1/2 SE EO -CVCM T2000 (GEN)T2008 CH C EC -CVCM T2000 (GEN)RO-33 RO-33 RO-33 RO-33 RO-7 1E51-F090 1 CH SE C EO -Q EC -RO T2001 T2005 (GEN)T1272 (EO)DURING S/U, FOR THERMAL EXPANSION PTI-P0004 (EC)T1272 (EO, EC)DURING S/U IE51-F577 2 C F-4 ACTIVE 6 SE EO -Q CH C EC -Q T2001 T2001 3.4-57 Rev. 13 SYSTEM: REACTOR CORE ISOLATION COOLING (E51)DWG. NO. D-302-632 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-E51 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.VALVE/DEVICE NO.lE51-DO01 lE51-D002 REMARKS 2 D G-12 ACTIVE 02 D G-13 ACTIVE 2 B J-10 ACTIVE 2 B J-ll ACTIVE 8 SE RU C RD -5YP NONE IE51-F004 IE51-F005 8 RU 1 DI 1 DI SE C AO 0 AO C RD -5YP NONE REPETITIVE PROCEDURE lE51DO01,001 REPETITIVE PROCEDURE TE51D0D2,001 T1272 (EO, STO, STC, FS)DURING S/U E0 -Q STO-Q STC-Q FS -Q PI 2Y E0 -Q STO-Q STC-Q FS -Q PI 2Y T2001 T2001 T2001 T2001 T1272 T2001 T2001 T2001 T2001 T1272 3.7*3.5*2.5*4.3*T1272 (EO, STO, STC, FS)DURING S/U IE51-F018 1E51-F025 2 D-7 2 F-4 C ACTIVE B ACTIVE 1 RE 1 DI SE C AO 0 RT -10Y T2100 (GEN)5 dpm 150.0 LOC PROGRAM T1272 (EO, STO, STC, FS)DURING S/U E0 -Q STO-Q STC-Q FS -Q PI 2Y ED -Q STO-Q STC-Q FS -Q PI 2Y T2001 T2001 T2001 T2001 T1272 T2001 T2001 T2001 T2001 T1272 4.8*4.9*1E51-F026 2 F-4 B ACTIVE 1 DI AO 0 5.0*6.2*T1272 (EO, STO, STC, FS)DURING S/U 3.4-58 Rev. 13 SYSTEM: REACTOR CORE ISOLATION COOLING (E51)DWG. NO. D-302-632 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-E51 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE (psi)JUSTIFI-CATIONS &RELIEF REQUEST NO.VALVE/DEVICE NO.1E51-F045 REMARKS 2 B E-6 ACTIVE 4 GL MO EO -Q C EC -Q STO-Q STC-Q PI -2Y T2001 T2001 T2001 T2001 T1272 9.1*10.1*VR-3 VR-3 VR-3 1E51-F063 1 A C-5 ACTIVE 10 GT MO 0 EO -Q EC -Q STO-Q STC-Q LJ -PB PI -2Y E0 -Q EC -Q STO-Q STC-Q LJ -PB PI -2Y T2001 T2001 T2001 T2001 T9422 T9422/T2004 (GEN)17. 6 17.9 VR-3 VR-3 VR-3 2,311.0 T1272 (EC, EO, STO, STC)DURING S/U, SVI-C61-T1200 REMOTE S/D PAN VR-Pending 16790 T1272 (EC, EO, STO, STC)DURING S/U, SVI-C61-T1200 REMOTE S/D PAN VR-Pending 9065 T1272 (EC, EO, STO, STC)DURING S/U, SVI-C61-T1200 REMOTE S/D PAN VR-Pending 16845 T1272 (EC, EO, STO, STC)DURING S/U, SVI-C61-T1200 REMOTE S/D PAN VR-Pending 16847 1E51-F064 1 A C-3 ACTIVE 10 GT MO 0 T2001 T2001 T2001 T2001 T9422 T1272 17.8 18.3 VR-3 VR-3 VR-3 2,311.0 IE51-F076 1 A D-5 ACTIVE 1 GL MO EO -Q C EC -Q STO-Q STC-Q LJ -PB PI -2Y T2001 T2001 T2001 T2001 T9422 T9422/T2004 (GEN)8.5*8. 6*VR-3 VR-3 VR-3 2,311.0 3.4-59 Rev. 13 SYSTEM: REACTOR CORE ISOLATION COOLING (E51)DWG. NO. D-302-632 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-E51 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE (psi)JUSTIFI-CATIONS &RELIEF REQUEST NO.VALVE/DEVICE NO.IE51-F510 REMARKS 2 B E-8 ACTIVE 2 B E-9 ACTIVE MO EC -Q T2001 T2001 T1272 GL 0 STC-Q PI -2Y 8.4*T1272 (EC, ST)DURING S/U, SVI-C61-T1200 REMOTE S/D PANEL RCIC TRIP VALVE SKID MOUNTED PRV WITH NO FS SAFETY FUNCTION<L01937>RCIC TURBINE CONTROL OIL IE51-F511 4 GT HO PI -2Y 0 T1272 IE51-F561 03 C N/A ACTIVE RE SE RT -10Y T2100 (GEN)C 27.0 3.4-60 Rev. 13 SYSTEM: CONTAINMENT INTEGRATED LEAK RATE TESTING (E61)DWG. NO. D-302-811 CLASS VALVE SIZE ACTUATOR TEST SURV STROKE LEAKAGE DEVICE JUSTIFI-AND CATEGORY/ (in.) TYPE/ REQ. INST. TIME LIMIT(sccm SET PRESS. CATIONS &VALVE/ DWG. ACTIVE OR AND NORMAL AND NO. REFERENCE gpm or REFERENCE RELIEF DEVICE NO. COOR. PASSIVE TYPE POSITION FREQ. SVI-E61 VALUE(sec) bubbles) VALUE(psi)

REQUEST NO. REMARKS IE61-F549 2 A 1/2 MA LJ -PB T9317 1,000.0 D-10 PASSIVE GL LC lE61-F550 2 A -MA LJ -PB T9317 1,000.0 D-Il PASSIVE GL LC lE61-F551 2 A 4 MA LJ -PB T9319 1,000.0 D-10 PASSIVE GL LC lE61-F552 2 A A MA LJ -PB T9319 1,000.0 D-10 PASSIVE GL LC 3.4-61 Rev. 13 SYSTEM: INCLINED FUEL TRANSFER (F42)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-F42 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE DEVICE LIMIT(sccm SET PRESS.gpm or REFERENCE bubbles) VALUE(psi)

DWG. NO. D-302-970 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS VALVE/DEVICE NO.1F42-F003 2 A 4 G-9 PASSIVE BA MA/MO LJ -PB C T8205 1,000.0 Non-Class 1E power to motor 3.4-62 Rev. 13 SYSTEM: REACTOR WATER CLEANUP (G33)DWG. NO. D-302-671 CLASS VALVE SIZE ACTUATOR TEST SURV STROKE LEAKAGE DEVICE JUSTIFI-AND CATEGORY/ (in.) TYPE/ REQ. INST. TIME LIMIT(sccm SET PRESS. CATIONS &VALVE/ DWG. ACTIVE OR AND NORMAL AND NO. REFERENCE gpm or REFERENCE RELIEF DEVICE NO. COOR. PASSIVE TYPE POSITION FREQ. SVI-G33 VALUE(sec) bubbles) VALUE(psi)

REQUEST NO. REMARKS 1G33-F001 1 A 6 MO EC -CS T2003 CS-9 J-8 ACTIVE GT 0 STC-CS T2003 17 1,386.0 CS-9/VR-3 LJ -PB T9131 PI -2Y T2003 VR-3 VR-Pending 15026 3.4-63 Rev. 13 SYSTEM: REACTOR WATER CLEANUP (G33)DWG. NO. D-302-672 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-G33 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

VALVE/DEVICE NO.1G33-F004 IG33-F028 JUSTIFI-CATIONS &RELIEF REQUEST NO.CS-9 CS-9/VR-3 REMARKS 1 A H-7 ACTIVE 2 A B-8 ACTIVE 6 GT 4 GT MO 0 MO C EC -CS STC-CS LJ -PB PI -2Y EC -Q STC-Q LJ -PB PI -2Y EC -Q STC-Q LJ -PB PI -2Y EC -CS STC-CS LJ -PB PT -2Y 1G33-F034 2 A B-6 ACTIVE 4 GT MO C T2003 T2003 T9131 T2003 T2001 T2001 T9424 T2001 T2001 T2001 T9424 T2001 T2003 T2003 T9132 T2003 T2003 T2003 T9132 T2003 14 1,000.0 VR-3 VR-3 VR-3 17 1,386.0 SVI-G33-T2004 (PI) REMOTE S/D LOCAL BRKR VR-Pending 16729 VR-Pending 16751 13 1,000.0 1G33-F039 2 A C-6 ACTIVE 6 GT MO 0 CS-9 CS-9/VR-3 20.7 1,386.0 VR-3 VR-Pending 39164 IG33-F040 2 A C-7 ACTIVE 6 GT MO EC -CS 0 STC-CS LJ -PB PI -2Y CS-9 CS-9/VR-3 20.5 1,386.0 1G33-F052A 1G33-FO52B 2 C C-2 ACTIVE 2 C C-2 ACTIVE 6 SE EO -RO CH 0 EC -RO T2002A T2210 (E12)VR-3 RO-4 RO-4 RO-4 RO-4 VR-Pending 8480 6 CH SE 0 EO -RO T2002B EC -RO T2211 (E12)3.4-64 Rev. 13 SYSTEM: REACTOR WATER CLEANUP (G33)CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE 4 GT ACTUATOR TYPE/NORMAL POSITION 1G33-F053 2 A E-7 ACTIVE MO 0 TEST REQ.AND FREQ.EC -CS STC-CS LJ -PB PI -2Y EC -CS STC-CS LJ -PB PI -2Y SURV INST.NO.SVI-G33 T2003 T2003 T9419 T2003 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE (psi)DWG. NO. D-302-672 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS CS-9 CS-9/VR-3 13 1,000.0 VR-3 VR-Pending 44141 1G33-F054 2 A E-6 ACTIVE 4 GT MO 0 T2003 T2003 T9419 T2003 CS-9 CS-9/VR-3 14 1,000.0 VR-3 VR-Pending 11523 IG33-F646 IG33-F647 2 C B-7 ACTIVE 03 C B-8 ACTIVE RE RE SE C SE C RT -10Y T2100 (GEN)LJ -PB T9424 RT -10Y T2100 (GEN)1,000.0 1600 1600 3.4-65 Rev. 13 SYSTEM: FUEL POOL COOLING AND CLEANUP (G41)DWG. NO. D-302-651 CLASS VALVE SIZE ACTUATOR TEST SURV STROKE LEAKAGE DEVICE JUSTIFI-AND CATEGORY/ (in.) TYPE/ REQ. INST. TIME LIMIT(sccm SET PRESS. CATIONS &VALVE/ DWG. ACTIVE OR AND NORMAL AND NO. REFERENCE gpm or REFERENCE RELIEF DEVICE NO. COOR. PASSIVE TYPE POSITION FREQ. SVI-G41 VALUE(sec) bubbles) VALUE(psi)

REQUEST NO. REMARKS 1G41-F090 3 B 8 MO EC -Q T2001 H-13 ACTIVE BF 0 STC-Q T2001 28.0*PI -2Y T2001 1G41-F100 2 A 8 MO EC -Q T2001 F-I3 ACTIVE BF 0 STC-Q T2001 28.0* VR-3 LJ -PB T9203 1,849.0 PI -2Y T2001 VR-3 VR-Pending 15706 lG41-F140 2 A 10 MO EC -Q T2001 C-lI ACTIVE BF 0 STC-Q T2001 29.0* VR-3 LJ -PB T9301 2,311.0 PI -2Y T2001 VR-3 VR-Pending 16108 1G41-F145 2 A 10 MO EC -Q T2001 C-13 ACTIVE BF 0 STC-Q T2001 29.0* VR-3 LJ -PB T9301 2,311.0 PI -2Y T2001 VR-3 VR-Pending 23004 1G41-F522 2 AC 8 SE EC -CVCM T9203 RO-13 E-13 ACTIVE CH 0 EO -Q T2001 LJ -PB T9203 1,849.0 IG41-F801 2 AC 3/4 SE SP-2YD T2101(GEN)

C-11 ACTIVE SD C LJ -PB T9301 2,311.0 3.4-66 Rev. 13 SYSTEM: FUEL POOL COOLING AND CLEANUP (G41)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE VALVE/DEVICE NO.G41-F280 G41-F285 G41-F290 G41-F295 G41-F545A G41-F545B G41-F548A G41-F548B 3 B C-4 ACTIVE 3 B C-5 ACTIVE SIZE (in.)AND TYPE 12 BF 12 BF 12 BF 12 BF 10 CH ACTUATOR TYPE/NORMAL POSITION MO 0 MO 0 MO 0 MO 0 SE C TEST REQ.AND FREQ.EC -Q STC-Q PI -2Y EC -Q STC-Q PI -2Y EC -Q STC-Q PI -2Y EC -Q STC-Q PI -2Y EO -Q EC -Q SURV INST.NO.SVI-G41 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-654 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS 11.0*10.0*10.0*10.0*3 C-10 3 C-ll B ACTIVE B ACTIVE 3 C G-11 ACTIVE 3 C J-1l ACTIVE T2001 T2001 T2001 T2001 10 CH SE EO -Q C EC -Q 3 H-5 3 G-5 C ACTIVE C ACTIVE 3/4 RE SE RT -10Y T2100 (GEN)C 5 dpm 5 dpm 150.0 150.0 LOC PROGRAM LOC PROGRAM 3/4 SE RT -10Y T2100 (GEN)RE C 3.4-67 Rev. 13 SYSTEM: FUEL POOL COOLING AND CLEANUP (G41)DWG. NO. D-302-655 CLASS VALVE SIZE ACTUATOR TEST SURV STROKE LEAKAGE DEVICE JUSTIFI-AND CATEGORY/ (in.) TYPE/ REQ. INST. TIME LIMIT(sccm SET PRESS. CATIONS &VALVE/ DWG. ACTIVE OR AND NORMAL AND NO. REFERENCE gpm or REFERENCE RELIEF DEVICE NO. COOR. PASSIVE TYPE POSITION FREQ. SVI-G41 VALUE(sec) bubbles) VALUE(psi)

REQUEST NO. REMARKS G41-F085 3 B 10 MO EC -Q T2001 G-10 ACTIVE BF 0 STC-Q T2001 34.0*PI -2Y T2001 G41-F597A 3 C 3 SE EO -RO T2002 RO-29 ACOUSTIC D-10 ACTIVE CH C EC -RO T2002 RO-29 MONITORING G41-F597B 3 C 3 SE EO -RO T2002 RO-29 ACOUSTIC D-12 ACTIVE CH C EC -RO T2002 RO-29 MONITORING G41-F746A 3 C 3/4 SE RT -10Y T2100 (GEN) 150.0 H-5 ACTIVE RE C 3.4-68 Rev. 13 SYSTEM: SUPPRESSION POOL CLEANUP (G42)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-G42 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-681 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS VALVE/DEVICE NO.1G42-F010 2 B G-4 ACTIVE 12 BF MO EC -Q C STC-Q PI -2Y IG42-F020 2 G-5 B ACTIVE 12 MO EC -Q BF C STC-Q PI -2Y T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 29.7*VR-3 VR-3 VR-3 VR-3 VR-Pending 16848 29.4*VR-Pending 8641 IG42-F060 IG42-FO80 3 B G-7 ACTIVE 3 B E-11 ACTIVE 10 BF 8 BF MO EC -Q C STC-Q PI -2Y MO EC -Q C STC-Q PI -2Y 28.0*28.0*3.4-69 Rev. 13 SYSTEM: SUPPRESSION POOL MAKEUP (G43)DWG. NO. D-302-686 CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-G43 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 1G43-FO30A 1G43-F030B IG43-FO40A IG43-F040B 1G43-F050A 2 E-9 2 B-9 2 F-9 2 B-8 2 H-8 B ACTIVE B ACTIVE B ACTIVE B ACTIVE A ACTIVE 24 BF 24 BF 24 BF 24 BF 3/4 GL MO EO -Q C STO-Q Pi -2Y MO EO -Q C STO-Q PI -2Y MO EO -Q C STO-Q PI -2Y MO EO -Q C STO-Q PI -2Y T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2002 T2002 T2001 T2001 T2001 T2001 T2001 T2002 T2002 29.0 30.0 33.0 VR-3 VR-3 VR-3 VR-3 VR-3 VR-3 VR-3 VR-3 VR-Pending 16020 VR-Pending 16042 VR-Pending 16044 VR-Pending 16046 CONTAINMENT INSTRUMENT LINE, LEAKAGE EQUIVALENT TO 0.5 gpm 29.0 SO 0 EO -Q EC -Q ST0-Q STC-Q FS -Q LD -2Y PI -2Y EO -Q EC -Q STO-Q STC-Q FS -Q LD -2Y Pi -2Y 2.0*2.0*1,890.0 1G43-F050B 2 A H-13 ACTIVE 3/4 GL SO 0 2.0*2.0*CONTAINMENT INSTRUMENT LINE, LEAKAGE EQUIVALENT TO 0.5 gpm 1,890.0 3.4-70 Rev. 13 SYSTEM: SUPPRESSION POOL MAKEUP (G43)DWG. NO. D-302-686 CLASS AND VALVE/ DWG.DEVICE NO. COOR.IG43-F060 IG43-F508A IG43-F508B 2 H-5 2 E-9 VALVE CATEGORY/ACTIVE OR PASSIVE A ACTIVE C ACTIVE SIZE (in.)AND TYPE 3/4 GL 2 CH ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SO 0 SE C SE C EO -Q EC -Q STO-Q STC-Q FS -Q LD -2Y PI -2Y EO -Q EC -Q EO -Q EC -Q SURV INST.NO.SVI-G43 T2001 T2001 T2001 T2001 T2001 T2002 T2002 STROKE TIME REFERENCE VALUE(sec) 2.0*2.0*LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE (psi)JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS CONTAINMENT INSTRUMENT LINE, LEAKAGE EQUIVALENT TO 0.5 gpm 1,890.0 T2003 T2003 T2003 T2003 FOR THERMAL EXPANSION FOR THERMAL EXPANSION 2 C C-9 ACTIVE 2 CH 3.4-71 Rev. 13 SYSTEM: LIQUID RADWASTE (G50)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1GS0-F272 TEST REQ.AND FREQ.EC -Q STC-Q LJ -PB PI -2Y SURV INST.NO.SVI-G50 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-737 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS 2 A E-11 ACTIVE 4 GT MO 0 T2001 T2001 T9420 T2001 T2001 T2001 T9420 T2001 16.7*1,000.0 VR-3 VR-3 VR-3 VR-3 VR-Pending 17539 1GSO-F277 2 A E-10 ACTIVE 4 GT MO EC -Q 0 STC-Q LJ -PB PI -2Y SE RT-10Y C LJ -PB 15.0*1,000.0 VR-Pending 17561 1GS0-F823 2 AC D-10 ACTIVE 1/4 RE T2100 (GEN)T9420 150 +/-25 1,000.0 3.4-72 Rev. 13 SYSTEM: LIQUID RADWASTE SUMPS (G61)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-G61 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-739 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS VALVE/DEVICE NO.1G61-F030 1G61-F035 1G61-F075 02 B A-9 ACTIVE 02 B A-8 ACTIVE 2 A C-6 ACTIVE 2 1/2 MO EC -Q GT 0 STC-Q PI -2Y 2 1/2 MO EC -Q GT 0 STC-Q PI -2Y 3 MO EC -Q GT 0 STC-Q LJ -PB PI -2Y T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T9417 T2001 T2001 T2001 T9417 T2001 16.0*15.2*VR-3 VR-3 VR-3 VR-3 VR-3 VR-3 VR-3 VR-3 VR-Pending 18020 VR-Pending 9220 17.4*1,000.0 VR-Pending 16132 1G61-F080 2 A C-5 ACTIVE 3 GT MO 0 EC -Q STC-Q LJ -PB PI -2Y 16.0*1,000.0 100.0 1,000.0 VR-Pending 26084 IG61-F655 2 AC C-6 ACTIVE 1/4 SE SD C SP -2YD T2101 (GEN)LJ -PB T9417 3.4-73 Rev. 13 SYSTEM: LIQUID RADWASTE SUMPS (G61)DWG. NO. D-302-740 CLASS VALVE SIZE ACTUATOR TEST SURV STROKE LEAKAGE DEVICE JUSTIFI-AND CATEGORY/ (in.) TYPE/ REQ. INST. TIME LIMIT(sccm SET PRESS. CATIONS &VALVE/ DWG. ACTIVE OR AND NORMAL AND NO. REFERENCE gpm or REFERENCE RELIEF DEVICE NO. COOR. PASSIVE TYPE POSITION FREQ. SVI-G61 VALUE(sec) bubbles) VALUE(psi)

REQUEST NO. REMARKS 1G61-F150 02 B 2 1/2 MO EC -Q T2001 B-10 ACTIVE GT 0 STC-Q T2001 16.0* VR-3 PI -2Y T2001 VR-3 VR-Pending 32021 IG61-F155 02 B 2 1/2 MO EC -Q T2001 B-9 ACTIVE GT 0 STC-Q T2001 15.0* VR-3 PI -2Y T2001 VR-3 VR-Pending 32024 IG61-F165 2 A 3 MO EC -Q T2001 B-7 ACTIVE GT 0 STC-Q T2001 17.6* VR-3 LJ -PB T9418 1,000.0 PI -2Y T2001 VR-3 VR-Pending 16134 1G61-F170 2 A 3 MO EC -Q T2001 B-6 ACTIVE GT 0 STC-Q T2001 16.0* VR-3 LJ -PB T9418 1,000.0 PI -2Y T2001 VR-3 VR-Pending 16138 1G61-F657 2 AC 3/4 SE SP-2YD T2101(GEN)

B-7 ACTIVE SD C LJ -PB T9418 1,000.0 3.4-74 Rev. 13 SYSTEM: CONTAINMENT VESSEL AND DRYWELL PURGE (M14)DWG. NO. D-912-604 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE VALVE/DEVICE NO.IM14-F040 SIZE (in.)AND TYPE 42 BF ACTUATOR TYPE/NORMAL POSITION AO C TEST REQ.AND FREQ.EC -Q STC-Q FS -Q LJ -Q PI -2Y SURV INST.NO.SVI-M14 T2001 T2001 T2001 T9313 T2001 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 2 A C-8 ACTIVE 3.5 4,310.0 1M14-F045 2 A C-9 ACTIVE 42 BF AO EC -R0 C STC-RO FS -R0 LJ -Q PI -2Y 1M14-FOS5A 1M14-FO5B 1M14-FOSOA 02 B G-13 ACTIVE 02 B G-10 ACTIVE 02 B J-13 ACTIVE 24 BF 24 BF 24 BF AO C AO C AO C EC -R0 STC-RO FS -R0 PI -2Y EC -RU STC-RO FS -RO PI -2Y EC -R0 STC-R0 FS -R0 PI -2Y T2003 T2003 T2003 T9313 T2003 T2003 T2003 T2003 T2003 T2003 T2003 T2003 T2003 T2003 T2003 T2003 T2003 4,310.0 4.0 RO-28 RO-28 RO-28 2.0 2.4 2.4 RO-28 RO-28 RO-28 RO-28 RO-28 RO-28 RO-28 RO-28 RO-28 ADMINISTRATIVE SEALED WITH KEYLOCK SW IN MODES 1, 2 & 3 ADMINISTRATIVE SEALED WITH KEYLOCK SW IN MODES 1, 2 & 3 ADMINISTRATIVE SEALED WITH KEYLOCK SW IN MODES 1, 2 & 3 ADMINISTRATIVE SEALED WITH KEYLOCK SW IN MODES 1, 2 & 3 3.4-75 Rev. 13 SYSTEM: CONTAINMENT VESSEL AND DRYWELL PURGE (M14)DWG. NO. D-912-604 CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-M14 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE (psi)JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 1M14-F060B 02 B J-1O ACTIVE 1M14-F065 02 B F-13 ACTIVE 1M14-F070 02 B F-lI ACTIVE 24 BF 36 BF 36 BF AO C AO C AO C 1M14-F085 1M14-F090 EC -RD STC-RD FS -RD PI -2Y EC -RD STC-RO FS -RD PI -2Y EC -RD STC-RD FS -RD PI -2Y EC -RD STC-RO FS -RD LJ -Q PI -2Y EC -Q STC-Q FS -Q LJ -Q PI -2Y T2003 T2003 T2003 T2003 T2003 T2003 T2003 T2003 T2003 T2003 T2003 T2003 T2003 T2003 T2003 T9314 T2003 T2001 T2001 T2001 T9314 T2001 3.0 4.0 3.3 3.0 RO-28 RO-28 RO-28 RO-28 RO-28 RO-28 RO-28 RO-28 RO-28 RO-28 R0-28 R0-28 ADMINISTRATIVE SEALED WITH KEYLOCK SW IN MODES 1, 2 & 3 ADMINISTRATIVE SEALED WITH KEYLOCK SW IN MODES 1, 2 & 3 ADMINISTRATIVE SEALED WITH KEYLOCK SW IN MODES 1, 2 & 3 ADMINISTRATIVE SEALED WITH KEYLOCK SW IN MODES 1, 2 & 3 2 F-9 A ACTIVE 42 AO BF C 4,310.0 2 A G-8 ACTIVE 42 BF AO C 3.0 4,310.0 3.4-76 Rev. 13 SYSTEM: CONTAINMENT VESSEL AND DRYWELL PURGE (M14)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE VALVE/DEVICE NO.1M14-F190 SIZE (in.)AND TYPE 18 BF ACTUATOR TYPE/NORMAL POSITION AO C TEST REQ.AND FREQ.EC -Q STC-Q FS -Q LJ -Q PI -2Y SURV INST.NO.SVI-M14 T2001 T2001 T2001 T9313 T2001 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE (psi)DWG. NO. D-912-604 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS 2 A C-9 ACTIVE 2.3 4,310.0 1M14-F195 2 A C-10 ACTIVE 2 A E-9 ACTIVE 18 BF 18 BF AO EC -Q C STC-Q FS -Q LJ -Q PI -2Y 1M14-F200 AO C EC -Q STC-Q FS -Q LJ -Q PI -2Y EC -Q STC-Q FS -Q LJ -Q PI -2Y T2001 T2001 T2001 T9313 T2001 T2001 T2001 T2001 T9314 T2001 T2001 T2001 T2001 T9314 T2001 4,310.0 2.0 3.0 4,310.0 1M14-F205 2 A E-10 ACTIVE 18 BF AO C 2.0 4,310.0 3.4-77 Rev. 13 SYSTEM: DRYWELL (MI6) AND CONTAINMENT VACUUM RELIEF (M17)DWG. NO. D-912-606 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE VALVE/DEVICE NO.IM16-F010A IMI6-F010B IMI6-F020A 1M16-F020B 1M17-F010 1M17-F015 02 B H-8 ACTIVE 02 B H-5 ACTIVE 02 C H-8 ACTIVE 02 C H-4 ACTIVE 2 AC B-13 ACTIVE 2 A B-12 ACTIVE SIZE (in.)AND TYPE 10 BF 10 BF 10 SD ACTUATOR TYPE/NORMAL POSITION MO C MO C TEST REQ.AND FREQ.EO -M EC -M STO-M STC-M PI -PI EO -M EC -M STO-M STC-M PI -PI SURV INST.NO.SVI-M17 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS NOTE 5 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 (MI6)(MI6)(MI6)(M16)(M16)(M16)(M16)(MI6)(MI6)(MI6)5.0 5.0*VR-3 VR-3 VR-3 NOTE 5 5.0 5.0*VR-3 VR-3 VR-3 10 SD 24 SD SE/AO SP -2YD T0414 (MI6)C SE/AO SP -2YD T0414 (M16)C SE/AO SP -2YD T0408 C LJ -PB T9114 TESTABLE VACUUM BREAKER TESTABLE VACUUM BREAKER TSTBL VAC BRKR 4,159.0 EC/EO MONTHLY 24 MO BF 0 EO -M EC -M STO-M STC-M LJ -PB PI -PI T2002 T2002 T2002 T2002 T9114 T2002 NOTE 5 5.0 5.0*VR-3 VR-3 VR-3 4,159.0 IM17-F020 2 AC D-13 ACTIVE 24 SD SE/AO SP -2YD T0408 C LJ -PB T9208 TSTBL VAC BRKR 4,159.0 EC/EO MONTHLY 3.4-78 Rev. 13 SYSTEM: DRYWELL (M16) AND CONTAINMENT VACUUM RELIEF (M17)DWG. NO. D-912-606 CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE 24 BF ACTUATOR TYPE/NORMAL POSITION 1M17-F025 2 A D-12 ACTIVE MO 0 TEST REQ.AND FREQ.EO -M EC -M STO-M STC-M LJ -PB PI -PI SURV INST.NO.SVI-M17 T2002 T2002 T2002 T2002 T9208 T2002 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS NOTE 5 5.0 5.0*VR-3 VR-3 VR-3 4,159.0 1M17-F030 1M17-F035 2 AC G-13 ACTIVE 2 A G-12 ACTIVE 24 SD 24 BF SE/AO SP -2YD T0408 C LJ -PB T9428 TSTBL VAC BRKR 4,159.0 EC/EO MONTHLY MO 0 EO -M EC -M STO-M STC-M LJ -PB PI -PI T2002 T2002 T2002 T2002 T9428 T2002 NOTE 5 5.0 5.0*VR-3 VR-3 VR-3 4,159.0 1M17-F040 1M17-F045 2 AC J-13 ACTIVE 2 A J-12 ACTIVE 24 SD 24 BF SE/AO SP -2YD T0408 C LJ -PB T9436 TSTBL VAC BRKR 4,159.0 EC/EO MONTHLY MO 0 EO -M EC -M STO-M STC-M LJ -PB PI -PI T2002 T2002 T2002 T2002 T9436 T2002 NOTE 5 5.0 5.0*VR-3 VR-3 VR-3 4,159.0 3.4-79 Rev. 13 SYSTEM: DRYWELL (M16) AND CONTAINMENT VACUUM RELIEF (M17)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-M17 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-912-606 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS VALVE/DEVICE NO.1M17-F055 2 A D-9 ACTIVE 2 A D-4 ACTIVE 3/4 so EC -Q GL 0 STC-Q FS -Q LD 2Y PI -2Y T2001 T2001 T2001 T2003 T2003 T2001 T2001 T2001 T2003 T2003 2.0 1,000.0 1M17-F065 3/4 so GL 0 EC -Q STC-Q FS -Q LD 2Y PI -2Y 2.0 1,000.0 3.4-80 Rev. 13 SYSTEM: COMBUSTIBLE GAS CONTROL (M51)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1M51-F010A TEST REQ.AND FREQ.EC -Q STO-Q STC-Q PI -2Y 2 B B-12 ACTIVE 4 GL MO C IM51-F010B 2 B F-12 ACTIVE 4 MO EC -Q GL C STO-Q STC-Q PI -2Y 1M51-F020A 1M51-F020B 2 B A-9 ACTIVE 2 B E-9 ACTIVE 2 A J-8 ACTIVE 2 GL 2 GL MO C MO C IMS1-F090 2 MO GL C EO -Q STO-Q PI -2Y EO -Q STO-Q PI -2Y EC -Q STC-Q LJ -PB PI -2Y EC -Q STC-Q LJ -PB PI -2Y EO -Q EC -Q EO -Q EC -Q SURV INST.NO.SVI-M51 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T9302 T2001 T2001 T2001 T9302 T2001 T2003A T2003A T2003B T2003B 29.3*28.7*28.9*28.1*STROKE TIME REFERENCE VALUE(sec) 14.1*VR-3 VR-3 VR-3 VR-3 VR-3 VR-3 VR-3 VR-3 VR-3 VR-3 VR-3 VR-3 VR-3 VR-3 VR-Pending 23107 LEAKAGE LIMIT(sccm gpm or bubbles)VR-Pending 23110 VR-Pending 23213 VR-Pending 23109 15.0*DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-831 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS 15.0*1,000.0 VR-Pending 23124 1M51-F110 IM51-F501A IM51-F501B 2 A J-6 ACTIVE 2 C B-II ACTIVE 2 C F-II ACTIVE 2 GL 4 CH 4 CH MO C SE C SE C 10.0*1,000.0 VR-Pending 23148 3.4-81 Rev. 13 SYSTEM: COMBUSTIBLE GAS CONTROL (M51)DWG. NO. D-302-832 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1M51-F210A 2 E-5 A ACTIVE 1/2 so GL C TEST REQ.AND FREQ.EO -Q EC -Q STO-Q STC-Q LJ -PB PI -2Y SURV INST.NO.SVI-M51 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 1M51-F210B IM51-F220A 2 A E-lI ACTIVE 2 A F-5 ACTIVE 1/2 so EO -Q GL C EC -Q STO-Q STC-Q LJ -PB PI -2Y T2001 T2001 T2001 T2001 T9425 T9425/T2007A T2001 T2001 T2001 T2001 T9318 T9318/T2007B T2001 T2001 T2001 T2001 T9425 T9425/T2007A T2001 T2001 T2001 T2001 T9318 T9318/T2007B CONTAINMENT INSTRUMENT LINE, SOLENOID OPEN & CLOSED CONTAINMENT INSTRUMENT LINE, SOLENOID OPEN & CLOSED 2.0*2.0*1,000.0 2.0*2.0*1,000.0 1/2 so GL C EO -Q EC -Q STO-Q STC-Q LJ -PB PI -2Y EO -Q EC -Q STO-Q STC-Q LJ -PB PI -2Y CONTAINMENT INSTRUMENT LINE, SOLENOID OPEN & CLOSED 2.0*2.0*1,000.0 1MSI-F220B 2 A F-11 ACTIVE 1/2 so GL C CONTAINMENT INSTRUMENT LINE, SOLENOID OPEN & CLOSED 2.0*2.0*1,000.0 3.4-82 Rev. 13 SYSTEM: COMBUSTIBLE GAS CONTROL (M51)DWG. NO. D-302-832 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-M51 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.VALVE/DEVICE NO.1M51-F230A IM51-F230B REMARKS 2 F-5 A ACTIVE 1/2 GL 1/2 GL SO C EO -Q EC -Q STO-Q STC-Q LJ -PB PI -2Y 2 A F-1I ACTIVE so EO -Q C EC -Q STO-Q STC-Q LJ -PB PI -2Y T2001 T2001 T2001 T2001 T9425 T9425/T2007A T2001 T2001 T2001 T2001 T9318 T9318/T2007B T2001 T2001 T2001 T2001 T9425 T9425/T2007A T2001 T2001 T2001 T2001 T9318 T9318/T2007B 1,000.0 CONTAINMENT INSTRUMENT LINE, SOLENOID OPEN & CLOSED 2.0*2.0*CONTAINMENT INSTRUMENT LINE, SOLENOID OPEN & CLOSED 2.0*2.0*1,000.0 IM51-F240A IM51-F240B 2 A G-5 ACTIVE 2 A G-11 ACTIVE 1/2 GL 1/2 GL SO C SO C EO -Q EC -Q STO-Q STC-Q LJ -PB PI -2Y EO -Q EC -Q STO-Q STC-Q LJ -PB PI -2Y CONTAINMENT INSTRUMENT LINE, SOLENOID OPEN & CLOSED 2.0*2.0*1,000.0 CONTAINMENT INSTRUMENT LINE, SOLENOID OPEN & CLOSED 2.0*2.0*1,000.0 3.4-83 Rev. 13 SYSTEM: COMBUSTIBLE GAS CONTROL (M51)DWG. NO. D-302-832 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1M51-F250A IM51-F250B 2 G-5 A ACTIVE 1/2 so GL C 1/2 so GL C 2 A G-11 ACTIVE TEST REQ.AND FREQ.EO -Q EC -Q STO-Q STC-Q LJ -PB PI -2Y EO -Q EC -Q STO-Q STC-Q LJ -PB PI -2Y EC -Q STC-Q PI -2Y EC -Q STC-Q PI -2Y SURV INST.NO.SVI-M51 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.T2001 T2001 T2001 T2001 T9425 T9425/T2007A T2001 T2001 T2001 T2001 T9318 T9318/T2007B CONTAINMENT INSTRUMENT LINE, SOLENOID OPEN & CLOSED 2.0*2.0*1,000.0 REMARKS CONTAINMENT INSTRUMENT LINE, SOLENOID OPEN & CLOSED 2.0*2.0*1,000.0 1M51-F26OA 1M51-F260B 3 E-4 B ACTIVE 3 B E-13 ACTIVE 3/4 GL 3/4 GL 3/4 GL 3/4 GL SO 0 SO 0 T2004 T2004 T2004 T2004 T2004 T2004 T2004 T2004 T2004 T2004 T2004 T2004 2.0*2.0*SOLENOID OPEN AND CLOSED SOLENOID OPEN AND CLOSED SOLENOID OPEN AND CLOSED SOLENOID OPEN AND CLOSED 1M51-F270A iNS 1-F270B 3 D-4 B ACTIVE SO EC -Q O STC-Q PI -2Y SO EC -Q O STC-Q PT -2Y 2.0*3 B D-13 ACTIVE 2.0*3.4-84 Rev. 13 SYSTEM: COMBUSTIBLE GAS CONTROL (M51)VALVE/DEVICE NO.1M51-F531A IM51-F531B IM51-F532A 1M51-F532B 1M51-F618A lM51-F618B CLASS AND DWG.COOR.2 F-7 2 F-9 2 G-7 2 G-9 VALVE CATEGORY/ACTIVE OR PASSIVE C ACTIVE C ACTIVE C ACTIVE C ACTIVE SIZE (in.)AND TYPE 1 CH ACTUATOR TYPE/NORMAL POSITION SE 0 TEST REQ.AND FREQ.EO -RO EC -RO ED -RO EC -RO EO -RO EC -RO EO -RO EC -RO SURV INST.NO.SVI-M51 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE (psi)1 SE CH 0 1 CH 1 CH 1 CH 1 CH SE 0 SE 0 T2006 T2005 T2006 T2005 T2006 T2005 T2006 T2005 T2006 T2005 T2006 T2005 DWG. NO. D-302-832 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS RO-8 RO-8 RO-8 RO-8 RO-S RO-8 RO-8 RO-8 2 C F-7 ACTIVE 2 C F-10 ACTIVE SE EO -RO 0 EC -RO RO-8 RO-8 RO-8 RO-8 SE 0 EO -RO EC -RO 3.4-85 Rev. 13 SYSTEM: MAIN STEAM (NMl)DWG. NO. D-302-011 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.lNll-F020A lNll-F020B lNll-F020C lNll-F020D 2 B D-13 ACTIVE 2 B G-13 ACTIVE 2 B C-13 ACTIVE 2 B F-13 ACTIVE 28 GT 28 GT MO 0 MO 0 TEST REQ.AND FREQ.EO -CS EC -CS STO-CS STC-CS PI -2Y EO -CS EC -CS STO-CS STC-CS PI -2Y EO -CS EC -CS STO-CS STC-CS PI -2Y EO -CS EC -CS STO-CS STC-CS PI -2Y SURV INST.NO.SVI-NII STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 104.6*101.9*100.8*99.4*103.0*100.0*100.2*100.1*JUSTIFI-CATIONS &RELIEF REQUEST NO.CS-2 CS-2 CS-2/VR-3 CS-2/VR-3 VR-3 CS-2 CS-2 CS-2/VR-3 CS-2/VR-3 VR-3 CS-2 CS-2 CS-2/VR-3 CS-2/VR-3 VR-3 CS-2 CS-2 CS-2/VR-3 CS-2/VR-3 VR-3 REMARKS 28 MO GT 0 VR-Pending 9214 VR-Pending 11497 VR-Pending 8774 VR-Pending 15050 28 GT MO 0 3.4-86 Rev. 13 SYSTEM: MAIN, REHEAT, EXTRACTION, AND MISC. DRAINS (N22)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.IN22-F420A 2 B D-6 ACTIVE 1 1/2 AO GL C IN22-F420B 2 B D-5 ACTIVE 1N22-F420C lN22-F420D 2 D-6 2 D-5 B ACTIVE B ACTIVE 1 1/2 AO GL C 1 1/2 AO GL C 1 1/2 AO GL C TEST REQ.AND FREQ.EO -Q EC -Q STO-Q STC-Q FS -Q PI -2Y EO -Q EC -Q STO-Q STC-Q FS -Q PI -2Y EO -Q EC -Q STO-Q STC-Q FS -Q PI -2Y EO -Q EC -Q STO-Q STC-Q FS -Q PT -2Y SURV INST.NO.SVI-N22 T2001 T2001 T2001 T2001 T2001 T2001 STROKE TIME REFERENCE VALUE(sec)

T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 4.4*6.0*5.9*4.5*4.5*3.8*LEAKAGE DEVICE LIMIT(sccm SET PRESS.gpm or REFERENCE bubbles) VALUE(psi) 8.3*4.1*DWG. NO. D-302-121 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS 3.4-87 Rev. 13 SYSTEM: FEEDWATER (N27)DWG. NO. D-302-082 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE VALVE/DEVICE NO.1B21-F032A 1B21-F032B 1 AC B-8 ACTIVE 1 AC C-8 ACTIVE 2 A B-12 ACTIVE 2 A D-11 ACTIVE SIZE (in.)AND TYPE 20 CH 20 CH ACTUATOR TYPE/NORMAL POSITION SE 0 SE 0 1B21-F065A 1B21-F065B 20 GT 20 GT MO 0 MO 0 TEST REQ.AND FREQ.EO -Q EC -RO LD -2Y EO -Q EC -RO LD -2Y EC -CS STC-CS LD -2Y PI -2Y EC -CS STC-CS LD -2Y PI -2Y EO -Q EC -RO LD -2Y EO -Q EC -RO LD -2Y SURV INST.NO.SVI-N27 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)T2001 T2005 P9121 T2001 T2005 P9414 (GEN)(GEN)(PTI)(GEN)(GEN)(PTI)RO-13 200.0 Note 9 RO-13 200.0 DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS Note 9 T2004 (B21)T2004 (B21)T7121 T2004 (B21)T2004 (B21)T2004 (B21)T7414 T2004 (B21)75.0 3.0 GPH CS-I SEAT LEAKAGE CS-1/VR-3 INCLUDED IN LOC TOTALS VR-3 VR-Pending 16819 CS-I SEAT LEAKAGE CS-1/VR-3 INCLUDED IN LOC TOTALS VR-3 VR-Pending 14814 72.6 3.0 GPH IN27-F559A IN27-F559B 1 AC B-6 ACTIVE 1 AC C-6 ACTIVE 20 CH 20 CH SE 0 SE 0 T2001 T2005 P9121 T2001 T2005 P9414 (GEN)(GEN)(PTI)(GEN)(GEN)(PTI)Note 9 RO-13 200.0 Note 9 RO-13 200.0 3.4-88 Rev. 13 SYSTEM: FEEDWATER LEAKAGE CONTROL (N27)DWG. NO. D-302-971 CLASS VALVE SIZE ACTUATOR TEST VALVE/DEVICE NO.IN27-F737 1N27-F739A IN27-F739B 1N27-F740 AND DWG.COOR.CATEGORY/ACTIVE OR PASSIVE (in.)AND TYPE TYPE/NORMAL POSITION 2 A C-12 ACTIVE 1 1/2 MO GL C REQ.AND FREQ.EO -CS STO-CS STC-CS LK -2Y PI -2Y SURV INST.NO.SVI-N27 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 2 D-8 2 C-8 AC ACTIVE AC ACTIVE 1 CH 1 CH SE C SE C EO EC LK EO EC LK-RO-RO-2Y-RO-RO-2Y T2001 T2001 T2201 T2201 T2001 T2201 T2201 T2201 T2201 T2201 T2201 T2001 T2001 T2001 T2202 T2001 T2202 T2202 T2202 T2202 T2202 T2202 15.7*14.8*0.75 VR-3 RO-21 RO-21 RO-21 RO-21 VR-Pending 16754 CS-3 CS-3/VR-3 CS-3/VR-3 1.0 1.0 2 A G-12 ACTIVE 1 1/2 MO GL C EO -CS STO-CS STC-CS LK -2Y PI -2Y 16.0*14.3*CS-3 CS-3/VR-3 CS-3/VR-3 0.75 VR-3 VR-Pending 8649 1N27-F742A IN27-F742B 2 AC H-8 ACTIVE 2 AC G-8 ACTIVE 1 CH 1 CH SE EO C EC LK SE EO C EC LK-RO-RO-2Y-RO-RO-2Y 1.0 RO-21 RO-21 RO-21 RO-21 1.0 1 N27-F751 2 A 1 MA LJ -PB F-6 PASSIVE GL LC T9107 (E12)1,000.0 3.4-89 Rev. 13 SYSTEM: CONDENSATE TRANSFER AND STORAGE (P1I)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-PII STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-102 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS VALVE/DEVICE NO.lPll-F060 2 A C-10 ACTIVE 12 BF MO O EO -Q EC -Q STO-Q STC-Q LJ -PB PI -2Y IPlI-F080 2 A B-4 ACTIVE 10 BF MO EO -Q C EC -Q STO-Q STC-Q LJ -PB PI -2Y T2002 T2002 T2002 T2002 T9108 T2002 T2002 T2002 T2002 T2002 T9111 T2002 T2002 T2002 T2002 T2002 T9111 T2002 28.1*28.7*VR-3 VR-3 VR-3 2,773.0 VR-Pending 16787 27.9*27.9*VR-3 VR-3 VR-3 2,311.0 VR-Pending 126781 lPll-F090 1P1l-F545 2 A B-6 ACTIVE 2 AC C-1I ACTIVE 10 BF 12 CH MO C SE C EO -Q EC -Q STO-Q STC-Q LJ -PB PI -2Y EO -CVCM EC -CVCM LJ -PB 29.0*29.0*VR-3 VR-3 VR-3 2,311.0 VR-Pending 126782 T2005 (GEN)T9108 T9108 RO-26 RO-26 2,773.0 3.4-90 Rev. 13 SYSTEM: MIXED BED DEMIN & DISTRIBUTION (P22)CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-P22 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-713 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS 1P22-F010 2 A F-II ACTIVE 3 GT MO EC -Q 0 STC-Q LJ -PB PI -2Y T2002 T2002 T9309 T2002 T2002 T2002 T2002 17.0*1,000.0 VR-3 VR-3 VR-Pending 13880 1P22-F015 lP22-F577 02 B H-i1 ACTIVE 2 AC G-11 ACTIVE 1 1/4 MO EC -Q GL C STC-Q PI -2Y 16.0*3 CH SE EO -CVCM C EC -CVCM LJ -PB T2005(GEN)

T9309 T9309 RO-26 RO-26 1,000.0 3.4-91 Rev. 13 SYSTEM: SERVICE WATER SYSTEM (P41)DWG. NO. D-302-212 CLASS VALVE SIZE ACTUATOR TEST SURV STROKE LEAKAGE DEVICE JUSTIFI-AND CATEGORY/ (in.) TYPE/ REQ. INST. TIME LIMIT(sccm SET PRESS. CATIONS &VALVE/ DWG. ACTIVE OR AND NORMAL AND NO. REFERENCE gpm or REFERENCE RELIEF DEVICE NO. COOR. PASSIVE TYPE POSITION FREQ. SVI-P41 VALUE(sec) bubbles) VALUE(psi)

REQUEST NO. REMARKS P41-F420 3 B 36 MO EC -Q T2001 J-12 ACTIVE BF 0 STC-Q T2001 16.0* VR-3 PI -2Y T2001 VR-3 VR-Pending 13014 P41-F430 3 B 36 MO EC -Q T2001 J-11 ACTIVE BF 0 STC-Q T2001 16.0* VR-3 PI -2Y T2001 VR-3 VR-Pending 13012 3.4-92 Rev. 13 SYSTEM: EMERGENCY CLOSED COOLING SYSTEM (P42)CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE 1P42-F5lPA 3 C E-I1 ACTIVE 1P42-F519B 3 C G-1l ACTIVE SIZE (in.)AND TYPE 12 CH 12 CH ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-P42 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-621 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS SE C SE C SE C EO -Q T2001A EC -2Y T2001A EO -Q T2001B EC -2Y T2001B Acoustic Monitoring Acoustic Monitoring P42-F543A 3 C-5 P42-F543B 3 H-5 C ACTIVE C ACTIVE 3/4 RE 3/4 RE SE C RT -10Y T2100 (GEN)RT -10Y T2100 (GEN)RT -10Y T2100 (GEN)150.0 150.0 150.0 P42-F543C 3 C F-5 ACTIVE 3/4 SE RE C 3.4-93 Rev. 13 SYSTEM: EMERGENCY CLOSED COOLING SYSTEM (P42)CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE B ACTIVE P42-F255A P42-F255B P42-F260A P42-F260B P42-F265A P42-F265B P42-F380A 3 C-7 3 B G-6 ACTIVE 3 D-8 3 F-7 3 D-4 3 F-4 3 D-7 B ACTIVE B ACTIVE B ACTIVE B ACTIVE B ACTIVE SIZE (in.)AND TYPE 10 BF I0 BF 10 BF 10 BF 10 BF 10 BF 10 BF MO 0 MO 0 MO C MO C MO C MO C MO 0 ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.EC -Q STC-Q PI -2Y EC -Q STC-Q PI -2Y EO -RO STO-RO PI -2Y EO -RO STO-RO PI -2Y EO -RO STO-RO PI -2Y EO -RO STO-RO PI -2Y EC -Q STC-Q PI -2Y SURV INST.NO.SVI-P42 T2002 T2002 T2002 T2002 T2002 T2002 T2003A T2003A T2003A T2003B T2003B T2003B T2003A T2003A T2003A T2003B T2003B T2003B T2002 T2002 T2002 STROKE TIME REFERENCE VALUE(sec) 28.0 29.3 LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-352-621 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS 30.0 25.0 RO-15 RO-15 RO-15 RO-15 RO-15 RO-15 RO-15 RO-15 29.0 26.0 31.0 3.4-94 Rev. 13 SYSTEM: EMERGENCY CLOSED COOLING SYSTEM (P42)DWG. NO. D-352-621 CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE P42-F380B P42-F390A P42-F390B P42-F440 P42-F445 3 B E-7 ACTIVE 3 D-4 B ACTIVE SIZE (in.)AND TYPE 10 BF 10 BF 10 BF 10 BF 10 BF ACTUATOR TYPE/NORMAL POSITION MO 0 MO 0 MO 0 MO 0 MO 0 TEST REQ.AND FREQ.EC -Q STC-Q PI -2Y EC -Q STC-Q PI -2Y EC -Q STC-Q PI -2Y EC -Q STC-Q PI -2Y EC -Q STC-Q PI -2Y SURV INST.NO.SVI-P42 T2002 T2002 T2002 T2002 T2002 T2002 T2002 T2002 T2002 T2002 T2002 T2002 T2002 T2002 T2002 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi) 3 B E-3 ACTIVE JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 29.0 28.0 28.0 28.0 30.0 3 E-7 3 E-3 3 D-5 3 E-5 B ACTIVE B ACTIVE C ACTIVE C ACTIVE P42-F590A P42-F5 POD 3/4 RE 3/4 RE SE C SE C RT -10Y T2100 (GEN)RT -10Y T2100 (GEN)150.0 150.0 3.4-95 Rev. 13 SYSTEM: EMERGENCY CLOSED COOLING SYSTEM (P42)DWG. NO. D-302-622 CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-P42 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE (psi)JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 1P42-F540 3 C C-3 ACTIVE 1P42-F566A 3 C D-7 ACTIVE lP42-F566B 3 C H-Il ACTIVE 1P42-F566C 3 C H-6 ACTIVE lP42-F570 3 C C-Il ACTIVE 1P42-F671A 3 C B-6 ACTIVE 1P42-F671B 3 C F-Il ACTIVE 3/4 RE 3/4 RE 3/4 RE 3/4 RE 3/4 RE SE C SE C SE C SE C SE C SE C SE C SE C RT -10Y T2100 (GEN)RT -10Y T2100 (GEN)RT -10Y T2100 (GEN)RT -10Y T2100 (GEN)RT -10Y T2100 (GEN)RT-10Y T2100 (GEN)RT-10Y T2100 (GEN)RT-10Y T2100 (GEN)94.0 94.0 94.0 94.0 94.0 150.0 150.0 150.0 56.0 psi BACK-PRESSURE 56.0 psi BACK-PRESSURE 56.0 psi BACK-PRESSURE 56.0 psi BACK-PRESSURE 56.0 psi BACK-PRESSURE RE RE RE 1P42-F671C 3 F-6 C ACTIVE 3.4-96 Rev. 13 SYSTEM: NUCLEAR CLOSED COOLING (P43)DWG. NO. D-302-613 VALVE /DEVICE NO.1P43-F055 CLASS AND DWG.COOR.2 J-13 VALVE CATEGORY/ACTIVE OR PASSIVE A ACTIVE SIZE (in.)AND TYPE 12 BF ACTUATOR TYPE/NORMAL POSITION MO 0 TEST REQ.AND FREQ.EC -RO STC-RO LJ -PB PI -2Y EC -RO STC-RO LJ -PB PI -2Y SURV INST.NO.SVI-P43 T2001 T2001 T9310 T2001 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.RO-3 RO-3/VR-3 28.6*REMARKS VR-Pending 23028 2,773.0 VR-3 1P43-F140 2 A J-4 ACTIVE 12 BF MO 0 IP43-F215 1P43-F355 IP43-F400 IP43-F410 2 A J-4 ACTIVE 02 B J-11 ACTIVE 02 B J-7 ACTIVE 02 B J-6 ACTIVE 2 AC J-12 ACTIVE 2 AC J-4 ACTIVE 12 BF MO EC -RO 0 STC-RO LJ -PB PI -2Y 10 MO EC -RO BF 0 STC-RO PI -2Y T2001 T2001 T9311 T2001 T2001 T2001 T9311 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 T2001 RO-3 RO-3/VR-3 27.9*2,773.0 VR-3 28.1*2,773.0 10 BF 10 BF 12 CH MO EC -RO O STC-RO PI -2Y MO EC -RO O STC-RO PI -2Y SE EO -Q O EC -CVCM LJ-PB VR-Pending 23024 9.9*10.0*10.0*RO-3 RO-3/VR-3 VR-3 RO-3 RO-3/VR-3 VR-3 RO-3 RO-3/VR-3 VR-3 RO-3 RO-3/VR-3 VR-3 VR-Pending 22930 VR-Pending 9652 VR-Pending 32599 VR-Pending 30518 IP43-F721 1P43-F851 IP43-F852 T2001 (GEN)T9310/T2003 T9310 T2100 (GEN)T9311 T2100 (GEN)RO-13 2,773.0 2,773.0 1/4 SE RT-10Y RE C LJ -PB 150 +/-30 150 +/-30 02 J/6 C 1/4 RE SE RT-10Y C 3.4-97 Rev. 13 SYSTEM: EMERGENCY SERVICE WATER (P45)DWG. NO. D-302-791 CLASS VALVE SIZE ACTUATOR TEST VALVE/DEVICE NO.1P45-F130A 1P45-F130B 1P45-F140 IP45-F501A IP45-F501B IP45-F502A IP45-F502B AND DWG.COOR.CATEGORY/ACTIVE OR PASSIVE (in.)AND TYPE TYPE/NORMAL POSITION 3 B C-13 ACTIVE 3 B C-lI ACTIVE 3 B D-8 ACTIVE 3 C G-13 ACTIVE 3 C G-11 ACTIVE 3 C G-13 ACTIVE 3 C G-10 ACTIVE 24 MO BF C 24 BF 8 BF 24 CH MO C MO C SE C REQ.AND FREQ.EO -Q EC -Q STO-Q STC-Q PI -2Y EO -Q EC -Q STO-Q STC-Q PI -2Y EO -Q EC -Q STO-Q STC-Q PI -2Y EO -Q EC -Q EO -Q EC -Q EO -Q EC -Q EO -Q EC -Q SURV INST.NO.SVI-P45 STROKE TIME REFERENCE VALUE(sec)

T2001 T2001 T2001 T2001 T2001 T2002 T2002 T2002 T2002 T2002 T2003 T2003 T2003 T2003 T2003 T2001 T2001 T2002 T2002 T2006 T2001 T2006 T2002 LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi) 29.4*29.6*VR-3 VR-3 VR-3 29.0*29.0*JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS VR-3 VR-3 VR-3 SVI-C61-T1201 REMOTE S/D PANEL VR-Pending 23041 SVI-C61-T1202 REMOTE S/D LOCAL BREAKER VR-Pending 13766 VR-Pending 22942 29.8*29.9*VR-3 VR-3 VR-3 REFERENCE IEB: 83-03 REFERENCE IEB: 83-03 24 SE CH C 2 CH 2 CH SE C SE C 3.4-98 Rev. 13 SYSTEM: EMERGENCY SERVICE WATER (P45)DWG. NO. D-302-791 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-P45 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.VALVE/DEVICE NO.1P45-F506 1P45-F517 1P45-F520 1P45-F525 1P45-F526 1P45-F527 1P45-F552 P45-FO06A P45-F006B REMARKS 3 C G-8 ACTIVE 3 A-6 3 F-5 C ACTIVE C ACTIVE 2 CH 3/4 RE 3/4 RE SE EO -Q T2006 C EC -Q T2003 SE RT -10Y T2100 (GEN)C SE RT -10Y T2100 (GEN)C 150.0 150.0 3 B C-2 ACTIVE 3 B-2 3 D-2 3 G-8 3 H-5 3 G-5 B ACTIVE B ACTIVE 8 BF 24 B F 24 BF MA 0 MA 0 EO -Q EC -Q EO -Q EC -Q MA EO -Q 0 EC -Q See Remarks See Remarks See Remarks See Remarks See Remarks See Remarks T2003 T2003 T2007 T2007 T2007 Note 11: Note 11: Note 11: Note 11: Note 11: Note 11: C 8 SE EO -Q ACTIVE CH C EC -Q REFERENCE IEB: 83-03 AC 1/2 SE ACTIVE CH C AC 1/2 SE ACTIVE CH C EO EC LD EO EC LD-Q-Q-1Y-Q-Q-lY Note 8: 2.0 SCFH T2007 T2007 T2007 Note 8: 2.0 SCFH 3.4-99 Rev. 13 SYSTEM: EMERGENCY SERVICE WATER (P45)DWG. NO. D-302-791 VALVE/DEVICE NO.P45-F007A P45-F007B P45-F009A P45-F009B CLASS AND DWG.COOR.3 H-5 3 G-5 3 H-5 VALVE CATEGORY/ACTIVE OR PASSIVE AC ACTIVE AC ACTIVE AC ACTIVE SIZE (in.)AND TYPE 1/2 CH 1/2 CH 1/2 CH 1/2 CH ACTUATOR TYPE/NORMAL POSITION SE C SE C TEST REQ.AND FREQ.EO -Q EC -Q LD -lY SURV INST.NO.SVI-P45 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS Note 8: SE C SE C EO EC LD EO EC LD EO EC LD-Q-Q-lY-Q-Q-lY-Q-Q-lY T2007 T2007 T2007 T2007 T2007 T2007 T2007 T2007 T2003 T2007 T2007 T2007 Note 8: 2.0 SCFH Note 8: 2.0 SCFH 2.0 SCFH 3 AC G-5 ACTIVE Note 8: 2.0 SCFH 3.4-100 Rev. 13 SYSTEM: EMERGENCY SERVICE WATER (P45)DWG. NO. D-302-792 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ, SURV INST.NO.SVI-P45 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.VALVE/DEVICE NO.IP45-F531A 1P45-F531B IP45-F537A 1P45-F537B 1P45-F543A 1P45-F543B 1P45-F571A 1P45-F571B IP45-F575 REMARKS 3 C B-13 ACTIVE 3 C J-13 ACTIVE 3 C C-10 ACTIVE 3 C G-10 ACTIVE 3/4 RE SE RT -10Y T2100 (GEN)3/4 SE RT -10Y T2100 (GEN)RE C 3/4 SE RT -10Y T2100 (GEN)RE C 3/4 RE 3/4 RE SE C SE C 3 E-8 3 F-8 3 B-5 C ACTIVE C ACTIVE C ACTIVE 3/4 SE RE C RT -10Y T2100 (GEN)RT -10Y T2100 (GEN)RT -10Y T2100 (GEN)RT -10Y T2100 (GEN)RT -10Y T2100 (GEN)EO -CVCM T2000 (GEN)EC -CVCM T2000 (GEN)150.0 150.0 150.0 150.0 150.0 150.0 125.0 125.0 1 1/2 RE 1 1/2 RE 3 C K-6 ACTIVE SE C SE C SE C 2 F-9 C ACTIVE 18 CH RO-2 RO-2 optionally tested 3.4-101 Rev. 13 SYSTEM: CONTROL COMPLEX CHILLED WATER (P47)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE VALVE/DEVICE NO.P47-F506A P47-F506B P47-F506C P47-F574A P47-F574B P47-F574C SIZE (in.)AND TYPE 10 CH ACTUATOR TYPE/NORMAL POSITION SE C TEST REQ.AND FREQ.EO -Q EC -Q 3 C C-5 ACTIVE 3 C H-5 ACTIVE 3 C E-5 ACTIVE 3 C C-5 ACTIVE 3 C H-5 ACTIVE 3 C E-5 ACTIVE SURV INST.NO.SVI-P47 T2001A T2001C T2001B T2001C T2001C T2001C STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-913-001 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS 10 SE EO -Q CH C EC -Q 10 CH 3/4 RE SE C EO -Q EC -Q SE RT -10Y T2100 (GEN)C 3/4 SE RT -10Y T2100 (GEN)RE C 150.0 150.0 150.0 3/4 RE SE RT -10Y T2100 (GEN)C 3.4-102 Rev. 13 SYSTEM: CONTROL COMPLEX CHILLED WATER (P47)VALVE/DEVICE NO.P47-F290A P47-F290B P47-F295A P47-F295B CLASS AND DWG.COOR.3 D-3 3 E-3 VALVE CATEGORY/ACTIVE OR PASSIVE B ACTIVE B ACTIVE SIZE (in.)AND TYPE 6 BF 6 BF ACTUATOR TYPE/NORMAL POSITION MO 0 MO 0 TEST REQ.AND FREQ.EC -Q STC-Q PI -2Y EC -Q STC-Q PI -2Y EC -Q STC-Q PI -2Y EC -Q STC-Q PI -2Y SURV INST.NO.SVI-P47 T2001A T2001A T2001A T2001B T2001B T2001B T2001A T2001A T2001A T2001B T2001B T2001B STROKE TIME REFERENCE VALUE(sec)

LEAKAGE DEVICE LIMIT(sccm SET PRESS.gpm or REFERENCE bubbles) VALUE(psi)

DWG. NO. D-913-002 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS 28.0*30.0*32.0*29.0*3 B E-4 ACTIVE 6 MO BF 0 3 F-3 B ACTIVE 6 BF MO 0 3.4-103 Rev. 13 SYSTEM: EMERGENCY SERVICE SCREEN WASH (P49)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-P47 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-214 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS VALVE/DEVICE NO.P49-FS02A P49-FS02B 03 C C-lI ACTIVE 03 C G-11 ACTIVE 6 CH 6 CH SE C SE C EO -N/A NONE EC -N/A NONE REFERENCE IEB: 83-03, OPEN VERIFICATION PTI-P49-POO01 REFERENCE IEB: 83-03, OPEN VERIFICATION PTI-P49-POO01 EO -N/A NONE EC -N/A NONE 3.4-104 Rev. 13 SYSTEM: CONTAINMENT VESSEL CHILLED (P50)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1P50-F060 1P50-F140 2 A F-4 ACTIVE 2 A E-5 ACTIVE 6 BF 6 BF MO 0 MO 0 TEST REQ.AND FREQ.EC -Q STC-Q LJ -PB PI -2Y EC -Q STC-Q LJ -PB PI -2Y SURV INST.NO.SVI-P50 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-913-008 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS T2001 T2001 T9404 T2001 T2001 T2001 T9405 T2001 T2001 T2001 T9405 T2001 28.0*1,386.0 31.0*1,386.0 VR-3 VR-3 VR-3 VR-3 VR-3 VR-3 VR-Pending 32630 VR-Pending 14482 1P50-F150 2 A E-4 ACTIVE 6 BF MO EC -Q 0 STC-Q LJ -PB PI -2Y 29.9*1,386.0 VR-Pending 14424 IP50-F539 2 AC F-5 ACTIVE 02 AC E-5 ACTIVE 6 CH SE 0 EO -Q EC -CVCM LJ -PB T2001 (GEN)T9404 T9404 T2100 (GEN)T9405 RO-13 1,386.0 1,386.0 1P50-F606 1/4 SE RT-10Y RE C LJ -PB 200 +/-40 3.4-105 Rev. 13 SYSTEM: SERVICE AIR DISTRIBUTION (P51)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1P51-F150 TEST REQ.AND FREQ.EC -Q STC-Q FS -Q LJ -PB PI 2Y SURV INST.NO.SVI-P51 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-242 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS 2 A G-9 ACTIVE 2 1/2 AO GL 0 T2001 T2001 T2001 T9308 T2001 9.7*1,000.0 1P51-F530 2 AC H-9 ACTIVE 02 B K-11 ACTIVE 2 1/2 SE EO -CVCM CH C EC -CVCM LJ -PB 1 1/2 MO EC -Q GL C STC-Q PI -2Y T2005 (GEN)T9308/T2003 T9308 RO-26 RO-26 1,000.0 IP51-F652 T2001 T2001 T2001 9.0*3.4-106 Rev. 13 SYSTEM: INSTRUMENT AIR (P52)DWG. NO. D-302-243 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-P52 STROKE TIME REFERENCE VALUE (sec)LEAKAGE LIMIT (sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.VALVE/DEVICE NO.1P52-F170 REMARKS 2 A G-II ACTIVE 3/4 so EC -Q GL 0 STC-Q FS -Q LJ -PB PT 2Y T2002 T2002 T2002 T9312 (P53)T9312 (P53)/T2004 (P53)2.0*1,000.0 3.4-107 Rev. 13 SYSTEM: INSTRUMENT AIR (P52)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1P52-F160 2 A G-11 ACTIVE 3/4 so GL 0 TEST REQ.AND FREQ.EC -Q STC-Q FS -Q LJ -PB PI 2Y EC -Q STC-Q LJ -PB PI -2Y SURV INST.NO.SVI-P52 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-244 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS T2002 T2002 T2002 T9305 T9305 T2003 T2001 T2001 T9306 T2001 2.0*(P53)(P53)/(P53)1,000.0 1P52-F200 2 A D-8 ACTIVE 2 GL MO 0 14.0*1,000.0 VR-3 VR-3 VR-Pending 37676 1P52-F550 2 AC E-8 ACTIVE 02 B G-7 ACTIVE 1 1/2 SE CH C EO -RO EC -CVCM LJ -PB T2009 (B21)T9306 T9306 RO-22 RO-22 1,000.0 1P52-F646 2 GL MO 0 EC -Q STC-Q PI -2Y T2001 T2001 T2001 13.0*VR-3 VR-3 VR-Pending 43270 3.4-108 Rev .13 SYSTEM: PENETRATION PRESSURIZATION (P53)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1P53-F010 1P53-F015 1P53-F020 2 A B-9 ACTIVE 2 A C-9 ACTIVE 2 A F-9 ACTIVE GL GL GL SO C SO C SO C TEST REQ.AND FREQ.EO -Q EC -Q STO-Q STC-Q FS -Q LJ -PB PI -2Y EO -Q EC -Q STO-Q STC-Q FS -Q LJ -PB PI -2Y EO -Q EC -Q STO-Q STC-Q FS -Q LJ -PB PI -2Y SURV INST.NO.SVI-P53 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-761 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS T2001 T2001 T2001 T2001 T2001 T9305 T9305/T2003 T2001 T2001 T2001 T2001 T2001 T9305 T9305/T2003 T2001 T2001 T2001 T2001 T2001 T9312 T9312/T2004 T2001 T2001 T2001 T2001 T2001 T9312 T9312/T2004 2.0*2.0*1,000.0 2.0*2.0*1,000.0 2.0*2.0*1,000.0 IP53-F025 2 A G-9 ACTIVE SO EO -Q GL C EC -Q STO-Q STC-Q FS -Q LJ -PB PI -2Y 2.0*2.0*1,000.0 3.4-109 Rev .13 SYSTEM: PENETRATION PRESSURIZATION (P53)DWG. NO. D-302-761 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1P53-F030 IP53-F035 2 A C-li ACTIVE 2 A D-12 ACTIVE GL GL SO 0 SO C TEST REQ.AND FREQ.EQ -Q EC -Q STO-Q STC-Q LJ -PB PI -2Y ED -Q EC -Q STO-Q STC-Q LJ -PB PI -2Y ED -Q EC -Q STO-Q STC-Q LJ -PB PI -2Y ED -Q EC -Q STO-Q STC-Q LJ -PB PI -2Y SURV INST.NO.SVI-P53 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE (psi)JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS T2001 T2001 T2001 T2001 T9305 T9305/T2003 T2001 T2001 T2001 T2001 T9305 T9305/T2003 T2001 T2001 T2001 T2001 T9312 T9312/T2004 T2001 T2001 T2001 T2001 T9312 T9312/T2004 SOLENOID OPEN AND CLOSED 2.0*2.0*1,000.0 SOLENOID OPEN AND CLOSED 2.0*2.0*1,000.0 1P53-F040 1P53-F045 2 A H-11 ACTIVE 2 A J-12 ACTIVE k SO GL 0 SOLENOID OPEN AND CLOSED 2.0*2.0*1,000.0 GL SO C SOLENOID OPEN AND CLOSED 2.0*2.0*1,000.0 3.4-110 Rev. 13 SYSTEM: PENETRATION PRESSURIZATION (P53)DWG. NO. D-302-761 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-P53 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.VALVE/DEVICE NO.1P53-F070 REMARKS 2 A B-8 ACTIVE GL so EC -Q 0 STC-Q LJ -PB PI -2Y T2001 T2001 T9305 T9305/T2003 T2001 T2001 T9312 T9312/T2004 SOLENOID OPEN AND CLOSED 2.0*1,000.0 1P53-F075 2 A F-8 ACTIVE G SO GL 0 IP53-F536 IP53-F541 IP53-F556 IP53-F561 IP53-F570 IP53-F571 2 A 1 D-9 PASSIVE GL MA LC 2 A 1 MA H-9 PASSIVE GL LC 2 A 3/4 MA C-13 PASSIVE GL LO EC -Q STC-Q LJ -PB PI -2Y LJ -PB LJ -PB LJ -PB LJ -PB LJ -PB LJ -PB 2.0*T9305 T9312 T9305 T9312 T9305 T9312 1,000.0 1,000.0 1,000.0 1,000.0 1,000.0 1,000.0 1,000.0 SOLENOID OPEN AND CLOSED 2 A 3/4 G-13 PASSIVE GL MA L0 2 A 1 MA D-9 PASSIVE GL LC 2 H-9 A 1 PASSIVE GL MA LC 3.4-111 Rev. 13 SYSTEM: PENETRATION PRESSURIZATION (P53)CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-P53 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-762 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS IP53-F572A 2 AC C-3 ACTIVE IP53-F572B 2 AC C-6 ACTIVE IP53-F573A 2 AC D-3 ACTIVE 1P53-F573B 2 AC D-6 ACTIVE 1P53-F574 2 AC C-5 ACTIVE 1P53-F579A 2 A D-2 ACTIVE 1P53-F579B 2 A D-5 ACTIVE 1P53-F580A 2 A D-3 ACTIVE SE EO CH C EC LD CH SE EO C EC LD SE EO CH C EC LD CH CH 1 BA 1 BA 1 BA SE ED C EC LD-Q-RO-2Y-Q-R0-2Y-Q-RO-2Y-Q-RO-2Y-Q-R0 2Y-Q-Q-PB-Q-Q-PB-Q-Q-PB T2022 T7305 T7305 T2022 T7305 T7305 T2022 T7305 T7305 T2022 T7305 T7305 T2022 T7305 T7305 T2022 T2022 T7305 T2022 T2022 T7305 T2022 T2022 T7305 N/A RO-30 RO-30 N/A N/A RO-30 RO-30 N/A SE C MA C MA C MA C EO EC LD-EO EC LJ EO EC LJ EO EC LJ RO-30 1,000.0 1,000.0 1,000.0 3.4-112 Rev. 13 SYSTEM: PENETRATION PRESSURIZATION (P53)DWG. NO. D-302-762 CLASS AND VALVE/ DWG.DEVICE NO. COOR.IP53-F580B 2 D-6 1P53-F581 2 E-4 VALVE CATEGORY/ACTIVE OR PASSIVE A ACTIVE AC ACTIVE SIZE (in.)AND TYPE 1 BA 1 SD ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-P53 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 1P53-F582 IP53-F587A IP53-F587B IP53-F588A IP53-F588B 2 E-5 AC ACTIVE 2 AC B-10 ACTIVE 2 AC B-13 ACTIVE 2 AC C-10 ACTIVE 2 AC C-13 ACTIVE 2 A D-9 ACTTVE 1 SD CH CH CH CH MA C SE C SE C SE C SE C SE C SE C EO EC LJ-Q-Q-PB SP -2YD T8305 LJ -PB T8305 SP -2YD T8305 LJ -PB T8305 T2022 T2022 T7305 1,000.0 1,000.0 1,000.0 2.5 2.5 EO EC LD EO EC LD EO EC LD EO EC LD-Q-RO-2Y-Q-RD-2Y-Q-RO-2Y-Q-RO-2Y-Q-Q-PB T2022 T7312 T7312 T2022 T7312 T7312 T2022 T7312 T7312 T2022 T7312 T7312 RO-30 N/A RO-30 N/A RO-30 N/A RO-30 N/A IP53-F593A 1 MA EO BA C EC LJ T2022 T2022 T7312 1,000.0 3.4-113 Rev. 13 SYSTEM: PENETRATION PRESSURIZATION (P53)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE VALVE/DEVICE NO.1P53-F593B 1P53-F594A lP53-F594B 2 A D-12 ACTIVE 2 A D-10 ACTIVE 2 A D-13 ACTIVE 2 AC E-11 ACTIVE 2 AC E-12 ACTIVE 02 AC H-7 ACTIVE 02 AC H-10 ACTIVE SIZE (in.)AND TYPE 1 BA 1 BA 1 BA ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-P53 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-762 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS MA C MA C MA C EO -Q EC -Q LJ -PB EO -Q EC -Q LJ -PB EO -Q EC -Q LJ -PB T2022 T2022 T7312 T2022 T2022 T7312 T2022 T2022 T7312 1,000.0 1, 000.0 1P53-F595 1P53-F596 IP53-F601A 1P53-F601B 1P53-F602A I SE SD C SP -2YD T8312 LJ -PB T8312 1,000.0 1,000.0 1,000.0 2.5 2.5 1 SD CH CH CH SE SP -2YD T8312 C LJ -PB T8312 SE C SE C SE C ED -RO EC -RO LD -2Y ED -RO EC -RO LD -2Y ED -RO EC -RO LD -2Y T2021 T9023 T9023 T2021 T9023 T9023 T2021 T9023 T9023 N/A RD-17 RO-17 RO-17 RO-17 RO-17 RO-17 N/A 02 G-7 AC ACTIVE N/A 3.4-114 Rev. 13 SYSTEM: PENETRATION PRESSURIZATION (P53)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-P53 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-762 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS VALVE/DEVICE NO.1P53-F602B 1P53-F633A 1P53-F633B 1P53-F638 02 AC G-10 ACTIVE 02 A H-7 ACTIVE 02 A H-10 ACTIVE 02 AC J-9 ACTIVE SE EO -RO CH C EC -RO LD -2Y 1 MA EO -RO BA C EC -RO LD -2Y T2021 T9023 T9023 T2021 T2021 T2021 T2021 T2021 T2021 N/A RO-17 RO-17 RO-17 RO-17 RO-17 RO-17 N/A 1 BA MA E0 C EC LD-RO-RO-2Y N/A 1 SE SP -2YD T2021 SD C LD -2Y T2021 2.5 1,180.0 3.4-115 Rev. 13 SYSTEM: FIRE SERVICE WATER (P54)CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION IP54-F726 2 A 4 MA G-5 PASSIVE GT LC 2 A 4 MA B-8 PASSIVE GT LC TEST REQ.AND FREQ.LJ -PB PI -2Y LJ -PB PI -2Y SURV INST.NO.SVI-P54 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE DEVICE LIMIT(sccm SET PRESS.gpm or REFERENCE bubbles) VALUE(psi)

DWG. NO. D-914-003 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS T9406 T9406/T2004 (GEN)T9406 T9406/T2004 (GEN)1,000.0 IP54-F727 1,000.0 3.4-116 Rev. 13 SYSTEM: FIRE SERVICE CARBON DIOXIDE (P54)CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION 1P54-F340 2 A G-7 ACTIVE 4 MO GT C TEST REQ.AND FREQ.EC -Q STC-Q LJ -PB PI -2Y EC -Q STC-Q PI -2Y SURV INST.NO.SVI-P54 T2002 T2002 T9210 T2002 T2002 T2002 T2002 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-914-005 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS 15.0*1,000.0 IP54-F395 IP54-F1098 IP54-F5604 02 B G-6 ACTIVE 2 AC G-7 ACTIVE 02 C G-7 ACTIVE 4 GT 4 CH MO 0 SE C EO -CVCM EC -CVCM LJ -PB 14.0*T9210/T2003 T9210/T2003 T9210 RO- 6 RO-6 1,000.0 3SE SV C RT -10Y T2100 (GEN)500.0 (S/N 009)490.0 (S/N 015)3.4-117 Rev. 13 SYSTEM: SAFETY RELATED INSTRUMENT AIR (57)DWG. NO. D-302-271 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1P57-F015A TEST REQ.AND FREQ.EC -Q STC-Q LJ -PB PT -2Y SURV INST.NO.SVI-P57 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 2 A B-7 ACTIVE 1 GL MO 0 1P57-F015B 2 G-7 A ACTIVE 1 GL MO EC -Q 0 STC-Q LJ -PB PI -2Y T2001 T2001 T9304 T2001 T2001 T2001 T9116 T2001 T2001 T2001 T2001 T2001 T2001 T2001 1,000.0 11.0*10.7*VR-3 VR-3 VR-3 VR-3 VR-3 VR-3 SVI-P57-T2003 (PI) REMOTE S/D LOCAL BRKR VR-Pending 10239 1,000.0 1P57-FO2OA 1P57-F020B 1P57-F524A 1P57-F524B 1P57-F555A 3 B B-5 ACTIVE 3 B G-5 ACTIVE 2 AC B-6 ACTIVE 2 AC G-6 ACTIVE 3 AC C-8 ACTIVE 1 MO GL 0 EC -Q STC-Q PI -2Y EC -Q STC-Q PI -2Y 11.0*1 GL 1 CH MO 0 SE C 10.9*EO -RO EC -CVCM LJ -PB VR-Pending 26272 SVI-P57-T2003 (PI) REMOTE S/D LOCAL BRKR VR-Pending 14033 VR-Pending 15924 1 SE CH C 1 SE CH C EO EC LJ EO EC LD-RO-CVCM-PB-RO-RO-2Y T2005 T9304/T2005 T9304 T2005 T9116/T2005 T9116 T2005(GEN)

T2200 T2200 1,000.0 VR-3 VR-3 RO-23 RO-23 RO-23 RO-23 RO-27 RO-27 1,000.0 295.0 3.4-118 Rev. 13 SYSTEM: SAFETY RELATED INSTRUMENT AIR (57)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE VALVE/DEVICE NO.1P57-F555B 1P57-F556A 3 AC H-8 ACTIVE SIZE (in.)AND TYPE 1 CH 1 CH TYPE/NORMAL POSITION ACTUATOR TEST REQ.AND FREQ.SURV INST.NO.SVI-P57 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-271 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS 3 C-8 AC ACTIVE IP57-F556B 1P57-F559A lP57-F559B lP57-E569B 1P57-F572B lP57-F574B 3 AC H-8 ACTIVE 3 AC C-6 ACTIVE 3 AC G-6 ACTIVE 3 AC G-3 ACTIVE 1 CH 1 SV 1 SV 1 SV 1 CH 1 CH SE C SE C SE C SE C SE C SE C SE C SE C EO EC LD EO EC LD EO EC LD-RO-RO-2Y-RO-RO-2Y-RO-RO-2Y T2005(GEN)

T2201 T2201 T2005(GEN)

T2200 T2200 T2005(GEN)

T2201 T2201 295.0 295.0 RT -10Y T2100 (GEN)RT -10Y T2100 (GEN)RT -10Y T2100 (GEN)RO-27 RO-27 RO-27 RO-27 RO-27 RO-27 295.0 0.167 0.167 180.0 180.0 150.0 40.0 BUBBLES 3 G-2 3 G-2 AC ACTIVE AC ACTIVE EO EC LD ED EC LD-RO-RO-2Y-RO-RO-2Y T2004 T2004 T2004 T2004 T2004 T2004 188.7 RO-19 RO-19 RO-19 RO-19 188.7 3.4-119 Rev. 13 SYSTEM: NITROGEN (P86)CLASS AND VALVE/ DWG.DEVICE NO. COOR.VALVE CATEGORY/ACTIVE OR PASSIVE A ACTIVE SIZE (in.)AND TYPE 2 GL ACTUATOR TYPE/NORMAL POSITION 1P86-F002 2 F-7 MO C TEST REQ.AND FREQ.EC -Q STC-Q LJ -PB PI -2Y EO -RO EC -CVCM LJ -PB SURV INST.NO.SVI-P86 T2001 T2001 T9117 T2001 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-950 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS 14.0*1,000.0 VR-3 VR-3 RO-26 RO-26 VR-Pending 43284 IP86-F528 2 AC F-6 ACTIVE 2 CH SE C T2005 (GEN)T9117 T9117 1,000.0 3.4-120 Rev. 13 SYSTEM: POST ACCIDENT SAMPLING (P87)DWG. NO. D-302-431 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1P87-F001 2 B C-12 ACTIVE 2 B D-12 ACTIVE 3/8 so GL C 1P87-F007 3/8 GL SO C 1P87-F025 1P87-F028 2 B F-12 ACTIVE 2 B G-12 ACTIVE 3/8 GL 3/8 GL SO C SO C TEST REQ.AND FREQ.EO -Q STO-Q FS -Q PI -2Y EO -Q STO-Q FS -Q PI -2Y EO -Q STO-Q FS -Q PI -2Y EO -Q STO-Q FS -Q PI -2Y EO -Q EC -Q STO-Q STC-Q FS -Q LW -PB PI -2Y T2001 T2001 T2001 T2002 T2001 T2001 T2001 T2002 T2001 T2001 T2001 T2002 T2001 T2001 T2001 T2002 SURV INST.NO.SVI-P87 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 2.0*2.0*2.0*2.0*1P87-F037 2 A H-II ACTIVE 3/4 GL SO C T2001 T2001 T2001 T2001 T2001 T8401 T8401/T2004 (GEm)CONTAINMENT INSTRUMENT LINE 2.0*2.0*0.5 3.4-121 Rev. 13 SYSTEM: POST ACCIDENT SAMPLING (P87)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE VALVE/DEVICE NO.1P87-F046 SIZE (in.)AND TYPE 3/4 GL ACTUATOR TYPE/NORMAL POSITION 2 A E-10 ACTIVE SO C 1P87-F049 1P87-F052 2 A D-10 ACTIVE 3/4 GL 3/4 GL SO C SO C TEST REQ.AND FREQ.EO -Q EC -Q STO-Q STC-Q FS -Q LJ -PB PI -2Y EO -Q EC -Q STO-Q STC-Q FS -Q LJ -PB PI -2Y EO -Q EC -Q STO-Q STC-Q FS -Q LJ -PB PI -2Y EO -Q EC -Q STO-Q STC-Q FS -Q LJ -PB PI -2Y SURV INST.NO.SVI-P87 T2001 T2001 T2001 T2001 T2001 T9413 T9413 2.0*2.0*1,000.0 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-431 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS 2 E-9 A ACTIVE T2001 T2001 T2001 T2001 T2001 T9413 T9413/T2002 T2001 T2001 T2001 T2001 T2001 T9413 T9413 T2001 T2001 T2001 T2001 T2001 T9413 T9413/T2002 2.0*2.0*1,000.0 2.0*2.0*1,000.0 1P87-F055 2 A D-9 ACTIVE 3/4 so GL C 2.0*2.0*1,000.0 3.4-122 Rev. 13 SYSTEM: POST ACCIDENT SAMPLING (P87)DWG. NO. D-302-431 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1P87-F065 2 C-5 A ACTIVE 1/2 GL SO C 1P87-F071 2 B-8 A ACTIVE 1/2 GL SO C TEST REQ.AND FREQ.EO -Q EC -Q STO-Q STC-Q FS -Q LJ -PB PI -2Y EO -Q EC -Q STO-Q STC-Q FS -Q LJ -PB PI -2Y EO -Q EC -Q STO-Q STC-Q FS -Q LJ -PB PI -2Y SURV INST.NO.SVI-P87 T2001 T2001 T2001 T2001 T2001 T9318 (M51)T9318 (M51)/T2007B (M51)T2001 T2001 T2001 T2001 T2001 T9318 (M51)T9318 (M51)/T2007B (M51)T2001 T2001 T2001 T2001 T2001 T9318 (M51)T9318 (M51)/T2007B (M51)CONTAINMENT INSTRUMENT LINE 2.0*2.0*1,000.0 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS CONTAINMENT INSTRUMENT LINE 2.0*2.0*1,000.0 1P87-F074 2 B-8 A ACTIVE 1/2 GL SO C CONTAINMENT INSTRUMENT LINE 2.0*2.0*1,000.0 3.4-123 Rev. 13 SYSTEM: POST ACCIDENT SAMPLING (P87)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1P87-F077 2 A A-8 ACTIVE 1/2 so GL C TEST REQ.AND FREQ.EO -Q EC -Q STO-Q STC-Q FS -Q LJ -PB PI -2Y SURV INST.NO.SVI-P87 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-431 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS T2001 T2001 T2001 T2001 T2001 T9318 (M51)T9318 (M51)/T2007B (M51)CONTAINMENT INSTRUMENT LINE 2.0*2.0*1,000.0 1P87-F083 1P87-F264 2 A H-8 ACTIVE 1/2 so EO -Q GL C EC -Q STO-Q STC-Q FS -Q LJ -PB PI -2Y T2001 T2001 T2001 T2001 T2001 T9429 T9429 T2004 T2001 T2001 T2001 T2001 T2001 T9429 T9429 T2004 2.0*2.0*(E12)(E12)/(GEN)1,000.0 2 H-8 A ACTIVE 1/2 GL SO EO -Q C EC -Q STO-Q STC-Q FS -Q LJ -PB PI -2Y 2.0*2.0*(E12)(E12)/(GEm)1,000.0 IP87-F277 2 AC n-P ACTIVE 1/4 SE RE C RT-10Y TO -PB T2100 (GEN)T94 13 1650 +/-40 1,000.0 3.4-124 Rev. 13 SYSTEM: STANDBY DIESEL GENERATOR STARTING AIR (R44)DWG. NO. D-302-351 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.IR44-FO10A IR44-FO11A 1R44-F010B IR44-F011B 3 B G-12 ACTIVE 3 B G-12 ACTIVE 3 B D-12 ACTIVE 3 B D-12 ACTIVE 3 B G-11 ACTIVE 3 B G-11 ACTIVE 3 B D-11 ACTIVE 3 B D-11 ACTIVE 3 GT 1/4 so GL C 1/4 so GL C AO C 3 GT AO C TEST REQ.AND FREQ.EO -M STO-M FS -M EO -M STO-M FS -M EO -M STO-M FS -M EO -M STO-M FS -M EO -M STO-M FS -M EO -M STO-M FS -M EO -M STO-M FS -M EO -M STO-M FS -M SURV INST.NO.SVI-R44 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS T2001 T2001 T2001 T2001 T2001 T2001 T2002 T2002 T2002 T2002 T2002 T2002 T2001 T2001 T2001 T2001 T2001 T2001 T2002 T2002 T2002 T2002 T2002 T2002 Skid-Mounted N/A Note 13 Skid-Mounted N/A Note 13 Skid-Mounted N/A Note 13 Skid-Mounted N/A Note 13 Skid-Mounted N/A Note 13 Skid-Mounted N/A Note 13 Skid-Mounted N/A Note 13 Skid-Mounted N/A Note 13 IR44-F015A 1/4 so GL C IR44-F016A 3 GT AD C 1R44-F015B 1/4 so GL C 1R44-F01 6R 3 GT AO C 3.4-125 Rev. 13 SYSTEM: STANDBY DIESEL GENERATOR STARTING AIR (R44)DWG. NO. D-302-351 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.1R44-F020A 1R44-FO21A 1R44-F020B 1R44-F021B 1R44-F025A 1R44-FO26A IR44-F025B 3 B G-12 ACTIVE 3 B G-12 ACTIVE 3 B D-12 ACTIVE 3 B D-12 ACTIVE 3 B G-12 ACTIVE 3 B G-12 ACTIVE 3 B D-12 ACTIVE 3 B D-12 ACTIVE 1/4 GL 3 GT 1/4 GL 3 GT SO C AO C SO C AO C TEST REQ.AND FREQ.EO -M STO-M FS -M EO -M STO-M FS -M EO -M STO-M FS -M EO -M STO-M FS -M EO -M STO-M FS -M EO -M STO-M FS -M EO -M STO-M FS -M SURV INST.NO.SVI-R44 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)T2001 T2001 T2001 T2001 T2001 T2001 T2002 T2002 T2002 T2002 T2002 T2002 T2001 T2001 T2001 T2001 T2001 T2001 T2002 T2002 T2002 T2002 T2002 T2002 N/A DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS N/A N/A Skid-Mounted Note 13 Skid-Mounted Note 13 Skid-Mounted Note 13 Skid-Mounted Note 13 Skid-Mounted Note 13 Skid-Mounted Note 13 Skid-Mounted Note 13 N/A 1/4 so GL C N/A 3 GT AO C N/A 1/4 so GL C N/A 1R44-FO26B 3 GT AO EO -M C STO-M FS -M Skid-Mounted N/A Note 13 3.4-126 Rev. 13 SYSTEM: STANDBY DIESEL GENERATOR STARTING AIR (R44)CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION VALVE/DEVICE NO.TEST REQ.AND FREQ.EO -M EC -Q EO -M EC -Q SURV INST.NO.SVI-R44 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

DWG. NO. D-302-351 JUSTIFI-CATIONS &RELIEF REQUEST NO. REMARKS IR44-F503A 3 C E-6 ACTIVE 1 1/2 SE CH C 1 1/2 SE CH C IR44-F503B 1R44-F504A IR44-F504B 3 C C-6 ACTIVE 3 C E-9 ACTIVE 3 C C-9 ACTIVE T1317 (R43)T2001 (R45)T1318 (R43)T2002 (R45)T1317 (R43)T2001 (R45)T1318 (R43)T2002 (R45)1 1/2 SE EO -M CH C EC -Q 1 1/2 SE CH C EO -M EC -Q IR44-F508A 3 C E-7 ACTIVE IR44-F508B 3 C C-7 ACTIVE 1 SV 1 SV 1 SV 1 SV SE RT -10Y T2100 (GEN)C SE RT -10Y T2100 (GEN)C SE RT -10Y T2100 (GEN)C SE RT -10Y T2100 (GEN)C 278.0 278.0 278.0 278.0 275.0 ADJUST FOR COLD SET 275.0 ADJUST FOR COLD SET 275.0 ADJUST FOR COLD SET 275.0 ADJUST FOR COLD SET 1R44-F518A 3 C E-10 ACTIVE IR44-F518B 3 C C-10 ACTIVE 3.4-127 Rev. 13 SYSTEM: HPCS DIESEL GENERATOR STARTING AIR (E22A)DWG. NO. D-302-358 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-E22 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE (psi)JUSTIFI-CATIONS &RELIEF REQUEST NO.VALVE/DEVICE NO.IE22-F533A IE22-F533B 1E22-F538A IE22-F538B IE22-F541A 1E22-F541B IE22-F543A REMARKS 3 C B-7 ACTIVE SV SV SE RT -10Y T2100 (GEN)C SE RT -10Y T2100 (GEN)C 250.0 250.0 3 F-7 C ACTIVE 3 C B-7 ACTIVE 3 C F-7 ACTIVE 3 B C-3 ACTIVE 3 B F-3 ACTIVE 3 B C-4 ACTIVE 1 1/2 SE CH C 1 1/2 SE CH C EO -M EC -Q EO -M EC -Q T1319 T2003 (R45)T1319 T2003 (R45)1 1/2 AO EO -M GT C STO-M FS -M 1 1/2 AO EO -M GT C STO-M FS -M T1319 T1319 T1319 T1319 T1319 T1319 T1319 T1319 T1319 T1319 T1319 T1319 N/A N/A Skid-Mounted Note 13 Skid-Mounted Note 13 Skid-Mounted Note 13 Skid-Mounted Note 13 1 1/2 so GT C EO -M STO-M FS -M N/A 1E22-F543B 3 F-4 B ACTIVE 1 1/2 So EO -M GT C STO-M FS -M N/A 3.4-128 Rev. 13 SYSTEM: STANDBY DIESEL GENERATOR FUEL OIL (R45)DWG. NO. D-302-352 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-R45 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT (sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.VALVE/DEVICE NO.IR45-F502A 1R45-F502B 1R45-F548A lR45-F548B IR45-F559A IR45-F559B lR45-F577A IR45-F577B lR45-F578A lR45-F578B REMARKS 3 C H-12 ACTIVE 3 C H-6 ACTIVE 3 C H-Ii ACTIVE 3 C H-5 ACTIVE 3 C D-11 ACTIVE 3 C D-5 ACTIVE 3 C G-10 ACTIVE 3 C G-4 ACTIVE 3 C G-10 ACTIVE 3 C G-4 ACTTVE 3 CH 3 CH 3 CH 3 CH SE EO -Q C EC -Q SE C SE C EO -Q EC -Q EO -Q EC -Q T2001 T2001 T2002 T2002 T2001 T2001 T2002 T2002 1 1/2 RE 1 1/2 RE SE EO -Q C EC -Q SE RT 10Y C SE RT 10Y C T2100 (GEN)T2100 (GEN)71.0 71.0 3/4 SE CH C EO -Q T2001 EC -CVCM T2000(GEN)

RO-33 4.0 psi BACK PRESSURE 4.0 psi BACK PRESSURE Sample Disassembly Sample Disassembly Sample Disassembly Sample Disassembly 3/4 SE EO -Q T2002 CH C EC -CVCM T2000(GEN)

RO-33 3/4 SE CH C EO -Q T2001 EC -CVCM T2000(GEN)

RO-33 3/4 SE EO -Q T2002 CH C EC -CVCM T2000(GEN)

RO-33 3.4-129 Rev. 13 SYSTEM: STANDBY DIESEL GENERATOR FUEL OIL (R45)DWG. NO. D-302-356 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE VALVE/DEVICE NO.1R45-F5IOA 1R45-F510B 1R45-F579A 1R45-F579B SIZE (in.AND TYPE 3 CH 3 CH ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.EO -Q EC -Q EO -Q EC -Q SURV INST.NO.SVI-R45 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE (psi)JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS 3 C H-6 ACTIVE 3 C H-6 ACTIVE 3 C G-5 ACTIVE 3 C G-4 ACTIVE SE C SE C T2003 T2003 T2003 T2003 3/4 SE CH C 3/4 SE CH C EO -Q T2003 EC -CVCM T2000(GEN)

EO -Q T2003 EC -CVCM T2000(GEN)

RO-33 RO-33 Sample Disassembly Sample Disassembly 3.4-130 Rev. 13 SYSTEM: STANDBY DIESEL GENERATOR JACKET WATER (R46)DWG. NO. D-302-354 VALVE/DEVICE NO.IR46-F504A 1R46-F504B 1R46-F508A IR46-F508B CLASS AND DWG.COOR.3 E-9 3 E-3 VALVE CATEGORY/ACTIVE OR PASSIVE C ACTIVE C ACTIVE SIZE (in.)AND TYPE 1 CH 1 CH 8 CH 8 CH ACTUATOR TYPE/NORMAL POSITION SE 0 SE 0 SE C SE C TEST REQ.AND FREQ.EO -M EC -M EO -M EC -M EO -M EC -M EO -M EC -M SURV INST.NO.SVI-R46 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE(psi)

JUSTIFI-CATIONS &RELIEF REQUEST NO.REMARKS T1317 (R43)T1317 (R43)T1318 (R43)T1318 (R43)T1317 (R43)T1317 (R43)T1318 (R43)T1318 (R43)3 C F-12 ACTIVE REFERENCE IEB: 83-03 REFERENCE IEB: 83-03 3 F-6 C ACTIVE 3.4-131 Rev. 13 SYSTEM: STANDBY DIESEL GENERATOR LUBE OIL (R47)DWG. NO. D-302-353 CLASS AND DWG.COOR.VALVE CATEGORY/ACTIVE OR PASSIVE SIZE (in.)AND TYPE ACTUATOR TYPE/NORMAL POSITION TEST REQ.AND FREQ.SURV INST.NO.SVI-R47 STROKE TIME REFERENCE VALUE(sec)

LEAKAGE LIMIT(sccm gpm or bubbles)DEVICE SET PRESS.REFERENCE VALUE (psi)JUSTIFI-CATIONS &RELIEF REQUEST NO.VALVE/DEVICE NO.IR47-F502A IR47-F502B IR47-F504A IR47-F504B 1R47-F506A IR47-F506B REMARKS 3 C J-ll ACTIVE 3 C J-5 ACTIVE 3 C H-10 ACTIVE 3 C H-3 ACTIVE 3 C G-12 ACTIVE 3 C G-5 ACTIVE 6 SE EO -M CH C EC -M T1317 (R43)T1317 (R43)T1318 (R43)T1318 (R43)6 CH 2 RE 2 RE SE EO -M C EC -M SE RT -10Y T2100 (GEN)C SE RT -10Y T2100 (GEN)C 44.0 44.0 70.0 70.0 6.0 psi BACK PRESSURE 6.0 psi BACK PRESSURE 1 1/2 SE RT -10Y T2100 (GEN)RE C 1 1/2 SE RT -10Y T2100 (GEN)RE C 3.4-132 Rev. 13

3.5 Valve

Test Table Notes NOTE 1: The exercising and stroke timing of the 1B21-F005 with SVI-B21-T2004 is for reasons other than satisfying Technical Specification requirements (ASME Code). Reference resolution to NRC concerns on the ISTP submittal (NRC Site Meeting Summary Correspondence Dated May 29, 1991 Log No. PY-NRR/CEI-0559L).

NOTE 2: The scram volume vent and drain valves do not have a specific leakage limit and seat leakage is being tested for reasons other than satisfying Technical Specification requirement (ASME Code). The testing requirement for seat leakage, to address the concerns of IEN 85-72 involving failures of Scram Discharge Volume Vent and Drain Valves, is specified in PTI-Cll-P0007 and will be performed after maintenance only.NOTE 3: The inboard MSIV Accumulator check valves are tested at 68.0 to 69.0 psig.NOTE 4: The outboard MSIV Accumulator check valves are tested at 43.0 to 45.0 psig with an acceptance criteria of 1873.4 SCCM, however DES is to be notified if leakage exceeds 849.4 SCCM.NOTE 5: Valves IM16-F010A, 1M16-F010B, IM17-F015, 1M17-F025, 1M17-F035 and 1M17-F045 may have their closed stroke times rounded down as not to exceed the maximum closing stroke times (e.g., 5.04 sec may be rounded down to 5 sec.). Their open stroke times may not be rounded.NOTE 6: Each Main Steam Line leakage is less than or equal to 100 SCF per hour as long as the total leakage rate through all four main steam lines is less than or equal to 250 SCF per hour.NOTE 7: Deleted based on implementation of DCP 02-213 and 02-213A.NOTE 8: Valves 0P45-F006A, 0P45-F006B, 0P45-FO07A, 0P45-F007B, 0P45-FO09A, and 0P45-FO09B will be tested prior to the ESW Sluice Gates being inflated on a yearly bases. They will additionally be tested quarterly when required to be in operation.

This testing includes Exercise Open, Exercise Close, and leak testing to ensure system integrity.

When the ESW Sluice Gates are not required to inflated this testing will not be performed.

This approach is an OM Code accepted method per paragraph ISTC-3570, Valves in Systems Out of Service.3.5-1 Rev. 13 NOTE 9: The 200 gpm leak rate test on Feedwater check valves F032A/B and F559A/B is based on Appendix A to Calculation 3.2.15.7"Feedwater Line Break Accident";

letter PY-CEI/NRR-2370L dated March 4, 1999; the NRC Safety Evaluation for Amendment 105 dated March 26, 1999 (PY-NRR/CEI-0964L);

an NRC Clarification Letter on Amendment 105, dated April 27, 1999 (PY-NRR/CEI-0976L);

the Exception to Regulatory Guide 1.163"Performance Based Containment Leak-Test Program" provided for the Feedwater check valves (see USAR Table 1.8-1 and Technical Specification 5.5.12); and Calculation N27-054 "Feedwater Check Valve Leak Test Acceptance Criteria".

If the check valves do not pass the water leak test acceptance criteria curve within Calculation N27-054 which was developed to meet the intent of OM Code, paragraph ISTC-3630(b)

(4), then a visual examination using a fiberscope is performed to verify significant orifice seat defect(s) do not exist. This inspection includes lifting the check valve disc up off of its seat. Significant observed defects or any leak rate test results equivalent to more than 200 gpm at 1.1 Pa require additional investigation/repair and retest per ISTP program requirements.

NOTE 10: Based on issuance of GE SIL No. 643 and NRC Information Notice 2002-15, Perry initiated Condition Report CR 02-00995.

Based on all the evaluation performed to eliminate the potential for Hydrogen detonation of the Reactor Core Isolation Cooling Injection/Residual Heat Removal Head Spray piping, Calculation E51-031 was initiated.

This calculation has determined that allowable leakage for 1E12-F023 and 1E51-F013 when tested in parallel is 0.036 gpm.NOTE 11: The manual swale isolation valves are to be full exercised each quarter in accordance with Condition Report 06-00428.Currently this is accomplished via Repetitive Maintenance Plan Number 89362 and completion of a Test Requirements Applicability form (NOP-WM-2003-03) to document Technical Specification compliance.

NOTE 12: The solenoid valves are proven operable by remotely actuating the SRV to verify open and close capability of the relief valve prior to resumption of electric power generation.

The solenoid operated valves will be tested at the Technical Specification Surveillance required frequency of testing. ISTC-1200, the valves associated with the control circuitry of ADS/SRVs are considered skid-mounted.

3.5-2 Rev. 13 NOTE 13: At least one set of diesel starting air valves shall be verified operable during monthly Division 1 and Division 2 diesel generator surveillance testing with both sets of diesel starting air solenoids being tested quarterly per a separate surveillance instruction.

Satisfactory diesel start times shall demonstrate operability of the starting air valves.The operability of Division 3 HPCS starting air valves shall be determined by monitoring HPCS diesel starting time.NOTE 14: These valves (1C11-114 typical of 177) are classified as skid-mounted and verified to function through testing of each respective hydraulic control unit, of which the valve is a subcomponent.

The HCUs are verified functional per satisfaction of Technical Specification Surveillance Requirements SR 3.1.3.4, 3.1.4.1, 3.1.4.2, 3.1.4.3, 3.1.4.4 and 3.1.5.1.Identifies valves that may have their stroke times rounded to the nearest tenth of a second, even if the obtained stroke time exceeds the surveillance stroke time (e.g., 1D23-FO10A strokes in 2.04 seconds, 2.0 seconds may be recorded).

3.5-3 Rev. 13 Enclosure B to Letter L-11-082 Perry Nuclear Power Plant Snubber Program (40 pages follow)

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 15 [ 1 of 40 SNUBBER AUGMENTED VISUAL INSERVICE INSPECTION/EXAMINATION AND FUNCTIONAL TESTING PROGRAM Plant Administrative Procedure Effective Date: 11-8-10 Preparer: Approver: Gerry Freddo / 9-1-10 Date Scott Seman / 10-29-10 Date PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 15__2 of 40 TABLE OF CONTENTS Paqe 1.0 PURPOSE 3 2.0 SCOPE 3 3.0 DEFINITIONS 3 4.0 PROCEDURE DETAILS 6 4.1 Responsibilities 6 4.2 Compliance Requirements for ORM Applicable Snubbers 9 4.3 Functional Testing Requirements for ORM Applicable Snubbers 12 4.4 Visual Inspection/Examination Requirements for ORM Applicable Snubbers 17 4.5 Scheduling for ORM Applicable Snubbers 22 4.6 Administration for ORM Applicable Snubbers 24 5.0 RECORDS 27

6.0 REFERENCES

28 7.0 SCOPE OF REVISION 30 ATTACHMENTS Attachment 1 -Alternate Qualification Record 31 Attachment 2 -OM Code Table 4252-1 33 Attachment 3 -Requirements for Non-Safety/Non-Seismic Snubbers 34 Attachment 4 -Failure Mode Groups (FMGs) & Additional Testing 39 PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page:______________________________15 3 of 40 1.0 PURPOSE To establish administrative requirements for performance, scheduling, evaluation and follow-up action (e.g., corrective) of the snubber preservice and inservice inspection/examination, testing and service life monitoring surveillances.

2.0 SCOPE

This procedure applies to all safety-related and/or Seismic Category I snubbers on systems affecting safe operation or shutdown of the reactor, or to ensure the integrity of the reactor coolant pressure boundary.

The visual inspection/examination of safety-related and/or Seismic Category I snubbers shall be in compliance with Operational Requirements Manual (ORM) TR 6.4.1.1.a, b, c, and d and ASME OM Code (2001 Edition with Addenda through 2003). The functional testing of safety-related and/or Seismic Category I snubbers shall be in compliance with ORM TR 6.4.1.1.e, f, g and h and ASME OM Code (2001 Edition with Addenda through 2003). The service life monitoring of snubbers shall be in compliance with ORM TR 6.4.1.1 .i and OM Code, ISTD-6000 and procedure SVI-L51-T201 1.The visual inspection/examination and functional testing of non-safety/non-seismic snubbers shall be to the parameters as stated within this procedure.

Reference Attachment 3 for a list of those snubbers.3.0 DEFINITIONS NOTE The definitions of ISTA-2000 and ISTD-2000 shall apply, as applicable, in addition to the definitions below.3.1 Accessible Snubbers -Those snubbers that can be inspected/examined during normal plant operating conditions.

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

1Page:____________________________15 4 of 40 3.2 Activation Acceleration (Mechanical)

-Snubber distinct acceleration which is usually characterized by an abrupt increase in resistive force or reduction in velocity.3.3 Activation Velocity (Hydraulic)

-Snubber distinct velocity which is usually characterized by an abrupt increase in resistive force or reduction in velocity.3.4 Authorized Nuclear Inservice Inspector (ANII) -An individual holding a commission from the National Board of Boiler and Pressure Vessel Inspectors, qualified in accordance with ANSI/ASME-626.1-1975.

This individual is responsible for certifying results of activities carried out under the requirements of the ASME Boiler and Pressure Vessel Code,Section XI.3.5 As Found -The condition of a snubber as it exists in the system prior to any preventive maintenance, corrective maintenance, or disassembly to perform testing.3.6 Augmented Inservice Inspection Program -An inspection/examination program which meets additional requirements beyond those of the ASME OM Code, ISTD. Augmented requirements may be established by the Regulatory Authority or other agencies and do not require complete compliance with the ASME OM Code, ISTD.3.7 Bleed Rate (Hydraulic)

-See definition of release rate.3.8 Breakaway Force (Mechanical)

-The minimum applied force required to initiate extension or retraction of the snubber.3.9 Component

-Denotes an item in a Nuclear Power Plant such as a vessel, pump, valve, support, snubber, or piping system.3.10 Design Test Plan Group (DTPG) -A population of snubbers selected for testing in accordance with the 10% or 37 testing sample plan.3.11 Drag Force (Mechanical)

-The force required to maintain the snubber movement at a constant velocity prior to actuation.

3.12 Equipment Dynamic Restraint

-See definition of snubber.

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

TPage: 15 F f4 3.13 Inspection

-For the purposes of this program, Inspection denotes the performance of a visual observation in which the inspector shall be qualified by the owner or his agent in accordance with the comparable levels of competency as defined in ANSI N45.2.6-1978.

NOTE When the visual observation is also being performed in accordance with ASME Section XI, Article IWF-2000 the term examination is used in place of inspection. (See 3.26)3.14 Failure Mode Group (FMG) -A group of snubbers that have failed and those other snubbers that have similar potential for similar failure.3.15 Functional Adequacy -A visual examination to confirm operability by the verification of the settings or freedom of motion.3.16 Functional Testing -An in-place or bench test exercise of a snubber while measuring and-observing all the required parameters.

3.17 Hydraulic Snubber -A device which provides restraint to a component or system during a sudden application of force in which load is transmitted through a hydraulic fluid. The device shall allow essentially free motion during thermal movement.3.18 Inaccessible Snubbers -Snubbers within a high radiation area or under conditions that would render it impractical for examinations during reactor operation without endangering personnel.

3.19 Maintenance

-Actions taken to prevent or correct deficiencies in the functional operation of a snubber.3.20 Mechanical Snubber -A device which provides restraint to a component or system during a sudden application of force in which load is transmitted entirely through mechanical parts/items.

The device shall allow essentially free motion during thermal movement.3.21 Release Rate (Hydraulic)

-The velocity of snubber movement under a load and/or after activation takes place.

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page:_____________________________15 6 of 40 3.22 Replacement Snubber -Snubbers that have a proven suitability for the application and environment which replace existing snubbers.3.23 Service Life -The period of time from installation/acceptance that the snubber or individual snubber parts are expected to meet the operational readiness requirements without maintenance.

3.24 Structural InteQrity

-The capability of a given component or structure to perform the design function (e.g., pressure retaining boundary, support of structural weight, restriction of movement, etc.). Structural integrity is not related to operability of components being tested (e.g., pumps, valves, or snubbers).

3.25 Transient Event -An unexpected or potentially damaging occurrence which was determined from review of operating data or during a visual inspection/examination.

3.26 Visual Examination

-Observing, monitoring, or measuring to determine conformance to Owner-specified requirements.

1. VT-3 Visual Examination Method -Examination to determine the general mechanical and structural conditions of components and their supports.4.0 PROCEDURE DETAILS 4.1 Responsibilities 4.1.1 Director, Site Engqineering, has overall responsibility for: 1. Implementation of the Perry Plant Unit 1 Snubber Testing Program.2. Evaluating the snubber program's effectiveness.

4.1.2 Manager, Technical Services Engineering, has responsibility for: 1. Identifying the required safety-related snubber and/or Seismic Category I testing and inspections/examinations.

Identifying the required non-safety/non-seismic snubber testing and inspections/examinations.

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 15r 7 of 40 2. Verifying procedures and instructions are revised to comply with Operational Requirements Manual (ORM), ASME OM Code, Regulatory Guides, 10CFR50.55a(g), and other industry practices.

4.1.3 Supervisor, Nuclear Engineering Programs, has responsibility for: 1. Approving the snubber testing and inspection/examination sample method employed and transmitting the functional testing sampling method to Licensing and Compliance Section for submittal to the NRC.2. Maintaining a status of the current snubber testing sample and snubber inspection/examination frequency.

3. Implementing preparation and approval of instructions for testing and inspection/examination for compliance to Operational Requirements Manual and ASME OM Code, ISTD Inservice Test Requirements.

4. Providing Environmental Qualification (EQ) Program resources in support of snubber Service Life determinations.

4.1.4 Site Engineering Program Owner (SEPO)-Snubbers, has responsibility for: 1. Identifying snubbers subject to surveillance and instructions for performance of the required testing and inspections/examinations.

Coordinating all snubber activities with the Surveillance Coordinator, Work Control Section, Perry Maintenance.

2. Changing the inspection/examination frequency requirements upon identification of an unacceptable (i.e., inoperable) condition and the testing sample upon exceeding testing acceptance criteria.3. Entering testing, inspection/examination, repair, and replacement data into the applicable plant computer system (e.g. SnubbWorks).

4. Implementing performance of snubber inspection/examination and functional testing.5. Reviewing industry Operating Experience (OE) for applicability to PNPP snubber population and the PNPP snubber program.

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 15 8 of 40 6. Evaluating all captured Snubber program data (i.e. testing, inspection/examination, repair and replacement data) for trending.Snubber SEPO shall report those evaluation results per the communication requirements specified in NOBP-CC-1006, FENOC Conduct of Engineering and make changes to the Snubber Program commensurate with identified trends (e.g. increased examination frequency, adjustments to Service Life Monitoring program, etc.).7. Maintaining the Snubber Program configuration management including the recognition and communication of controlled program information to other site organizations.

Communication shall be per NOBP-CC-1006, FENOC Conduct of Engineering.

4.1.5 Director, Site Maintenance, has responsibility for: 1. Implementing performance of snubber removal, repair, internal parts examination, replacement, and installation.

4.1.6 Manager, Design Engineering Section, has the responsibility for: 1. Determining snubber functional testing acceptance criteria.2. Dispositioning Condition Reports pertaining to snubber visual examination or functional testing failures.3. Conducting root cause failure analysis.4. Maintaining the list of snubbers required for containment integrity (reference Eng. CaIc. EA-1 13).5. Defining the scope of all safety related and/or Seismic Category I snubber MPL's and all non-safety/non-seismic snubber MPL's.6. Establishing acceptance guidelines for snubber inspection/

examination and direct efforts to evaluate, repair or replace snubber/snubber parts declared inoperable.

7. Transmitting revised snubber settings (design cold set tolerances and snubber movements) to Snubber SEPO in accordance with Engineering Design Guide (EDG)97-015.

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1 115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

1 Page:____________________________15 9 of 40 4.1.7 Manager, Site Work Management:

1. Has the responsibility for scheduling the identified snubber tests and inspections/examinations.

4.2 Compliance

Requirements for ORM Applicable Snubbers 4.2.1 Snubbers The snubbers included in this section of the program were selected in accordance with their safety significance.

Factors considered in snubber categorizations were accessibility, manufacturer, design characteristics, operating environment, design application, and size. Factors considered when establishing snubber types were manufacturer and design characteristics (i.e., hydraulic or mechanical).

4.2.2 Procedure

This procedure and all supporting instructions have been written to comply with specific requirements of the ASME OM Code, Subsection ISTD for functional testing and visual inspection/examination.

1. Functional Testing Requirements:

Testing implements the requirements of ORM TR 6.4..1 I.e, f, g and h and ISTD-5000.

a. Sampling and additional testing criteria shall be in accordance with ORM TR 6.4.1.1 .e functional tests, ISTD-5260, ISTD-5270 and ISTD-5280.

2. Visual Inspection/Examination Requirements:

Visual inspection/examination implements the requirements of ORM TR 6.4.1.1.a, b, c, d and h. and ISTD-4000.

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 15 10 of 40 3. Service Life Monitoring Requirements:

Service Life Monitoring instruction SVI-L51-T2011 implements the requirements of ORM TR 6.4.1.1.i and ISTD-6000.

a. Service Life Monitoring is initially established by the Environmental Qualification Program requirements and shall be extended or shortened based on monitoring test results and failure history.b. Snubber service life is based upon manufacturer recommendations and evaluated performance.

c. Each refuel cycle, the Snubber SEPO will evaluate the performance of the snubber population and based upon the results of that evaluation, may assign certain snubbers to be tested for service life monitoring purposes.

The results of such testing do not require testing of additional snubbers;however, the results of such testing will be evaluated.

NOTE PNPP has established an extended range of operability for snubbers.

When snubber test results fall within this extended range, they are categorized as degraded and replaced with pretested spare snubbers from inventory.

Performance of all snubbers included in this program is evaluated by the Snubber SEPO each refuel cycle. This ensures that snubbers that begin to show degradation prior to the established service life will be replaced and the service life for that location will be evaluated.

4. Personnel Qualification Requirements:

a. Personnel performing visual examinations shall be qualified/certified as either a VT Level II (unlimited) or a VT Level Il-Limited to VT-3 in accordance with NOP-CC-5708.

Prior to performing examination activities in support of PNPP, vendor personnel qualifications/

certifications shall be processed in accordance with NOP-CC-5709.

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1 115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 15 11 of 40 b. As an alternative to the above, personnel who perform non-ASME Section Xl visual inspections of snubbers only (i.e., ORM required visual inspection only), may be qualified as a Snubber Inspector in accordance with the requirements listed in Attachment 1.c. Snubber Functional Testing, Rebuild/Overhaul and Failure Analysis:

Vendors providing these services at PNPP must submit personnel certification records to the Snubber SEPO for review and approval at least 45 days prior to scheduled work start. Certification records shall include: Name of certified individual, Level of certification and test method, Educational background and experience, Statements indicating satisfactory completion of training, Results of the physical examinations and eye tests, Evidence of successful completion of examinations (i.e. qualification records with examination results), signed by a Level III Examiner, Other suitable evidence of satisfactory qualifications, when such qualifications are used in lieu of examinations, Dates of certification and/or recertification, Signature of employers designated representative (e.g. Level III Examiner) and Individual's resume.For any work performed by vendor outside of PNPP program procedure scope, vendor shall have in place, and available for review by the Snubber SEPO, a Quality Assurance program which meets 10CFR50, Appendix B, of the ASME Code, and applicable industry standards/regulatory guides/codes for personnel certifications associated with intended work scope.d. Snubber SEPO, Primary and Backup Qualification shall be as specified in NOP-SS-2101, Engineering Program Management.

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 1 15 12 of 40 e. Personnel performing snubber rebuild, overhaul and failure analysis activities shall have successfully completed formal training related to the activity to be performed for the specific snubber model/type being rebuilt, overhauled or analyzed.In addition, personnel shall have a documented history of performing said activities with an amount of experience commensurate with the complexity of the activity to be performed.

Documentation related to both training and experience shall be made available to the Snubber SEPO for review prior to commencement of any related activities.

5. Storage Requirements:

Replacement seal kits for hydraulic snubbers are to be stored in level "B" storage facility per ANSI N45.2.2. Assembled hydraulic snubbers are to be stored per NOBP-CC-7006, Storage Maintenance Requirements, SMR-009 (E-Systems Snubbers) and SMR-012 (Hydraulic-Lisega-Snubbers).

4.3 Functional

Testing Requirements for ORM Applicable Snubbers 4.3.1 Test requirements shall be measured and parameters observed to verify operability of either hydraulic or mechanical snubbers.

Test methods of ISTD-5200 shall be used. The acceptance criteria for each parameter shall be established by DES in accordance with ISS-2600.

Guidelines noted in OM Code, ISTD Non Mandatory Appendix H are considered.

4.3.2 Parameters

Measured or Observed for Mechanical Snubbers 1. Breakaway/Running Drag Force -compliance to ORM TR 6.4.1.1.f.3.

2. Activation Acceleration

-compliance to ORM TR 6.4.1.1.f.1.

4.3.3 Parameters

Measured or Observed for Hydraulic Snubbers 1. Activation Velocity -compliance to ORM TR 6.4.1.1 .f. 1.2. Bleed/Release Rate -compliance to ORM TR 6.4.1.1.f.2.

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: I1 15 1 13 of 40 4.3.4 Evaluation Snubber test data that exceeds the acceptable level acceptance criteria established in the Surveillance Instruction shall require an Engineering evaluation by submitting a Condition Report (CR). [Exception:

PSA mechanical snubbers whose Drag Values are found in the expanded (degraded) range do not require a condition report. Reference ISS-2600 (SEN 515) and Engineering Calculation EA-0101.]NOTE Pre-service and inservice testing is intended to verify operational readiness.

When testing is conducted at ambient temperature, as was the original factory test, no correction factors are required.Design Engineering shall evaluate/disposition the deviation with three possible disposition conditions as follows: 1. ACCEPTABLE

-reinstall existing snubber.2. DEGRADED -replace existing snubber with a new or rebuilt snubber, no additional testing sample is required.3. FUNCTIONAL FAILURE -replace existing snubber with a new or rebuilt snubber -additional testing sample is required per ORM TR 6.4.1.1.e

-additional evaluation will be required per ORM TR 6.4.1.1.g.

The results of this evaluation shall be used, if applicable, in selecting snubbers to be tested in an effort to determine the operability of other snubbers irrespective of type which may be subject to the same failure mode.4. Evaluations shall contain as a minimum;a. General Description

1) System and component affected 2)Location PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 15 14 of 40 b. Nature of Problem 1) How the problem was found 2) Description of problem 3) Probable cause(s) of the existing condition (e.g., manufacturer or design deficiency)

c. Safety Concern 1) Consequences on the component and/or system.NOTE The purpose of this evaluation shall be to determine if the attached component was adversely affected by the problem.d. Service Life 1) Snubber or individual snubber part repetitive failures.(INTENTIONALLY BLANK)

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1 115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 15 15 of 40 NOTE Repetitive failures or evidence of degradation require the evaluation to determine if the snubber or individual snubber parts service life should be revised. Snubber SEPO shall also consider the need for testing for SLM purposes as a result of this evaluation.

4.3.5 Disposition

Functional test failures or degraded snubbers shall be repaired or replaced with the repaired or replaced snubbers being retested prior to installation.

If the snubber performs below the functional capability or performance level, a Limiting Condition for Operation exists and the applicability/action statements within ORM 6.4.1 must be followed.1. Retest Requirements:

a. Snubbers placed in the location of a failed snubber shall be tested during the next functional test (i.e., next refueling).

1) The snubber shall not be included in the sample plan.2) The snubber's failure shall not be the sole cause for increasing the sample size for the sample plan.3) Snubbers having been repaired shall be tested before installation if the repair could affect the functional test results.4) Replacement snubbers shall be tested before installation.

a) Mechanical snubbers shall have met the acceptance criteria subsequent to their most recent service and the freedom-of-motion test must have been performed within 12 months before being installed.

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1 115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 15 J 16 of 40 2. Additional Testing Requirements:

Upon snubber testing failure, additional testing shall be established in accordance with the sample plan used (i.e., sample plan provided to the NRC).a. 10% Plan -At least 10% of the total of each Design Test Plan Group to be tested.1) Each failure requires an additional 5% from the same Design Test Plan Group or Failure Mode Group to be tested until no further failures occur or all snubbers of that Design Test Plan Group or Failure Mode Group have been functionally tested and the requirements of ISTD-5330 and 5331 are met.b. 37 Plan -A random sample of 37 snubbers from each Design Test Plan Group to be tested in accordance with Figure ISTD-5431-1.

1) For each snubber type that fails, another sample of at least one half the size of the initial sample shall be tested per ISTD-5400 requirements.

When sample plan test results fall on or below the "Accept" line, testing of that type of snubber may be terminated.

a) Accept line follows evaluation N = 36.49 +18.18C where N = number of snubbers of that type tested and C = number of failed snubbers.2) Terminate testing if all the snubbers of that type have been tested.If any snubber selected for functional testing either fails to lock up or fails to move; i.e., frozen-in-place; the root cause will be evaluated by Engineering and, if caused by manufacturer or design deficiency, all snubbers of the same type subject to the same defect shall be functionally tested. This testing requirement shall be independent of the requirements stated in ORM TR 6.4.1.1 .e for snubbers not meeting the functional test acceptance criteria.

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 15 17 of 40 4.4 Visual Inspection/Examination Requirements for ORM Applicable Snubbers 4.4.1 Acceptance Standards NOTES The snubber settings contained in the SnubbWorks database are specified in decimal form, consistent with design calculation data format and as-received by the Snubber SEPO from DES (ref. EDG-97-015), while design drawings may provide the same data in fractions of an inch.Either the design calculation data (decimal) or the design drawing data (fractions) can be used when performing snubber inspections/

examinations and the existence of both does not constitute an unevaluated condition (ref. CR 06-7968).* The Snubber Visual/VT-3 Examination form (PNPP No. 6985) is a dual purpose form that can be used for snubber surveillance program visual inspections, VT-3 examinations, or both. The Acceptance Standards provided here are specific to the snubber surveillance program requirements as detailed in surveillance instruction SVI-L51-T2000.

The Acceptance Standards for snubber VT-3 Visual Examinations performed per ASME Boiler and Pressure Vessel Code Section XI requirements and/or as dictated by the Inservice Examination Plan (ISEP), include larger "examination boundaries" and are governed by the ISEP and NOP-CC-5708.

• Examination boundary for the snubber surveillance program shall include the snubber assembly from pin to pin inclusive.

Acceptance criteria, established by Design Engineering to meet the requirements of ORM TR 6.4.1.1.c, includes verification that indications recorded during the visual inspection/examination (hydraulic fluid level, hot/cold setting, etc.) are categorized as inoperable (unsat./rejectable), operable relevant (sat./acceptable), or operable nonrelevant (sat./acceptable).

Categorization details are as follows: 1. Inoperable (rejectable) conditions.

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 15 18 of 40 NOTE An inoperable indication may require entering into a Limiting Condition of Operation (LCO) and shall require a disposition.

a. Hydraulic Fluid Level: 1) E-System (all sizes) indicator rod at empty or below.2) Lisega (all sizes) leading edge or any part of the gold color brass alloy of the reservoir piston appears in the sight glass.b. Hot/Cold Setting -recorded hot or cold setting indicates the snubber to be topped or bottomed out and/or the calculated thermal growth would cause snubber to top or bottom out.c. Indications

-missing, detached, or loosened snubber or snubber attachment devices (within the augmented examination boundary).

Arc strikes, weld spatter, roughness, general corrosion, paint, or scoring on close tolerance machined or sliding surfaces.

Deformed or structurally degraded snubber or snubber attachment devices.2. Operable relevant (acceptable) conditions.

NOTE An operable relevant indication shall require a disposition.

a. Hydraulic Fluid Level: 1) E-System (all sizes) indicator rod at less than seventy percent (70%) and greater than zero percent (0%) of full or reservoir capacity.2) Lisega (all sizes) not applicable.

b. Hot/Cold Setting -Not applicable.

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 15 19 of 40 c. Indications

-detached, loosened, or missing locking devices.Damaged or bound spherical bearings.

Thread engagement less than flush. Incorrect or missing identification tags. Tape (or tape residue) on the PSA Mechanical Snubber between the inner and outer tube for PSA 1/4, 1/2, or on the Support Cylinder for all other sizes.d. Excessive gap -between the snubber paddle (spherical bearing) and the pipe attachment or structural attachment greater than one washer thickness that could not be temporarily corrected by use of clips (ISS-2600).

3. Operable nonrelevant (acceptable).

NOTE An operable nonrelevant indication requires no disposition.

a. Hydraulic Fluid Level: 1) E-Systems (all sizes) -Not applicable.

2) Lisega (all sizes) is the appearance of the silver color of the stainless steel cylinder tube completely across the sight glass.b. Hot/Cold Setting -Not applicable.

c. Indications

-weld spatter, scratches, or surface abrasion marks on other than close tolerance machined or sliding surfaces.

Fabrication marks. Roughness or general corrosion showing no visible evidence of snubber or snubber attachment device weakening.

Chipped or discolored paint resulting from other than actual snubber degradation.

Tape (or tape residue) on the snubber which does not interfere with the intended snubber operation.

d. Existing gap -between the snubber paddle (spherical bearing)and the pipe attachment or structural attachment of one washer thickness or less that were temporarily corrected by use of clips (ISS-2600).

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1 115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 15 20 of 40 4.4.2 Evaluation Snubber inspection/examination indications which exceed the acceptance criteria established in the Surveillance Instruction shall require an Engineering evaluation by submitting a Condition Report (CR) to Design Engineering.

When performing evaluations on inspection/examination indications, the following items shall be addressed:

1. General

Description:

a. System and component affected b. Location 2. Nature of Problem: a. How problem was identified

b. Description of problem c. Probable cause(s) of the existing condition 3. Safety Concerns: a. Importance to plant and/or system operation b. Probability and consequence of snubber failure 4.4.3 Disposition Visual inspection/examination indications categorized as inoperable or operable relevant shall be addressed to determine a final resolution.

Final resolution may require repair, replacement, evaluation, or testing.If the snubber indicates that its performance would be below the functional capability or performance level, a Limiting Condition for Operation may exist and the action statements within ORM 6.4.1 must be followed.1. Re-inspection/Re-examination:

a. Snubber installed after repair, replacement, or testing shall be re-inspected/re-examined.

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1 115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 15 I 21 of 40 2. Additional Visual Inspection/Examination:

a. All snubbers attached to sections of systems that have experienced unexpected or potentially damaging transients shall be inspected/examined.

1) Accessible systems shall be inspected/examined within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.2) Inaccessible systems shall be inspected/examined within 6 months.3) Snubbers shall be verified to have freedom-of-motion by one of the following:

a) Manually induced b) In-place snubber piston setting c) Stroking through full range of travel 3. Functional Testing: Snubbers that fail a visual examination may be functionally tested to determine operability of the snubber. This functional test data may be used to reclassify the snubber as "Operable Non-Relevant" or"Operable Relevant." Such testing shall be in accordance with ISTD-4233 and 4240.

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 15 [ 22 of 40 4.5 Schedulinq for ORM Applicable Snubbers 4.5.1 Frequency 1 .Visual Inspection/Examination:

a. A visual inspection of all snubbers shall be performed according to the schedule determined by ISTD Table 4252-1 (Attachment 2). Snubbers are categorized as inaccessible or accessible during reactor operation.

Each of these categories inaccessible or accessible may be inspected independently.

The visual inspection for each type of snubber shall be determined based on the criteria provided in ISTD Table 4252-1 and the initial inspection interval utilizing this criteria shall be 18-months, beginning from the conclusion of the last visual inspection conducted during RFO4.b. Surveillance and general maintenance instructions shall implement an (As-Found) visual inspection/examination prior to (defined as within the previous six months) and after (As-Left) performance of repairs, replacement, testing or any other evolution which involves the unpinning of at least one end of a snubber.c. Increased or decreased visual inspection frequency shall conform to ISTD Table 4252-1.d. PNPP may also implement the extended visual examination interval allowed by ASME Code Case OMN-1 3. This Code Case allows the extension of the visual examination interval beyond the maximum of 48 months allowed by ISTD Table 4252-1, provided certain prerequisites are satisfied.

This Code Case has been approved for use by the NRC in Regulatory Guide 1.192. Adjustments to the extended interval of this Code Case shall be in accordance with SVI-L51-T2000, paragraph

5.1.4. PERRY

NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 15 1 23 of 40 2. Functional Testing: a. During the first refueling outage and at least once per refueling interval thereafter.

The test interval is based upon a fuel cycle. The test interval may start sixty (60) days prior to a scheduled refueling outage and shall be completed prior to the end of the scheduled refueling outage.b. Retests and additional testing requirements shall conform to Section 4.3.5 of this procedure.

4.5.2 Sample

Plan 1. Visual Inspection/Examination:

a. Snubbers shall be visually inspected during each inspection interval as determined in ORM 6.4.1.1.2. Functional Testing: One of the following methods shall be used to select a representative sample of snubbers from each Design Test Plan Group for functional testing.NOTE Snubbers that do not meet testing requirements shall be evaluated and additional testing shall be determined in accordance with ISTD-5200.

Failure Mode Groups (FMG's) shall be established if applicable based upon failure evaluation results. FMG guidance can be found in Attachment 4.a. 10% Plan -At least 10% of the total of each snubber Design Test Plan Group and ISTD-5300.

b. 37 Plan -An initial random sample of 37 snubbers for each Design Test Plan Group in accordance with ISTD-5400.

c. Any change in the sample plan selection methodology from originally submitted to the NRC shall require formal communication with the Nuclear Regulatory Commission.

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 15 24 of 40 4.6 Administration for ORM Applicable Snubbers 4.6.1 Sample Plan Development/Routing

1. Snubber functional testing sample plan.a. The Snubber SEPO shall: 1) Generate an appropriate sample plan for each snubber type as identified in Section 4.5.2.2.2) Generate any additional (augmented) test plans, as appropriate.

3) Review and submit initial sample plans and/or additional sample selection for approval to the Supervisor, Test & Performance.

b. The Supervisor, Nuclear Engineering Programs, or designee, shall: 1) Approve the sample plans generated.

2) Forward approved sample plans to the appropriate organizations.

2. Snubber visual inspection/examination sample plan.a. The Snubber SEPO shall: 1) For each required interval population/category of snubbers generate a sample plan using a representative selection of snubbers in each category/type.

2) Forward sample plan(s) to the appropriate organizations.

3) Following the refueling outage adjust the snubber inspection/examination frequency (by failure rate, in accordance with Table ISTD 4252-1) and notify Surveillance Coordinator.

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1 115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 15 1 25 of 40 4.6.2 Computer Update 1. The Snubber SEPO shall update the plant site applicable computer software (e.g. SnubbWorks) by reviewing the surveillance data sheets listed below.a. Snubber functional testing SVI-L51 -T201 0 1) Functional Test Data Sheet(s), PNPP No. 7117 and/or PSA Snubber Validator Test Data Sheet, PNPP No. 7640, or computer equivalent forms, as applicable.

b. Snubber visual inspection/examination SVI-L51-T2000

1) Snubber Visual/VT-3 Examination, PNPP No. 6985, or computer equivalent forms, as applicable.

c. Snubber Service Life Monitoring SVI-L51-T2011

1) Snubber Service Life is implemented and scheduled by NOP-WM-3001.

4.6.3 Snubber

Location Data SVI-L51-T201 1, Snubber Service Life Monitoring, contains a listing of all snubbers included in the Perry Unit 1 Snubber Augmented Inservice Visual Inspection/Examination and Functional Testing Program.Snubber location data, shown under the table heading "Location Data" on that listing (SVI-L51-T2011 Attachments 1, 2, and 3), supports ongoing snubber service life monitoring by providing a unique set of location-specific data for each installed snubber included in the Perry Unit 1 Snubber Augmented Inservice Visual Inspection/Examination and Functional Testing Program.

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 11 15 26 of 40 NOTE Unique snubber Functional Location Numbers provide additional location-specific information, specifically; The Unit, System, and Snubber (Hanger) Number assigned for each in-plant / installed snubber location.The information provided by the 6 digit alpha-numeric Location Data field is as follows;First Digit -(H) Hydraulic (M) Mechanical (L) Lisega.Second Digit -(1) Accessible (2) Inaccessible Third Digit for PSA Mechanical Snubbers -(1) PSA 1/4 (2) PSA 1/2(3) PSA 1 (4) PSA 3 (5) PSA 10 (6) PSA 35 (7) PSA 100 Third Digit for (E-Systems)

Hydraulic Snubbers (1) 20 Kip (2) 30 Kip (3) 50 Kip (4) 70 Kip (5) 100 Kip Third Digit for Lisega Hydraulic Snubbers (1) 3018 (2) 3038 (3) 3042 (4) 3052 (5) 3062 (6) 3072 (7) 3082 (8) 3092 Fourth Digit -- (1) Inservice System (2) Functional System Fifth Digit-- Operating Temperature (1) Less than 200°F (2) 200OF and Greater Sixth Digit --Vibration Displacement (1) Less than 20 Mils (2) 20 Mils and Greater.4.6.4 Snubbers Required for Containment Integrity The listing of snubbers required for Containment Vessel Integrity can be found in PDB-B0007.

Requirements for the removal of snubbers required for Containment Integrity can be found in OAI-0201.

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 1 15 1 27 of 40 NOTES Additions or deletions of snubbers due to design changes have no impact on the context of the PDB. Snubbers listed in PDB-B0005, PDB-B0006, and PDB-B0007 will be updated to reflect those types of changes on a periodic basis.Snubbers deleted for design changes shall nevertheless be considered in their respective examination population, examination category, or Failure Mode Group (FMG) for determining the corrective action.4.6.5 Snubbers With Special Requirements Snubbers attached to the Reactor Recirculation System have special requirements for removal activities, refer to OAI-0201.4.6.6 Snubber Removal Cautions 1. CAUTION shall be exercised when removing a snubber from an Operable system when that system is required to be operable, refer to OAI-0201.5.0 RECORDS 5.1 Records Handling Records completed/generated by this document shall be handled in accordance with the established records management program.5.2 Records Capture The following records are completed/generated by this document: Quality Records Visual Inspection/Examination Sample Plans Functional Testing Sample Plans PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1 115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

age: 15 1 28 of 40 Quality Records (Cont.)Functional Test Data Sheet (PNPP No. 7117)PSA Snubber Validator Test Data Sheet (PNPP No. 7640)Snubber Visual/VT-3 Examination (PNPP No. 6985)Alternate Qualification Record Non-Quality Records None

6.0 REFERENCES

6.1 Discretionary

American National Standards Institute (ANSI)/ASME-626.1-1975 American National Standards Institute (ANSI) N45.2.6-1978 American Society for Nondestructive Testing Recommended Practice No. SNT-TC-1A, 1984 Edition Engineering Calculation EQ-141, Qualification Life of Lisega Snubbers at PNPP Engineering Calculation EQ-166, Service Life of E-System Snubbers within the Drywell Engineering Calculation EQ-176, Service Life of E-System Snubbers in areas other than the Drywell Engineering Calculation EA-0101, Evaluation of piping for pipe support 1E12H0460 topped out snubbers Engineering Calculation EA-01 13, Snubbers required for Containment Structural Integrity ISS-2600, Fabrication and Installation of Pipe Supports PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 15 29 of 40 NOP-CC-5708, Written Practice for the Qualification and Certification of Nondestructive Examination Personnel NOP-CC-5709, Review and Approval of Contracted Nondestructive Examination Activities NOP-ER-3203, Snubber Program NOP-WM-3001, Work Management PM Process OAI-0201, Operating General Instructions and Operating Practices PDB-B0005, Snubber MPL to Analytical Drawing Cross Reference PDB-B0006, Analytical Drawing to Snubber MPL Cross Reference PDB-B0007, Containment Integrity Penetration to Snubber MPL Cross Reference PDB-ROO01, Operational Requirements Manual (ORM)SVI-L51-T2010, Augmented Snubber Functional Testing of Safety Related Snubbers SVI-L51-T2000, Augmented Visual Inservice Inspection/Examination of Safety -Related Snubbers SVI-L51-T201 1, Snubber Service Life Monitoring Technical Assignment File (TAF) 81542, Snubber Service Life Monitoring Program Technical Assignment File (TAF) 81655, SP-2600 to allow the use of Lisega Snubber Data 6.2 Obligations American Society of Mechanical Engineers (ASME) OM Code, 2001 Edition with Addenda through 2003 American Society of Mechanical Engineers (ASME) Section Xl, 2001 Edition with Addenda through 2003 PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1 115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 15 L 30 of 40 ISEP, Inservice Examination Program NRC Regulatory Guide 1.192 PNPP Snubber Test Plan PNPP Technical Specifications PNPP Updated Safety Analysis Report (USAR)Title 10 of the Code of Federal Regulations (CFR) 50.55a(b):

Codes and Standards, Reference Applicability Title 10 of the Code of Federal Regulations (CFR) 50.55a(g):

Inservice Inspection Requirements Commitments addressed in this document: F00871 SCOPE OF REVISION 7.0 Rev. 15 1. Added ISTD-6000 reference to paragraph 4.2.2.3, Service Life Monitoring Requirements.

2. Retitled and revised Section 4.6.3, Snubber Location Data, to reflect transfer of related data from ISEP to SVI-L51-T201 1 and to better align this procedure with that SVI.3. Added reference to NOP-ER-3203, Snubber Program.

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 15 31 of 40 ATTACHMENT 1: ALTERNATE QUALIFICATION RECORD Page 1 of 2 of is qualified in accordance with the guidelines of ANSI N45.2.6 to a competency of Level II for the sole purpose of performing snubber visual inspections and review of non-ASME Section Xl, Snubber Visual Inspection/Examination Reports per PAP-1 115, "Snubber Augmented Visual Inservice Inspection/Examination and Functional Testing Program".

This qualification is valid for three (3) years from the date of approval and is based on the following education and experience:

EDUCATION High School College Graduated (Year)Graduated (Year)Completion (Year)Degree Other TRAINING ISEP: PAP-1115: SVI-L51-T2000:

/ /_/ // // I// /Date SP-2600: ORM 6.4.1 : Signature PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 11 15 1 32 of 40 ATTACHMENT 1: ALTERNATE QUALIFICATION RECORD Page 2 of 2 PRACTICAL Demonstrate the ability to perform required snubber inspections on all types of snubbers (i.e., any one PSA 1/4 to PSA 10, any one PSA 35 or 100, any one E-Systems Hydraulic, and any one Lisega Hydraulic snubber): Witnessed By D I Date EXPERIENCE Six months experience in Fabrication, Installation, Testing, Visual Inspection, or VT-1,2,3 Examination of Component Support assemblies.

Dates Dates Dates Employer Employer Job Description Job Description Job Description Employer OTHER: Documented satisfactory completion of a near distance visual acuity exam and a color vision test.Applicants Signature:

Date Date Approved by: Manager Technical Services Engineering PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 15 _ 33 of 40 ATTACHMENT 2: OM CODE TABLE 4252-1 Page 1 of 1 TABLE ISTD-4252-1 VISUAL EXAMINATION TABLE Number of Unacceptable Snubbers Column A Column B Column C Population or for Extended for Interval Same for Interval Category Interval as Previous Reduction to 13[Note (1)] [Notes (2), (3)] [Notes (2), (4), (5)] [Notes (2), (5), (6)]1 0 0 1 80 0 0 2 100 0 1 4 150 0 3 8 200 2 5 13 300 5 12 25 400 8 18 36 500 12 24 48 750 20 40 78>1000 29 56 109 NOTES: (1) Interpolation between population or category sizes and the number of unacceptable snubbers is permissible.

The next lower integer shall be used when interpolation results in a fraction.(2) The basic interval shall be the normal fuel cycle up to 24 months. The examination interval may be as great as twice, the same, or as small as fractions of the previous interval as required by the following Notes. The examination interval may vary +/-25% of the current interval.(3) If the number of unacceptable snubbers is equal to or less than the number in Column A, then the next examination interval may be increased to twice the previous examination interval, not to exceed 48 months. In that case, the next examination according to the previous interval may be skipped.(4) If the number of unacceptable snubbers exceeds the number in Column A, but is equal to or less than the number in Column B, then the next visual examination shall be conducted at the same interval as the previous interval.(5) If the number of unacceptable snubbers exceeds the number in Column B, but is equal to or less than the number in Column C, then the next examination interval shall be decreased to two-thirds of the previous examination interval or, in accordance with the interpolation between Columns B and C, in proportion to the exact number of unacceptable snubbers.(6) If the number of unacceptable snubbers exceeds the number in Column C, then the next examination interval shall be decreased to two-thirds of the previous interval.

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 15 1 34 of 40 ATTACHMENT 3: REQUIREMENTS FOR NON-SAFETY/NON-SEISMIC SNUBBERS Page 1 of 5 Non-Safety/Non-Seismic snubbers identified in Table 1 shall be functionally tested and visually inspected in accordance with this Attachment.

1. Functional Testing of Non-Safety/Non-Seismic Snubbers a. All non-safety/non-seismic snubbers shall be functionally tested over an approximate 10-12 year schedule beginning with RFO4. These snubbers shall be scheduled during Refueling Outages over this period to ensure that each is tested at least once.b. Functional testing parameters shall be the same as for the Safety-Related/Seismic Category 1 snubbers and tested in accordance with SVI-L51-T2010.

Snubber test data that exceeds the acceptable level acceptance criteria established in the surveillance instruction shall require Engineering evaluation by submitting a Condition Report (CR), as determined by Technical Services Engineering to Design Engineering.

[Exception:

PSA mechanical snubbers whose Drag Values are found in the expanded (degraded) range do not require a condition report. Reference SP-2600, SEN 515 and Engineering Calculation EA-0101.]Design Engineering shall evaluate the deviation in accordance with Section 4.3.4.c. Functional test failures or degraded snubbers shall be repaired or replaced with repaired or replaced snubbers being retested prior to installation.

1) Mechanical snubbers shall have met the acceptance criteria subsequent to their most recent service and freedom-of-motion test must have been performed within 12 months before being installed.

d. Additional testing upon snubber testing failure shall be determined by DES based upon the failure mode and extent of condition.

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

/ Page: ATTACHMENT 3: REQUIREMENTS FOR NON-SAFETY/NON-SEISMIC SNUBBERS Page 2 of 5 2. Visual Inspection of Non-Safety/Non-Seismic Snubbers a. All non-safety/non-seismic snubbers shall be visually inspected at the discretion of the Snubber SEPO, however, generally on the same frequency as the Safety-Related/Seismic Category 1 snubbers.b. Visual inspection parameters shall be the same as for the Safety-Related/Seismic Category 1 snubbers and inspected in accordance with SVI-L51-T2000 with the exception that incorrect or missing identification tags shall be an "Operable Non-Relevant (acceptable)" concern. Snubber inspection results which exceed the acceptance criteria established in the surveillance instruction shall require Engineering evaluation by submitting a Condition Report (CR)as determined by Technical Services Engineering to Design Engineering.

Design Engineering shall evaluate the deviation in accordance with Section 4.3.4.c. Personnel performing visual inspections shall be qualified in accordance with Section 4.2.2.4.d. Visual inspections which reveal "Inoperable (Rejectable)" conditions may be functionally tested to determine operability of the snubber.This functional test data may be used to reclassify the snubber as"Operable Relevant (acceptable)" or "Operable Non-Relevant (acceptable)".

e. Additional visual inspections or increased frequency of inspections upon a visual failure shall be determined by Design Engineering based upon the failure mode and extent of condition.

3. Administration for Non-Safety/Non-Seismic Snubbers The Snubber SEPO is responsible for maintaining the status of visual inspection and testing of non-safety/non-seismic snubbers.

Table 1 contains the listing of all Non-Safety/Non-Seismic snubbers.

This listing will periodically be updated and not required to be changed upon DCP implementations.

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program PgRevision:

/ge: 15 .36 f 4 ATTACHMENT 3: REQUIREMENTS FOR NON-SAFETY/NON-SEISMIC SNUBBERS Page 3 of 5 TABLE 1 -Non-Safety/Non-Seismic Snubber Listing Sorted by Support MPL/Asset Number SUPPORT MPL/ASSET NUMBER lC85H6000 lC85H6001 lC85H6002 1C85H6003 1G50H0017 1N11H0209 1N11H0210 1N11H0211 1N11H0212 1N11H0213 1N11H0214 1NllH0215 1NllH0216 1NllH0217 1N11H0218 1N11H0219 1N11H0220 1N11H0275 1N11H0276 1N11H0277 1N11H0326 1N11H0327 1N11H0332 1N11H0333 1N11H0338 1N11H0339 1N11H0343 1N11H0344 (abandoned in place)(Tandem)(Tandem)(Tandem)(Tandem)(Tandem)(Tandem)(Tandem)(Tandem)ANALYSIS NUMBER 1N11-1G01A 1N11-1G01A 1N11-1G01 1N11-1G01 1 G50-0G57 1N11G01 1N11G01 1N11G01 1N11G01 1N11G01 1N11G01 1N11G01 1N11G01 1N11G01 1N11G01 1N11G01 1N11G01 1N11G01 1N11G01 1N11G01 1N11G04 1N11G04 1N11G03 1N11G03 1N11G02 1N11G02 1N11G35 1N11G35 PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1 115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 115 37 of 40 ATTACHMENT 3: REQUIREMENTS FOR NON-SAFETY/NON-SEISMIC SNUBBERS Page 4 of 5 TABLE 1 -Non-Safety/Non-Seismic Snubber Listing Sorted by Support MPL/Asset Number SUPPORT MPL/ASSET NUMBER ANALYSIS NUMBER 1 N 11 H0349 (Tandem)1 N 11 H0350 (Tandem)1 N 11 H0355 (Tandem)1 N 11 H0356 (Tandem)1N25H0025 1N25H0026 1N25H0027 1N26H0054 1 N26H0055 (Tandem)1N26H0056 1N26H0057 1N26H0058 1N26H0059 1N26H0060 1N26H0061 1 N27H0270 (Tandem)1N27H0271 1 N27H0272 1N27H0273 1N27H0274 1N27H0275 1N27H0276 1N27H0277 1N27H0278 1N27H0279 1N27H0280 1N27H0281 1N33H0143 1N11G34 1N11G34 1N11G33 1N11G33 1N25G19 1N25G19 1N25G19 1N26G05 1N26G05 1N26G05 1N26G05 1N26G05 1N26G05 1N26G05 1N26G05 1N27G04 1N27G04 1N27G04 1N27G04 1N27G04 1N27G04 1N27G04 1N27G03 1N27G03 1N27G03 1N27G03 1N27G03 1N33G01 PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 15 __38 of 40 ATTACHMENT 3: REQUIREMENTS FOR NON-SAFETY/NON-SEISMIC SNUBBERS Page 5 of 5 TABLE 1 -Non-Safety/Non-Seismic Snubber Listing Sorted by Support MPL/Asset Number SUPPORT ANALYSIS MPL/ASSET NUMBER NUMBER 1N33H0144 1N33G01 1 N33H0145 1 N33G01 1 N33H0146 1 N33G01 1 N63H0012 1 N62G01 1 N63H0013 1 N62G01 1 N63H0014 1 N62G01 1N64H0017 (Tandem) 1N64G01 1N64H0021 (Tandem) 1N64G01 1N64H0022 (Tandem) 1N64G01 1N64H0023 (Tandem) 1N64G01 PERRY NUCLEAR POWER PLANT Procedure Number: PAP- 1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 15 39 of 40 ATTACHMENT 4: FAILURE MODE GROUPS (FMG's) & ADDITIONAL TESTING Page 1 of 2 Failure Mode Groups (FMG): Snubbers found unacceptable by inservice testing shall be evaluated for cause. The results of the evaluation shall be used if applicable to assign the unacceptable snubbers and all snubbers generically susceptible to the same failure to one or more of the Failure Mode Groups (FMG)defined below.Application-induced failure -failures resulting from environmental conditions or improper application of the snubber.Design or manufacturing failure -failures resulting from potential defects in manufacturing or design. This includes failures of any snubber that fails to withstand the environment or application for which it was designed.Isolated failure -a failure which does not cause other snubbers to be suspect.Maintenance, repair or installation failure -failures resulting from damage during maintenance, repair or installation activities.

Transient dynamic event failure -failures resulting from water or steam hammer.Unexplained failure -failures that cannot be classified into any of the above Failure Mode Group categories.

PERRY NUCLEAR POWER PLANT Procedure Number: PAP-1115 Title: Use Category: Snubber Augmented Visual Inservice General Skill Reference Inspection/Examination and Functional Testing Program Revision:

Page: 1 15 40 of 40 ATTACHMENT 4: FAILURE MODE GROUPS (FMG's) & ADDITIONAL TESTING Page 2 of 2 Additional Testing: Test failures may require additional testing depending on the Failure Mode Group category and the extent of corrective action. For each snubber found unacceptable through inservice testing one additional sample shall be selected and tested according to the table below. Except for unexplained and isolated failures, additional snubbers shall be selected randomly from the untested snubbers in the Failure Mode Group. For unexplained failures, the selection shall be from the test group (TG). However, regardless of whether the source of additional snubbers is selected from the Failure Mode Group or the test group, the size of any additional sample will be 1/2 of the test group's initial sample size rounded up to the next integer. Testing will continue until no more unacceptable snubbers are found.FMG Category Additional Testing Sample Source Sample Size Application-Not required if all FMG snubbers are FMG/DTPG 1/2 initial sample induced failure replaced or modified OR if all unacceptable snubbers in the FMG are replaced or repaired and the environment or application is made compatible; otherwise required.Design or Not required if all FMG snubbers are FMG/DTPG 1/2 initial sample manufacturing replaced or modified; otherwise required.failure Maintenance, Required FMG/DTPG 1/2 initial sample repair or installation failure Isolated failure Not required N/A N/A Transient Stroke or test all in FMG FMG 100% FMG dynamic event failure Unexplained Required DTPG (Note 1) 1/2 initial sample failure NOTE 1: As practical, the additional sample from the test group (DTPG) shall include the following: (a)(b)(c)(d)(e)Snubbers of the same manufacturing design.Snubbers immediately adjacent to the unacceptable snubbers.Snubbers from the same piping system.Snubbers from the similar piping systems.Snubbers that are previously untested.