Text

Submittal of Inservice Testing Program Plan for the Third Ten-Year Interval
	ML102010118
Person / Time
Site:	Clinton
Issue date:	07/12/2010
From:	Kemper D; Exelon Nuclear
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	U-603967
	Download: ML102010118 (191)
	v • d • e

Exelkn.

Clinton Power Station Nuclear 8401 Power Road Clinton, IL 61727 U-603967 10 CFR 50.55a July 12, 2010 U. S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001 Clinton Power Station, Unit 1 Facility Operating License No. NPF-62 NRC Docket No. 50-461

Subject:

Submittal of Inservice Testing Program Plan for the Third Ten-Year Interval In accordance with the American Society of Mechanical Engineers (ASME) Code for Operation and Maintenance of Nuclear Power Plants (OM Code), Subsection ISTA-3200(a),

"Administrative Requirements," attached for your information is a copy of the Inservice Testing Program Plan for the third ten-year interval. The third ten-year interval complies with the ASME OM Code 2004 Edition. The third ten-year interval began on July 1, 2010 and concludes on June 30, 2020.

There are no regulatory commitments contained within this letter.

Should you have any questions concerning this matter, please contact me at (217) 937-2800.

Respectfully, t~ne empeH Regulatory Assurance Manager Clinton Power Station Attachment - Clinton Power Station, Unit 1 - Inservice Testing Program Plan for the Third Ten-Year Interval JLP/blf cc: Regional Administrator- NRC Region III NRC Senior Resident Inspector - Clinton Power Station Illinois Emergency Management Agency - Division of Nuclear Safety A

IST Program Plan Clinton Power Station, Unit 1, 3(d Interval Clinton Nuclear Power Station Unit 1 Inservice Testing Program Plan Third Ten Year Interval Revision 0 Conunercial Service Date:

Unit 1 - April 24, 1987 Prepared '; ,

1 36 //aý Reviewed __ _ _ _ _ _ _ _

Approved 6ý/ T hYj/ri

-f -1 .

Clinton Power Station 8401 Power Road Clinton, IL 61727 Revision Date: 6/28/2010

L1.)L Z -L QJ LL LU L I Clinton Power Station, Unit 1, 3rd Interval REVISION LOG Initial Revision 06/28/10 Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 d Interval TABLE OF CONTENTS SECTION

1.0 INTRODUCTION

1.1 Purpose 1.2 Scope 2.0 INSERVICE TESTING PLAN FOR PUMPS 2.1 Pump Inservice Testing Plan Description 2.2 Pump Plan Table Description 3.0 INSERVICE TESTING PLAN FOR VALVES 3.1 Valve Inservice Testing Plan Description 3.2 Valve Plan Table Description 4.0 ATTACHMENTS

1. Pump Relief Request Index

2. Pump Relief Requests

3. Valve Relief Request Index

4. Valve Relief Requests

5. Cold Shutdown Justification Index

6. Cold Shutdown Justifications

7. Refuel Outage Justification Index

8. Refuel Outage Justifications

9. Station Technical Positions Index

10. Station Technical Positions

11. Corporate Technical Positions Index

12. Corporate Technical Positions

13. Inservice Testing Pump Index

14. Inservice Testing Pump Table

15. Inservice Testing Valve Index

16. Inservice Testing Valve Table Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval

1.0 INTRODUCTION

1.1 Purpose To provide requirements for the performance and administration of assessing the operational readiness of those pumps and valves with specific functions that are required to:

Shutdown the reactor to the cold shutdown condition,

Maintaining the cold shutdown condition, or

To mitigate the consequences of an accident.

1.2 Scope Title 10, Part 50.55a of the Code of Federal Regulations, Paragraph (f) (4) (ii) requires that 10-year IST Programs comply with the latest NRC approved edition and addenda of the Code incorporated by reference in Paragraph (b), 12 months prior to the start of the 120-month inspection interval. The third 10-year inservice testing interval for Clinton Power Station (CPS) Unit 1 commences on July 1, 2010. The use of any later edition and addenda of the ASME OM Code is allowed if it has been incorporated in Paragraph (b) (2) of 10 CFR 50.55a, or if approved by the NRC as an acceptable alternative.

The Inservice Testing (IST) Program for pumps at CPS, Unit 1, is based on the following:

" American Society of Mechanical Engineers (ASME) OM Code-2004 Edition, Code for Operation and Maintenance of Nuclear Plants.

" Generic Letter No. 89-04, "Guidance on Developing Acceptable Inservice Testing Programs"

" NUREG-1482, Revision 1 "Guidelines for Inservice Testing at Nuclear Power Plants" The pumps included in this program are all ASME Class 1, 2, or 3 pumps that are provided with an emergency power source, which are required in shutting down a reactor to the safe shutdown condition, maintaining the safe shutdown condition, or mitigating the consequences of an accident, at CPS, Unit 1.

Exclusions The following are excluded from the requirements of Subsection ISTB:

Drivers, except where the pump and driver form an integral unit and the pump bearings are in the driver.

Pumps that are supplied with emergency power solely for operating convenience. j Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 Interval Skid-mounted pumps that are tested as part of the major component and are justified to be adequately tested. Skid-Mounted Pumps are pumps which are integral to or support operation of a parent pump or major component. NUREG-1482, Rev.l, Section 3.4, "Skid-mounted Components and Component Subassemblies" provides further discussion pertaining to skid-mounted components.

The Clinton Nuclear Power Station Pump and Valve Inservice Testing Plan will be in effect through the Third 120-month interval.

0 Unit One: July 1, 2010 through June 30, 2020 Revision Date: 6/28/2010

+/-Ti irogram v+/-an Clinton Power Station, Unit 1, 3 rd Interval 2.0 INSERVICE-TESTING PLAN FOR PUMPS 2.1 Pump Inservice Testing Plan Description This program plan meets the requirements of OM Code ISTB with the exception of specific relief requests contained in Attachment 2.

The hydraulic circuit and location/type of measurement for the required test parameters need to be specified in station procedures per requirements of ISTB-9200.

2.2 Pump Plan Table Description Transitioning to the applicable edition of the ASME OM Code for the IST Third 10-Year Interval requires the Grouping of pumps according to. function as well as adopting the Comprehensive Pump Test.

When a Group A test is required a Comprehensive test may be substituted. When a Group B test is required a Group A test or Comprehensive test may be substituted. A preservice test may be

-substituted for any inservice test.

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. CPS considers the following Unit 1 pumps as being categorized as Group A:

Residual Heat Removal (RHR) Pumps A and B

" Control Room HVAC Chilled Water Pump A and B

" RHR Loop B/C Water Leg Pump 0 LPCS and.-RHR Loop A Water Leg Pump

HPCS Water Leg Pump

RCIC Water Leg Pump

Fuel Pool Cooling Pumps A and B

Diesel Fuel Oil Pumps Group B Pumps The ASME OM Code defines Group B pumps as those pumps in standby systems that are not operated routinely except for testing. CPS considers the following pumps as being categorized as Group B:

Residual Heat Removal (RHR) Pump C

Low Pressure Core Spray (LPCS) Pump Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval

" High Pressure Core Spray (HPCS) Pump

Standby Liquid Control (SLC) Pump A and B

" Reactor Core Isolation Cooling (RCIC) Pump

" Shutdown Service Water Pumps A, B, and C The pumps included in the Clinton Nuclear Power Station IST Plan are listed in Attachment 10. The information contained in these tables identifies those pumps required to be tested to the requirements of the OM Code, the testing parameters and frequency of testing,.and associated relief requests and remarks. The headings for the pump tables are delineated below.

System The system abbreviation codes for thesystem containing the pump.

Pump Name The descriptive name for the pump.

Pump EPN The unique Equipment Part Number (EPN) for the pump.

Each EPN is preceded with a Unit designator for the pump:

0 Common Unit 1 Unit 1 Safety Class The ASME Code classification of the pump 1 Class 1 2 Class 2 3 Class 3 P&ID The Piping and Instrumentation Drawing on which the pump is represented.

P&ID Coor. The P&ID Coordinate location of the pump.

Pump Tvyoe The type of pump.

C Centrifugal PD Positive Displacement VLS Vertical Line Shaft Pump Driver The type of pump driver.

MOTOR Motor driven TURBINE Steam turbine driven Revision Date: 6/28/2010

IST Program Pian Clinton Power Station, Unit 1, 3 rd Interval Test Type The tests identified include, Comprehensive, Group A and Group B. The following test parameters will be measured for each test as required by ISTB.

PUMP SPEED Measured only for variable speed pumps.

DIFFERENTIAL PRESSURE Calculated from suction and discharge pressures or obtained by direct measurement.

DISCHARGE PRESSURE Measured for positive displacement pumps.

FLOW RATE Measured using a rate or quantity meter installed in the pump test circuit.

VIBRATION Pump bearing'vibration.

Test Freq. The frequency for performing the specified inservice test.

M3 Quarterly (92 Days)

Y2 Once every 2 years Relief Request A relief request number is listed when a specific code requirement is determined to be impracticable or an alternative testing methodology is desired.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 rd Interval 3.0 INSERVICE TESTING PLAN FOR VALVES 3.1 Valve Inservice Testing Plan Description The Inservice Test (IST) Program for valves at Clinton Power Station (CPS), Unit 1, is based on the following:

American Society of Mechanical Engineers (ASME) OM Code-2004 Edition, Code for Operation and Maintenance of Nuclear Plants."

" Generic Letter No. 89-04, "Guidance on Developing Acceptable Inservice Testing Programs"

NUREG-1482, Revision 1, "Guidelines for Inservice Testing at Nuclear Power Plants"

Implementation of ASME OM Code Case .OMN7 in accordance with applicable Corrective Maintenance Procedures (CMPs). (See Valve Relief Request No. 2201)

The valves included in *this program are all ASME Class 1, 2 'or 3 required to perform a specific function in shutting down a reactor to the safe shutdown condition, in maintaining the safe shutdown condition, or in mitigating the consequences of an accident. The pressure-relief devices covered are those for protecting systems or portions of systems which perform one or more of the three aforementioned functions at CPS. Exemptions are listed in ISTC-1200.

This plan establishes the test intervals, parameters to be measured and meets the requirements of ISTA and ISTC with the exception of the specific relief requests contained in Attachment 4.

Where the frequency requirements for valve testing have been determined to be impracticable, Cold Shutdown or Refuel Outage Justifications have been identified and written. These justifications are provided in Attachments 6 and 8 respectively.

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 obturatbr movement it is not necessary to be performed simultaneous to manual exercising.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit i, 3 rd Interval This testing methodology is consistent with the discussion provided in NUREG-1482, Revision 1, Section 4.4.4. 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).

AOV Valves Typically,. AOVs have solenoid valves that control the flow of air to the air operator. These solenoid valves are considered skid mounted. They are exercised when the AOV is exercised.

Check Valves In transitioning to ASME OM Code-2004, each check valve will require exercising to both the open and closed positions regardless of their safety function. Additionally, periodic partial stroke exercising is no longer a Code requirement.

Category C check valves shall. be exercised nominally every 3 months, except as provided by ISTC-3522 and ISTC-5221. During operation at power, each check valve shall be exercised or examine*

in a manner that .verifies obturator travel by using the methods in ISTC-5221. Each check valve exercise test shall include an open and closed test. Open and closed tests need only be performed at an interval when it is practicable to perform both tests. Test order (e.g. whether the'open test precedes the closed test) shall be determined by CPS.

CPS check valve surveillance testing will be in accordance with the following interpretation: (1) if a check valve can be tested in both directions at the same frequency, then that is the required frequency. (e.g., if the valve can be tested in both the open and closed directions on a quarterly frequency, then the Code-required frequency for bidirectional testing is quarterly, (2) if a check valve is not able to be tested in both directions at the same frequency, then the Code-required frequency is the less frequent of the two frequencies .(e.g., if a valve can be tested in the open direction quarterly but can only be tested in the closed direction on a refueling outage frequency, then the Code-required frequency for bidirectional testing is the refueling outage frequency).

Credit can only be taken for a check valve exercise test when it can be tested in both directions. Therefore, the testing frequency is not dependent on safety vs. non-safety direction Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 Interval Check Valve Condition Monitoring As an alternative to the requirements of paragraphs ISTC-3510, ISTC-3520, ISTC-3530, ISTC-3550, and ISTC-5221, CPS-l 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.

CPS may implement this program on a valve or a group of similar valves basis.

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

have an unusually high failure rate during inservice testing or operations cannot be exercised under normal operating conditions or during shutdown exhibit unusual, abnormal, or unexpected behavior during exercising or operation

the Owner elects to monitor for improved valve performance Examples of candidates for (b) optimization of testing, examination, and preventive maintenance activities are check valves with documented acceptable performance that:

have had their performance improved under the Check Valve Condition Monitoring Program

. cannot be exercised or are not readily exercised during normal operating conditions or during shutdowns

can only be disassembled and examined the Owner elects to optimize all the associated activities of the valve or valve group in a consolidated program.

The program shall be implemented in accordance with Appendix II, "Check Valve Condition Monitoring Program", of OM-2004. A site administrative procedure and site implementing procedures will 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.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3r Interval 3.2 Valve Plan Table Description The valves included in the Clinton Nuclear Station IST Plan are listed in Attachment 12. The information contained in these tables*

identify the requirements of ISTA and ISTC, the test parameters, frequency of testing, and the associated relief requests. The headings for the valve tables are delineated below.

System The unique system identifier.

Valve Name The description of the valve.

Valve EPN A unique identifier for the valve. Each EPN is preceded with a Unit designator for the valve:

0 Common Unit 1 Unit 1

2. Unit 2 Safety Class The ASME Class abbreviation.

1 Class 1 2 Class 2 3 Class 3 AQ Augmented Quality NC Non-Code, Safety Related NS Non-Safety Related P&ID The Piping and Instrumentation Drawing (P&ID) numbe*

on which the valve appears. If the valve appears on multiple P&IDs, the primary P&ID will be listed.

P&ID Coor. The coordinate location on the P&ID where the valve, appears.

Categorv The code category (or categories) as defined in paragraph ISTC-1300.

A Seat Leakage Limited.B Seat Leakage Not Required.

C Self-Actuating Valves.

D Single Use Valves.

Size The nominal pipe size of the valve, in inches.

Valve Typoe The valve body style abbreviation.

BAL Ball Valve BTF Butterfly Valve CK Check Valve DAM Damper DIA Diaphragm Valve Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 d Interval GA Gate Valve GL Globe Valve PLG Plug Valve PLT Pilot Valve PPT Poppet Valve RPD Rupture Disk RV Relief Valve SCK Stop Check Valve SHR Shear Valve/SQUIB-Valve VR Vacuum Relief 3W 3-Way Valve 4W 4-Way Valve XFC Excess Flow Check Valve Act. TVpe The actuator type abbreviation.

AO Air Operator DF Dual Function (Self Actuated and Power Operated)

EXP Explosive Actuator HO Hydraulic Operator M Manual MO Motor Operator SA Self-Actuating SAP Self-Actuated Pilot SO Solenoid Operator Normal Position The normal position abbreviation. The valve's position during normal power operation. If the system does not operate during power operation, then the normal position is the position of the valve when the system is not operating.

C Closed CKL Closed / Hand Switch Key Locked in Position LC Locked Closed D De-energized (3-way and 4-way valves)

E Energized (3-way and 4-way valves) 0 Open OKL Open / Hand Switch Key Locked in Position LO Locked Open SYS System Condition Dependent Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval 3.2 Valve Plan Table Description (Cont'd)

Safety Position The safety function position(s). For valves

that perform safety functions in the open and closed*

positions more than one safety function position may be specified.

C Closed D De-energized (3-way and 4-way valves)

E Energized (3-way and 4-way valves)

D/E De-energized or Energized 0 Open O/C Open or Closed Test Tyve The test type abbreviation.

LT Leakage Rate Test LTJ Appendix J air leak test PIV High pressure water leak test SC Exercise Closed SD De-energize SE Energize SO Exercise Open RT Relief Valve Test CC Exercised Closed - Check Valve CO Exercise Open - Check Valve BDO Bi-directional open test (non-safety)

BDC Bi-directional closed test (non-safety)

CP Partial Exercise Open DT Rupture Disk / Explosive Valves FC Fail Safe Test Closed FO Fail Safe Test Open PI Position Indication Test OPR Routing Operator Rounds (condition monitoring)

ET Full Exercise without stroke timing DIA Diagnostic Test - MOVs (includes stroke time and PI)

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 Interval ATTACHMENT 1 PUMP RELIEF REOUEST INDEX Relief Request # Description Date Submitted Date Approved Remarks 3201 Flow Rate 6116/09 6/10/10 Includes RAI Measurement 3201-001 for Water Leg submitted Pumps 3/31/2010 Revision Date: 6/28/2010

ISI Program vian Clinton Power Station, Unit 1, 3r Interval ATTACHMENT. 2 PUMP RELIEF REQUESTS Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval PUMP RELIEF REQUEST 3201 Proposed Alternative In Accordance with 10CFR50.55a(a) (3) (i)

1. ASME Code Component(s) Affected 1E12-C003, Residual Heat Removal (RHR) Loop B/C Waterleg Pump (Class 2) 1E21-C002, Low Pressure Core Spray (LPCS) and RHR A Waterleg Pump (Class 2) 1E51-C003, Reactor Core Isolation Cooling (RCIC) Waterleg Pump (Class 2)

2. Applicable Code Edition and Addenda

American Society of Mechanical Engineers (ASME), "Code for Operation and Maintenance of Nuclear Power Plants," 2004 Edition (ASME OM Code-2004).,

3. Applicable Code Requirement

Table ISTB-3000-1 specifies the parameters to be measured during IST.

ISTB-3300, "Reference Values," paragraph (e) (2) states, "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."

ISTB-3400, "Frequency of Inservice Tests," states, "An inservice test shall be run on each pump as specified in Table ISTB-3400-1." Table ISTB-3400-1, "Inservice Test Frequency," specifies that a Group A pump test shall be performed on a quarterly frequency.

ISTB-5121 requires that Group A tests shall be conducted with the pump operating at a specified reference point. ISTB 5121(b) requires that the resistance of the system shall be varied until the flow rate equals the reference point. The differential pressure shall then be determined and compared to its reference value. Alternatively, the flow rate shall be varied until the differential pressure equals the reference point and the flow rate determined and compared to the reference flow rate value.

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

4. Reason for Request

The waterleg pumps are continuously-running pumps whose safety function is to keep their supported system's pump discharge header piping in a filled condition. This function prevents water hammer Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 rd Interval and the delay of flow to the reactor upon the supported system's pump start. The actual output and hydraulic performance of the waterleg pumps are not critical to their safety function, as long as the waterleg pumps are capable of maintaining their associated system's pump discharge piping full of water. The amount of flow delivered by each waterleg pump is dependent upon each supported system's leakage rate.

The suction pressure for these waterleg pumps is essentially constant; however, quarterly monitoring of discharge pressure and bearing vibration in accordance with Position 9, "Pump Testing Using Minimum-Flow Return Lines With or Without Flow Measuring Devices," of Generic Letter (GL) 89-04, "Guidance On Developing Acceptable Inservice Testing Programs," dated April 3, 1989, will be performed to monitbr 'for pump degradation and to assess pump performance' (Referenced). The flowrate for each of these waterleg pumps varies little during normal operation, and testing of these pumps at a predetermined reference point as described in ISTB-5121(b) is not necessary to detect pump degradation or to establish that theset pumps can perform their safety function.

The proposed alternative provides an acceptable level of quality and safety.

5. Proposed Alternative and Basis for Use The CPS waterleg pumps will be monitored for degradation on a quarterly basis by observing pump discharge pressure and bearing vibration during normal operating conditions.' This testing will be performed without varying the resistance of the system as discussed in ISTB-5121(b). These parameters will then be evaluated and trended to assess the pump's performance. The measurement and trending of these parameters under these conditions will provide satisfactory indication of the operational readiness of the pumps and detect degraded performance. These waterleg pumps will be full flow tested every 24 months in conjunction with the comprehensive pump test performed in accordance with the requirements specified in ISTB-5123, "Comprehensive Test Procedure."

In addition to this quarterly testing, each of these waterleg pump's supported system pump discharge headers have sensors that continuously monitor header pressure, and provide an alarm in the main control room when their low pressure setpoint is reached. This will provide indication that the associated waterleg pump is no longer performing its safety function, and allow CPS operators to respond according to station procedures. Moreover, these pumps are currently being monitored under the CPS Vibration Monitoring Program, which is not currently required by any Federal, state or industry mandate. Because rotating equipment faults that can be detected by vibration monitoring will show up any time the equipment is operating, returning these pumps to a fixed set of operating Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval conditions is not necessary to detect such faults. Lastly, each of these waterleg pump's supported system pump discharge header is verified to be filled with water on a monthly basis in accordance with Surveillance Requirements (SRs) in the CPS Technical Specifications (TS). Any indication that the supported system's pump discharge header piping is not filled with water would provide timely indication that the associated waterleg pump's performance has degraded.

In summary, using the provisions of this relief request as an alternative to the requirements of ISTB-3300(e) (2), ISTB-3400, and ISTB-5121(b), provides a reasonable alternative to the ASME OM Code requirements, and an acceptable level of quality and safety. The actual output and hydraulic performance of the waterleg pumps are not critical to their safety function, as long as the pumps are capable of maintaining their supported system's pumpidischarge header piping full of water. Alarms would promptly alert plant operators whenever the waterleg pumps do not maintain the piping pressure above a set alarm level. In addition, vibration data trending, toward unacceptable values would indicate degradation in pump performance, and allow time for CPS personnel to plan and take corrective actions before the pumps fail.

Therefore, the proposed alternative provides a reasonable assurance of operational readiness of the subject waterleg pumps because (1) discharge pressure and bearing vibration are measured and trended, (2) alarms are present in the Main Control Room, which provide continuous monitoring for. degradation in the pressure of the supported system's pump discharge header, and (3) monthly' venting of supported system's pump discharge header piping according to CPS TS will verify that the associated waterleg pump is performing its safety function.

6. Duration of Proposed Alternative The proposed alternative identified in this relief request shall.be utilized during the Third 10-Year IST Interval

7. Precedents In Reference 2, the Perry Nuclear Power Plant submitted Request Number PR-l, Revision 0, to request relief from quarterly testing waterleg pumps associated with the Residual Heat RemQval, Low Pressure Core Spray, High Pressure Core Spray, and Reactor Core Isolation Cooling systems. This request is similar to that request approved by the NRC in a safety evaluation report dated August 9, 1999 (Reference 3).

8. References

1. Generic Letter 89-04, "Guidance On Developing Acceptable Inservice Testing Programs," dated April 3, 1989 Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 rd Interval

2. Letter from Mr. M. Bezilla (First Energy Nuclear Operating Company) to U. S. NRC, "Eight Separate In-Service Testing Program*

10 CFR 50.55a Requests in Support of the Third Ten-Year Interval," dated November 18, 2008. (Accession Number ML083370198)

3. Letter from U. S. NRC, "Safety Evaluation of the Inservice Testing Program Second Ten-Year Interval for Pumps and Valves -

Perry Nuclear Power Plant (TAC MA3328), dated August 9, 1999 Revision Date: 6/28/2010

Clinton Power Station, Unit 1, 3 d Interval 3.2 Valve Plan Table Description (Cont'd)

Test Frecr. The test frequency abbreviation.

AJ Appendix J CMP Condition Monitoring Program CS Cold Shutdown M3 Quarterly OP Operating Activities RR Refuel Outage S2 Explosive Charge Sample MOV MOV Program frequency Relief Rectuest A relief request number is listed when a specific code requirement is determined to be impracticable or an alternative testing methodology is desired.

Deferred Just. Deferred Test Justification. This section refers to Cold Shutdown Justifications and Refuel Outage Justifications.

A Cold Shutdown Justification number is listed when the testing frequency coincides with Cold Shutdowns instead of being performed quarterly. Cold Shutdown Justification numbers for valves are prefixed with "CSJ".

A Refuel Outage Justification number is listed when the testing frequency coincides with Refuel Outages instead of being performed quarterly or during Cold Shutdowns. Refuel Outage Justification numbers for valves are prefixed with "RFJ".

Tech. Pos. A technical position number is listed when the requirements of the code are not easily interpreted and clarifying information is needed. The technical position is used to document how Code requirements are being implemented at the station.

Revision Date: 6/28/2010

Clinton Power Station, Unit 1, 3'- Interval 4.0 Attachments Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval RAIs for Relief Request 3201 RAI 3201-001 Please provide the rated flow and differential pressure for each waterleg pump.

Response

The rated flows and rated differential pressures associated with the subject waterleg pumps are contained in Table 1 below.

Table 1: Rated Flow and Rated Differential Pressure for Waterleg Pumps Rated Rated Pump Flow Differential (gpm) Pressure (ft) 1 E12-C003, Residual Heat Removal (RHR) Loop B/C Waterleg Pump 43 199 1 E21-C002, Low Pressure Core Spray (LPCS) and RHR A Waterleg Pump 43 199 1 E51 -C003, Reactor Core Isolation Cooling (RCIC) Waterleg Pump 50 130 RAI 3201-002 Do pressure taps exist in the waterleg pumps' suction and dischargepiping where pump suction and dischargepressure can be measured for calculationof differentialpressure?

Response

Yes. The systems associated with the subject waterleg pumps have been designed with suction pressure instruments on the pump suction headers, and flow and pressure instruments on the pump discharge headers to allow for testing. These instruments are isolated during normal plant operation via closed isolation valves and are only placed into service to support waterleg pump testing. Relief Request 3201 proposes in part, to detect degradation in waterleg pump readiness by recording the associated main system discharge pressure on a quarterly basis. As a point of clarification, the waterleg pump discharge pressure as discussed in this relief request is the main system header pressure resulting from the pressure head supplied by the waterleg pumps. The recorded header pressure will be compared to pressures observed in previous tests, and changes in pressure will be evaluated to determine the cause.

Relief is requested due to the impact that traditional waterleg pump testing has on the plant without a compensating increase in the level of quality or safety.

The Low Pressure Core Spray (LPCS) waterleg pump (i.e., 1 E21 -C002) services the LPCS system piping and Loop A of Residual Heat Removal (RHR) system, and 1 E12-C003 services RHR Loops B and C.

Traditional testing of the RHR and LPCS waterleg pumps requires declaring portions of the RHR and LPCS systems inoperable.

Testing of 1 E21 -C002 as described in the 2004 American Society of Mechanical Engineers (ASME) Code for Operation and Maintenance of Nuclear Power Plants (OM Code) requires disabling the main LPCS pump motor, rendering the LPCS System inoperable. Additionally, RHR Loop A is required to be isolated from 1E21 -C002, and an abnormal alignment is required to maintain the discharge header pressurized and full of water. A similar alignment is required for testing 1 El 2-C003, rendering RHR C inoperable during the test.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval Testing the Reactor Core Isolation Cooling (RCIC) waterleg pump currently requires the RCIC system to be declared inoperable due to the system configuration changes that are necessary to perform the surveillance.

The RHR and LPCS waterleg pump surveillances will be performed with the suppression pool as the suction source. Suppression pool level at Clinton Power Station (CPS) is maintained within limits according to CPS Technical Specifications Section 3.6.2.2. A review of plant data showed that the suppression pool level over the past year was maintained within a five-inch band. Therefore, the pumps' suction pressures are essentially constant, allowing waterleg pump readiness to be confirmed by monitoring the supported system's main header pressure. Changes in the supported system's main header pressure identified during testing will be evaluated to determine if they are a result of a change in the associated waterleg pump's performance.

The RCIC waterleg pump (i.e., 1 E51 -C003) surveillance will be performed with the RCIC Storage tank as the suction source for 1 E51 -C003. RCIC storage tank volume is also controlled. A review of the past year's plant data showed that the RCIC tank water level was maintained within a band of approximately five inches. As such, 1 E51 -C003 suction pressure is essentially a constant. The readiness of 1 E51 -C003 will be confirmed by monitoring the main RCIC system header pressure. Changes in the RCIC system's main header pressure between tests will be evaluated to determine if they are a result of a change in pump performance.

According to the testing methodology proposed in Relief Request 3201, changes in supported system's main header pressure will be evaluated to determine if they are a result of changes in the waterleg pump performance. Testing the waterleg pumps in this manner ensures a level of quality and safety equivalent to the testing methodologies described in theASME OM Code. Moreover, the waterleg pumps will be tested in accordance with traditional testing methodologies during the biennial comprehensive pump testing that will be performed in accordance with the ASME OM Code.

In summary, performing the waterleg pump surveillances on a quarterly frequency in accordance with traditional IST pump surveillance methodologies places the unit in a higher risk state without a compensating increase in quality or safety. The testing methodology proposed in Relief Request 3201 would provide an acceptable level of quality and safety without placing the unit in an elevated state of risk.

RAI 3201-003 Are there throttle valves in the waterleg pumps' discharge piping that can be used to set differential pressure?

Response

Yes.

RAI 3201-004 Are there any flow rate meters, orifices, or other measurement devices installedin the system for measurement of waterlegpump flow rate?

Response

Yes.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval ATTACHMENT 3 VALVE RELIEF REQUEST INDEX Relief Request Description Date Submitted Date Approved Remarks 2201 Use of Code 6116/09 6/10/10 Case OMN-1 2202 Relief From 5- 6/16/09 6/10/10 Includes RAI Year Test 2202-001 Interval for submitted Safety Relief 3/31/2010 Valves Revision Date: 6/28/2010

Clinton Power Station, Unit 1, 3rd Interval ATTACHMENT 4 Valve Relief Recruests Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3" Interval RAI 3201-005 Have any attempts been made to use portable ultrasonic flow instruments to measure waterleg pump flow rates? If not, explain why not.

Response

No. As previously discussed, the systems were designed and built to allow for waterleg pump testing.

RAI 3201-006 Is there flow instrumentationin the main headerpiping? If so, explain why this instrumentationcan or cannot be used to measure the waterlegpump flow.

Response

Yes. The flow instrumentation ranges for the main system headers are as follows:

RHR: 0- 7000 gpm

LPCS: 0 - 8000 gpm

RCIC: 0- 800 gpm The ranges for these instruments are not suitable for measuring the low flow rates at which the waterleg pumps are tested.

RAI 3201-007 At what pressure does each low headerpressureannunciatoralarm? For each of these values, state what percentage it is of the respective waterlegpump operating differentialpressure.

Response

As shown in Table 2 below, Control Room annunciator alarms are based on pressure. The alarm setpoints were compared to the normal operating pressure of their associated headers, and shown as a percentage of that normal operating pressure. As previously discussed, the suction pressures for the waterleg pumps are essentially constant; therefore it is appropriate to consider control room alarm setpoints in relation to normal pump discharge/associate system header pressure versus as a percentage of pump differential pressure.

Table 2: Waterleg Pump Parameters Including Control Room Alarm Setpoint as a Percentage of Normal Discharge Pressure Alarm Normal Operatin Alarm Setpoint as Alar Opeatin Percentage of System ATM Setpoint ATM g Normal Operating (psig) Pressure Pr ereting (psig) Pressure_(%)

RHR "A" E12-N654A 58.4 1E12-N653A -94 62.1 RHR "B" E12-N654B 57.8 1E12-N653B -88 65.7 Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval RHR "C" E12-N654C 21.6 1E12-N653C -91 23.7 LPCS E21-N654 35 1E21-N654 -94 37.2 RCIC E51-N652 39 1E51-N654 -55 70.9 Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 Interval This conditional acceptance of OMN-I, Revision 0, per RG 1.19.2 is applicable in lieu of the provisions for stroke-time testing in Subsection ISTC of ASME OM Code-2004. Since RG 1.192 was last published, Code Case OMN-l has been updated/modified to address and incorporate all of the original RG 1.192 listed provisions. EGC proposes to adopt the requirements of Code Case OMN-I, Revision 1, as presented in the ASME OMb Code, "Addenda to ASME OM Code-2004, Code for Operation and Maintenance of Nuclear Power Plants," for 2006, in lieu of the performance of stroke time testing and position indication testing as described by ASME OM Code Subsection ISTC of the 2004 Edition.

The CPS MOV testing program was developed as a result of NRC Generic Letter (GL) 89-10, "Safety Related Motor Operated Valve Testing and Surveillance," and GL 96-05, "Periodic Verification of Design Basis Capability of Safety Related Motor Operated Valves," utilizing Topical Report MPR-1807, "Joint BWR, Westinghouse and Combustion Engineering Owners' Group Program on Motor-Operated Valve (MOV)

Periodic Verification," Revision 2. CPS is currently utilizing MPR-2524-A, "Joint Owners' Group (JOG) Motor Operated Valve Periodic Verification Program Summary," (November 2006) as guidance for the MOV Program. The adoption of OMN-I will consolidate testing between the station's IST and MOV Programs.

Section 4.2.5 "Alternatives to Stroke-Testing," of NUREG-1482, "Guidance for Inservice Testing at Nuclear Power Plants," Revision 1, states in part that as an alternative to MOV stroke-time testing, ASME developed Code Case OMN-l, which provides periodic exercising and diagnostic testing for use in assessing the operational readiness of MOVs, may be used. Section 4.2.5 recommends that licensees implement ASME Code Case OMN-l as an alternative to the MOV stroke-time testing. The periodic exercising and diagnostic testing requirements in OMN-l provide an improved method for assessing the operational readiness of MOVs.

Application of code cases is addressed in 10 CFR 50.55a(b) (6) through references to RG 1.192, which lists acceptable and conditionally acceptable code cases for implementation in IST programs. RG 1.192, Table 2, conditionally approves the use of Code Case OMN-l and states that the code case is applicable to the 2000 Addenda and earlier editions and addenda of the Code. There is no technical reason for prohibiting the use of Code Case OMN-l with ASME OM Code-2004.

Therefore, Code Case OMN-l provides an acceptable level of quality and safety for testing of MOVs and is an acceptable alternative for use in CPS IST program. This conclusion is consistent with the NRC position in NUREG-1482, Revision 1, and RG 1.192.

Code Case OMN-I was revised in the 2006 Addenda to the ASME OM Code-2004. Most of the revisions are enhancements such as clarification of valve remote position indication requirements and Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval ball/plug/diaphragm valvetest requirements, and the expansion of risk-informed provisions. However, there was one significant revision in Section 6.1, "Acceptance Criteria," that states that £ motor control center (MCC) testing is acceptable if correlation with W

testing at the MOV has been established. MCC diagnostic testing was not specifically addressed in the original version of OMN-l.

Historically, diagnostic testing of MOVs has been conducted using at-the-valve tests. Although there may be potential benefits of testing conducted at the MCC, the ASME OM Code does not address any method for the correlation of MCC-based measurements to diagnostic test measurements conducted at-the-valve. For these reasons, EGC has excluded the provision for MCC testing from this relief request.

Therefore, the MCC test method will not, be used as an acceptance criterion to determine the operational readiness of MOVs,.

Technical Position The following positions describe how EGC interprets and complies with the various requirements of OMN-l (ASME OMb Code-2006).

1. OMN-1, Section 3.1 allows for the use of testing that was conducted prior to the implementation of OMNT-l if it meets the requirements of the Code Case. EGC intends to utilize the testing credited under its GL 89-10/96-05 responses to satisfy the requirement for a one-time test to verify the capacity of each individual or group of MOV's safety-related design basis requirements.

2. OmN-1, Section 3.2 requires that each MOV be tested during the preservice test period or before implementing inservice inspection. EGC intends to utilize the testing credited under its GL 96-05 response to satisfy this requirement.

3. OMN-l, Section 3.3(b) states'that inservice tests shall be conducted in the as-found condition, and activities shall not be conducted if they might invalidate the as-found condition for inservice testing. CPS maintenance activities that would affect the as found condition of the valve, such as motor operator preventive maintenance or stem lubrication, are typically scheduled to occur in conjunction with the performance of the MOV Periodic Verification Testing, and are performed after as-found testing. Any other activities that could affect the as-found test results are not performed until after the as found testing has been conducted.

4. OMN-l Section 3.3(c) requires the inservice test program to include a mix of static and dynamic MOV performance testing.

CPS has utilized the JOG program's mix of static and dynamic MOV performance testing (i.e., MPR-2524-A) to develop its current MOV testing program. Additionally, CPS will continue to utilize Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 rd Interval VALVE RELIEF REQUEST 2201 Proposed Alternative In Accordance with 10CFR50.55a(a) (3) (i)

1. ASME Code Component(s) Affected All ASME Class 1, 2, and 3 motor-operated valves (MOVs) currently included in the Clinton Power Station (CPS) MOV Testing Program.

2. Applicable Code Edition and Addenda

American Society of Mechanical Engineers (ASME), "Code for Operation and Maintenance of Nuclear Power Plants," 2004 Edition: (ASME OM Code-2004).

3. Applicable Code Requirement

ISTA-3130(b) requires that code cases be applicable to the edition and addenda specified in the test plan.

ISTC-3100 requires that any motor operated valve (MOV) that has undergone maintenance that could affect its performance after the preservice test be tested in accordance with ISTC-3310.

ISTC-3310 requires that a new reference value be determined or the previous reference value be reconfirmed by an inservice test after a MOV has been replaced, repaired, or has undergone maintenance that could affect the valve's performance.

ISTC-3510 requires that active Category A and B MOVs be exercised nominally every 3 months.

ISTC-3521 requires that active Category'A and B MOVs be exercised during cold shutdowns if it is not practicable to exercise the valves at power, or that active Category A and B MOVs be exercised during refueling outages if it is not practicable to exercise the valves during cold shutdowns.

ISTC-3700 requires that valves with remote position indicators be observed locally at least once every 2 years to verify that valve operation is accurately indicated.

ISTC-5120 requires that MOVs be stroke-time tested when exercised in accordance with ISTC-3510.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval

4. Reason for Reqluest In accordance with 10 CFR 50.55a(a) (3) (i), relief is requested from the requirements of the OM Code, Subsection ISTC-3000, excluding ISTC-3600, "Leak Testing Requirements," and the requirements of Subsection ISTC-5120. The proposed alternative would provide an acceptable level of quality and safety.

5. Proposed Alternative and Basis for Use EGC proposes to adopt the requirements of Code Case OMN-l as revised in the 2006 Addenda to the ASME OM Code-2004 in lieu of the performance of stroke time testing and position indication testing as described by ASME OM ISTC 2004. The provision to allow for motor control center testing, as contained in Section 6.1 of-Code Case OMN-1, is excluded from this request.

The NRC amended its regulations to incorporate by reference the 2004 Edition of! the ASME Code for Operation and Maintenance of Nuclear Power Plants on September 10, 2008. In the latest 10 CFR 50.55(a) (b), it states in part, that Regulatory Guide (RG) 1.192, "Operating, and Maintenance Code Case Acceptability, ASME Code", has been approved-for incorporation by reference. In RG 1.192, it states within Table 2, "Conditionally Acceptable OM Code Cases," that the alternative rules of ASME. Code Case OMN-l, "Alternative Rules for Preservice and Inservice Testing of Certain Electric Motor-Operated Valve Assemblies in Light-Water Reactor Power Plants," Revision 0, when applied in conjunction with the provisions for leakage rate testing in ISTC-3600, may be applied with the following provisions:

1. The adequacy of the diagnostic test interval for each valve must be evaluated and adjusted as necessary but not later than 5 years or three refueling outages (whichever is longer) from initial implementation of ASME Code Case OMN-I.

2. When extending the exercise test intervals for high risk MOVs beyond a quarterly frequency, licensees shall ensure that the potential increase in core damage frequency and risk associated with the extension is small and consistent with the intent of the Commission's Safety Goal Policy Statement.

3. When applying risk insights as part of the implementation of OMN-l, licensees must categorize MOVs according to their safety significance using the methodology described in Code Case OMN-3, "Requirements for Safety Significance Categorization of Components Using Risk Insights for Inservice Testing of LWR Power Plants," with the conditions discussed in this regulatory guide or use other MOV risk-ranking methodologies accepted by the NRC on a plant-specific or industry-wide basis with the conditions in the applicable safety evaluations.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 Interval the existing engineering standards, which are consistent with the JOG standards, to justify any changes to the mix of required MOV performance testing. The use of such an evaluation will serve to ensure CPS continues to meet this requirement.

5. OMN-l, Section 3.3(e) requires that Remote Position Indication shall be verified locally during inservice testing or maintenance activities. EGC will continue to verify the operability of each MOV's position indication system as part of each MOV's diagnostic test. In addition, the function of each MOV's position indication system will be verified during the performance of maintenance activities affecting remote position indication.

6. OMN-I, Section 3.3.1(b) requires MOV inservice testing to be conducted every 2 refueling cycles or 3 years '(whichever is longer), if insufficient data exists to determine inservice test frequencies. CPS has sufficient MOV testing data to justify its current testing frequencies, and therefore meets this requirement.) If in the future, modification or replacement results in the necessity to re-baseline a Valve or group of valves, the requirements of OMN-1, Section 3.3.1(b) or 3.7.2.2(c) as applicable, will be followed.

7. OMN-I, Section 6.4.4 requires that calculations for determining the MOV's functional margin are evaluated to account for potential performance-related degradation. The CPS MOV Program, including the corporate MIDAS Software (or similar updated product), takes into account performance-related degradation, to calculate valve margin.

8. The provision of motor control center testing contained in Section 6.1 ("Acceptance Criteria") is excluded from this request ("i.e., Motor control center testing is acceptable if correlation with testing at the MOV has been established").

6. Duration of Proposed Alternative The proposed alternative identified in this relief request shall be utilized during the Third 10-Year IST Interval or until the NRC publishes the version of Code Case OMN-l found in the 2006 addenda to ASME OM Code-2004 in a future revision of Regulatory Guide 1.192.

7. Precedents Similar relief has been approved for LaSalle County Station, Units 1 and 2, Relief Request RV-02, in NRC Safety Evaluation Report, dated September 26, 2007 (Reference 1), and Peach Bottom Atomic Power Station, Units 2 and 3, Relief Request GVRR-l, in NRC Safety Evaluation, dated September 3, 2008 (Reference 2).

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3ta Interval

8. References

1. Letter from R. Gibbs (U.S. NRC) to C. M. Crane (EGC), "Relief Requests for the LaSalle County Station, Units 1 and 2, Third 10-Year Pump and Valve Inservice Testing Program (TAC Nos. MD5988, MD5989, MD5992, MD5993, MD5994, MD5995)," dated September 26, 2007

2. Letter from H. K. Chernoff (U.S. NRC) to C. G. Pardee (EGC), "Peach Bottom Atomic Power Station, Units 2 and 3 - Requests for Relief Associated with the Fourth Inservice Testing Interval (TAC Nos.

MD7461 and MD7462)," dated September 3, 2008 Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 rd Interval VALVE RELIEF REQUEST 2202 Proposed Alternative In Accordance with 10CFR50.55a(a) (3)(ii)

1. ASME Code Component(s) Affected Components:

1B21-F041A, IB21-F041B, 1B21-F041C, IB21-F041D, 1B21-F041F, IB21-F041G, IB21-F041L, IB21-F047A, IB21-F047B, 1B21-F047C, IB21-F047D, IB21-F047F, 1B21-F051B, IB21-F051C, IB21-F051D, 1B21-F051G

Description:

Clinton Power Station (CPS) Main Steam Line Safety Relief Valves (SRVs), Dikkers Valves Model G-471

2. Applicable Code Edition and Addenda

American Society of Mechanical Engineers, "Code for Operation and Maintenance of Nuclear Power Plants," 2004 Edition (ASME OM Code-2004)

3. Applicable Code Requirement

ASME OM Code mandatory Appendix I, "Inservice Testing of Pressure Relief Devices in Light-Water Reactor Nuclear Power Plants," Section 1-1320, "Test Frequencies, Class 1 Pressure Relief Valves," paragraph (a).

This section states that all Class 1 pressure relief valves shall be tested at least once every 5 years starting with initial electric power generation. No maximum limit is specified for the number of valves to be tested within each 5-year 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 test interval for any individual valve shall not exceed 5 years.

4. Reason for Request

10 CFR 50.55a(f) (4) directs a licensee to meet inservice testing requirements for ASME Code Class 1 valves set forth in the ASME OM Code and addenda. The third 10-year inservice testing (IST) interval for CPS is based on the ASME OM Code-2004; specifically, Mandatory Appendix I, which contains requirements to augment the rules of Subsection ISTC, "Inservice Testing of Valves in Light-Water Reactor Nuclear Power Plants."

ISTC-3200, "Inservice Testing," states that inservice testing shall commence when the valves are required to be operable to fulfill their Revision Date: 6/28/2010

ib-i+/- Program P+/-an Clinton Power Station, Unit 1, 3 Interval required function(s). ISTC-5240, "Safety and Relief Valves," directs that safety and relief valves meet the inservice testing requirements set forth in Mandatory Appendix I of the ASME OM Code. Appendix I, Section 1-1320 of the ASME OM Code states that Class 1 pressure relief valves shall be tested at least once every 5 years, starting with initial electric power generation.

The Dikkers Model G-471 SRVs have shown exemplary test history at CPS, as described in Section 5 below. However, given the current 24-month operating cycle for CPS, Exelon Generation Company, LLC (EGC) is required to remove and test fifty percent (i.e., eight of 16) of the SRVs every refueling outage, so that all valves are removed and tested every two.refueling outages. This ensures compliance with the ASME OM Code. requirements for testing Class 1 pressure relief valves every five; years. Approval of extending the test interval to 6.5 years would.reduce-the minimum number of SRVs tested at CPS over three refueling outages by eight.

Without relief, the incremental outage work due.to the inclusion of the eight :additionalSRVs would be contrary to the principles of maintaining exposure to radiation as low as reasonably achievable (ALARA), in that the removal and replacement of an additional eight SRVs over three refueling outages will result in:approximately 5.6 person-rem of additional cumulative radiation exposure. In addition, as discussed below, historical SRV test results for the Dikkers Model G-471 SRVs indicate that the CPS SRVs continue to perform well.

Therefore, this additional cumulative radiation exposure represents al hardship for CPS without a compensating increase in the level of quality or safety.

In accordance with 10 CFR 50.55a, "Codes and standards," paragraph (a) (3) (ii)', EGC requests relief from the five-year test interval requirements of ASME OM Code, ISTC Appendix I Section 1-1320, "Test Frequencies, Class 1 Pressure Relief Valves," paragraph (a), for the Dikkers Model G-471 SRVs at CPS. EGC requests that the test interval be increased from five years to 6.5 years. All other requirements of the ASME OM Code would be met. Compliance with the applicable requirements of the ASME QM Code for these SRVs results in hardship due to unnecessary personnel radiation exposure without a.

compensating increase in the level of quality or safety.

5. Proposed Alternative and Basis for Use For the third 10-year IST interval at CPS, EGC proposes that ASME Class 1 pressure relief valves (i.e., Dikkers Model G-471 SRVs) shall be tested at least once every 6.5 years. A minimum.of 20% of the pressure relief valves will be tested within any 24-month interval and this 20%, shall consist of valves that have not been tested during Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 rd Interval

. the current 6.5 year interval, if they exist.

any individual valve shall not exceed 6.5 years.

The test interval for All SRVs are located in the upper elevations of the CPS drywell. The major contributors to radiation exposure are the main steam lines, including the SRVs, along with High Pressure Core Spray system and Low Pressure Core Spray system piping passing through the area.

Removal of an installed SRV and installation of a replacement-SRV requires installation of scaffolding, removal of insulation and various appurtenances on the SRV, and unbolting the SRV. Once unbolted, the SRV is maneuvered from its location in the upper drywell and lowered to the first elevation and transported through the drywell and containment equipment hatches. Each SRV weighs approximately 3050 pounds, and due to its size, a crew of 'five to seven personnel is required to safely move each valve.;'

EGC has evaluated the historical cumulative radiation exposure at CPS for removal and replacement of SRVs from the last five CPS refueling outages. The work evolutions necessary to remove and replace these valves each refueling outage, which includes the removal and replacement of eight SRVs, are conducted under equivalent radiological conditions and with the same personnel requirements.

This historical cumulative radiation exposure data is provided in Table 1.

. Table 1: Cumulative Radiation Exposure Refueling RF-7 CIR08 CIR09 CiRl0 ClRII Outage Number of SRVs 16 16 8 8 8 Replaced Cumulative Person-Re 8.062 8.837 12.139. 5.325 4.9 Person-Rem Based on this data, EGC has concluded that the expected cumulative radiation exposure to remove and replace a single SRV would be approximately 0.7 person-rem. The outage-specific variability of cumulative radiation exposure is attributed to the location of a particular valve relative to its respective radiation field, the physical configuration of surrounding equipment for a particular valve, and the impact of outage-specific plant configurations.

Therefore, absent the requested relief, replacement of eight incremental SRVs would result in approximately 5.6 additional person-rem over three refueling outages.

The data from the IST history for-SRVs at CPS from 2001 to present Aindicates that 37 of 40, or 92.5% of the SRVs tested have Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval successfully passed the ASME OM Code as-found acceptance criteria of plus or minus 3%. A majority of the valves tested-had been-installed for two operating cycles. Historical data also indicates that the as-found set points for 28 of 40 tests remained within the as-left tolerance of plus or minus 1%.

The as-found test data for the three SRV failures indicates that two of the three SRV test failures did not decrease the level of quality or safety, in that the as-found setpoint for one SRV was within 0.004% of the acceptance criteria, and one SRV exceeded the acceptance criteria in a negative or more conservative direction.

The three SRV failures that occurred were SRVs. that were as-left setpoint tested using nitrogen by. on-site personnel and then as-found setpoint tested by an off-site National Board Code Stamp-certified vendor usihg steam., CPS has since abandoned on-site nitrogen setpoint testing and refurbishment by on-site personnel, and opted to send the SRVs to a certified off-site vendor for as-found and as-left setpoint testing using steam. No. failures have been noted following the transition to steam as the test medium for as-found and as-left testing.

In addition to the historical test results, the current CPS reload ASME overpressure analysis assumes that .two SRVs are out of service, and all of. the operable SRVs open to relieve pressure at the upper ASME Code limit of 1375 psig. This value is greater than the plus 3%

of the SRV setpoint. These conservative assumptions provide additional assurance that the requested relief from the ASME OM Code requirement for the subject SRVs would not result in a decrease in the level of quality or safety.

CPS currently utilizes a National Board Code Stamp-certified off-site vendor to perform as-found and as~-left testing, inspection, and refurbishment of the SRVs. An EGC-approved and qualified procedure is used for disassembly and inspection of the SRVs. This procedure requires that each SRV be disassembled and inspected upon removal from service, independent of the as-found test results. The procedure identifies the critical components that are required to be inspected for wear and defects, and the critical dimensions that are required to be measured during the inspection. If components are found worn or outside of the specified tolerance(s), the components are either reworked to within the specified tolerances, or replaced.

All parts that are defective, outside-of-tolerance, and all reworked/replaced components are identified, and EGC is notified of these components by the off-site vendor. The SRV is then reassembled, the as-left test is performed, and the SRV is returned to CPS.

The ASME OM Sub-Group on Relief Valves developed Code Case OMN-17, "Alternative Rules for Testing ASME Class 1 Pressure Relief/Safety Valves." Code Case OMN-17 allows owners to extend the test interval

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 Interval for safety and relief valves from 60 months to 72 months plus a six-month grace period. This code case imposes a special maintenance requirement to disassemble and inspect each safety and relief valve to verify that parts are free from defects resulting from the time related degradation or service induced wear prior to the start of the extended test interval. The purpose of this maintenance is to reduce the potential for setpoint drift. As noted above, EGC utilizes a National Board Code Stamp-certified off-site vendor to perform as-found and as-left testing, inspection, and refurbishment of the Dikkers Model G-471 SRVs for CPS. EGC has verified that the approved and qualified procedure that is used by the off-site vendor for disassembly, inspection, repair, and testing of the SRVs satisfies the special maintenance requirement specified in Code' Case OMN-17.

All currently installed SRVs at CPS were disassembled,. inspected, repaired, and tested in accordance with the qualified procedure, prior to installation, to verify that parts were free from defects resulting from time-related degradation or maintenance-induced wear.

Therefore, currently installed SRVs at CPS comply with Code Case OMN-17.

Furthermore, each SRV removed from service at CPS will continue to be disassembled, inspected, repaired, and tested in accordance with the qualified procedure prior to reinstallation. Upon approval of the proposed relief request, the test interval (i.e., the frequency for disassembly, inspection, repair, and testing) for any SRV shall not exceed 6.5 years (i.e., 72 months plus a six-month grace period)-.

Based upon the estimated cumulative radiation exposure to comply with the ASME OM Code, coupled with historical SRV test results for Dikkers Model G-471 SRVs at CPS, EGC has concluded that compliance with the ASME OM Code would result in hardship, without a compensating increase in the level of quality or safety.

EGC submitted Relief Request No. 2210 on November 3, 2008 (Reference

1) for the remainder of the Second CPS 10-Year IST interval. The circumstances and basis for this request do not differ from those provided in Reference 1.

6. Duration of Proposed Alternative The proposed alternative identified in this relief request shall be utilized during the Third 10-Year IST Interval.

7. Precedents In Reference 2, the NRC reviewed and approved relief requests for both Dresden Nuclear Power Station (DNPS), Units 2 and 3, and Quad Cities Nuclear Power Station (QCNPS), Units 1 and 2 to extend their main steam safety valve (MSSV) test interval duration for individual Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval valves to 6.5 years for the remainder fourth 10-year IST interval.

In Reference 3, the NRC reviewed and approved a relief request-for Susquehanna Steam Electric Station (SSES), Units 1 and 2, to extend the MSSV test interval duration for individual valves to six years W for the entire third 10-year IST interval. In Reference 4, the NRC reviewed and approved a relief request for Nine Mile Point Nuclear Power Station, Unit 2 (NMP2) to extend the MSSV test interval duration for individual valves to three refueling outages or approximately six years for the entire third 10-year IST interval.

In all of these approvals, the NRC allowed for a total installed interval of at least six years.

In Reference 1,: EGC requested relief for CPS similar to that approved in Reference 2. This request was for the Second CPS IST Interval.

This proposed relief request is consistent with the.DNPS, QCNPS, SSES and NMP2 precedents, in that it will establish a test interval that would enable EGC to maintain a Dikkers Model G-471 SRV in service for three operating cycles, while also allowing adequate time to transport, test, and refurbish an SRV, at an external facility prior to reinstallation.

8. References

1) Letter from Mr. J. L. Hansen, (Exelon Generation Company, LLC) to the U. S. NRC, "Request for Relief from ASME OM Code 5-year Test Interval for Safety Relief Valves (Relief Request No. 2210)," dates November 3, 2008 (Accession Number ML083090066)

2) Letter from U. S. NRC to Mr. Charles G. Pardee (Exelon Generation Company, LLC), "Dresden Nuclear Power Station Units 2 and 3 -

Relief Request No. RV-02C from 5-Year Test Interval for Main Steam Safety Valves (TAC Nos. MD8150 and MD8151) and Quad Cities Nuclear Power Station, Relief Requests No. RV-30E and RV-30F from 5-Year Test Interval for Main Steam Safety Valves (TAC Nos. MD6682, MD6683, MD8241, and MD8242)," dated June 27, 2008

3) Letter from U. S. NRC to Mr. B. L. Shriver (PPL Susquehanna, LLC),

"Susquehanna Steam Electric Station Units 1 and 2 -Third 10-year Interval Inservice Testing (IST) Program Plans (TAC Nos. MC3382, MC3383, MC3384, MC3385, MC3386, MC3387, MC3388, MC3389, MC4421, MC4422)," dated March 10, 2005

4) Letter from U. S. NRC to Mr. J. H. Mueller (Niagara Mohawk Power Corporation), "Nine Mile Point Nuclear Power Station, Unit No. 2 -

Alternative to American Society of Mechanical Engineers Boiler and Pressure Vessel Code (ASME Code) Regarding Inservice Testing of Main Steam Safety/Relief Valves (TAC No. MB0290)," dated April 17, 2001 Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval RAI 2202-001 Request No. 2202 proposes to extend the test interval for the main steam line safety relief valves to 6.5 years and references Code Case OMN- 17, "AlternativeRules for Testing ASME Class 1 Pressure Relief/Safety Valves," as a basis for extending the test interval. Code Case OMN- 17 allows owners to extend the test interval for safety relief valves from 5 years with no grace period to 6 years plus a 6-month grace period. It is preferable to the NRC staff to be consistent with the provisions in Code Case OMN- 17. Please discuss if a 6 year plus a six month grace period safety relief valve test interval is acceptable in lieu of a 6.5 year test intervalwith no grace period.

Response

Clinton Power Station (CPS) would consider a six year frequency with the allowance for a six month grace period an acceptable alternative to the 6.5 year frequency with no grace period that was proposed in 10 CFR 50.55a Request Number 2202. The six year interval with six month grace period will continue to reduce the number of Safety Relief Valves (SRVs) that are tested over three refueling outages and maintain the site's radiation exposure as low as reasonably achievable.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval ATTACHMENT 5 COLD SHUTDOWN JUSTIFICATIONINDEX 4 CSJ-101 1B21-F022A, 1B21-F022B, 1B21-F022C, 1621-F022D, 1B21 -F028A, 1B21 -F028B, 1 B21 -F028C, 1B21 -F028D:

Main Steam Isolation Valves (MSIV's)

CSJ-102 1RE019 & 1RFO19 - Drywell Isolation Valve Testing Impractical on Quarterly Basis CSJ-103 1SA032 Service air inboard isolation valve CSJ-104 1VRO06A/B, 1VRO07A/B, 1VR035, 1VR036, 1VR040, 1VR041 1VQ003 Containment HVAC valves CSJ-105 1E12-F050A, 1E12-FO50B, 1E51-F066 PIV check valves CSJ-1 06 1 1A005, 11A006, 11A007, 11A008:, Instrument Air System Isolation Valves CSJ-107 1VQ004A, 1VQ004B, 1VRO01A, 1VRO01 B: Containment Ventilation and Purge CIV's CSJ-108 1E31-F014,15,17,18; 1B33-F019,20; 1E51-F063, 64 Containment and/or Drywell Isolation Valves CSJ-109 1E12-F019: RHR to RCIC Head Spray Check Valve CSJ-110 1 E51 -F065: RCIC Injection Line Check Valve CSJ-111 1 E12-F042A, 1E12-F042B, 1E12-F042C, 1E21-F005, 1E22-F004, 1E51-F013: RCS PIVs CSJ-1 12 1G33-FOO1, 1G33-F004: Reactor Water Cleanup system CIVs CSJ-1 13 1 IA01 2A, 1 IA01 3A: Instrument Air Containment Isolation valves CSJ-1 14 1CM002B, 1E51 -F377B, 1 SM008: Excess Flow Check Valves CSJ-115 1B33-F019, 1B33-F020: RR Sample Line Drywell Isolation Valves CSJ-1 16 1PS004/9/16/22/31/34/37/56/70: PASS Inboard Containment Isolation Valves.

CSJ-117 1B21 -F016/19: Main Steam Line Drain Valves Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 Interval ATTACHMENT 6 COLD SHUTDOWN JUSTIFICATIONS Revision Date: 6/28/2010

+/-iT i-rogram F+/-an Clinton Power Station, Unit 1, 3rd Interval Cold Shutdown Justification CSJ-101 Valve Number System Safety Class Category 1B21 -F022A MS 1 A 1B21 -F022B MS 1 A 1B21 -F022C MS 1 A 1B21 -F022D MS 1 A 1B21 -F028A MS 1 A 1B21 -F028B MS 1 A 1B21 -F028C MS 1 A 1B21 -F028D MS 1 A Function: Main Steam Isolation Valves (MSIV's)

Basis for Full stroke exercising the Main Steam Isolation Valves for the purposes of Justification: meeting Inservice Testing Program requirements,,is defined as verifying that the valves will fully close in 3 to 5 seconds. Performing this testing quarterly during normal operation would increase the possibility of main

.. steam line isolation due to high flow in the other lines and could cause a Reactor scram at full power.

These valves will receive a partial-stroke test as described above on a quarterly basis, and will be full-stroke exercised during Cold Shutdowns.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval Cold Shutdown Justification CSJ-102 Valve Number System Safety Class Category 1RE019 RE 2 B 1RF019 RF 2 B Function: 1 RE019 - Drywell RE Inboard Isolation Control Valve - This valve must close to isolate the drywell from the equipment drain system during emergency and accident conditions.

1RF01 9 - Drywell RF Inboard Isolation Control Valve - This valve must close to isolate the drywell from the floor drain water system during emergency and accident conditions.

Basis for These' normally open air operated valves have a safety function to provide Justification: drywell isolation in the event of an accident. They are normally open to allow pumping down and processing the drywell floor and equipment drains sumps during normal operation. Failure of these inaccessible valves during the quarterly test could result in an unnecessary shutdown since the drywell floor/equipment drain sumps would not be able to be pumped down for processing.

Based on the above, these valves are impractical to test on a quarterly bases as per NUREG 1482.

These valves have no open safety function.

The Drywell Isolation valves 1RE01 9 and1 RF01 9 will be fail safe tested to the closed position during Cold Shutdown.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval Cold Shutdown Justification CSJ-103 Valve Number System Safety Class Category 1SA032 SA 2 B Function: Valve 1SA032 is the drywell Service Air Inboard Isolation Valve. It must close to isolate the drywell from the service air system during emergency and accident conditions requiring drywell isolation.

Basis for Valve 1SA032.is the drywell Service Air inboard Isolation Valve. It Justification: is required. to automatically close within 10 seconds. upon receipt of an automatic isolation signal to isolate the drywell from the service air system. It is the drywell isolation valve for Penetration 1MD-059

.[P&ID M05-1048 Sheet 6]. This valve fails closed on loss of air or electrical power and may be remotely closed by-the operator. It forms a part of the drywell boundary. There are requirements that limit total drywell bypass leakage. There are, however, no specific requirements for seat leakage for individual valves [ITS B 3.6.5.3].

This valve opens to provide a flow path for Service Air to the drywell hose stations. This is not a safety function and is not required

-during normal power operation. During normal power operation the drywell is inaccessible and the hose stations this valve supplies are not used.

The closing safety function for 1SA032 is limited to operating modes 1, 2 and 3. (Ref. Tech Spec 3.6.5.3): Since Service Air through this valve is not required during Modes 1, 2 and 3, the only time it is cycled is during quarterly stroke time testing. Exercising this valve increases the potential for air leakage inside the drywell with subsequent drywell pressurization. This could increase the frequency for venting the drywell resulting in cycling of the hydrogen mixing compressors and unnecessarily reduce their life expectancy.

Step 8.3, Drywell Venting, of CPS procedure 3316.01, states that each hydrogen mixing compressor should not be run for more than 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months per month to prevent exceeding the expected 40 year life runtime. In addition, leakage resulting from stroke time testing could require a plant shutdown to implement repairs. This concern would be exacerbated by other conditions inside the drywell also contributing to drywell pressurization that were already existent at the time of the stroke time test.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 Interval The possibility of stroke time testing resulting in air leakage is documented on IR 519897, issued on 8/14/06. IR 519897 identified a condition of a potential air leak on one or both air operated drywell isolation valves 1VQ002 and 1VQ003. In this event, the frequency of drywell venting increased following IST surveillance testing in accordance with 9061.03C005. The issue report identified that following valve stroking the venting frequency increased from once every 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months to once every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . A number of IRs have been generated over the past year as a result of the hydrogen mixing compressors exceeding the 3 hour3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months run time identified in procedure 3316.01.

In addition to the above, instrument air valve 1 IA818 in the supply line to the actuator will be maintained in the closed during MODEs 1, 2 and 3. The solenoid valve to the actuator will remain energized because 1SA032 shares a hand switch with containment isolation valve 1SA029, which is maintained in the open position during normal power operation. Since the actuator spring closes, isolating air to its actuator will not impact the closing safety function for the valve. Therefore although 1SA032 will not be secured in its closed safety position, it is expected it will be in its closed safety position if called upon to perform is closing safety function.

Paragraph 2.4.5 of NUREG 1482, Rev. 1, identifies impractical conditions justifying test deferrals include those conditions which could cause an unnecessary plant shutdown, cause unnecessary cycling of equipment or unnecessarily reduce the life expectancy of the plant systems and components. Based on the above discussion and NUREG 1482 quarterly stroke time testing of 1SA032 is considered impractical.

Valve 1SA032 will be exercise tested closed during Cold Shutdown.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 Interval Cold Shutdown Justification CSJ-104 Valve Number System Safety Class Category 1VRO06A/B, VR 2 A 1VRO07A/B, 1VR035, 1VR036, 1VR040 1VR041 1VQ003 VQO 2 B Function: Valve 1SA032 is the drywell Service Air Inboard Isolation Valve. It

-must close to isolate the drywell from the service air system during emergency and accident conditions requiring drywell isolation.

.1VRO06A. - Continuous CNMT HVAC Supply Outboard Isolation -

This valve must close to isolate containment from the continuous containment purge system during emergency and accident conditions.

1VRO06B'.- Continuous CNMT HVAC Supply Inboard isolation -

'This valve must close to isolate containment from the continuous containment purge system during emergency and accident conditions.

1VRO07A - CCP Outboard Exhaust Isolation Valve - This valve must close to isolate containment from the continuous containment purge system during emergency and accident conditions.

1VRO07B - CCP Inboard Exhaust Isolation Valve - This valve must Close to isolate containment from the continuous containment purge system during emergency and'accident conditions.

1VR035 - 1PDCVR020 Air Line Isolation Valve - This.valve must close to isolate containment from the containment building ventilation system during emergency and accident conditions.

1VR036 - 1 PDCVR020 CNMT Purge Air Line Isolation Valve - This valve must close to isolate containment from the containment building ventilation system during emergency and accident conditions.

1VR040 - CCP Air Line Isolation Valve - This valve must close to isolate containment from the containment building ventilation system during emergency and accident conditions.,

1VR041 - ITSVR166 Isolation Valve - This valve must close to Revision Date: 6/28/2010

Clinton Power IST Program Station, Plan Unit 1, 3 rd Interval isolate containment from the containment building ventilation system during emergency and accident conditions.

1VQ003 - Exhaust Outboard Drywell Isolation Valve - This valve must close to isolate the drywell from the primary containment purge system during emergency and accident conditions.

Basis for Valves 1VRO06A/B are containment isolation valves on the CCP Justification: inlet to containment. They are normally open to support continuous containment purge (CCP). CCP is used during normal operation to maintain primary to secondary containment differential pressure within Tech Spec limits. A failure of one of them to close during stroke time testing would require the penetration to be administratively isolated, resulting in loss of CCP System function.

Likewise a failure of the valve to open following stroke time testing would result in the loss of CCP System function.

Valves 1VRO07A/B are normally open containment isolation valves on the outlet side of the CCP System. A failure of one of them to close during stroke time testing would require the penetration to be administratively isolated, resulting in loss of system function.

Likewise a failure of the valve to open following stroke time testing would result in the loss of CCP System function.

Valves 1VR036 and 1VR037 are solenoid valves that provide containment isolation for instrument air lines supplying valves 1VRO06A/7A. Valves 1VR035 and 1VR040 are solenoid valves that provide containment isolation for instrument air lines supplying valves 1VR006B/7B. A failure of one of these valves during testing would require the penetration to be administratively isolated resulting in one of the 1VRO06A/B or 1VRO07A/B valves closing due to loss of air. Consequently failure of one of these valves could result in loss of the CCP System function.

1VQ003 is a normally open drywell isolation valve. This valve is required to automatically close on a drywell isolation signal. This valve is located in the main flow path for the CCP System. If the valve failed closed during stroke time testing, CCP operation would be interrupted until the valve could be repaired and reopened. The inboard CCP drywell isolation valves are maintained in the closed position during MODES 1, 2 and 3.

Loss of the CCP system function could result in a plant shutdown.

CCP is used during normal operation to maintain primary to Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 Interval secondary containment differential pressure within Tech Spec limits. Tech Spec 3.6.1.4 requires the primary containment to secondary containment differential pressure to be > -0.25 psid and

< 0.25 psid. If these differential pressure limits are not maintained, there is a 1 hr time limit for restoring them. If the limits are not restored within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , there is a 12 hr time limit for being in MODE 3 and a 36 hr time limit for being in MODE 4. According to Operations personnel there is no standard alternate method for returning the differential pressure to within limits and it may be difficult to maintain the Tech Spec required primary containment to

-secondary containment differential pressure if the CCP System is not available. Therefore stroke time testing could result in an unnecessary plant shutdown.

As'such, these valves are impractical to test on a quarterly basis

,per paragraph 2.4.5 of NUREG 1482 because testing them could result in an unnecessary plant shutdown..

The valves included in this cold shutdown justification will be exercise tested closed during Cold Shutdown Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 d Interval Cold Shutdown Justification CSJ-105 Valve Number System Safety Class Category 1El2-FO50A RH 2 A/C 1El 2-FO50B RH 2 A/C 1E51 -F066 RI 1 A/C Function: Reactor Coolant system Pressure Isolation Valves (PIV's)

Basis for These check valves are Reactor Coolant Pressure Boundary PIV's. They Justification: are required to close to limit leakage between the high pressure Reactor Coolant System and connected systems (RHR and RCIC) in which LOCA.

It is not practical to perform a full or partial exercise test of these valves quarterly during normal operation.. Opening these valves at power would remove one of the two valves in its respective line from performing its PIV function. If the second valve was in a degraded condition, this could create a pressure spike throughout the system, since, each system is maintained filled and pressurized. Depending on the severity of the pressure spike, this could result in an inter-system LOCA with the potential for release of reactor coolant outside the primary containment.

Alternate Test: Closure for these valves will be performed during cold shutdown conditions. Additional assurance of proper closure is provided by performance of leak rate testing during refueling outages.

NOTE: Bi-directional exercising in the non-safety related open direction is performed at the same frequency for valves 1El 2-FO50A and B.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 rd Interval Cold Shutdown Justification CSJ-106 Valve Number System Safety Class Category 11A005 IA 2 A 1IA006 IA 2 A 1IA007 IA 2 B 1IA008 IA 2 B Function: Instrument Air System Isolation Valves Basis for These are the Containment and Drywell Isolation Valves for the Instrument Justification: Air System. Exercising these valves quarterly during normal operation would interrupt the air supply to IA System loads Inside Containment, including the MSIV and SRV accumulators, several safety-related air operated isolation valves, and various pneumatic instruments. Repeated pressure fluctuations or the inability to reopen one of these valves following testing would cause a Reactor scram and forced shutdown of the Plant.

The pneumatic actuators for these valves are designed to provide full-stroke capability only; partial-stroke testing is not available.

Alternate Test These valves will be exercise tested to the closed position during Cold

Shutdowns.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval Cold Shutdown Justification CSJ-107 Valve Number System Safety Class Category 1VQ004A VQ 2 A 1VQ004B VQ 2 A 1VRO01A VR 2 A 1VRO01B VR 2 A Function: 1VQ004A/B - These drywell purge containment isolation valves close to isolate containment from the primary containment purge system during emergency and accident conditions.

1VRO01A/B - These valves close to isolate containment from the containment building ventilation system during emergency and accident conditions.

Basis for These are 36-inch air-operated butterfly Containment Isolation Valves in Justification: the Containment Ventilation and Containment/Drywell Purge Systems.

They are required by Technical Specification 3.6.1.3 to be maintained closed in Modes 1, 2 and 3, except during specific, infrequent evolutions and are normally tagged shut. The safety function of these valves is to close for Containment isolation; they receive several isolation signals. In addition, these valves are Secondary Containment valves and are required to be operable in modes 4 and 5 when Secondary Containment is required.

Opening these valves for quarterly testing takes them out of their normal safety-related position and results in unnecessary cycling of equipment that could lead to damage or shortened life of the valve seat resilient seal.

(ref: U-601736, L30-90(09-27)-1A.120). In addition, the Technical Specifications recognize the potential for resilient seal damage due to cycling these valves by requiring an LLRT of the affected penetration within 92-days after they are cycled. Due to the limitations on use for these valves, it is likely that the only time these valves would be cycled during power operation would be for stroke time testing. As a result, quarterly testing of these valves during power operation is considered impractical as per NUREG 1482. An appropriate level of testing will be maintained because stroke time testing during power operation, in accordance with ASME Code OM-1 0, will be required for these valves prior to use if it has been more than 92 days since they were last stroke time tested.

Revision Date: 6/28/2010

ICbtT PowIe ga[ UnI ,L 3lI ev Clinton Power Station, Unit 1, 3 rd Interval Alternate Test: These valves will be full-stroke exercise tested to the closed position during Cold Shutdowns. If these valves are to be opened during Modes 1, 2 and 3, and have not been full-stroke exercise tested to the closed position in the previous 92 days, the valves will be full-stroke exercised individually to the closed position to verify their ability to reposition in order to maintain containment integrity prior to being used.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval Cold Shutdown Justification CSJ-108 Valve Number System Safety Class Category 1E31-F014, F015, LD 2 B F017, F018; 1E51-F063, 1E51- RI 1 A F064 Function: Containment and/or Drywell Isolation Valves Basis for Valves 1E31 -F014/15/17/18 are normally open, solenoid actuated, drywell Justification: isolation valves. Should a valve fail during stroke time testing the penetration would be isolated per T.S. 3.6.5.3 and the plant would be forced to operate under the burden of a TS LCO and abnormal system configuration and associated compensatory actions. In addition, 1E31 -

F01 4 and 1 E31 -FO1 8 are located in the Drywell and should they fail, they cannot be repaired without shutting the plant down.

Valves 1 E51 -F063 and 1 E51 -F064 are normally opened motor operated containment isolation valves. They are the RCIC turbine steam supply valves. A failure of one of these valves during exercise testing would result in a loss of the RCIC function and could require the plant to be shutdown.

Based on the above discussions, stroking of these valves on a quarterly basis can result in unnecessary plant shutdown or unnecessary challenge to plant safety systems should the valves fail in the non-conservative position (i.e. a primary containment isolation valve fail in the open position requiring isolation of the containment penetration).

Alternate Test: These valves will be full-stroke exercised during Cold Shutdowns.

Revision Date: 6/28/2010

+/-_s'r program sian Clinton Power Station, Unit 1, 3rd Interval Cold Shutdown Justification CSJ-109 Valve Number System Safety Class Category 1E12-F019 RH 1 C Function: RHR to RCIC Head Spray Check Valve Basis for This is the RHR to RCIC Head Spray check valve. It is located within a Justification: portion of the Reactor Coolant Pressure Boundary which is bounded by Pressure Isolation Valves (PIV's) 1El 2-F023, 1 E51 -F01 3 and 1E51 -F066.

.,The RHR Head Spray line is used during normalcooldown of the Reactor, but is not required to achieve the Cold Shutdown condition.

In order to exercise this valve to the open position, flow from RHR Pump 1El 2-CO02B must be injected through the RHR Head Spray line via PIV 1El 2-F023. During normal operation, 1El 2-F023 is interlocked closed until pressure drops below the point at which Shutdown Cooling may be initiated. Therefore, this valve cannot be exercised during normal operation.

This valve will be full-flow exercised during Cold Shutdowns.

NOTE: Bi-directional exercising in the non-safety related open direction is performed at the same frequency.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit , 3 rd Interval Cold Shutdown Justification CSJ-110 Valve Number System Safety Class Category 1E51-F065 RI 1 C Function: RCIC Injection Line Check Valve Basis for This valve opens to admit RCIC flow into the Reactor Vessel when Justification: required. It also opens to admit flow from the RHR to RCIC Head Spray line during normal Reactor cooldown; this function, however, is not required to achieve Cold Shutdown.

This valve is located within the Reactor Coolant Pressure Isolation boundary. No credit is taken, however, for this valve to function as a Containment Isolation Valve or Reactor Coolant Pressure Isolation Valve (PIV).

Exercising this valve with flow at power would require injecting cold water from the RCIC System into the dome of the Reactor Vessel via the Head Spray line. This would result in significant thermal and reactivity transients, potentially causing a Reactor scram. Exercising this valve with a mechanical exerciser during normal operation is impractical because the potential exists for differential pressure equivalent to Reactor pressure across the disc. Exercising the valve under this condition could result in damage to the valve or in a pressure spike to portions of the RCIC and RHR Systems.

This valve will be exercise tested with flow on a Cold shutdown frequency while RHR is providing Head Spray to the Reactor Vessel for Shutdown Cooling.

NOTE: Bi-directional exercising in the non-safety related closed direction is performed at the same frequency.

Revision Date: 6/28/2010

LSI vrogram i+/-an Clinton Power Station, Unit 1, 3rd Interval Cold Shutdown Justification CSJ-111 Valve Number System Safety Class Category 1E12-F042A RH 1 A 1El 2-F042B RH 1 A 1El 2-F042C RH 1 A 1E21 -F005 RI 1 A 1 E22-F004 HP 1 A 1E51-F013 LP 1 A Function: Reactor. Coolant system Pressure Isolation Valves (PIV's)

Basis for

These valves are Reactor Coolant Pressure Boundary PIV's. They are Justification: required to limit leakage between the high pressure Reactor Coolant System and connected systems (RHR, LPCS, HPCS, and RCIC) to prevent an intersystem LOCA. They are also required to open to place or maintain the reactor in Cold Shutdown or to mitigate the consequences of an accident. It is not practical to perform a full or partial exercise test of these valves quarterly during normal operation based on the following considerations:

1) Opening any Reactor Coolant PIV at power would remove one of the two valves in its respective line from performing its PIV function. If the second valve was in a degraded condition, this could create apressure spike throughout the system, since each system is maintained filled and pressurized. Depending on the severity of the pressure spike, this could result in an inter-system LOCA with the potential for release of reactor coolant outside the primary containment.

2) Several MOV's in the above list have operators which are not designed to open against full differential pressure when the Reactor is at power.

Furthermore, these valves are interlocked to prevent opening them until pressure drops below a preset value.

3) The shutoff head of the RHR and LPCS Pumps is below the normal operating pressure of the Reactor Coolant System.

Alternate Test These valves will be full stroke exercise tested during cold shutdowns.

Additional assurance of proper closure is provided by performance of leak rate testing during refueling outages.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval Cold Shutdown Justification CSJ-112 Valve Number System Safety Class Category 1G33-FOO1 RT 1 A 1G33-F004 Function: Reactor Water Cleanup System Containment Isolation Valves Basis for These are the Containment Isolation Valves in the Reactor Water Cleanup Justification: (RT) System. They isolate automatically on receipt of several Containment and system isolation signals. Exercising these valves requires the RT System to be taken out of service. Isolating the system, performing the testing, and restoring the system to service during power operations is a complex evolution and involves a significant amount of time. The RT System maintains the water quality limits of the Reactor Coolant within ORM limits. Sudden changes in temperature or flow could result in significant water chemistry changes which may require more time than is permitted by the applicable action statements. In addition, instances of resin intrusion into the RPV have occurred at other Plants while attempting to test RT System valves at power.

Alternate Test. These valves will be full-stroke exercised during Cold Shutdowns.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 rd Interval Cold Shutdown Justification CSJ-1 13 Valve Number System Safety Class Category 1IA012A IA 2 A 11A013A IA 2 A Function: Instrument Air Containment Isolation Valves Basis for These valves are the outboard Containment Isolation Valves for the Justification: instrument air line connecting the ADS valves with their air back-up bottles.

1IA012A supplies the Div 1 ADS valves and 1IA013A supplies the Div 2 ADS valves. A failure of one of these valves to open during exercise testing would result in the associated division of ADS backup air bottles becoming inoperable. The inboard containment isolation valve is check valve that is located in the drywell and is not accessible when the plant is on line. In addition, there are no valves located between the inboard and outboard isolation valves that could be shut in order to allow repair that required disassembly of 1 IA01 2A/1 3A, Similarly a failure of one of these valves to close during exercise testing would require closing of the manual valve outside containment. Since the manual valve is not located between the outboard containment isolation valve and the containment, in body repair of the containment isolation valve could not be implemented with the plant on line.

For both of the above scenarios, the associated division of ADS back up air supply would be out of service until repairs could be completed. A 30-day allowable outage time is a recommended maximum out-of-service time for removing one ADS backup air supply during plant operation (Ref.

Paragraph 6.3 of CPS Procedure 3101.01, Main Steam (MS, IS AND ADS).

Based on the above discussion, exercise testing for valves 1 IA01 2A and 1IA01 3A is considered impractical when the plant is on line.

Alternate Test: These valves will be full-stroke exercised during Cold Shutdowns.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval Cold Shutdown Justification CSJ-1 14 Valve Number System Safety Class Category 1CM002B CM 2 C 1 E51 -F377B RI 2 C 1SM008 SM 2 C Function: Excess Flow Check Valves Basis for These are excess flow check valves in low pressure systems. They Justification: are required to close to eliminate a level rise in the instrument standpipe. They are required to reopen to allow operation of the instruments in their associated line.

Testing these valves during normal plant operation requires isolating numerous safety-related instruments associated with scram logic, ECCS activation and accident monitoring. This involves filling, venting and draining operations, breaking connections to the instruments, setting up a test rig, introducing water flow through lines with high potential for contamination, then restoring the instrument to service.

These instruments have the potential for scramming the Reactor, causing an ECCS actuation, or initiating a Containment Isolation signal.

In addition, testing these valves during Plant operation or Cold Shutdown results in numerous LCO entries.

These valves will be full-stroke exercised during refueling outages Alternate Test: when they are not required to perform their protective functions.

Open and close exercising is performed at the same frequency.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3r Interval Cold Shutdown Justification CSJ-115 Valve Number System Safety Class Category 1B33-FO1 9 RR 2 B 1 B33-F020 Function: Valves 1B33-FO1 9 and 1 B33-F020 are the reactor sample inboard and outboard drywell isolation valves for the reactor sample station.

'1 B33-FO1 9 is the inboard isolation valve and 1B33-F020 is the outboard Isolation valve. These valves close to isolate the drywell under accident conditions.

Basis for Valves 1 B33-FO1 9 and 1B33-F020 are the reactor sample station Justification: drywell isolation valves. They closed automatically upon receipt of an automatic isolation signal to isolate the drywell. They are the drywell isolation valves for Penetration 1MD-013 [P&ID M05-1072 Sheet 1]. They close on loss of air or electrical power and may be remotely closed by the operator. They form part of the drywell boundary. There are requirements that limit total drywell bypass leakage. There are, however, no specific requirements for seat leakage for individual valves [ITS B 3.6.5.3].

These valves are normally open to provide a flow path for sampling the reactor coolant. This is not a safety function and sampling through this line is not required during accident conditions. During normal power operation 1B33-FO19 is inaccessible.

The closing safety function for these valves is limited to operating modes 1, 2 and 3. (Ref. Tech Spec 3.6.5.3) Since they are maintained open during power operation, the only time they are cycled is during quarterly stroke time testing. Exercising 1B21 -FO1 9 increases the potential for air leakage inside the drywell with subsequent drywell pressurization. 11B33-FO19 would also be required to be stroked closed if 1B33-F020 failed open during stroke time testing, again creating a potential for air leakage inside the drywell. Air leakage inside the drywell could increase the frequency for drywell venting resulting in cycling of the hydrogen mixing compressors and unnecessarily reduce their life expectancy.

Step 8.3, Drywell Venting, of CPS procedure 3316.01, states each hydrogen mixing compressor should not be run for more than 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months per month to prevent exceeding the expected 40 year life runtime. In addition, leakage resulting from stroke time testing Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 rd Interval could require a plant shutdown to implement repairs. This concern would be exacerbated by other conditions inside the drywell also contributing to drywell pressurization that were already existent at the time of the stroke time test.

The possibility of stroke time testing resulting in air leakage is documented on IR 519897, issued on 8/14/06. IR 519897 identified a condition of a potential air leak on one or both air operated drywell isolation valves 1VQ002 and 1VQ003. In this event, the frequency of drywell venting increased following IST surveillance testing in accordance with 9061.03C005. The issue report identified that following valve stroking the venting frequency increased from once every 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months to once every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

Paragraph 2.4.5 of NUREG 1482, Rev. 1, identifies impractical conditions justifying test deferrals include those conditions which could cause an unnecessary plant shutdown, cause unnecessary cycling of equipment or unnecessarily reduce the life expectancy of the plant systems and components. Based on the above discussion and NUREG 1482 quarterly stroke time testing of 1B33-F019 and 1B21-F020 is considered impractical.

Alternate Test: Valves 1B33-FO19 and 1B33-F020 will be exercise tested during Cold Shutdown.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 Interval Cold Shutdown Justification CSJ-1 16 Valve Number System Safety Class CategorV 1 PS004/9/16/22/ PS 2 A 31/34/37/43A/43B/

56/70 Function: Valves 1PS004/9/16/22/31/34/37/43A/43B/56/70 are inboard primary containment isolation valves. They are installed in the Post Accident Sampling System. They automatically close on a low reactor water signal or a high drywell pressure signal. Additionally, they can be manually initiated from the control room. The valves also close on a loss of power.

Basis for Failure of one of these valves to close during stroke time testing will Justification: require the corresponding outboard isolation valve to be closed and power removed. The electrical design for the outboard isolation is such that when power is removed the Division 1 diesel generator starting air compressors will be shunt tripped. Therefore quarterly stroke time testing for the above valves is considered impracticable.

Alternate Test: Valves 1PS004/9/16/22/31/34/37/56/70 will be stroke time tested during cold shutdowns.

Revision Date: 6/28/2010

-- - ' j\.L G.1LL r -CiLI Clinton Power Station, Unit 1, 3rd Interval Cold Shutdown Justification CSJ-1 17 Valve Number System Safety Class Category 11B21-F016 MS 1 A 1B21-F019 MS 1 A Function: Valves 1B21-F016 and 1B21-F019 are the containment isolation valves for the main steam line drain, Penetration 1MC-045. 1B21 -

F01 6 is the inboard isolation valve and 1B21 -FO1 9 is the outboard isolation valve. These valves are required to close for an event requiring containment isolation for the main steam lines.

Basis for Valves 1B21-F016 and 1B21-F019 are containment isolation valves Justification: that are inaccessible during power operation (they are located in the drywell and the auxiliary building steam tunnel, respectively). If one of them failed open during exercise testing, the other valve would be required to be closed to maintain containment. As a result, the main steam drain line function would be lost. The same result would occur if one of the valves failed in the closed position during exercise testing. 1B21-F016 and 1B21-F019 in the main steam drain line are used to provide a method for pressure control following a reactor scram. In addition they can be used to reduce the pressure across the MSIVs so the MSIVs can be opened. The ability to use the steam line drain to perform these functions would be lost if one of these valves failed during IST exercise testing.

In addition to the above, if a packing leak were to occur during valve exercising the plant would be required to be placed in cold shutdown in order to effect repair.

Based on the above, quarterly exercising of valves 1621 -FO1 6 and 1B21-F019 is considered impractical.

Alternate Test Valves 1B21 -F016 and 1B21 -F019 will be exercise tested closed during Cold Shutdown.

Revision Date: 6/28/2010

Clinton Power Station, Unit 1, 3"' Interval ATTACHMENT 7 REFUEL OUTAGE JUSTIFICATION INDEX RFJ-001 1C41 -F006: Standby Liquid Control System Injection Check Valve RFJ-002 1E51 -F066: RCIC Injection Check Valve RFJ-003 1B21 -FO1 OA, 1B21 -FO1 OB, 1B21 -F032A, 1B21 -F032B: Feedwater System Containment Isolation Valves RFJ-004 1B21 -F041 B, 1B21 -F041C, 1B21-F041 D, 1B21 -F041 F, 1 B21 -F047A, 1B21 -F047C, 1B21-FO51G: Automatic Depressurization System (ADS) Valves RFJ-005 1 El 2-F041 A, 1 El 2-F041 B, 1El 2-F041 C, 1 E21 -F006, 1E22-F005: Reactor Coolant System Pressure Isolation Valves (PIV's)

RFJ-006 1B21 -F024A, 1B21 -F024B, 1B21 -F024C, 1B21 -F024D, 1 B21 -F029A, 1B21 -F029B, 1B21 -F029C, 1B21 -F029D: Instrument Air Supply Check Valves to MSIV Accumulators RFJ-007 1B21 -F036A, 1B21 -F036F, 1 B21 -F036G, 1B21 -F036J, 1B21 -F036L, 1B21 -F036M, 1B21 -F036N, 1B21 -F036P, 1B21 -F036R, 1B21 -F039B, 1 B21 -F039C, 1B21 -F039D, 1 B21 -F039E, 1B21 -F039H, 1B21 -F039K, 1B21 -F039S: Instrument Air Supply to SRV Accumulator Check Valves 0 RFJ-008 1B21 -F433A, 1 B21 -F433B: IA Supply Check Valves to FW Check Valve Accumulators RFJ-009 1C11-114, 1C11-115, 1C11-126, 1C11-127, 1C11-138, 1C11-139: Control Rod Drive System Hydraulic Control Unit Valves RFJ-010 1C11 -F376A, 1C11 -F376B, 1C11 -F377A, 1C11 -F377B: RV Level Instrumentation Reference Leg Keep Fill Check Valves RFJ-01 1 1C41-F033A, 1C41-F033B: Standby Liquid Control Pump Discharge Check Valves RFJ-01 2 1C41 -F336: Standby Liquid Control System Injection Check Valve RFJ-013 1CM066, 1CM067 Excess Flow Check Valves RFJ-01 4 1 1A042A, 11A042B: Instrument Air Supply Header to ADS/LLS Valves Revision Date: 6/28/2010

.IST Program Plan Clinton Power Station, Unit 1, 3rd Interval ATTACHMENT 8 REFUEL OUTAGE JUSTIFICATIONS Revision Date: 6/28/2010

IST Program 2ian Clinton Power Station, Unit 1, 3" Interval Refuel Justification RFJ-001 Valve Number System Safety Class Category 1C41 -F006 SC , 1 C Function: Standby Liquid Control system Injection Check Basis for This valve is the Standby Liquid Control (SC) System injection flow path Justification: check valve. It is located inside Primary Containment and is accessible during normal. operation and Cold, Shutdowns.

This valve is equipped with a mechanical exerciser. It has been

.determined, .however, that use of the exerciser to test the valve to the open position does not provide consistent or conclusive results.

Breakaway force required to move the valve off its seat has been measured at 2 in. lbs. This results in an acceptance range of 1 to 3 in.

lbs. for inservice testing. Due to the low torque valves involved, it is very difficult to distinguish between the force represented by the hinge pin packing load and the actual force required to lift the disc. Thus, there is no direct correlation between breakaway force and valve degradation.

This is a 3-inch stainless steel valve in a stainless steel system containing de-ionized water. During normal plant operation this valve is isolated from reactor pressure and temperature. Because of the stainless steel system, lack of flow, ambient containment temperature, and the use of DI water, corrosion products or other contaminates are minimal and as such this valve will not undergo normal degradation processes.

The only means to test this valve with flow is to activate one train of the SC System which fires the explosive-actuated Squib valve in the selected train, and injects flow through 1C41 -F006 into the RPV. Firing of the explosive valve on a quarterly basis or during cold shutdown would not be practical.

This valve will be tested with flow from alternating SC loops during Refueling Outages. One loop will have its valve tested open with flow, while the other loop will be tested closed.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 Interval Refuel Justification RFJ-002 Valve Number System Safety Class Category 1E51 -F066 RI 1 A/C Function: RCIC Injection Check Valve Basis for This check valve isolates the Reactor Vessel from the RCIC injection Justification: header. Full-stroke exercising of this valve during normal operation would involve the injection of accident-rated flow from the RCIC Pump into the Reactor Vessel. RCIC is normally lined up to take suction from the RCIC Storage Tank, the temperature of which can be as low as 40'F. This would involve the injection of a significant amount of cold water into the vessel at power resulting in a reactivity addition excursion and thermal shock to the RCIC head spray and Reactor Vessel components, and possible damage to turbine blades from the impingement of water droplets carried through the Main Steam lines.

This valve is exercise tested to the open position during Cold shutdowns (refer to CSJ-1 05) and will be tested in the closed position by means of a Reactor Coolant System Pressure Isolation Valve (PIV) leak rate test during refueling outages.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval Refuel Justification RFJ-003 Valve Number System Safety Class Category 1B21-F010A/B FW 2 C 1B21 -F032A/B FW 2 A/C Function: Feedwater System Containment Isolation Valves Basis for These are the Reactor Feedwater Inlet Containment Isolation Check Justification: Valves. Shutdown Cooling flow from the RHR System returns to the Reactor Vessel through these valves.

1B21 -F01 OA/B are simple check valves located inside the Drywell. There is no means to exercise, test these valves to the closed position during normal operation.

Exercising .1B21 -F032A/B to the closed position would interrupt the flow of feedwater to the RPV, which would introduce undesirable operational transients and could result in a Reactor Trip.

Closure of these valves is demonstrated by performance of leak rate tests each refueling outage.

NOTE: Bi-directional exercising in the non-safety related open direction is performed during routine operations. These valves are normally open with flow.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station-, Unit 1, 3rd Interval Refuel Justification RFJ-004 Valve Number System Safety Class Category 1B21 -F041 B/C/D/F MS 1 B/C 1B21 -F047A/C MS 1 B/C 1B21-FO51G MS 1 B/C Function: Automatic Depressurization System (ADS) Valves Basis for These valves depressurize the Reactor in order to allow injection of LPCI Justification: and LPCS flow in the event of a small-break LOCA.

These valves cannot be exercised during normal operation because the resulting pressure fluctuations, particularly if the valve failed to close and reseat in a timely manner, could result in an inadvertent Reactor shutdown and possible ECCS actuation. Exercising these valves during Cold Shutdowns would increase the number of challenges to the Main Steam SRV's in conflict with the recommendations of NUREG-0737.

These valves are tested in accordance.with the exercise testing requirements for Category B valves per ISTC and with the safety/relief valve requirements for Class 1 valves with auxiliary actuating devices of Appendix I.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 Interval Refuel Justification RFJ-005 Valve Number System Safety Class Category 1E12-F041A/B/C RH 1 A/C 1E21 -F006 RH 1 A/C 1E22-F005 RH 1 A/C Function: Reactor Coolant System Pressure Isolation valves (PIV's)

Basis for These check valves isolate the Reactor Vessel from the RHR LPCI, LPCS Justification: and HPCS injection headers. Full-stroke exercising of these valves during normal operation would involve the injection of accident-rated flow from

,the respective pumps into the Reactor Vessel.

Valves 1 E12-FO41A, B and C and 1 E21-F006 cannot be exercised quarterly since the shutoff head of the RHR and LPCS pumps are below normal RV pressure. Testing of 1E22-F005 quarterly would involve the injection of a significant amount of cold water into the vessel at power resulting in a reactivity addition excursion and thermal shock to the HPCS and Vessel components. Full stroke exercising of these valves during Cold shutdowns would also increase the number of thermal fatigue cycles on the Reactor Vessel nozzles.

These valves are full-stroke exercised during refueling outages.

Satisfactory closure of these valves is also demonstrated during refueling outages by performance of the PIV leak rate test.

Revision Date: 6/28/2010

IST Program Plan I

Clinton Power Station, Unit 1, 3r Interval Refuel Justification RFJ-006 Valve Number System Safety Class Category 1B21 -F024A/B/C/D MS 3 C 1B21 -F029A/B/C/D MS 3 C Function: Instrument Air Supply Check Valves to MSIV Accumulators.

Basis for These are the Instrument Air Supply Check valves to the air accumulators Justification: for the MSIV's. They prevent depressurization of the accumulators in the event of a loss of Instrument Air supply.

Excessive leakage past any of these valves would result in depressurization of the accumulator. During normal operation at power, this would lead to closing of the associated MSIV, which would most likely cause a Reactor scram. It is also impractical to test these valves during Cold Shutdowns due to the significant amountof time and manpower required to set up and perform the test. In addition, 1B21 -F024A through D are located in the Drywell which is not accessible during normal operation or most Cold Shutdowns.

These valves will be tested in the closed position by means of a leak rate test during refueling outages.

NOTE: Bi-directional exercising in the non-safety related open direction is performed at the same frequency.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval I Refuel Justification RFJ-007 Valve Number System Safety Class Category 1B21 -F036A/F/G/J/L MS 3 A/C 1B21 -F036M/N/P/R MS 3 A/C 1B21 -F039B/C/D/E/H MS 3 A/C 1B21 -F039K/S MS 3 A/C Function: Instrument Air Supply to SRV Accumulator Check Valves Basis for ..These are the Instrument Air supply check valves to the air accumulators Justification: for the Main Steam SRV's. They prevent depressurization of the accumulators in the event of a loss of Instrument Air supply in order to allow the SRV's to operate in the relief mode. Additionally, some of these valves perform a safety function in the open direction for the purpose of refilling the SRV accumulators. These valves lack design provisions for "on-line" testing and are located in the drywell which is inaccessible during normal operation.

Exercise testing of these valves in the closed direction is performed by isolating the Instrument Air supply and depressurizing the upstream side of the check valve. The open test is performed by measuring the air flow rate through the check valve. Performance of either of these tests during power operation is impractical. Both open and closed tests require transporting and setting up test equipment in the drywell. NUREG-1482, paragraph 4.1.4 allows these valves to be tested during refueling outages.

Therefore, these valves will be tested, in the open and closed positions during refueling outages.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1,. 3rd Interval Refuel Justification RFJ-008 Valve Number System Safety Class Category 1 B21 -F433A/B FW 3 C Function: IA Supply Check Valves to FW Check Valve Accumulators Basis for These are the Instrument Air supply check valves to the accumulators for Justification: Feedwater Check Valves 1 B21 -F032A and 1B21 -F032B. They prevent depressurization of the accumulators on loss of Instrument Air in order to assure pneumatic pressure will be available to the closing side of the Feedwater Check Valve air actuators.

These valves and other valves necessary to perform the exercise test are located in the Steam Tunnel, which is inaccessible during normal operation. It is also impractical to test them during Cold Shutdowns due to the significant amount of time and manpower required to set up and perform the test, which would most likely delay Plant startup.

These valves are tested in the closed position during refueling outages by isolating the Instrument Air supply and depressurizing the upstream side of the check valve.

NOTE: Bi-directional exercising in the non-safety related open direction is performed at the same frequency.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1,. 3 rd Interval Refuel Justification RFJ-009 Valve Number System Safety Class Category 1C11-114, 1C11-115 RD 0 C 1C11-126, 1C11-127 RD 0 B 1C11-138, 1C11-139 RD 0 A/C Function: Control Rod Drive System Hydraulic Control Unit Valves Basis for Each EIN listed above actually represents 145 valves (1 valve for each of Justification: 145 Control Rod Drive Hydraulic Control Units [HCU's]) which are required to perform specific functions during a Reactor scram.

1C11-114 is a check valve which opens to permit water from the top of its associated Control Rod Drive piston to be discharged to the Scram Discharge Volume header, and closes to prevent backpressure from the SDV causing an inadvertent withdrawal of a scrammed Control Rod.

1C11-115 is a check valve in the Charging Water supply to each associated HCU accumulator which closes to assure sufficient pressure to scram its Control Rod in the event of a loss of Drive Water pressure.

1011-126 and 1Cl1-127 are the air-operated scram valves which open to direct drive water to the bottom of each Control Rod Drive piston and exhaust water from the top of the piston to the SDV.

1C11-138 is a:check valve in the CRD cooling water supply header which prevents diversion of scram flow away from the CRD.

1C11-139 is a pilot valve which exhausts air from the actuators of the scram valves (1C11-126 and 1C11 -127), causing them to open.

All of the valves in this Refuel Justification, with the exception of 1C11-115 are verified to perform their required functions by the performance of Control Rod Scram Time testing in accordance with the requirements of the Technical Specifications. This complies with the recommendations of Position 7 of NRC Generic Letter 89-04. The 1C11-115 valves are tested in the closed position by performance of a leak rate test using the pressure drop method during each refueling outage.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 Interval Refuel Justification RFJ-010 Valve Number System Safety Class Category 1C11 -F376A/B RD 0 A/C 1C11 -F377A/B RD 0 A/C Function: RV Level Instrumentation Reference Leg Keep Fill Check Valve Basis for These valves are located in lines-which provide a steady source of keep-fill Justification: water to the Reactor Vessel level instrumentation reference legs during normal operation and Cold Shutdown. They are required to close to prevent backflow and keep the instrument reference leg full of water in order to maintain level indication for the reactor vessel and to prevent a small-break LOCA in the event of a loss of the non-safety related upstream RD piping.

Testing these valves in the closed position during normal operation would require securing the keep fill flow to the reference legs which could result in a false indication of high level in the RV, which in turn could cause a turbine trip at power. Accurate level indication is also required during Cold shutdowns in order to assure that adequate decay heat removal capacity is available.

The only practical method of assuring that these valves are closed is by means of a leak rate test. These valves are tested in the closed position during refueling outages.

NOTE: Exercising in the open direction is performed during routine operations.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit .1, 3 rd Interval Refuel Justification RFJ-01 1 Valve Number System Safety Class Category 1C41 -F033A/B SC 2 C Function: Standby Liquid Control Pump Discharge Check Valves Basis for It is not practical to exercise these valves to the closed position during Justification: normal operation or during Cold Shutdowns, because there is no instrumentation between the pumps and these valves that can be used to detect reverse flow or pressure; nor are there any vents or drains that would indicate excessive reverse flow.

These valves are tested during refueling outages by removing the relief

valve (1C41 -F029A or B) while running the pump in, the opposite train, and monitoring the open flange connection for back leakage.

Open exercise test is performed quarterly in conjunction with pump testing.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval Refuel Justification RFJ-01 2 Valve Number System Safety Class Category 1C41- F336 SC 1 C Function: Standby Liquid Control System Injection Check Valve Basis for This check valve is located in the common Standby Liquid Control System Justification: injection header downstream of explosive injection valves 1C41 -FO04A and B, inside the drywell. It is a totally enclosed valve with no provisions for external exercising. The only means to test this valve with flow is to activate one Train of the SC System which would fire the explosive-actuated Squib valve in the selected Train.

Exercise testing to the open position is accomplished during each refueling outage when one of the explosive valves is fired to satisfy Technical Specification surveillance requirements and flow is injected into the Reactor Vessel from the Test Tank. Testing in the closed position is accomplished by means of the Reactor Coolant System Leakage Test which requires access to the Drywell.

This valve will be tested to the open and closed positions during refueling outages.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 Interval Refuel Justification RFJ-013 Valve Number System Safety Class Category 1CM066 CM 2 A/C 1CM067 CM 2 A/C Function: Excess Flow Check Valves Basis for These are Containment Isolation Valves and provide isolation capability for Justification:: various Reactor Vessel and Primary Containment instrument lines in the

,event of an instrument line break as discussed in US NRC Regulatory Guide 1.11 (Safety Guide 11).

These valves communicate directly to the RPV and during operation are exposed to RPV pressure. Testing in such conditions exposes the test performer to unnecessary risk and exposure. Also, testing these valves during normal plant operation requires isolating numerous safety-related instruments associated with scram logic, ECCS activation and accident monitoring. This involves filling, venting and draining operations, breaking connections to the instruments, setting up a test rig,,introducing water flow through lines with high potential for contamination, then restoring the instrument to service. These instruments have the potential for scramming the Reactor, causing an ECCS actuation, or initiating a Containment Isolation signal. In addition, testing these valves during Plant operation or Cold Shutdown results in numerous LCO entries. These valves cannot be partially exercised.

These valves will be exercised open and closed during refueling outages when they are not required to perform their protective functions.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 Interval Refuel Justification RFJ-01 4 Valve Number System Safety Class Category 1IA042A IA 2 A/C 1 IA042B IA 2 A/C Function: Instrument Air Supply Header to ADS/LLS Valves Basis for These are Containment Isolation Valves which are located in the Justification: Instrument Air (IA) supply lines from the Compressors and Emergency Bottle Banks to the Main Steam Safety/Relief Valve accumulators used for ADS and LLS service.

Testing of these valves during normal operation or during unscheduled Cold Shutdowns is impractical because they and others required to perform the test are located in the' Drywell, which is inaccessible during these conditions.'

Proper functioning of these valves to the open position is confirmed on a continuous basis during normal Plant Operation by maintaining pressure in the accumulators. Testing to the open position is accomplished during refueling outages by means of a flow test. Testing of these valves in the closed position is performed by isolating the supply sources, depressurizing the upstream side and measuring pressure drop over a 10-minute period.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval ATTACHMENT 9 STATION TECHNICAL POSITION INDEX Designator De script ion Revision None Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 Interval ATTACHMENT 10 STATION TECHNICAL POSITION None Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval

.ATTACHMENT 11 Designator Description Issue Date CTP-IST-001, Rev.0 Excess Flow Check Valve 09/10/2009 Testing (Not implemented at CPS)

CTP-IST-002, Rev.0 Quarterly Pump Testing 09/10/2009 Under Full Flow Conditions CTP-IST-003, Rev.0 Quarterly Testing of Group 09/10/2009 B Pumps CTP-IST-004, Rev.0 Classification of Pumps: 09/10/2009 Centrifugal vs. Vertical Line Shaft CTP-IST-005, Rev.0 Preservice Testing of 09/10/2009 Pumps CTP-IST-006, Rev.0 Testing of Power Operated 09/10/2009 Valves with both Active and Passive Safety Functions (Not implemented at CPS)

CTP-IST-007, Rev.0 Skid-Mounted Components 09/10/2009 CTP-IST-008, Rev. 0 Position Verification 09/10/2009 Testing Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval ATTACHMENT 12 CORPORATE TECHNICAL POSITIONS Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval Number: CTP-IST-001, Rev. 0

Title:

Preconditioning of IST Program Components Applicability: All Exelon IST Programs

Background:

There are no ASME Code requirements regarding preconditioning or the necessity to perform as-found testing, with the exception of setpoint testing of relief valves. Nevertheless, there has been significant concern raised by the NRC, and documented in numerous publications, over this issue. It is the intent of this Technical Position to provide a unified, consistent approach to the issue, of preconditioning as it applies to IST Programs throughout the Exelon fleet.

The purpose of IST is to confirm the operational readiness of pumps and valves within the scope of the IST Program to perform their intended safety functions whenever called upon. This is generally accomplished by testing using quantifiable parameters which provide an indication of degradation in the performance of the component. Preconditioning can diminish or eradicate the ability to obtain any meaningful measurement of component degradation, thus defeating the purpose of the testing.

Preconditioning is defined as the alteration, variation,

'manipulation, or adjustment of the physical condition of a system, structure, or component before Technical Specification surveillance or ASME Code testing. Since IST is a component-

.level program, this Technical Position* will address preconditioning on a component-level basis. Preconditioning may be acceptable or unacceptable.

" Acceptable preconditioning is defined as preconditioning which

'is necessary for the protection of personnel or equipment, which has been evaluated as having insufficient impact to*

invalidate the results of the surveillance test, or which provides performance data or information which is equivalent or superior to that which would be provided by the surveillance test.

" Unacceptable preconditioning is preconditioning that could potentially mask degradation of a component and allow it to be returned to or remain in service in a degraded condition.

In most cases, the best means to eliminate preconditioning concerns is to perform testing in the as-found condition. When this is not practical, an evaluation must be performed to determine if the preconditioning is acceptable. Appendix 1 to this Technical Position may be used to document this evaluation.

The acceptability or unacceptability of preconditioning must be evaluated on a case-by-case basis due to the extensive variability in component design, operation, and performance requirements. Preconditioning of pumps may include filling and venting of pump casings, venting of discharge piping, speed adjustments, lubrication, adjustment of seals or packing, etc.

Preconditioning of valves may include stem lubrication, cycling of the valve prior to the "test" stroke, charging of accumulators, attachment of electrical leads or jumpers, etc.

Factors to be considered in the evaluation of preconditioning acceptability include component size and type, actuator or driver type, design requirements, required safety functions, safety significance, the nature, benefit, and consequences of the preconditioning activity, the frequencies of the test an 0 Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 rd Interval preconditioning activities, applicable service and environmental conditions, previous performance data and trends, etc.

Lubrication of a valve stem provides a good example of the variability of whether or not a preconditioning activity is acceptable. For example, lubrication of the valve stem of an AC-powered MOV during refueling outages for a valve that is exercise tested quarterly would almost certainly be considered acceptable, unless service or environmental conditions could cause accelerated degradation of its performance. Lubrication of a valve stem each refueling outage for an MOV that is exercise tested on a refueling outage frequency may be unacceptable if the lubrication is always performed prior to the exercise test.

Lubrication of a valve stem for an AOV prior to exercise testing is likely to be unacceptable, unless it can be documented that the preconditioning (i.e., maintenance or diagnostic testing) can provide equal or better information regarding the as-found condition of the valve. Manipulation of a check valve or a vacuum breaker that uses a mechanical exerciser to measure breakaway force prior to surveillance testing would be unacceptable preconditioning. Additional information regarding preconditioning of MOVs may be found in Reference 4.

Position: Preconditioning shall be avoided unless an evaluation has been performed to determine that the preconditioning is acceptable. Appendix 1 to this Technical Position may be used to document this evaluation. In cases where the same information applies to more than one component, a single acceptability evaluation may be performed and documented.

Evaluations should be prepared, reviewed and approved by persons with the appropriate level of knowledge and responsibility. For example, persons preparing an evaluation should hold a current certification in IST or area related to the activity. Reviewers should be certified in a related Engineering area. The evaluation should be approved by an Engineering Manager or designee.

If it is determined that an instance of preconditioning has occurred without prior evaluation, the evaluation should be performed as soon as practical following discovery. If the evaluation concludes that the preconditioning is unacceptable, an IR shall be written to evaluate the condition and identify corrective actions.

References:

1. NRC Information Notice 97-16, "Preconditioning of Plant Structures, Systems, and Components before ASME Code Inservice Testing or Technical Specification Surveillance Testing".

2. NUREG-1482, Revision 1 (January, 2005), Section 3.5 "Pre-Conditioning of Pumps and Valves".

3. NRC Inspection Manual Part 9900: Technical Guidance, "Maintenance -

Preconditioning of Structures, Systems and Components Before Determining Operability".

4. ER-AA-302-1006, "Generic Letter 96-05 Program Motor-Operated Valve Maintenance and Testing Guidelines"

5. ER-AA-321, "Administrative Requirements for Inservice Testing" Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval APPENDIX I EVALUATION OF PRECONDITIONING ACCEPTABILITY I. NRC Inspection Manual Part 9900 Review Answer the following questions to determine the acceptability of the preconditioning activity based on Section D.2 of Reference 3.

NOT YES NO DETERMINED

1. Does the alteration, variation, manipulation, or adjustment ensure that the component will meet the surveillance test acceptance criteria?

D

2. Would the component have failed the surveillance without the alteration, variation, manipulation, or adjustment?

D

3. Does the practice bypass or mask the as-found DDQ condition? 0D0

4. Is the alteration, variation, manipulation, or adjustment routinely performed just before the testing?

EDD

5. Is the alteration, variation, manipulation, or adjustment performed only for scheduling convenience?

1-1 F If all answers to Questions 1 through 5 are "No", the activity is acceptable; go to Section III. Otherwise, continue with Section II.

II. Additional Evaluation The following questions may be used to determine if preconditioning activities that do not meet the screening criteria of Section I are acceptable.

NO YES

6. Is the alteration, variation, manipulation, or adjustment required to prevent personnel injury or equipment damage? If yes, explain below.

7. Does the alteration, variation, manipulation, or adjustment provide performance data or information that is equivalent or superior to that provided by the surveillance test? If yes, E] F explain below.

8. Is the alteration, variation, manipulation, or adjustment being performed to repair, replace, inspect, or test a component that is inoperable or is otherwise unable to meet E] F the surveillance test acceptance criteria? If yes, explain below.

9. Is there other justification to support classification of the alteration, variation, manipulation, or adjustment as acceptable preconditioning? If yes, explain below; provide references.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval Explanation/Details:

==

Conclusion:==

The preconditioning activity evaluated herein (is/is not acceptable Review/Approval:

Prepared by: Date:

Reviewed by: Date:

Approved by: Date:

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 rd Interval Number: CTP-IST-002, Rev. 0

Title:

Quarterly Pump Testing Under Full Flow Conditions Applicability: ASME OM-1995 Code and Later, Subsection ISTB

Background:

Pumps included in the scope of the IST Program are classified as Group A or Group B. The OM Code defines a Group A pump as a pump that is operated continuously or routinely during normal operation, cold shutdown, or refueling operations. A Group B pump is defined as a pump in a standby system that is not operated routinely except for testing.

Testing of pumps in the IST Program is performed in accordance with Group A, Group B, comprehensive or preservice test procedures. In general, a Group A test procedure is intended to satisfy quarterly testing requirements for Group A pumps, a Group

B test procedure is intended to satisfy quarterly testing requirements for Group B pumps and a comprehensive test procedure

isl required to be performed on a frequency of once every two years for all Group A and Group B pumps. The Code states that when a Group A test is required a comprehensive test may be substituted; when a Group B test is required a comprehensive test or a Group A test may be substituted. A preservice test may be substituted for any inservice test. The Corporate Exelon position on preservice testing requirements for pumps in the IST Program is provided in CTP-IST-005.

Subsection ISTB provides different acceptance, alert and required action ranges for centrifugal, vertical line shaft, non-reciprocating positive displacement and reciprocating. positive displacement pumps, for Group A, Group B and comprehensive pum a tests. In each case, the acceptance bands for flow an -

differential or discharge pressure for the comprehensive test are narrower than those for the Group A and Group B tests. Since comprehensive pump test requirements did not exist prior to the OM-1995 Code, and since the frequency of comprehensive tests is once every two years, most stations have a very limited, if any, history of comprehensive pump test performance. Thus, pumps that have demonstrated satisfactory results during quarterly testing over a period of several years may fail a comprehensive test while continuing to operate at the same performance level.

Position: The following points summarize the Exelon position on full-flow testing of pumps:

1. Any specific pump is either Group A or Group B; it cannot be both. Any pump that is operated routinely for any purpose, regardless of safety significance or frequency, except for the performance of inservice testing, is a Group A pump. A pump cannot be classified as Group A for certain modes of operation and Group B for other modes of operation (e.g., pumps used for shutdown cooling are Group A pumps).

2. Under certain circumstances, similar or redundant pumps may be classified differently. For example, if a station has four identical RHR pumps with two used for shutdown cooling and two dedicated to ECCS service, the shutdown cooling pumps would be Group A, whereas the dedicated ECCS pumps would be Group B 0

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval provided they were maintained in standby except when performing inservice testing.

3. Quarterly testing of Group A pumps shall be performed in accordance with a Group A or comprehensive test procedure.

Post-maintenance testing of Group A pumps shall be performed in accordance with a Group A, a comprehensive, or a preservice test procedure.

4. Quarterly testing of Group B pumps shall be performed in accordance with a Group B, Group A, or comprehensive test procedure. Post-maintenance testing of Group B pumps shall be performed in accordance with a Group A, a comprehensive, or a preservice test procedure.

5. Credit can only be taken for a comprehensive test if all of the OM Code requirements for a comprehensive test are met, including flow, instrument range and accuracy, and acceptance limits.

Regardless of test conditions, quarterly pump testing is required to meet the acceptance criteria specified for- Group A or Group B pumps, as applicable, in the edition/addenda of the OM Code in effect at the Plant. More restrictive acceptance criteria may be applied optionally if desired to improve trending or administrative control.

References:

1. ASME OM Code, Code for Operation and Maintenance of Nuclear Power Plants, 1995 Edition and later, Subsection ISTB.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 Interval Number: CTP-IST-003, Rev. 0

Title:

Quarterly Testing of Group B Pumps Applicability: ASME OM-1995 Code and Later

Background:

Pumps included in IST Programs that must comply with the 1995 Edition of the ASME OM Code and later are required to be classified as either Group A or Group B pumps. The OM Code defines a Group A pump as a pump that is operated continuously or routinely during normal operation, cold shutdown, or refueling operations. A Group B pump is defined as a pump in a standby system that is not operated routinely except for testing.

Testing of pumps is performed in accordance with Group A, Group B, comprehensive or preservice test procedures. In general, a Group A test procedure is intended to satisfy quarterly testing requirements for a Group A pump, a Group B test procedure is intended to satisfy quarterly testing requirements for a Group B pump, and a comprehensive test procedure is required to be performed on a frequency of once every two years for all Group A and Group B pumps. A Group A test procedure may be substituted for a Group B procedure and a comprehensive or preservice test procedure may be substituted for a Group A or a Group B procedure at any time.

A Group A test procedure is essentially identical to the quarterly pump test that was performed in accordance with OM-6 and earlier Code requirements. Group B testing was introduced to the nuclear industry when the NRC endorsed the OM-1995 Edition with OMa-1996 Addenda in 10 CFR 50.55a(b) (3). The intent of the Group B test was to provide assurance that safety related-pump that sit idle essentially all of the time (e.g. ECCS pumps) woul*

be able to start on demand and achieve a pre-established reference condition. The requirements for Group B testing were significantly relaxed when compared with the Group A (traditional) pump test requirements based on the assumption that there were no mechanisms or conditions that would result in pump degradation while the pump sat idle.

Strong differences of opinion regarding the intent and requirements for Group B testing developed and have persisted since the beginning. These differences span the industry, the NRC, and even members of the OM Code Subgroup-ISTB who created them. One opinion is that the Group B test is intended to be a "bump" test in which the pump is started, brought up to reference flow or pressure, and then stopped. The opposing opinion is that the Group B test requires the pump to be brought to the reference flow or pressure followed by recording and evaluation of both the flow and pressure readings. Both opinions can be supported by the applicable OM Code verbiage. However, NRC personnel have expressed a reluctance to accept the "bump" test interpretation.

Position: Group B pump testing should be performed as follows:

1. When performing a Group B pump test, both hydraulic test parameters (i.e., flow and differential pressure OR flow and discharge pressure) shall be measured and evaluated in accordance with the applicable Code requirements for the pump type.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval

2. Vibration measurements are not required for Group B pump tests. Vibration measurements may continue to be taken optionally. In the event that a vibration reading exceeds an alert or required action limit for the comprehensive test for the pump being tested, an IR shall be written and corrective action taken in accordance with the CAP process.

References:

1. ASME OM Code, Code for Operation and Maintenance of Nuclear Power Plants, 1995 Edition and later, Subsection ISTB.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3rd Interval Number: CTP-IST-004, Rev. 0

Title:

Classification of Pumps: Centrifugal vs. Vertical Line Shaft Applicability: All Exelon IST Programs

Background:

Early Code documents that provided requirements for inservice testing of pumps did not differentiate between pump types.

Subsection IWP of the ASME Boiler and Pressure Vessel Code,Section XI, required the measurement of flow, differential pressure and vibration and comparison of the measured data with reference values, similar to the way in which centrifugal pump testing is currently performed. Some additional measurements were required (e.g., bearing temperature, lubrication level or pressure) which were later determined to be of minimal value to IST. A major limitation in the earlier Code was that the same parameters and acceptance criteria were specified for all pumps.

With the development of the OM Standards (OM-l, OM-6, OM-10, etc.),. it was recognized that pumps of different design performed differently and required different measurement criteria to determine acceptable performance. For example, discharge, pressure was determined to be a more representative measurement of performance for a positive displacement pump than differential pressure. Part 6 of the OM Standards (OM-6), also introduced different criteria for inservice testing of centrifugal and vertical line shaft pumps. Unfortunately, it did not provide any definition for a vertical line shaft pump.

The definition of "vertical line shaft" pump was first incorporated into the OM-1998 Edition of the OM Code as "

vertically suspended pump where the pump driver and pump elemenW are connected by a line shaft within an enclosed column." This definition failed to eliminate much of the uncertainty in determining whether certain pumps were vertically-oriented centrifugal pumps or vertical line shaft pumps.

Position: Code requirements for vibration measurement provide the clearest indication of the difference between a centrifugal pump and a vertical line shaft pump. On centrifugal pumps, vibration measurements are required to be taken in a plane approximately perpendicular to the rotating shaft in two approximately orthogonal directions on each accessible pump-bearing housing and int the axial direction on each accessible pump thrust bearing housing. On vertical line shaft pumps, measurements are required to be taken on the upper motor-bearing housing in three approximately orthogonal directions, one of which is the axial direction.

Therefore, a pump which is connected to its driver by a vertically-oriented shaft in which vibration measurements must be taken on the pump motor due to the inaccessibility of the pump bearings will be classified as a vertical line shaft pump.

References:

1. ASME OMb-1988, ASME/ANSI Operation and Maintenance of Nuclear Power Plants, Part 6, Inservice Testing of Pumps in Light-Water Reactor Power Plants.

2. ASME OM Code, Code for Operation and Maintenance of Nuclear Power Plants, 1995 Edition and later, Subsection ISTB.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 rd Interval Number: CTP-IST-005, Rev. 0

Title:

Preservice Testing of Pumps Applicability: 0M-1995 Code and Later

Background:

Requirements for preservice testing of pumps have been stated in ASME Code documents since the beginning. However, the 1995 Edition of the Om Code significantly expanded the scope of preservice testing by introducing the requirement that centrifugal and vertical line shaft pumps in systems where resistance can be varied establish a pump curve by measuring flow and differential pressure at a minimum of five points. These points are required to be from pump minimum flow to at least design flow, if practicable. At least one point is to be designated as the reference point for future inservice tests.

The OM Codes further state that it is the responsibility of the Owner to determine if preservice testing requirements apply when reference values may have been affected by repair, replacement, or maintenance on a pump. A new reference value or set of values is required to be determined or the previous reference value(s) reconfirmed by a comprehensive or Group A test prior to declaring the pump operable. In any case where the previous value cannot be reconfirmed, it is difficult to justify, establishing new reference values by any means other than the performance of a preservice test.

Performance of preservice testing in accordance with the OM Code 0 Position: is generally not required for pumps that are in service, including those that are inservice when the requirements of the OM Code become mandatory due to the periodic updating of a station's IST Program as required by 10 CFR 50.55a. Performance of a preservice test may be required in the event that a pump is replaced or undergoes major repair, such that the previous reference values cannot be reconfirmed for the new or repaired pump.

Performance of a preservice test for pumps that are capable of meeting the procedure stipulated in the ASME OM Code for a five-point curve is considered a good practice and is recommended.

Since a preservice test may be substituted for any other required inservice test, this test could be performed in place of any quarterly or comprehensive test. Performing it in lieu of a comprehensive test would have minimal impact, on test scope or schedule and would provide valuable information for evaluation of pump performance.

References:

1. ASME OM Code, Code for Operation and Maintenance of Nuclear Power Plants, 1995 Edition and later, Subsection ISTB.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 d Interval Number: CTP-IST-006, Rev. 0

Title:

Classification and Testing of Class 1 Safety/Relief Valves With Auxiliary Actuating Devices Applicability: All Exelon IST Programs

Background:

The definition for valve categories in the ASME Codes has been consistent *since the beginning. Category A, B, C and D valves are basically defined the same now as they were in early editions/addenda of Section XI of the ASME Boiler and Pressure Vessel Code. Likewise, the requirement that valves meeting the definition for more than one category be tested in accordance with all the applicable categories has been-consistent over time.

Due to a lack of clear testing requirements for Class 1 Safety/Relief Valves With Auxiliary Actuating Devices in early ASME Codes, these valves were historically classified as Category B/C. As relief valves, they were required to meet the Category C testing requirements; and since the auxiliary operators essentially put them in the classification of power-operated valves, Category B requirements were imposed to address stroke-time and position indication testing considerations.

Position: The B/C categorization of these valves was initially made due to a lack of specific Code requirements. However, with the publication of ASME OM Standard OM-I in 1981, which identified specific requirements for these valves, it became irrelevant.

All applicable testing requirements for these valves were specified in OM-l, which has been superceded by Appendix I of them ASME OM Code. Efforts of the Code to exempt these valves froi Category B testing requirements further demonstrate' their inapplicability. Therefore, these valves should be classified as Category C.

References:

1. ASME OM-1987, ASME/ANSI Operation and Maintenance of Nuclear Power Plants, Part 1, Requirements for Inservice Performance Testing of Nuclear Power Plant Pressure Relief Devices.

2. ASME OMb-1988, ASME/ANSI Operation and Maintenance of Nuclear Power Plants, Part 10, Inservice Testing of Valves in Light-Water Reactor Power Plants.

3. ASME OM Code, Code for Operation and Maintenance of Nuclear Power Plants, 1990 Edition, Subsection ISTC and Appendix I.

4. ASME OM Code, Code for Operation and Maintenance of Nuclear Power Plants, 1995 Edition and later, Subsection ISTC and Appendix I.

Revision Date: 6/28/2010

1ST Program Plan Clinton Power Station, Unit 1, 3rd Interval Number: CTP-IST-007, Rev. 0

Title:

Skid-Mounted Components Applicability: All Exelon IST Programs

Background:

The term "skid-mounted component" was coined to describe support components, such as pumps and valves for the purposes of IST, that function in the operation of a supported component in such a way that their proper functioning is confirmed by the operation of the supported component. For example, the successful operation of an emergency diesel-generator set confirms that essential support equipment, such as cooling water and lube oil pumps and valves, are functioning as required. The concept of "skid-mounted" is actually irrespective of physical location.

Position: Components that are required to perform a specific function in shutting down a reactor to the safe shutdown condition, in maintaining the safe shutdown condition, or in mitigating the consequences of an accident are required to tested in accordance with the ASME Code-in-effect for the station's IST Program. It is 'not the intent of the skid-mounted exemption-that it be used in cases where the specific testing requirements of the Code for testing of pumps and valves can be met. For example, if adequate instrumentation is provided to measure a pump's flow and differential pressure, and if required points for vibration measurement can be accessed, then invoking the skid-mounted exemption would be inappropriate.

References:

1. NUREG-1482 (Rev. 0 and Rev.1), Section .3.4, Skid-Mounted Components and Component Subassemblies

2. ASME OM Code, Code for Operation and Maintenance of Nuclear Power Plants, 1995 Edition OMa-1996 Addenda, ISTA 1.7, ISTC 1.2.

3. ASME OM Code, Code for Operation and Maintenance of Nuclear Power Plants, 1998 Edition and later, ISTA-2000 and ISTC-1200.

Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 Interval Number: CTP-IST-008, Rev. 0

Title:

Position Verification Testing Applicability: All Exelon IST Programs

Background:

Valves with remote position indicators are required to be observed locally at least once every two years to verify that valve operation is accurately indicated. This local observation should be supplemented by. other indications to verify obturator position. Where local observation is not possible, other indications shall be used for verification of valve operation.

Position: All valves within the scope of the IST Program that are equipped with remote position indicators, shall be tested. The testing shall clearly demonstrate that the position indicators operate as required and are indicative of obturator position. For example, a valve that has open and closed indication shall be cycled to demonstrate that both the open and closed indicators perform as designed, including both or neither providing indication when the valve is in mid-position. Valves that have indication in one position only shall be cycled to ensure that the indicator is energized/de-energized when appropriate. These requirements apply to all IST valves, regardless of whether they are classified as active or passive.

References:

1. ASME OMb-1988, ASME/ANSI Operation and Maintenance of Nuclear Power Plants, Part 10, Inservice Testing of Valves in Light-Water Reactor Power Plants, para 4.1.

2. ASME OM Code, Code for Operation and Maintenance of Nuclear Power Plants,i 1990 Edition, para ISTC 4.1.

3. ASME OM Code, Code for Operation and Maintenance of Nuclear Power Plants, 1995 Edition with OMa-1996 Addenda, para ISTC 4.1.

4. ASME OM Code, Code for Operation and Maintenance of Nuclear Power Plants, 1998 Edition and later, para ISTC-3700.

5. NUREG-1482, Rev. 1, Section 4.2.8 Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3fd Interval ATTACHMENT 13 INSERVICE TESTING PUMP TABLE INDEX System System Description Designator DO Diesel Fuel Oil FC Fuel Pool Cooling HP High Pressure Core Spray LP Low Pressure Core Spray RH Residual Heat Removal RI Reactor Core Isolation Cooling SC Standby Liquid Control SX Shutdown Service Water VC Main Control Room HVAC Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 Interval ATTACHMENT 14 INSERVICE TESTING PUMP TABLE Revision Date: 6/28/2010

Clinton Station IST PROGRAM PLAN Diesel Fuel Oil (Page 1)

Pump EPN Safety Pump Pump Nominal P&ID P&ID OM Pump Group Class Type Driver Speed Coor.

Notes 1 DO01PA 3 PD MOTOR 1750 1036,1 B1 A Diesel Oil Transfer Pump A Location: Diesel Gen AF 128 712 Test Designator Frequency Procedure Relief Request Tech. Position Deferred Just.

Comp Y2 j9080.12 ii7ii7 I*;ro u -A. . . .Gr. .....

u A..

90.012 3---o---2----- -.........

--M . ...........

Pump EPN Safety Pump Pump Nominal P&ID P&ID OM Pump Group Class Type Driver Speed Coor.

Notes 1DO01PB 3 PD MOTOR 1750 1036, 1 B5 A Diesel Oil Transfer Pump B Location: Diesel Gen AF 130 712 Test Designator Frequency Procedure Relief Request Tech. Position Deferred Just.

iComp .r *1 [

opI ..........

Y.2........ 9080.12 F ................

G ro up. A. . ... . ..........

~.......

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

~--~~~~~~~~~~~~~~~~~~~

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

~~ H~...................................

Pump EPN Safety Pump Pump Nominal P&ID P&ID OM Pump Group Class Type Driver Speed Coor.

Notes 1 DO01 PC 3 PD MOTOR 1750 1036, 2 B4 A Diesel Oil Transfer Pump C Location: Diesel Gen AF 125 712 Test Designator Frequency Procedure Relief Request Tech. Position Deferred Just.

!Comp _ Y2 19080.12

I 1 0.. .... .. . . . . ... .... .. .. ... . ... i f~roup ' [!9080.12' I

............. .... t ............ ..................

.................J t . . . . . . . J . .. . . . ...

Revision Date: 06/28/2010

Clinton Station IST PROGRAM PLAN Fuel Pool Cooling (Page 1)

Pump EPN Safety Pump Pump Nominal P&ID P&ID OM Pump Group Class Type Driver Speed Coor.

Notes 1FC02PA 3 C motor 1780 1037 -3 E-7 A Fuel Pool Cooling and Clean-Up Pump A Location: Fuel Bldg. 707 AL 109.5 Test Designator Frequency Procedure Relief Request Tech. Position Deferred Just.

fComp Y2~ 960-i c o upI ....... .....

Grou ...... .. .906....

.]......... M3 ....---

Pump EPN Safety Pump Pump Nominal P&ID P&ID OM Pump Group Class Type Driver Speed Coor.

Notes 1FC02PB 3 C Motor 1780 1037 -3 B-7 A Fuel Pool Cooling and Clean-Up Pump B Location: Fuel Bldg. AL 112.1 716 Test Designator Frequency Procedure Relief Request Tech. Position Deferred Just.

ICOMP Y2 P061. 10 ii.

Gro uP A.......... ...... ..... ....

I....

90 6........

1 .1............

10 ..... .........

r ..

Revision Date: 06/28/2010

Clinton Station IST PROGRAM PLAN High Pressure Core Spray (Page 1)

Pump EPN Safety Pump Pump Nominal P&ID P&ID OM Pump Group Class Type Driver Speed Coor.

Notes 1E22-CO01 2 VLS MOTOR 1780 1074 B3 B Location: Fuel Bldg. AH 102 708 High Pressure Core Spray (HPCS) Pump Test Designator Frequency Procedure Relief Request Tech. Position Deferred Just.

lComp . ..........i.9051.01 o .p.....

..... *or.u.

.... Y 9. ........................

O1 .....................................

..... .5 Pump EPN Safety Pump Pump Nominal P&ID P&ID OM Pump Group Class Type Driver Speed Coor.

Notes 1 E22-C003 2 C motor 3500 1074 C5 A Location: Fuel Bldg. AH 102 708 HPCS Water Leg Pump Test Designator Frequency Procedure Relief Request Tech. Position Deferred Just.

Comp Y2 9058.01 u.. 1.0...

1.. *.

... - .05 ...

Revision Date: 06/28/2010

Clinton Station IST PROGRAM PLAN Low Pressure Core Spray (Page 1)

Pump EPN Safety Pump Pump Nominal P&ID P&ID OM Pump Group Class Type Driver Speed Coor.

Notes 1E21-CO01 2 VLS MOTOR 1780 1073 E7 B Location: Aux. 707 V 122 Low Pressure Core Spray (LPCS) Pump Test Designator Frequency Procedure Relief Request Tech. Position Deferred Just.

1Comp Y2 i 905201

..... . . . .. ...... ............ L..

IGroup B M3 .9052.01.... . . . . . . . . . . .

Pump EPN Safety Pump Pump Nominal P&ID P&ID OM Pump Group Class Type Driver Speed Coor.

Notes 1E21-C002 2 c MOTOR 3500 1073 B7 A Location: Aux. 707 V 122 LPCS and RHR Loop A Water Leg Pump Test Designator Frequency Procedure Relief Request Tech. Position Deferred Just.

I m ....................................

[Comp .............................

..... I[ Y Y2 ........ J..................

i19ý058.01 o8 ,l ................. i,.................................

I

...............E . . . 7. . . 77 r..... A............... . ......... ...........

o...p.....................

-.... I......................

Revision Date: 06/28/2010O

Clinton Station IST PROGRAM PLAN Residual Heat Removal (Page 1)

Pump EPN Safety Pump Pump Nominal P&ID P&ID OM Pump Group Class Type Driver Speed Coor.

Notes 1E12-CO02A 2 VLS MOTOR 1780 1075 Sht.1 A-7 A Location: Aux 702, Z 117 Residual Heat Removal (RHR) Pump A Test Designator Frequency Procedure Relief Request Tech. Position Deferred Just.

C.r..p.

rom p x 1o -.--.. ....... .J F Y2 .

Y 2iM. -

V9052.01-------

- ...-5 "3 01

.... . ........... .... J

..9052 ! -. ... -. . .-.. .. - .. -............. ....... --

Pump EPN Safety Pump Pump Nominal P&ID P&ID OM Pump Group Class Type Driver Speed Coor.

Notes 1E12-CO02B 2 VLS MOTOR 1780 1075 Sht.2 8-4 A.

Residual Heat Removal (RHR) Pump B Location: AUX 707 V 106 Test Designator Frequency Procedure Relief Request Tech. Position Deferred Just.

Comp Y2 9053.07 Gro. . . ............. 9.......... ....................................................... I ............................ ................

... . . ............... ......... ..................I L. ... ... . ...... .......

Pump EPN Safety Pump. Pump Nominal P&ID P&ID OM Pump Group Class Type Driver Speed Coor.

Notes 1E12-CO02C 2 VLS MOTOR 1780 1075 Sht.3 B-3 B Location: Aux. 707, X104 Residual Heat Removal (RHR) Pump C Test Designator Frequency Procedure Relief Request Tech. Position Deferred Just.

CompY2 905307

.. 9.0...........07.......................

S...............

Revision Date: 06/28/2010

Clinton Station IST PROGRAM PLAN Residual Heat Removal (Page 2)

Pump EPN Safety Pump Pump Nominal P&ID P&ID OM Pump Group Class Type Driver Speed Coor.

Notes 1E12-C003 2 C MOTOR 3500 1075 Sht.3 C-3 A Location: AUX t07 Z 104 RHR LOOP BIC Water Leg Pump Test Designator Frequency Procedure Relief Request Tech. Position Deferred Just.

Comnp Y2 9058.01 . . .

.. . . . . .0............

.. ..... . .. 1 . - .. ... . .. . ..

Revision Date: 06/28/2010

Clinton Station IST PROGRAM PLAN Reactor Core Isolation Cooling (Page 1)

Pump EPN Safety Pump Pump Nominal P&ID P&ID OM Pump Group Class Type Driver Speed Coor.

Notes 1E51-CO01 2 C TURBINE 2550 1079 El B Reactor Core Isolation Cooling (RCIC) Pump Location: Aux. 707 V 112 Test Designator Frequency Procedure Relief Request Tech. Position Deferred Just.

Comp . . .. . .. ... . . ... i ... . ...... ....

Y2 ...........................

9054.01 ........... ............................

,G.........

op.....

............................. O1.. .......... .. ......

broupBI M3 950B .

Pump EPN Safety Pump Pump Nominal P&ID P&ID OM Pump Group Class Type Driver Speed Coor.

Notes 1E51 -C003 2 C MOTOR 3500 1079 B5 A RCIC Water Leg Pump Location: Aux. Bldg. X-1 12 709 Test Designator Frequency Procedure Relief Request Tech. Position Deferred Just.

Comp Y2 9058.01 Gqroup -A M3 ý9054.01 3201 Revision Date: 06/28/2010

Clinton Station IST PROGRAM PLAN Standby Liquid Control (Page 1)

Pump EPN Safety Pump Pump Nominal P&ID P&ID OM Pump Group Class Type Driver Speed Coor.

Notes 1C41-CO01A 2 PD MOTOR 378* 1077 C5 B Standby Liquid Control (SLC) Pump A Location: Containment 781, Az. 90 Test Designator Frequency Procedure Relief Request Tech. Position Deferred Just.

Comp Y-2 '9015.06-------

Group

-. B- - I - M3 19015.01 1-l-Pump EPN Safety Pump Pump Nominal P&ID P&ID OM Pump Group Class Type Driver Speed Coor.

Notes 1C41-CO01B 2 PD MOTOR 368* 1077 E5 B Standby Liquid Control (SLC) Pump B Location: Containment 781, Az. 90 Test Designator Frequency Procedure Relief Request Tech. Position Deferred Just.

Comp

............. Y2 ...............

........................................ 9015.06

. . . .0..... . . . . . .

]-

,Group BM3 9150 Revision Date: 06/28/2010

Clinton Station IST PROGRAM PLAN Shutdown Service Water (Page 1)

Pump EPN Safety Pump Pump Nominal P&ID P&ID OM Pump Group Class Type Driver Speed Coor.

Notes 1SX01 PA 3 VLS MOTOR 895 1052 D7 B Location: Screenhouse C-I 699 Shutdown Service Water Pump A Test Designator Frequency Procedure Relief Request Tech. Position Deferred Just.

'Corn Ii9690 L _~ ~ M !9069.01_

Pump EPN Safety Pump Pump Nominal P&ID P&ID OM Pump Group Class Type Driver Speed Coor.

Notes 1SX01PB 3 VLS MOTOR 895 1052 D7 B Shutdown Service Water Pump B LUodtlUon. oieeuiiUUbe u- I UUU Test Designator Frequency Procedure Relief Request Tech. Position Deferred Just.

Comp Y2 9069.01 I............ ......... ..... .............................. - ............. ............................... ..........

9.............. ...... .................

Pump EPN Safety Pump Pump Nominal P&ID P&ID OM Pump Group Class Type Driver Speed Coor.

Notes 1SX01PC 3 VLS MOTOR 1760 1052 D7 B Shutdown Service Water Pump C L oUIOlIUIl. , 4 003 creeIVIIIIUUse Test Designator Frequency Procedure Relief Request Tech. Position Deferred Just.

Corn--- Y2 -------

2 -------

90690---------------------------

9 ... - .*.....

- --.... ------ J..........

omp

.............. :.01........

....... .... L...........................

iGroup B M3 9069.01 Revision Date: 06/28/2010

Clinton Station IST PROGRAM PUAN Control Room Ventilation (Page 1)

Pump EPN Safety Pump Pump Nominal P&ID P&ID OM Pump Group Class Type Driver Speed Coor.

Notes OVC08PA 3 C MOTOR 1770 1102 D7 A Control Room HVAC Chilled Water Pump A Location: 825 Control Building Test Designator Frequency Procedure Relief Request Tech. Position Deferred Just.

Comp Y2 !9170.01

.0.........0.... .............. ...................................

1..

1. ............. . .. ................

IL .. .... .............................

Gr u ........... 7 .i1

.....i M,3, ..............

Pump EPN Safety Pump Pump Nominal P&ID P&ID OM Pump Group Class Type Driver Speed Coor.

Notes OVC08PB 3 C MOTOR 1770 1102 D7 A Control Room HVAC Chilled Water Pump B Location: 825 Control AC 130 Test Designator Frequency Procedure Relief Request Tech. Position Deferred Just.

]CompI I . ... ..

,.o oI ....

.......... ................I.....

..1.. . . . . . . . . . . ...................

Aom Y2 M3 i9170.01 -

A... -- - - - - - I Revision Date: 06/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 d Interval ATTACHMENT 15 INSERVICE TESTING VALVE TABLE INDEX System Designator System Description Cc Component Cooling Water CM Containment Monitoring CY Cycled Condensate DG Diesel Generator DO Diesel Fuel Oil FC Fuel Pool Cooling FP Fire Protection FW Feedwater HG Containment Combustible Gas Control HP High Pressure Core Spray IA Instrument Air Is MSIV Leakage Control LD Leak Detection LP Low Pressure Core Spray MC Makeup Condensate MS Main Steam NB Nuclear Boiler PS Process Sampling RA Breathing Air RD Control Rod Drive RE Equipment Drains RF Floor Drains RH Residual Heat Removal RI Reactor Core Isolation Cooling RR Reactor Recirculation RT Reactor Water Cleanup SA Service Air SC Standby Liquid Control SF Suppression Pool Cleanup & Transfer SM Suppression Pool Makeup Sx Shutdown Service Water VC Main Control Room Ventilation VP Drywell Chilled Water VQ Primary Containment Purge VR Containment Ventilation WO Chilled Water WX Radwaste Reprocessing & Disposal Revision Date: 6/28/2010

IST Program Plan Clinton Power Station, Unit 1, 3 rd Interval ATTACHMENT 16 INSERVICE TESTING VALVE TABLE Revision Date: 6/28/2010

Clinton Station IST PROGRAM PLAN Component Cooling Water (Page 1) 1~

Valve EPN Safety Category Size Valve Act. Active! Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1CC049 2 A 10 GA MO A 0 C 1032,3 C8 DIA MOV EX Y2 2201 LTJ AJ Valve Name CCW SUPPLY CMNT OUTBOARD ISOLATION VALVE 1CC050 2 A 6 GA MO A 0 C 1032,3 C7 DIA MOV EX Y2 2201 LTJ AJ Valve Name CCW CNMT FEED LINE INBOARD ISOL VALVE 1CC053 2 A 6 GA MO A 0 C 1032,3 C3 DIA MOV EX Y2 2201 LTJ AJ Valve Name CCW RETURN LINE CNMT INBOARD ISOLATION VALVE 1CC054 2 A 10 GA MO A 0 C 1032,3 C1 DIA MOV EX Y2 2201 LTJ AJ Valve Name CCW CNMT RETURN LINE OUTBOARD ISOLATION VALVE 1CC057 2 B 8 GA MO A 0 C 1032,3 D-8 DIA MOV EX Y2 2201

/ Valve Name CCW DRYWELL ISOLATION VALVE 1CCO60 2 A 8 GA MO A 0 C 1032,3 C-2 bIA MOV EX Y2 2201 LTJ AJ Valve Name CCW RETURN FROM NRHX INBOARD ISOLATION VALVE 1CC071 2 A 4 GA MO P C C 1032,3 E2 ýLTJ AJ Valve Name SSW CNMT FEED LINE INBOARD ISOL VALVE 1CC072 2 A 4 GA MO P C C 1032,3 El LTJ AJ Valve Name SSW CNMT FEED LINE OUTBOARD ISOL VALVE 1CC073 2 A 4 GA MO P C C 1032,3 F1 LTJ AJ Valve Name SSW CNMT FEED LINE OUTBOARD ISOL VALVE 1CC074 2 A 4 GA MO P C C 1032,3 F2 LTJ AJ Valve Name SSW CNMT FEED LINE INBOARD ISOL VALVE 1CC075A 3 A 14 B MO A 0 C 1032,2 E3 DIA MOV EX Y2 2201 LT Y2 Valve Name FC HEAT EXCHANGER 1A CCW INLET VALVE ICCO75B 3 A 14 B MO A 0 C 1032,2 C3 DIA MOV EX Y2 2201 LT Y2 Valve Name FC HEAT EXCHANGER l B CCW INLET VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Compoqnent Coo0ing Water (Pag,,2).

Test Test Relief Deferred Tech. ,-

Valve EPN Safety Category Size Valve Act. Active / Normal Safety P&ID P&ID Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1CC076A 3 A 14 B MO A 0 C 1032,2 D2 DIA MOV EX Y2 2201 LT Y2 Valve Name FC HEAT EXCHANGER 1A CCW OUTLET VALVE 1CC076B 3 A 14 8 MO A 0 C 1032,2 C2 DIA MOV EX Y2 2201 LT Y2 Valve Name FC HEAT EXCHANGER 18 CCW OUTLET VALVE 1CC127 2 A 8 GA MO A 0 C 1032,3 D-8 ' DIA MOV EX Y2 2201 LTJ AJ Valve Name CCW CONTAINMENT INBOARD ISOL VALVE 1CC128 2 B 8 GA MO A 0 C 1032,3 C-2 DIA MOV EX Y2 2201 Valve Name CCW DRYWELL ISOLATION VALVE 1CC185A 3 C 0.75xl RV SA. A C 0 1046,1 F1 *RT Y10 Valve Name FPC&C HX 1A SHELL RELIEF VALVE 1CC185B 3 C 0.75x0 RV SA A C 0 1046,1 F3 RT Y10 Valve Name FPC &C HX 1B SHELL RELIEF VALVE 1CC280A 3 C 0.75xl RV SA A C 0 1032,6 E4 RT Y10 Valve Name 1FC02PA MOTOR HX SHELL SIDE RELIEF VALVE 10C280B 3 C 0.75xl RV SA A C 0 1032,6 C4 RT Y10 Valve Name 1FC02PB MOTOR HX SHELL SIDE RELIEF VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Containment Monitoring (Page 1)

Valve EPN Safety Category Size Valve Act. Activel Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1CM002B 2 C 0.75 EFC SA A 0 O/C 1034, 1 A-7 CC CS CSJ-014 CO CS CSJ-014 PI Y2 Valve Name SUPP POOL LEVEL STP EXCESS FLOW CHECK VALVE 1CM011 2 A 0.75 G SO A C C 1034,2 C-7 FC M3 LTJ AJ PI Y2 Valve Name OUTBOARD CONT. MONITORING CONT. ISOL. VALVE DIV.1 ICM012 2 A 0.75 G SO A C C 1034,2 C-6 FC M3 LTJ AJ PI Y2 Valve Name INBOARD CONT. MONITORING CONT. ISOL. VALVE DIV.1 1CM022 2 A 0.75 G SO A C C 1034,2 0-3 FC M3 LTJ AJ PI Y2 Valve Name OUTBOARD CONT. MONITORING CONT. [SOL. VALVE DIV. 2 1CM023 2 A 0.75 G SO A C C 1034,2 D-3 FC M3 LTJ AJ PI Y2 Valve Name INBOARD CONT. MONITORING CONT. ISOL. VALVE DIV. 2 1CM025 2 A 0.75 G SO A C C 1034,2 C-3 FC M3 LTJ AJ.

PI Y2 Valve Name OUTBOARD CONT. MONITORING CONT. ISOL. VALVE DIV. 2 1CM026 2 A 0.75 G SO A C C 1034,2 C-3 FC M3 LTJ AJ P( Y2 Valve Name INBOARD CONT. MONITORING CONT. ISOL. VALVE DIV. 2 1CM047 2 A 0.75 G SO A C C 1034,2 D-6 FC M3 LTJ AJ PI Y2 Valve Name INBOARD CONT. MONITORING CONT. ISOL. VALVE DIV.1 1CM048 2 A 0.75 G SO A C C 1034,2 D-7 FC M3 LTJ AJ PI Y2 Valve Name OUTBOARD CONT. MONITORING CONT. ISOL. VALVE DIV.1 1CM066 2 A/C 0.75 EFC SA A 0 C 1071, 1 F-3 BDO RR RFJ-013 CC RR RFJ-013 PI Y2 Valve Name REACTOR PRESSURE EXCESS FLOW CHECK VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Containment Monitoring: (Page,2).

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1CM067 2 A/C 0.75 EFC SA A 0 C 1071,2 E-6 BDO RR RFJ-013 CC RR RFJ-013 PI Y2 Valve Name REACTOR PRESSURE EXCESS FLOW CHECK VALVE 1E22-F332 2 C 0.75 EFC SA A 0 0 IS 1074,1 C4 B6C M3 CO M3 PI Y2 Valve Name SUPP POOL WATER LVL SENSOR EX FL CHECK VLV 1E51-F377B 2 C 0.75 EFC SA A 0 O/C IS 1079,2 Cl CC CS CSJ-014 CO CS CSJ-014 PI Y2 Valve Name SUPP POOL INSTR EXCESS FLOW CHECK VALVE ISM008 2 C 0.75 EFC SA A 0 O/C 1069, 1 A-3 CC CS CSJ-014 CO CS CSJ-014 PI Y2 Valve Name SUPP POOL LVL EXCESS FLOW CHECK VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Cycled Condensate (Page 1)

Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

. Valve EPN Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1CY016 2 A 6.0 GA MO A 0 C 1012,6 C6 DIA MOV EX Y2 2201 LTJ AJ Valve Name CYCLED COND OUTBOARD INLET ISOL VALVE 1CY017 2 A 6.0 GA MO A 0 C 1012,6 C6 DIA MOV EX Y2 2201 LTJ AJ Valve Name CYCLED COND INBOARD INLET ISO VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Diesel Ge ne rator ..(Pageg 1)

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

lDG006A 3 C 0.75xl RV SA A C O/C 1035, 1 E-6 RT Y10 Valve Name 1DG04TA STARTING AIR RCVR 1A1 RELIEF VALVE IDG006B 3 C 0.75x0 RV SA A C O/C 1035,1 C-6 RT Y10 Valve Name 1DG04TB STARTING AIR RCVR 1A2 RELIEF VALVE 1DG006C 3 C 0.75xl RV SA A C O/C 1035,2 E-6 RT Y10 Valve Name 1DG05TA STARTING AIR RCVR 1B1 RELIEF VALVE 1DG006D 3 C 0.75x0 RV SA A C O/C 1035, 2 C-6 RT Y10 Valve Name 1DG05TB STARTING AIR RCVR 1B2 RELIEF VALVE IDG006E 3 C 0.75xl RV SA A C O/C 1035,3 E-6 RT Y10 Valve Name 1DG06TA STARTING AIR RCVR IC1 RELIEF VALVE 1DG006F 3 C 0.75xl RV SA A C O/C 1035, 3 D-6 RT Y10 Valve Name 1DG06TB STARTING AIR RCVR 1C2 RELIEF VALVE 1DG008A 3 B 2 DIA AO A C 0 1035,1 E-3 SC M3 CTP-IST-007 SO M3 CTP-IST-007 Valve Name 1DG16MA/ML 16 CYLINDER AIR START VALVE 10G0088 3 B 2 DIA AO A C 0 1035, 1 C-3 SC M3 CTP-IST-007 SO M3 CTP-ISTy 007 Valve Name 1DG16MB/MM 12 CYLINDER AIR START VALVE 1DG008C 3 B 2 DIA AO A C 0 1035, 1 F-3 SC M3 CTP-IST-007 SO M3 CTP-IST-007 Valve Name 1DG16MC 16 CYLINDER AIR START VALVE 1DG008D 3 B 2 DIA AO A C 0 1035,1 B-3 SC M3 CTP-IST-007 SO M3 CTP-IST-007 Valve Name IDG16MD 12 CYLINDER AIR START VALVE lDG008E 3 B 2 DIA AO A C 0 1035,2 E-3 SC M3 CTP-IST-007 SO M3 CTP-IST-007 Valve Name 1DG16ME/MN STARTING AIR SUPPLY VALVE 1DG008F 3 B 2 DIA AO A C 0 1035, 2 C-3 SC M3 CTP-IST-007 SO M3 CTP-IST-007 Valve Name 1DG16MF/MP STARTING AIR SUPPLY VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Diesel Generator (Page 2)

'Valve EPN Safety Class Category Size Valve Type Act.

Type Active I Passive Normal Position Safety Position P&ID P&ID Coor.

Test Test Type Freq.

Relief Request Deferred Just.

Tech.

Pos.

1DG008G 3 B 2 DIA AO A C 0 1035,2 F-3 SC M3 CTP-IST-007 SO M3 CTP-IST-007 Valve Name 1DG16MG STARTING AIR SUPPLY VALVE IDG008H 3 B 2 DIA AO A C 0 1035, 2 B-3 SC M3 CTP-IST-007 SO M3 CTP-IST-007 Valve Name 1DG16MH STARTING AIR SUPPLY VALVE lDG008J 3 B 2 DIA AO A C 0 1035,3 E-3 SC M3 CTP-IST-007 SO M3 CTP-IST-007 Valve Name 1DG16MJ/MR AIR START VALVE 1DG008K 3 B 2 DIA AO A C 0 1035,3 D-3 SC M3 CTP-IST-007 SO M3 CTP-IST-007 Valve Name 1DG16MKIMS AIR START VALVE 1DG168 3 C 1.25 CK SA A SYS C 1035,1 E-7 BDO M3 CC M3 Valve Name 1DG04TA AIR RECEIVER INLET CHECK VALVE 1DG169 3 C 1.25 CK SA A SYS C 1035,1 C-7 BDO M3 CC M3 Valve Name 1DG04TB AIR RECEIVER INLET CHECK VALVE 1DG170 3 C 1.25 CK SA A SYS C 1035,2 E-7 BDO M3 CC M3 Valve Name 1DG02CA DISCHARGE TO lDG05TA VALVE IDG171 3 C 1.25 CK SA A SYS C 1035,2 C-7 BOO M3 CC M3 Valve Name 1DG02CB DISCHARGE TO 1DG05TB VALVE 1DG172 3 C 1.25 CK SA A SYS C 1035,3 E-7 BDO M3 CC M3 Valve Name 1DG03CA STARTING AIR COMPRESSOR DISCHARGE 1DG173 3 C 1.25 CK SA A SYS C 1035,3 C-7 BDO M3 CC M3 Valve Name 1DG03CB STARTING AIR COMPRESSOR DISCHARGE 1DG646A 3 B 0.375 3W so A D E/D 1035, 1 D-4 SC M3 CTP-IST-007 SO M3 CTP-IST-007 Valve Name AIR START VALVE 1DG008A SOLENOID VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Diesel Generator (Page3)

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1DG646B 3 B 0.375 3W SO A D E/D 1035, 1 C-4 SC M3 CTP-IST-007 SO M3 CTP-IST-007 Valve Name AIR START VALVE IDG008B SOLENOID VALVE 1DG646C 3 B 0.375 3W so A D EJD 1035, 1 E-4 SC M3 CTP-IST-007 SO M3 CTP-IST-007 Valve Name AIR START VALVE 1DG008C SOLENOID VALVE 1DG646D 3 B 0.375 3W SO A D E/D 1035, 1 BA SC M3 CTP-IST-007 SO M3 CTP-IST-007 Valve Name AIR START VALVE lDG008D SOLENOID VALVE 1DG646E 3 B 0375 3W so A D E/D 1035, 2 D-4 SC M3 CTP-IST-007 SO M3 CTP-IST-007 Valve Name AIR START VALVE 1DG008E SOLENOID VALVE 1DG646F 3 B 0.375 3W so A D E/D 1035, 2 C-4 SC M3 CTP-IST-007 SO M3 CTP-IST-007 Valve Name AIR START VALVE IDG008F SOLENOID VALVE 1DG646G 3 B 0.375 3W so A D E/D 1035, 2 E-4 SC M3 CTP-IST- V 007 SO M3 CTP-IST-007 Valve Name AIR START VALVE 1DG008G SOLENOID VALVE 1DG646H 3 B 0.375 3W so A D E/D 1035,2 B4 SC M3 CTP-IST-007 SO M3 CTP-IST-007 Valve Name AIR START VALVE IDG008H SOLENOID VALVE 1DG646J 3 B 0.375 3W so A D E/D 1035,3 D4 SC M3 CTP-IST-007 SO M3 CTP-IST-007 Valve Name AIR START VALVE 1DG008J SOLENOID VALVE 1DG646K 3 B 0.375 3W so A D E/D 1035, 3 C4 SC M3 CTP-IST-007 SO M3 CTP-IST-007 Valve Name AIR START VALVE 1DG008K SOLENOID VALVE Revision Date: 06128110

Clinton Station IST PROGRAM PLAN Diesel Fuel Oil (Page 1)

Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

. Valve EPN Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1DO00iA 3 C 1.5 CK SA A SYS 0 1036,1 61 BDC M3 CO M3 Valve Name 1DO01PA DISCHARGE CHECK VALVE 1DO001B 3 C 1.5 CK SA A SYS 0 1036,1 B5 BDC M3 CO M3 Valve Name 1DO01PB FUEL OIL DISCHARGE CHECK VALVE 1DO001C 3 C 1.5 CK SA A SYS 0 1036,2 B3 BDC M3 CO M3 Valve Name IDO01PC FUEL OIL TRANSFER PUMP DISCHARGE VLV 1D0005A 3 C 0.75xl RV SA A C 0/C 1036, 1 C1 RT Y10 Valve Name 1DO01PA DISCHARGE RELIEF VALVE 1D0005B 3 C 0.75xl RV SA A C O/C 1036,1 C5 RT Y10 Valve Name 1DO01PB DISCHARGE RELIEF VALVE 1DO005C 3 C 0.75xl RV SA A C O/C 1036,2 C3 RT Y10 Valve Name 1DO01PC DISCHARGE RELIEF VALVE Revision Date: 06/28/10

CPS Station IST PROGRAM PLAN Fuel Pool Cooling .(Page I) _*'N N Safety Category Size Valve 'Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Valve EP Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1E12-F0O66 3 B 14 GA M A LC 0 1075,1 B-4 ET Y2 Valve Name RHR to FC Manual CrossTie 1E12-F0O99 3 B 14 GA M A LC 0 1075,1 C-6 ET Y2 Valve Name RHR to FC Manual CrossTie 1FC002 3 B 14 GA M A LC 0 1037,2 B2 ET Y2 Valve Name RHR to FC Suction Manual Isolation 1FC004A 3 B 8 GL AO A 0 0 1037,3 E-5 FO M3 PI Y2 Valve Name FC DEMINERALIZER BYPASS FLOW CONTROL VALVE 1FC004B 3 B 8 GL AO A 0 0 1037,3 A-5 FO M3 PI Y2 Valve Name FC DEMINERALIZER BYPASS FLOW CONTROL VALVE 1FC007 2 A 10 GA MO A 0 C 1037,1 B-2 DIA MOV EX Y2 2201 LTJ AJ Valve Name FC RETURN INSIDE CNMT ISOL VALVE IFCO08 2 A 10 GA MO A 0 C 1037,1 B-1 DIA MOV EX Y2 2201 LTJ AJ Valve Name FC RETURN OUTSIDE CNMT ISOLATION VALVE 1FC011A 3 B 14 BTF MO A 0 O/C 1037,.3 E-7 PI Y2 SC M3 SO M3 Valve Name FPC & C PUMP 1A SUCTION ISOL VALVE 1FC011B 3 B 14 BTF MO A 0 O/C 1037,3 A-7 PI Y2 SC M3 SO M3 Valve Name FPC & C PUMP 1B SUCTION ISOLATION VALVE 1FC013A 3 C 14 CK SA A 0 O/C 1037,3 E-7 CC M3 CO M3

- Valve Name 1FC02PA DISCHARGE CHECK VALVE 1FC013B 3 C 14 CK SA A 0 O/C 1037,3 A-7 CC M3 CO M3 Valve Name 1FC02PB DISCHARGE CHECK VALVE IFC015A 3 B 14 .BTF MO A 0 0 1037,3 E-2 PI Y2 SO M3 Valve Name FPC &C HX 1A INLET ISOLATION VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Fuel Pool Cooling (Page 2)

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1FC015B 3 B 14 BTF MO A 0 0 1037,3_. A-2 Pi Y2 SO M3 Valve Name FPC &C HX 18 INLET ISOLATION VALVE 1FC016A 3 B 8 BTF MO A 0 C 1037,3 D-6 DIA MOV EX Y2 2201 Valve Name FILTER DEMIN SUPPLY ISOLATION VALVE 1A 1FC016B 3 B 8 BTF MO A 0 C 1037,3 C-6 DIA MOV EX Y2 2201

,(. Valve Name FILTER DEMIN SUPPLY ISOLATION VALVE 1B 1FC024A 3 B 8 BTF MO A 0 C 1037,3 E-2 DIA MOV EX Y2 2201 Valve Name FILTER DEMIN RETURN ISOLATION VALVE 1A 1FC024B 3 B 8 BTF MO A 0 C 1037,3 C-2 DIA MOV EX Y2 2201 Valve Name FILTER DEMIN RETURN ISOLATION VALVE 1B 1FC026A 3 B 14 BTF MO A 0 O/C 1037,3 E-2 PI Y2 SC M3 SO M3 Valve Name FPC & C HX 1A OUTLET ISOLATION VALVE 1FC026B 3 B 14 BTF MO A 0 O/C 1037,3 B-2 PI Y2 SC -M3 SO M3 Valve Name FPC &C HX 1B OUTLET ISOLATION VALVE 1FC036. 2 A 8 GA MO A 0 C 1037,1 E-1 DIA .MOV EX -- Y2 2201 LTJ AJ Valve Name FC SUPPLY CNMT OUTBOARD ISOLATION VALVE 1FC037 2 A 8 GA MO A 0 C 1037, 1 E-2 DIA MOV EX, Y2 2201 LTJ AJ Valve Name FC SUPPLY CNMT INBOARD ISOLATION VALVE 1FC090 3 B 14 GA M A LC 0 1037,3 D1 ET Y2 Valve Name RHR to FC Manual Isolation 1FC091 3 C 4x6 RV SA A C 0 1037,3 E-1 RT Y10 Valve Name FC TO RHR HX RELIEF VALVE 1FC095A 3 C 0.75xl RV SA A C N/A 1046, 1 F-2 RT Y10 Valve Name 1FC01AA TUBE SIDE RELIEF VALVE 1FC095B 3 C 0.75xl RV SA A C N/A 1046, 1 F-3 RT Y10 Valve Name 1FC01AB TUBE SIDE RELIEF VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Fire Protection. (Page 1)

Valve EPN Safety Category Size Valve Act. Active / Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1FP050 2 A 6 GA MO A 0 C 1039,9 E3 DIA MOV EX Y2 2201 LTJ AJ Valve Name CNMT FP SYS INBOARD ISOLATION VALVE 1FP051 2 A 10 GA MO P LC C 1039,9 C8 LTJ AJ Valve Name CNMT FP SYS OUTBOARD ISOLATION VALVE 1FP052 2 A 10 GA MO A 0 C 1039,9 C6 DIA MOV EX Y2 2201 LTJ AJ Valve Name CNMT FP SYS INBOARD ISOL VALVE 1FP053 2 A 10 GA . MO A 0 C 1039,9 C4 DIA MOV EX Y2 2201 LTJ AJ Valve Name CNMT FP SYS INBOARD ISOL VALVE 1FP054 2 A 10 . GA MO P. LC C 1039,9 C2 LTJ AJ Valve Name CNMT FP SYS OUTBOARD ISOLATION VALVE 1FP092 2 A 6 GA MO A 0 C 1039,9 E2 DIA MOV EX Y2 2201 LTJ AJ Valve Name CONTAINMENT FP SYS OUTBOARD ISOLATION VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Feedwater (Page 1)

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

w Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1B21-FO10A 1 C 18 CK SA A 0 C 1004 C7 BDO RR RFJ-003 CC RR RFJ-003 Valve Name REACTOR FEEDWATER HEADER CHECK VALVE 1821-FOIOB 1 C 18 CK SA A 0 C 1004 A7 BDO RR RFJ-003 CC RR RFJ-003 Valve Name REACTOR FEEDWATER HEADER CHECK VALVE 1B21-F032A 1 A/C 20 CK SA/AO A 0 C 1004 C6 BDO RR RFJ-003 CC" RR RFJ-003 LTJ AJ Valve Name FEEDWATER OBD. CONT ISOL AIR OP CHECK VALVE 1B21-F032B 1 A/C 20 CK SA/AO A 0 C 1004 A6 BDO RR RFJ-003 CC RR RFJ-003 LTJ AJ Valve Name FEEDWATER OBD. CONT ISOL AIR OP CHECK VALVE 1B21-F065A 2 A 20 GA MO A 0 C 1004 C5 DIA MOV EX Y2 2201 LTJ AJ.

Valve Name FEED WATER INLET SHUTOFF VALVE A 2 A 20 GA MO A 0 C 1004 A5 DIA MOV

1821-F065B EX LTJ Y2 AJ 2201 Valve Name FEED WATER INLET SHUTOFF VALVE B 1B21-F433A 3 C 0.5 CK SA A 0 C 9004,8 D5 BDO RR CC RR RFJ-008 Valve Name 1B21A300A AIR SUPPLY CHECK VALVE TO ACCUMU 1B21-F433B 3 C 0.5 CK SA A 0 C 9004,8 D5 BDO RR CC RR RFJ-008 Valve Name 1B21A300B AIR SUPPLY CHECK VALVE TO ACCUMU Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Containment Combustible G as..ControI (Page 1)

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1HGO01 2 A 2 BTF MO A C O/C 1063 D3 DIA MOV EX Y2 2201 LTJ AJ Valve Name CGCS CONTAINMENT ISOLATION VALVE 1HGO04 2 A 2 BTF MO A C O/C 1063 C3 DIA MOV EX Y2 2201 LTJ AJ Valve Name CGCS CONTAINMENT ISOLATION VALVE 1HGO05 2 A. 2 BTF MO A C O/C 1063 E3 DIA MOV EX Y2 2201 LTJ AJ Valve Name CONTAINMENT ISOLATION VALVE 1HG008 2 A 2 BTF MO A C O/C 1063 E3 DIA MOV EX Y2 2201 LTJ AJ Valve Name CONTAINMENT ISOLATION VALVE 1HG009A 2 B 6 GA MO A C O/C 1063 E4 DIA MOV EX Y2 2201 Valve Name COMPRESSOR SUCTION VALVE 1A IHGO09B 2 B 6 GA MO A C O/C 1063 E6 DIA MOV EX Y2 2201 Valve Name COMPRESSOR SUCTION VALVE IB 1HGO10A 2 C 10 CK AO A C O/C 1063 C4 CC M3 CO M3 PI Y2 RT Y2 Valve Name H2 VACUUM RELIEF VALVE CHECK VALVE 1HGO10B 2 C 10 CK AO A C O/C 1063 C7 CC M3 CO M3 PI Y2 RT Y2 Valve Name H2 VACUUM RELIEF 1HGO10C 2 C 10 CK AO A C O/C 1063 B4 CC M3 CO M3 PI Y2 RT Y2 Valve Name H2 VACUUM RELIEF VALVE Revisioni Date: 06/28JI10

Clinton Station IST PROGRAM PLAN Containment Combustible Gas Control (Page 2)

) Valve EPN Safety Class Category Size Valve Type Act.

Type Active /

Passive Normal Position Safety Position P&ID P&ID Coor.

Test Test Type Freq.

Relief Request Deferred Just.

Tech.

Pos.

1HG01D C 10 CK AO A C 0/C 1063 87 CC M3 CO M3 PI Y2 RT Y2 Valve Name H2 VACUUM RELIEF VALVE 1HG011A 2 C 10 CK AO A C O/C 1063 C4 CC M3 CO M3 PI Y2 RT Y2 Valve Name H2 VACUUM RELIEF VALVE 1HGO11B 2 C 10 CK AO A C O/C 1063 C6 CC M3 CO M3 PI Y2 RT Y2 Valve Name H2 VACUUM RELIEF 1HGO11C 2 C 10 CK AO A C. 0/C 1063 84 CC M3 CO M3 PI Y2

.RT Y2 Valve Name H2 VACUUM RELIEF VALVE 1HG011D 2 C 10 CK AO A C O/C 1063 B6 CC M3 CO M3 PI Y2 RT Y2 Valve Name H2 VACUUM RELIEF Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN High Pressure Core Spray. (Page 1),

Test Test Relief Deferred Tech.

Valve EPN Safety Category Size Valve ,Act. Active I Normal Safety P&ID P&ID Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1E22-FOO1 2 A 16 GA MO A 0 O/C 1074 A6 DIA MOV EX M3 2201 LTJ AJ Valve Name HPCS SUCTION FROM RCIC STORAGE TANK VALVE 1E22-F002 2 C 16 CK SA A C O/C 1074 A5 CC CMP CO CMP Valve Name HPCS SUCTION CHECK VALVE FROM RCIC STOR TANK 1E22-F004 1 A 10 GA MO A C O/C 1074 E7 DIA MOV EX CS 2201 CSJ-111 LTJ AJ PIV Y2 Valve Name HPCS PUMP DISCH VALVE 1E22-F005 1 A/C, 10 CK AO A C O/C 1074 E8 CC RR RFJ-005 CO RR RFJ-005 PIV Y2 Valve Name HPCS RX PRESS VESSEL CHECK VALVE 1E22-F006 2 C 2 SCK SA A SYS O/C 1074 D4 CC M3 CO M3 Valve Name HPCS WATER LEG PUMP DISCHARGE STOP CK VLV 1E22-F007 2 C 2.5 CK SA A SYS 0/C 1074 D4 CC M3 I CO M3 Valve Name HPCS WATER LEG PUMP DISCHARGE CHECK VALVE 1E22-FO10 2 B 10 GL MO P C C 1074 D6 PI Y2 Valve Name STORAGE TANK TEST BYPASS VALVE 1E22-FO11 2 A 10 GL MO A C C 1074 D5 DIA MOV EX Y2 2201 LT Y2 LTJ AJ Valve Name COND STORAGE TANK TEST VALVE 1E22-F012 2 A 4 GA MO A C O/C 1074 D3 DIA MOV EX M3 2201 LTJ AJ Valve Name SUPPRESSION POOL MIN FLOW BYPASS VALVE 1E22-F014 2 A/C lx0.75 RV SA A C O/C 1074 C5 LTJ AJ RT Y10 Valve Name HPCS PUMP SUCTION HEADER RELIEF VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN High Pressure Core Spray (Page 2)

Safety Category Size Valve Act. Active / Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

. Valve EPN Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1E22-FO15 2 A 20 GA MO A C O/C 1074 B7 DIA MOV EX M3 2201 LTJ AJ Valve Name SUPPRESSION POOL PUMP SUCTION VALVE 1E22-F016 2 C 20 CK SA A C 0 1074 B6 BDC M3 CO M3 Valve Name HPCS PUMP SUCTION CHECK VALVE 1E22-F023 2 A 10 GL MO A C C 1074 D6 DIA MOV EX Y2 2201 LTJ AJ Valve Name SUPPRESSION POOL TEST BYPASS VALVE 1E22-F024 2 C 14 CK SA A C 0/C 1074 E3 CC M3 CO M3 Valve Name HPCS PUMP DISCHARGE CHECK VALVE 1E22-F035 2 A/C lx075 RV SA A C O/C 1074 E3 LTJ AJ RT Y10 Valve Name HPCS INJ LINE RELIEF VALVE 1E22-F036 1 B 12 GA MAN P LO 0 1074 E8 P1 Y2 Valve Name HPCS MAN INJ ISOL VALVE 1E22-F039 2 A/C lx0.75 RV SA A C O/C 1074 C6 LTJ AJ RT YI0 Valve Name RETURN TO RCIC TANK RELIEF VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Instr.ument Air, (Page !)-..

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

11A005 2 A 3 GL AO A 0 C 1040,5 D2 FC CS CSJ-106 LTJ AJ PI Y2 Valve Name CONTAINMENT IAISOLATION CONTROL VALVE 11A006 2 A 3 GL AO A 0 C 1040,5 D3 FC CS CSJ-106 LTJ AJ PI Y2 Valve Name CONTAINMENT IA ISOLATION CONTROL VALVE 11A007 2 B 3 GL AO A 0 C 1040,5 D5 FC CS CSJ-106 PI Y2 Valve Name DRYWELL IAOUTBOARD ISOLATION CONTROL VALVE 1IA008 2 B 3 GL AO A 0 C 1040,5 D7 FC CS CSJ-106 PI Y2 Valve Name DRYWELL IA INBOARD ISOLATION CONTROL VALVE 1IA012A 2 A 1 GL MO A C O/C 1040,7 D2 DIA MOV EX CS 2201 CSJ-113 LTJ AJ Valve Name ADS 1A CNMT OUTBOARD ISOLATION VALVE 1IA012B 2 A 1 GL MO A 0 C 1040,7 C3 DIA MOV Valve Name ADS 1A CNMT INBOARD ISOLATION VALVE EX LTJ Y2 AJ 2201

,O 1IA013A 2 A 1 GL MO A C O/C 1040,7 D7 DIA MOV EX CS 2201 CSJ-113 LTJ AJ Valve Name ADS 1B CNMT OUTBOARD ISOLATION VALVE 11A013B 2 A 1 GL MO A 0 C 1040,7 C6 DIA MOV EX Y2 2201 LTJ AJ Valve Name ADS 1B CNMT INBOARD ISOLATION VALVE 1IA042A 2 A/C 1 CK SA A SYS O/C 1040,7 D6 CC RR RFJ-014 CO RR RFJ-014 LTJ AJ Valve Name IATO DIV 2 ADS VALVES CHECK VALVE 1IA042B 2 A/C 1 CK SA A SYS O/C 1040,7 D4 CC RR RFJ-014 CO RR RFJ-014 LTJ AJ Valve Name IATO DIV 1 ADS VALVES CHECK VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Instrument Air (Page 2)

Valve EPN Safety Category Size Valve Act. Active! Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type. Type Passive Position Position Coor. Type Freq. Request Just. Pos.

11A128A 3 C 1.5x3 RV SA A C O/C 1040,7 E7 RT Y10 Valve Name lIA10TA-H DIV 2 ADS BACKUP HEADER RELIEF VALVE 1IA128B 3 C 1.5x3 .RV SA A C O/C 1040,7 E2 RT Y10 Valve Name 1WA11TA-H DIV 1 ADS BACKUP HEADER RELIEF VALVE 11A175 2 A/C 0.5 CK SA A SYS C 1040,5 E3 BDO CMP CC CMP LTJ AJ Valve Name IASYS PISTON CHECK VALVE Revision Date: 06/28/10 A"

Clinton Station IST PROGRAM PLAN MSIV Leakage Control (Page 1)

Valve EPN. Safety Category Size Valve Act. Active ) Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type -Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1E32-F001A A 1.5 GL MO P C C 1070 C7 LTJ AJ PI Y2 Valve Name MSIV LEAK CONTROL SYSTEM INBOARD VALVE 1E32-FO01E I A 1.5 GL MO P C C 1070 E7 LTJ AJ P1 Y2 Valve Name MSIV LEAK CONTROL SYSTEM INBOARD VALVE 1E32-F001J 1 A 1.5 GL MO P C C 1070 87 LTJ AJ PI Y2 Valve Name MSIV LEAK CONTROL SYSTEM INBOARD VALVE 1E32-F001N 1, A 1,5 GL MO P C C 1070 D7 LTJ AJ PI Y2 Valve Name MSIV LEAK CONTROL SYSTEM INBOARD VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Leak Detection (Page 1)

. Valve EPN Safety Class Category Size Valve Type Act.

Type Active/

Passive Normal Position Safety

P&ID Position P&ID Coor.

Test Test Type Freq.

Relief Request Deferred Just.

Tech.

Pos.

1E31-F014 2 8 1 GA SO A 0 C 1041,4 E8 FC CS CSJA08 P1 Y2 Valve Name DRYWELL ISOLATION VALVE 1E31-F015 2 B 1 GA SO A 0 C 1041,4 E7 FC CS CSJ-108 PI Y2 Valve Name DRYWELL ISOLATION VALVE IE31-F017 2 B 1 GA SO A 0 C 1041,4 C7 FC CS CSJ-108 P1 Y2 Valve Name DRYWELL ISOLATION VALVE 1E31-F018 2 B 1 GA SO A 0 C 1041,4 C8 FC CS CSJ-108 PI Y2 Valve Name DRYWELL ISOLATION VALVE W0 Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Low Pressure Core:Spray.,(Page 1)

Valve EPN Safety Category Size. Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech. (i Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1E21-FOOl 2 A 20 GA MO A 0 O/C 1073 B4 DIA MOV EX Y2 2201 LTJ AJ Valve Name LPCS SUCTION FROM SUP POOL VALVE 1E21-F003 2 C 12 CK SA A SYS O/C 1073 E6 CC M3 CO M3 Valve Name LPCS PUMP DISCHARGE CHECK VALVE 1E21-F005 1 A 10 GA MO A C O/C 1073 E4 DIA MOV EX CS 2201 CSJ-111 LTJ AJ PIV Y2 Valve Name LPCS INJECTION SHUTOFF VALVE 1E21-F006 1 A/C 10 CK SA A SYS O/C 1073 E2 CC RR RFJ-005 CO RR RFJ-005 PIV Y2 Valve Name LPCS INJECTION TESTABLE CHECK VALVE 1E21-F007 1 B 10 GA M P LO 0 1073 E2 P1 Y2 Valve Name LPCS MAN INJ ISOL VALVE IE21-FOI1 2 A 4 GA MO A 0 O/C 1073 D6 DIA MOV EX Y2 2201 LTJ AJ Valve Name LPCS MIN FLOW BYPASS TO SUP POOL VALVE 1E21-F012 2 A 10 GL MO A C C 1073 D5 DIA MOV EX Y2 2201 LTJ AJ Valve Name LPCS TEST RETURN TO SUPPRESSION POOL VALVE 1E21-FO18 2 A/C 1.5x2 RV SA A C O/C 1073 E5 LTJ AJ RT Y10 Valve Name INJECTION HEADER RELIEF VALVE 1E21-F031 2 A/C 1.5x1 RV SA A C O/C 1073 C8 LTJ AJ RT Y10 Valve Name LPCS PUMP SUCTION HEADER RELIEF VALVE 1E21-F033 2 C 2 CK SA A SYS O/C 1073 D6 CC M3 CO M3 Valve Name LPCS WATER LEG PUMP DISCH CHK VLV TO LP 1E21-F034 2 C 2 CK SA A SYS 0/C 1073 D6 CC M3 CO M3 Valve Name LPCS WATER LEG PUMP DISCH CHK VALVE TO LP Revision Date: 06128JI10

- t Clinton Station IST PROGRAM PLAN Low Pressure Core Spray (Page 2)

Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

. Valve EPN Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1E21-F303 2 C 10 CK SA A SYS 0 1073 C5 BDC M3 CO M3 Valve Name LPCS TEST LINE CHECK VALVE Revision Date: 06128/10

Clinton Station IST PROGRAM PLAN Clean Condensate Storage .(Page 1)

Valve EPN Safety Category Size Valve Act Active / Normal Safety P&ID P&ID Test Test Relief. Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

0MC009 2 A 4 GA MO A 0 C 1042,4 E5 DIA MOV EX Y2 2201 LTJ AJ Valve Name OUTBOARD DEMIN WATER CNMT ISOL VLVE 0MC010 2 A 4 GA MO A 0 C 1042,4 D5 DIA MOV EX Y2 2201 LTJ AJ Valve Name INBOARD DEMIN WATER CNMT ISOLATION VALVE 1MC090 2 A/C 3/4 RV SA A C O/C 1042,4 E4 LTJ AJ RT Y10 Valve Name Make-up Condensate Containment Pen Relief Valve

'0 Revision Date: 06/28110

Clinton Station IST PROGRAM PLAN Main Steam (Page 1)

. Valve EPN Safety Class Category Size Valve Type Act.

Type Active /

Passive Normal Position Safety Position P&ID P&ID Coor.

Test Test Type Freq.

Relief Request Deferred Just.

Tech.

Pos.

1821-F016 1 A 3 *GA MO A 0 C 1002,1 81 DIA MOV EX CS 2201 CSJ-117 LTJ AJ Valve Name MAIN STEAM LINE INB. DRAIN ISOL. VALVE 1B21-F019 1 A 3 GA MO A 0 C 1002,2 86 DIA MOV EX CS 2201 CSJ-117 LTJ AJ Valve Name MAIN STEAM LINE OUTB. DRAIN ISOL. VALVE 1B21-F022A I A 24 GL AO A 0 C 1002,1 C2 CP M3 FC CS CSJ-101 LTJ AJ PI Y2 Valve Name MAIN STEAM INBOARD ISOL VALVE 1B21-F022B I A 24 GL AO A 0 C 1002,1 F2 CP M3 FC CS CSJ-101 LTJ AJ P1 Y2 Valve Name MAIN STEAM INBOARD ISOL VALVE 1B21-F022C 1 A 24 GL AO A 0 C 1002,1 A2 CP M3 FC CS CSJ-101 LTJ AJ P1 Y2 Valve Name MAIN STEAM INBOARD ISOL VALVE 1B21-F022D 1 A 24 GL AO A 0 C 1002, 1 D2 CP M3 FC CS CSJ-101 LTJ AJ PI Y2 Valve Name MAIN STEAM INBOARD ISOL VALVE 1B21-F024A 3 C 0.5 CK SA A SYS C 9002, 5 C7 BDO RR RFJ-006 CC RR RFJ-006 Valve Name 1B21A001A INST AIR SUPPLY CK VLV TO ACCUMU 1B21-F024B 3 C 0.5 CK SA A SYS C 9002,5 C7 BDO RR RFJ-006 CC RR RFJ-006 Valve Name 1B21A001B INST AIR SUPPLY CK VLV TO ACCUMU 1B21-F024C 3 C 0.5 CK SA A SYS C 9002,5 C7 BOO RR RFJ-006 CC RR RFJ-006 Valve Name 1B21A001C INST AIR SUPPLY CK VLV TO ACCUMU 1B21-F024D 3 C 0.5 CK SA A SYS C 9002,5 C7 BDO RR RFJ-006 CC RR RFJ-006 Valve Name 1B21A001D INST AIRSUPPLY CK VLV TO ACCUMU Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Main Steam (Page 2).

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&lD P&ID Test Test Relief Tech.

Request *Deferred Just. Pos.

Class Type Type Passive Position Position Coor. Type Freq.

1B21-F028A 1 A 24. GL AO A 0 C 1002,2 C5 CP M3 FC CS CSJ-101 LTJ AJ PI Y2 Valve Name MAIN STEAM OUTBOARD iSOLATION VALVE 1B21-F028B I A 24 GL AO A 0 C 1002,2 F5 CP M3 FC CS CSJ-101 LTJ AJ PI Y2 Valve Name MAIN STEAM OUTBOARD ISOLATION VALVE 1B21-F028C 1 A 24 GL AO A 0 C 1002,2 B5 CP M3 FC CS CSJ-101 LTJ AJ PI Y2 Valve Name MAIN STEAM OUTBOARD ISOLATION VALVE 1B21-F028D 1 A 24 GL AO A 0 C 1002,2 E5 CP M3 FC CS CSJ-101 LTJ AJ PI Y2 Valve Name MAIN STEAM OUTBOARD ISOLATION VALVE 1B21-F029A 3 C 0.5 CK SA A SYS C 9002,5 D3 BDO RR RFJ-006 CC RR RFJ-006 Valve Name 1B21A002A INST AIR SUPPLY CKVLV TO ACCUMU 1B21-F029B 3 C 0.5 CK SA A SYS C 9002,5 D3 BDO RR RFJ-006 CC RR RFJ-006 Valve Name 1B21A002B INST AIR SUPPLY CK VLV TO ACCUMU 1B21-F029C 3 C 0.5 CK SA A SYS C 9002, 5 D3 BDO RR RFJ-006 CC RR RFJ-006 Valve Name 1B21A002C INST AIR SUPPLY CK VLV TO ACCUMU

1B21-F029D 3 C 0.5 CK SA A SYS C 9002,5 D3 BDO RR RFJ-006 CC RR' RFJ-006 Valve Name 1B21A002D INST AIR SUPPLY CK VALVE TOACCUMU 1B21-F036A 3 C 0.5 CK SA A SYS C 9002, 2 C3 BDO RR RFJ-007 CC RR RFJ-007 Valve Name 1B21AO04A INST AIR SUPPLY CK VALVE TO ACCUMU 1621-F036F 3 C 0.5 CK SA A SYS C 9002, 2 C3 BDO RR RFJ-007 CC RR RFJ-007 Valve Name 1B21AO04F INST AIR SUPPLY CK VALVE TO ACCUMU Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Main Steam (Page 3)

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Techi Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1B21-F036G 3 C 0.5 CK SA A SYS C 9002,2 C3 BDO RR RFJ-007 CC RR RFJ-007 Valve Name 1B21A004G INST AIR SUPPLY CK VALVE TO ACCUMU 1B21-F036J 3 C 0.5 CK SA A SYS C 9002, 2 C3 BDO RR RFJ-007 CC RR RFJ-007 Valve Name 1B21AO04J INST AIR SUPPLY CK VALVE TO ACCUMU 1B21-F036L 3 C 0.5 CK SA A SYS C 9002,2 C3 BDO RR RFJ-007 CC RR RFJ-007 Valve Name 1B21A004L INST AIR SUPPLY CK VALVE TO ACCUMU 1B21-F036M 3 C 0.5 CK SA A SYS C 9002,2 C3 BDO RR RFJ-007 CC RR RFJ-007 Valve Name 1B21A004M INST AIR SUPPLY CK VALVE TO ACCUMU IB21-F036N 3 C 0.5 CK SA A SYS C 9002,2 C3 BDO RR RFJ-007 CC RR RFJ-007 Valve Name 1B21AO04N INST AIR SUPPLY CK VALVE TO ACCUMU 11B21-F036P 3 C 0.5 CK SA A SYS C/O 9002,2 C3 CC RR RFJ-007 CO RR RFJ-007 Valve Name 1821AO04P INST AIR SUPPLY CK VALVE TO ACCUMU 1B21-F036R 3 C 0.5 CK SA A SYS C/O 9002,2 C3 CC RR RFJ-007 CO RR RFJ-007 Valve Name 1B21AO04R INST AIR SUPPLY CK VALVE TO ACCUMU 1B21-F037A 3 C 10 CK SA A C O/C 1002, 1 C6 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE iB21-F037B 3 C 10 CK SA A C 0/C 1002,1 E6 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE 1B21-F037C 3 C 10 CK SA A C O/C 1002, 1. A7 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE 1B21-F037D 3 C 10 CK SA A C O/C 1002, 1 D7 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE Revision Date: 06128/10

Clinton Station IST PROGRAM PLAN Main .Steam (page 4).,

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1B21-F037E 3 C 10 CK SA A C O/C 1002,1 E4 CC CMP CO CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE 1821-F037F 3 C 10 CK SA A C O/C 1002,1 A5 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE 1B21-F037G 3 C 10 CK SA A C O/C 1002,1 A4 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE 1221-F037H 3 C 10 CK SA A C 0/C 1002,1 C5 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE 1821-F037J 3 C 10 CK SA A C O/C 1002,1 E7 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE .

1B21-F037K 3 C 10 CK SA *A C O/C 1002,1 A5 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE 1B21-F037L 3 C 10 CK SA A C O/C 1002, 1 D6 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE 1B21-F037M 3 C 10 CK SA A C O/C 1002,1 E3 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE 1821-F037N 3 C 10 CK SA A C O/C 1002, 1 E5 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE 1821-FO37P 3 C 10 CK SA A C O/C 1002,1 A6 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE Revisioi Date: 06128110

Clinton Station IST PROGRAM PLAN Main Steam (Page 5) 0 Valve EPN Safety Class Category Size Valve Type Act.

Type Active I Passive Normal Position Safety Position P&ID P&ID Coor.

Test Test Type Freq.

Relief Request Deferred Just.

Tech.

Pos.

1B21-F037R 3 C 10 CK SA A C O/C 1002,1 D5 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE 1B21-F037S 3 C 10 CK SA A C O/C 1002,1 A3 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE 1B21-F039B 3 C 0.5 CK SA A C O/C 9002, 1 C4 CC RR RFJ-007 CO RR RFJ-007 Valve Name 1B21A003B INST AIR SUPPLY CK VALVE TO ACCUMU 1B21-F039C 3 C 0.5 CK SA A C O/C 9002, 1 C4 CC RR RFJ-007 CO RR RFJ-007 Valve Name 1B21A003C INST AIR SUPPLY CK VALVE TO ACCUMU 1B21-F0391 3 C 0.5 CK SA A C OIC 9002,1 C4 CC RR RFJ-007 CO RR RFJ-007 Valve Name IB21A003D INST AIR SUPPLY CK VALVE TO ACCUMU 1B21-F039E 3 C 0.5 CK SA A C O/C 9002, 1 C4 CC RR RFJ-007 CO RR RFJ-007 Valve Name 1B21A003E INST AIR SUPPLY CK VALVE TO ACCUMU 1B21-F039H 3 C 0.5 CK SA A C O/C 9002,1 C4 CC RR RFJ-007 CO RR RFJ-007 Valve Name -1B21A003H INST AIR SUPPLY CK VALVE TO ACCUMU 1B21-F039K 3 C 0.5 CK SA A C O/C 9002,1 C4 CC RR RFJ-007 CO RR RFJ-007 Valve Name IB21AO03K INST AIR SUPPLY CK VALVE TO ACCUMU 1821-F039S 3 C 0.5 CK SA A C O/C 9002, 1 C4 CC RR RFJ-007 CO RR RFJ-007 Valve Name 1B21A003S INST AIR SUPPLY CK VALVE TO ACCUMU 1B21-F041A 1 C 8x10 RV AO A C O/C 1002,1 C6 P! Y2 RT Y6.5 2202

.Valve Name MAIN STEAM SAFETY/RELIEF VALVE 1B21-F041B 1 C 8x10 RV AO A C OC1 1002,1 F7 FO RR RFJ-004 RT Y6.5 2202 Valve Name MAIN STEAM SAFETY/RELIEF VALVE 1821-FO41C 1 C 8x10 RV AO A C O/C 1002,1 B8 FO RR RFJ-004 RT Y6.5 2202 Valve Name MAIN STEAM SAFETY/RELIEF VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Main Steam (Page Safety P&ID P&ID Test Test Relief Deferred Tech.

Valve EPN Safety Category Size Valve Act. Active / Normal Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1B21-FO41D 1 C 8x10 RV AO A C O/C 1002, 1 D8 FO RR RFJ-004 RT Y6.5 2202 Valve Name MAIN STEAM SAFETY/RELIEF VALVE 1B21-F041F 1 C 8x10 RV AO A C O/C 1002, 1 F5 FO RR RFJ-004 RT Y6.5 2202 Valve Name MAIN STEAM SAFETY/RELIEF VALVE 1B21-F041G 1 C 8x10 RV AO A C O/C 1002, 1 66 PI Y2 RT Y6.5 2202 Valve Name MAIN STEAM SAFETY/RELIEF VALVE 1B21-FO41L 1 C 8x10 RV AO A C 0/C 1002,1 B4 PI Y2 RT Y6.5 2202 Valve Name MAIN STEAM SAFETY/RELIEF VALVE 1821-F047A 1 C 8x10 RV AO A C O/C 1002, 1 C6 FO RR RFJ-004 RT Y6.5 2202 Valve Name MAIN STEAM SAFETY/RELIEF VALVE 1B21-F047B 1 C 8x10 RV AO A C 0/C 1002, 1 F8 PI Y2 RT Y6.5 2202 Valve Name MAIN STEAM SAFETY/RELIEF VALVE 1B21-F047C 1 C 8x10 RV AO A C O/C 1002,1 B5 FO RR RFJ-004 RT Y6.5 2202 Valve Name MAIN STEAM SAFETY/RELIEF VALVE 1B21-F0471) 1 C 8x10 RV AO A C 0/C 1002,1 D7 PI Y2 RT Y6.5 2202 Valve Name MAIN STEAM SAFETY/RELIEF VALVE 1B21-F047F 1 C 8x10 RV AO A C 0/C 1002,1 F4 PI Y2 RT Y6.5 2202 Valve Name MAIN STEAM SAFETY/RELIEF VALVE 1821-F0518 I C 8x10 RV AO A C O/C 1002,1 F6 PI Y2 RT Y6.5 2202 Valve Name MAIN STEAM SAFETY/RELIEF VALVE 1I21-F051C 1 C 8x10 RV AO A C O/C 1002,1 B7 PI Y2 RT Y6.5 2202 Valve Name MAIN STEAM SAFETY/RELIEF VALVE 1821-F051I 1 C 8x10 RV AO A C O/C 1002,1 D6 P1 Y2 RT Y6.5 2202 Valve Name MAIN STEAM SAFETY/RELIEF VALVE 1821-FO51G 1 C 8x10 RV AO A C O/C 1002, 1 94 FO RR RFJ-004 RT Y6.5 2202 Valve Name MAIN STEAM SAFETY/RELIEF VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN I Main Steam (Page 7)

(Am w Valve EPN Safety Class Category Size Valve Type Act.

Type Active/

Passive Normal Position Safety Position P&ID P&ID Coor.

Test Test Type Freq.

Relief Request Deferred Just.

Tech.

Pos.

1B21-F067A 1 A 1.5 GL MO A 0 C 1002,2 C6 DIA MOV EX Y2 2201 LTJ AJ Valve Name OUTBOARD MSIV ABOVE SEAT DRAIN VALVE 1B21-F067B 1 A 1.5 GL MO A 0 C 1002,2 E6 DIA MOV EX Y2 2201 LTJ AJ Valve Name OUTBOARD MSIV ABOVE SEAT DRAIN VALVE 1B21-F067C 1 A 1.5 GL MO A 0 C 1002,2 A6 DIA MOV EX Y2 2201 LTJ AJ Valve Name OUTBOARD MSIV ABOVE SEAT DRAIN VALVE 1B21-F067D 1 A 1.5 .GL MO A 0 C 1002,2 D6 DIA MOV EX Y2 2201 LTJ AJ Valve Name OUTBOARD MSIV ABOVE SEAT DRAIN VALVE 1B21-F078A 3 C 10 CK SA A C O/C 1002,1 C6 CC CMP CO CMP

/ RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE w 1B21-F078B 3 C 10 CK SA A C O/C 1002, 1 E6 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE 1B21-F078C 3 C 10 CK SA A C O/C 1002,1 A7 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE 1B21-F078D 3 C 10 CK SA A C O/C 1002,1 D7 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE "

1B21-F078E 3 C 10 CK SA A C O/C 1002, 1 E4 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE 1B21-F078F 3 C 10 CK SA A C O/C 1002, 1 A5 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Main Steam (Page 8),

Test Test Relief Deferred Tech.

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1B21-F078G 3 C 10 CK SA A C 01C 1002,1 A4 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE 1B21-F078H 3 C 10 CK SA A C O/C 1002, 1 C5 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE 1B21-F078J 3 C 10 CK SA A C O/C 1002,1 E7 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE 1B21-F078K 3 C 10 CK SA A C 0/C 1002, 1 A5 CC CMP CO CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE.

1B21-F078L 3 C. 10 CK SA A C O/C 1002, 1 . D6 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE 1B21-F078M 3 C 10 CK SA A C O/C 1002,1 E3 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE 1B21-F078N 3 C 10 CK SA A C O/C 1002, 1 E5 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE 1B21-F078P 3 C 10 CK SA A C O/C 1002,1 A6 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE 1B21-FO78R 3 C 10 CK SA A C O/C 1002, 1 D5 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE 1B21-F078S 3 C 10 CK SA A C O/C 1002, 1 A3 CC CMP CO CMP RT CMP Valve Name MAIN STEAM SRV VACUUM RELIEF VALVE Revivion Date: 06/28/10

Clinton Station IST PROGRAM PLAN Main Steam (Page 9)

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1B21-F379A 3 -C 2 CK SA A C O/C 1002,1 F7 CC CMP CO CMP Valve Name 11321-F047B SRV VENT LINE VAC BKR VALVE 1B21-F379B 3 C 2 CK SA A .C O/C 1002, 1 F6 CC CMP CO CMP Valve Name 1B21-FO41B SRV VENT LINE VAC BKR VALVE 1B21-F379C 3 C 2 CK SA A C O/C 1002, 1 F5 CC CMP CO CMP Valve Name 1B21-F0511 SRV VENT LINE VAC BKR VALVE 1B21-F379D 3 C 2 CK SA A C 0/C 1002, 1 F4 CC CMP CO CMP Valve Name 1B21-FO41F SRV VENT LINE VAC BKR VALVE 1B21-F379E 3 C 2 CK SA A C O/C 1002,1 F3 CC CMP CO CMP Valve Name 1B21-F047F SRV VENT LINE VAC BKR VALVE 1B21-F379F 3 C 2 CK SA A C O/C 1002,1 E7 CC CMP CO CMP Valve Name 1B21-F041D SRV VENT LINE VAC BKR VALVE 1B21-F379G 3 C 2 CK SA A C O/C 1002, 1 E6 CC CMP CO CMP Valve Name 1B21-F047D SRV VENT LINE VAC BKR VALVE 1B21-F379H 3 C 2 CK SA A C 0/C 1002,1 E5 CC CMP CO CMP Valve Name 1821-F051D SRV VENT LINE VAC BKR VALVE 1B21-F379J 3 C 2 CK SA A C O/C 1002,1 C6 CC CMP CO CMP ValveName 1B21-FO41A SRV VENT LINE VAC BKR VALVE 1821-F379K 3 C 2 CK SA A C 0/C 1002,1 C5 CC CMP CO CMP Valve Name 1B21-F047A SRV VENT LINE VAC BKR VALVE 1921-F379L 3 C 2 CK SA A C 0/C 1002,1 B7 CC CMP CO CMP Valve Name 1821-FO41C SRV VENT LINE VAC BKR VALVE 1621-F379M 3 C 2 CK SA A C O/C 1002, 1 B6 CC CMP CO CMP Valve Name 1821-F051C SRV VENT LINE VAC BKR VALVE 1621-F379N 3 C 2 CK SA A C O/C 1002,1 B5 CC CMP CO CMP Valve Name 1B21-FO41G SRV VENT LINE VAC BKR VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Main Steam (Page 10)

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&lD P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1B21-F379P 3 C 2 CK SA A C O/C 1002, 1 B5 CC CMP CO CMP Valve Name 1B21-F047C SRV VENT LINE VAC BKR VALVE 1B21-F379Q 3 C 2 CK SA A C O/C 1002,1 B4 CC CMP CO CMP Valve Name 1B21-F041L SRV VENT LINE VAC BKR VALVE 1B21-F379R 3 C 2 CK SA A C O/C 1002, 1 B3 CC CMP CO CMP Valve Name 1B21-F051G SRV VENT LINE VAC BKR VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Nuclear Boiler (Page 1)

-. Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos..

1R21-F001 A GL MO P C C 1071,2 D4 LT Y2 PI Y2 Valve Name RPV HEAD VENTILATION VALVE 1B21-F002 1 A 2 GL MO P C C 1071,2 E4 LT Y2 PI Y2 Valve Name RPV HEAD VENTILATION VALVE Revision .Date: 06/28/10

Clinton Station IST PROGRAM PLAN Process Sampling (Page, 1)

Valve EPN Safety Category Size Valve- Act. Active Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

IPS004 2 A 0.75 GA SO A C C 1045,12 E6 FC CS CSJ-116 LTJ AJ PI Y2 Valve Name DRYWELL RF SUMP SAMPLE INBOARD ISOLATION VALVE 1PS005 2 A 0.75 GA SO A C C 1045,12 E6 FC M3 LTJ AJ PI Y2 Valve Name DRYWELL RF SUMP SAMPLE OUTBOARD ISOLATION VALVE 1PSO09 2 A 0.75 GA SO A C C 1045, 12 E5 FC CS CSJ-116 LTJ AJ Pi Y2 Valve Name DRYWELL RE SUMP SAMPLE INBOARD ISOLATION VALVE 1PS010 2 A 0.75 GA SO A C C 1045,12 E5 FC M3 LTJ AJ PI Y2 Valve Name DRYWELL RE SUMP SAMPLE OUTBOARD ISOLATION VALVE 1PS016 2 A 0.75 GA SO A C C 1045,12 E5 FC CS CSJ-116 LTJ AJ PI Y2 Valve Name CNMT FLOOR DRAIN SUMP SAMPLE INBOARD ISOLATION 1PS017 2 A 0.75 GA SO A C C 1045,12 E5 FC M3 LTJ AJ PI Y2 Valve Name CNMT FLOOR DRAIN SUMP SAMPLE OUTBOARD ISOLATION 1PS022 2 A 0.75 GA SO A C C 1045, 12 E4 FC CS CSJ-116 LTJ AJ PI Y2 Valve Name CNMT EQUIPT DRAIN SUMP SAMPLE INBOARD ISOLATION 1PS023 2 A 0.75 GA SO A C C 1045,12 E4 FC M3 LTJ AJ PI Y2 Valve Name CNMT EQUIPT DRAIN SUMP SAMPLE OUTBOARD ISOLATION 1PS031 2 A 0.75 GA SO N/A C N/A 1045,12 E2 FC CS CSJ-116 LTJ AJ PI Y2 Valve Name DRYWELL SAMPLE INBOARD ISOLATION VALVE 1PS032 2 A 0.75 GA SO N/A C N/A 1045,12 E2 FC M3 LTJ AJ P1 Y2 Valve Name DRYWELL ATMOSPHERE SAMPLE OUTBOARD ISOLATION VLV Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Process Sampling (Page 2)

' Valve EPN Safety Class Category Size Valve Type Act.

Type Active I Passive Normal Position Safety Position P&ID P&ID Coor.

Test Test Type Freq.

Relief Request Deferred Just.

Tech.

Pos.

1PS034 2 A 0.75 GA SO A C C 1045,12 El FC CS CSJ-116 LTJ AJ P1 Y2 Valve Name CNMT ATMOSPHERE SAMPLE INBOARD ISOLATION VALVE 1PS035 2 A 0.75 GA SO A C C 1045, 12 El FC M3 LTJ AJ PI Y2 Valve Name CNMT ATMOSPHERE SAMPLE OUTBOARD ISOLATION VALVE 1PS037 2 A 0.75 GA SO N/A C N/A 1045, 12 E8 FC CS CSJ-116 LTJ AJ PI Y2 Valve Name RX SAMPLE INBOARD ISOLATION VALVE 1PS038 2 A 0.75 GA SO N/A C N/A 1045, 12 E8 FC M3 LTJ AJ P! Y2 Valve Name RX SAMPLE OUTBOARD ISOLATION VALVE 1PS043A 2 B 0.75 GA SO A C C 1045,12 F2 FC M3 PI Y2 Valve Name RHR PUMP 1A SAMPLE IBISOLATION VALVE 1PS0438 2 B 0.75 GA SO A G C 1045,12 F3 FC M3 PI Y2 Valve Name RHR PUMP 1B SAMPLE IBISOLATION VALVE 1PS044A 2 B 0.75 GA SO A C C 1045,12 E2 FC M3 PI Y2 Valve Name RHR PUMP 1A SAMPLE OB ISOLATION VALVE 1PS044B 2 B 0.75 GA SO A C C 1045,12 E3 FC M3 P1 Y2 Valve Name RHR PUMP 1B SAMPLE OB ISOLATION VALVE 1PS055 2 A 0.75 GA SO A C C 1045, 12 C3 FC M3 LTJ AJ PI Y2 Valve Name GAS SAMPLE RETURN OUTBOARD ISOLATION VALVE 1PS056 2 A 0.75 GA SO A C C 1045,12 C3 FC CS CSJ-116 LTJ AJ PI Y2 Valve Name GAS SAMPLE RETURN INBOARD ISOLATION VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Process Sampling. (Page:3)_.

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1PS069 2 A 0.75 GA SO A C C 1045,12 B3 FC M3 LTJ AJ P1 Y2 Valve Name LIQUID SAMPLE RETURN INBOARD ISOLATION VALVE 1PS070 2 A 0.75 GA SO A C C 1045,12 B3 FC CS CSJ-116 LTJ AJ PI Y2 Valve Name LIQUID SAMPLE RETURN OUTBOARD ISOLATION VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Breathing Air (Page 1)

O Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

0RA026 2 A 1 GA AO P C C 1065,7 D8 LTJ AJ Pl Y2 Valve Name CONTAINMENT RA OUTBOARD ISOLATION VALVE 0RA027 2 A 1 GA AO P C C 1065,7 07 LTJ AJ PI Y2 Valve Name CONTAINMENT RA INBOARD ISOLATION VALVE 0RA028 2 B 1 GA AO P C C 1065,7 E5 PI Y2 Valve Name DRYWELL RA OUTBOARD ISOLATION VALVE 0RA029 2 B 1 GA AO P C C 1065,7 E2 P1 Y2 Valve Name DRYWELL RA INBOARD ISOLATION VALVE 1RA016A 3 C lx1.5 RV SA A C O/C 1065,8 C7 RT Y10 Valve Name DIV 1 RA BOTTLES UPSTRM PRESS REGULATOR RELIEF VLV 1RA016B 3 C lx1.5 RV SA A C O/C 1065,8 C3 RT Y10 Valve Name DIV 2 RA BOTTLES UPSTRM PRESS REGULATOR RELIEF VLV Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Control Rod Driye (Page, )

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech. **

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos,.

1CI1-114 0 C 0.75 CK SA A C O/C 1078,2 E-3 CC T.S. RFJ-009 CTP-IST-007 CO T.S. RFJ-009 CTP-IST-007 Valve Name CRD HCU SCRAM DISCHARGE CHECK VALVE (Typ. 145) 1C11-115 0 C 0.5 CK SA A 0 C 1078,2 E-6 BDO RR RFJ-009 CTP-IST-007 CC RR RFJ-009 Valve Name CRD HCU CHARGING WATER CHECK VALVE 1C11-126 0 B 1 DIA AO A C 0 1078,2 E-5 FO T.S. RFJ-009 CTP-IST-007 SO T.S. RFJ-009 CTP-IST-007 Valve Name CRD SCRAM INLET VALVE (Typ. 145) 1C1l-127 0 B 0.75 DIA AO A C 0 1078,2 F-4 FO T.S. RFJ-009 CTP-IST-007 SO T.S. RFJ-009 CTP-IST-007 Valve Name CRD SCRAM OUTLET VALVE (Typ. 145) 1C11-138 0 A/C 0.5 CK SA A 0 C 1078, 2 E-5 BDO T.S. RFJ-009 CTP-IST-007 CC T.S. RFJ-009 CTP-IST-007 Valve Name CRD HCU COOLING WATER CHECK VALVE (Typ. 145) lCll-139 0 B 0.75 3W so A E D 1078,2 F-3 FO T.S. RFJ-009 CTP-IST-007 SD T.S. RFJ-009 CTP-IST-007 Valve Name CRD HCU SCRAM PILOT VALVE (Typ. 145)

ICl1-FO10 2 B 1 GL AO A 0 C 1078,3 F-7 FC M3 PI Y2 Valve Name SCRAM VENT LINE FLOW CONTROL VALVE 1Cll-F011 2 B 2 GL AO A 0 C 1078,3 B-8 FC M3 PI Y2 Valve Name SCRAM DRAIN LINE FLOW CONTROL VALVE 1Cll-F083 2 A 2 GL MO A 0 C 1078,1 E-1 DIA MOV EX Y2 2201 LTJ AJ Valve Name CRD CONTAINMENT ISOLATION VALVE 1CIl-F122 2 A/C 2 CK SA A 0 C 1078,1 C-7 CC CMP CO CMP Valve Name CRD DRIVE WATER SUPPLY HDR CHECK VALVE 1C11-F180 2 B 1 GL AO A 0 C 1078,3 F-7 FC M3 PI Y2 Valve Name SCRAM VENT LINE FLOW CONTROL VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Control Rod Drive (Page 2)

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1C11-F181 2 B 2 GL AO A 0 C 1078,3 B-8 FC M3 P1 Y2 Valve Name SCRAM DRAIN LINE FLOW CONTROL VALVE 1C11-F376A 0 A/C 0.25 CK SA A 0 O/C 1078, 1 C-6 CC RR RFJ-010 CO NO LT Y2 Valve Name RPV LEVEL CONDENSING CHAMBER KEEP-FILL CHECK VLV 1C11-F376B 0 A/C 0.25 CK SA A 0 O/C 1078,1 B-6 CC RR RFJ-010 CO NO LT Y2 Valve Name RPV LEVEL CONDENSING CHAMBER KEEP-FILL CHECK VLV 1C11-F377A 0 A/C 0,25 CK SA A 0 O/C 1078,1 C-6 CC RR RFJ-010 CO NO LT Y2 Valve Name RPV LEVEL CONDENSING CHAMBER KEEP-FILL CHECK VLV 1C11-F377B 0 A/C 0.25 CK SA A 0 O/C 1078,1 B-6 CC RR RFJ-010 CO NO LT Y2 Valve Name RPV LEVEL CONDENSING CHAMBER KEEP-FILL CHECK VLV Revkvion Date: 06/28/10

Clinton Station "TST PROGRAM PLAN Equipment Drains (P.age.,)

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech, Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1RE019 2 B 3.0 GL AO A 0 C 1046,4 A7 FC CS CSJ-102 PI Y2 Valve Name DRYWELL RE INBOARD ISOLATION CONTROL VALVE 1RE020 2 B 3.0 GL AO A 0 C 1046,3 A4 FC CS CSJ-102 PI Y2 Valve Name DRYWELL RE OUTBOARD ISOLATION CONTROL VALVE 1REO21 2 A 3.0 GL AO A 0 C 1046,3 85 FC M3 LTJ AJ PI Y2 Valve Name EQUIP DRAIN SUMP DISCHARGE CNMT INBOARD ISOLATION 1RE022 2 A 3.0 *GL AO A 0 C 1046,3 B6 FC M3 LTJ AJ PI Y2 Valve Name EQUIP DRAIN SUMP DISCHARGE CNMT OUTBOARD ISOLATION Revision .Date: 06/28/10

Clinton Station IST PROGRAM PLAN Floor Drains (Page 1)

Safety Category Size Valve Act. Active I Normal Safety

. Valve EPN Class Type. Type Passive Position Position P&ID P&ID Coor.

Test Test Type Freq.

Relief Request Deferred Just.

Tech.

Pos.

1RF019 2 B 3.0 GL AO A 0 C 1047,3 B2 FC CS CSJ-102 PI Y2 Valve Name DRYWELL RF INBOARD ISOLATION CONTROL VALVE 1RF020 2 B 3.0 GL AO A 0 C 1047,3 83 FC M3 PI Y2 Valve Name DRYWELL RF OUTBOARD ISOLATION CONTROL VALVE 1RF021 2 A 3.0 GL AO A 0 C 1047,3 B6 FC M3 LTJ AJ PI Y2 Valve Name CONTAINMENT RF INBOARD ISOLATION CONTROL VALVE 1RF022 2 A 3.0 GL AO A 0 C 1047,3 B7 FC M3 LTJ AJ Pl Y2 Valve Name CONTAINMENT RF OUTBOARD ISOLATION CONTROL VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Residual Heat Removal (Page-I)

Valve EPN Safety Category Size Valve Act. Active ) Normal Safety P&ID P&ID Test Test Relief Deferred Tech. a Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1E12-F003A 2 B 14 GL MO A 0 0 1075,4 C-2 DIA MOV 2201 EX Y2 2201 Valve Name RHR HX 1A SHELL SIDE OUTLET VALVE 1E12-F003B 2 B 14 GL MO A 0 0 1075,4 C-7 DIA MOV EX Y2 2201 Valve Name RHR HX 1B SHELL SIDE OUTLET VALVE 1E12-F004A 2 A 20 G MO A 0 O/C 1075,1 A-4 DIA MOV EX Y2 2201 LTJ AJ Valve Name RHR PUMP IA SUCTION VALVE 1E12-F004B 2 A 20 G MO A 0 O/C 1075,2 A-6 DIA MOV EX Y2 2201 LTJ AJ Valve Name RHR PUMP 1B SUCTION VALVE 1E12-F005 2 A/C 1.5x2 RV SA A C O/C 1075, 1 B-5 RT Y10 Valve Name SDC SUCTION RELIEF TO SUPPRESSION POOL 1E12-FO06A 2 A 16 G MO P C C 1075, 1 A-5 LTJ AJ P1 Y2 Valve Name RHR SHUTDOWN COOLING SUCTION VALVE 1E12-F006B 2 A 16 G MO P C C 1075,2 A-6 LTJ AJ PI Y2 Valve Name RHR SHUTDOWN COOLING SUCTION VALVE 1E12-FOO8 1 A 18 G MO A C C 1075,1 6-4 DIA MOV EX Y2 2201 LTJ AJ PIV Y2 Valve Name SHUTDOWN COOLING OUTBOARD SUCT ISOL VALVE 1E12-FO09 1 A 18 G MO A C C 1075, 1 B-2 DIA MOV EX Y2 2201 LTJ AJ PIV Y2 Valve Name SHUTDOWN COOLING INBOARD SUCT ISOL VALVE 1E12-FO10 1 B 12 GA MAN P LO 0 1075,1 C-2 PI Y2 Valve Name SHUTDOWN COOLING MANUAL SHUTOFF VALVE 1E12-FO11A 2 A 4 GL M P C C 1075,4 D-4 LTJ AJ Valve Name RHR HEAT EXCHANGER 1A FLOW TO SUP POOL VALVE 1E12-F011B 2 A 4 GL M P C C 1075,2 C-3 LTJ AJ Valve Name RHR HEAT EXCHANGER 11B FLOW TO SUP POOL VALVE Revision Date: 06J2811 0

Clinton Station IST PROGRAM PLAN Residual Heat Removal (Page 2)

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1E12-F014A 3 B 18 G MO A C 0 1052,1 D-2 DIA MOV 2201 EX M3 2201 Valve Name RHR HEAT EXCHANGER 1A SSW INLET VALVE 1E12-F014B 3 B 18 G MO A C 0 1052,2 D-2 DIA MOV EX M3 2201 Valve Name RHR HEAT EXCHANGER 1B SSW INLET VALVE 1E12-FO17A 2 A/C 1.5x2 RV SA A C O/C 1075, 1 B-6 LTJ AJ RT Y1O Valve Name RHR PUMP A SUCTION RELIEF VLV TO SUPPRESSION POOL 1E12-FO176 2 A/C 1.5x2 RV SA A C O/C 1075,2 B-6 LTJ AJ RT Y10 Valve Name RHR PUMP B SUCTION RELIEF VLV TO SUPPRESSION POOL 1912-F021 2 A 14 GL MO A C C 1075,3 D-3 DIA MOV EX Y2 2201 LTJ AJ.

Valve Name RHR PUMP 1C TEST RETURN TO SUP POOL VALVE 1E12-F023 1 A 4 GL MO A C O/C 1075,2 C-5 DIA MOV.

EX Y2 2201 LTJ AJ PIV Y2 Valve Name RH B SUPP TO RX HEAD SPRAY VALVE 1E12-F024A 2 A 10 G MO A C 0/C 1075, 1 C-7 DIA MOV 2201 EX M3 2201 LTJ AJ Valve Name RHR PUMP IATEST RET TO SUP POOL VALVE 1E12-F024B 2 A 10 G MO A C O/C 1075,2 C-2 DIA MOV EX M3 2201 LTJ AJ Valve Name RHR PUMP 1B TEST RETURN TO SUP POOL VALVE 1E12-F025A 2 A/C lxl.5 RV SA A C O/C 1075,1 D-4 LTJ AJ RT Y10 Valve Name RHR PUMP ADISCHARGE RELIEF VALVE TO SUPRSN POOL 1112-F025B 2 A/C lxl.5 RV SA A C O/C 1075,2 E-5 LTJ AJ RT Y10 Valve Name RHR PUMP B DISCHARGE RELIEF VALVE TO SUPRSN POOL 1E12-F025C .2 A/C . lxl.5 RV SA A C O/C 1075,3 F-3 LTJ AJ RT Y10 Valve Name RHR PUMP C DISCHARGE RELIEF VLV TO SUPRSION POOL Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Residual, Heat Removal. (Page 3):,,

Test Test Relief Deferred Tech.

Valve EPN Safety Category Size Valve Act. Active i Normal Safety P&ID P&ID Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1E12-F027A 2 A 12 G MO A 0 O/C 1075,1 D-4 DIA MOV EX Y2 2201 LTJ AJ Valve Name RHR PUMP 1A LPCl INJ SHUTOFF VALVE 1E12-F027B 2 A 12 G MO A 0 OIC 1075,2 D-5 DIA MOV EX Y2 2201 LTJ AJ Valve Name RHR PUMP 1B LPCI INJ SHUT OFF VALVE 1E12-F028A 2 A 10 G MO A C O/C 1075,1 F-3 DIA MOV EX Y2 2201 LTJ AJ Valve Name RHR SYS 1A CNMT SPRAY VALVE 1E12-F028B 2 A 10 G MO A C O/C 1075,2 F-6 DIA MOV EX Y2 2201 LTJ AJ Valve Name RHR SYS 18 CNMT SPRAY VALVE 1E12-FO31A 2 C 14 CK SA A C O/C 1075, 1 B-8 CC M3 CO M3 Valve Name RHR PUMP ADISCHARGE CHECK VALVE

-N 1E12-F031B 2 C 14 CK SA A Valve Name RHR PUMP B DISCHARGE CHECK VALVE C O/C 1075,2 B-1 CC CO M3 M3 0 1E12-FO31C 2 C 14 CK SA A C O/C 1075,3 D-1 CC M3 CO M3 Valve Name RHR PUMP C DISCHARGE CHECK VALVE 1E12-F036 2 A/C 4x6 RV SA A C O/C 1075,4 E-5 LTJ AJ RT Y10 Valve Name RHR CONDENSATE TO RCIC PUMP SUCTION RELIEF VLV 1E12-F037A 2 A 10 GL MO A C C 1075,1 F-2 DIA MOV EX Y2 2201 LTJ AJ Valve Name RHR SYS 1A SHUTDOWN CLG UPPER POOL VALVE 1E12-F037B 2 A 10 GL MO A C C 1075,2 F-7 DIA MOV EX Y2 2201 LTJ AJ Valve Name RH SYSTEM 18 SHUTDOWN CLG UPPER POOL VALVE 1E12-FO39A 1 B 12 GA M P LO 0 1075, 1 D1 PI Y2 Valve Name RHR MAN INJ ISOL VALVE Revision Date: 06/28/10

Station IST PROGRAM PLAN Residual Heat Removal (Page 4)

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor, Type Freq. Request Just, Pos.

1E12-FO39B 1 B -12 GA M P LO 0 1075,2 D-7 PI Y2 Valve Name RHR MAN iNJ ISOL VALVE 1E12-FO39C 1 B 12 GA M P LO 0 1075,3 E-7 PI Y2 Valve Name RHR MAN INJ ISOL VALVE 1E12-F040 2 B 3 GL MO A d C 1075,2 E-1 DIA MOV EX Y2 2201 Valve Name RHR SYS 1B RADWASTE DRAIN OUTBD ISOL VALVE 1E12-F041A 1 A/C 12 CK SA A C O/C 1075, 1 D-2 CC RR RFJ-005 CO RR RFJ-005 PIV Y2 Valve Name RHR A REACTOR PRESS VESSEL ISOL CHECK VALVE 1E12-FO41B 1 A/C 12 CK SA A C O/C 1075,2 D-7 CC RR RFJ-005.

CO RR RFJ-005 PIV Y2 Valve Name RHR B REACTOR PRESS VESSEL iSOL CHECK VALVE 1E12-F041C 1 A/C 12 CK SA A C O/C 1075,3 E-7 CC RR RFJ-005 CO RR RFJ-005 PIV Y2 0.-- Valve Name RHR C REACTOR PRESS VESSEL ISOL CHECK VALVE 1E12-F042A 1 A 12 G MO A C O/C 1075,1 D-3 DIA MOV EX CS 2201 CSJ-111 LTJ AJ PIV Y2 Valve Name RHR PUMP 1A LPCI INJECTION VALVE 1E12-F042B 1 A 12 G MO A C O/C 1075,2 D-6 DIA MOV EX CS 2201 CSJ-111 LTJ AJ PIV Y2 Valve Name RHR PUMP 18 LPCI INJECTION VALVE 1E12-F042C 1 A 12 G MO A C O/C 1075,3 E-5 DIA MOV EX CS 2201 CSJ-111 LTJ AJ PIV Y2 Valve Name RHR PUMP 1C LPCI INJECTION VALVE 1E12-F046A 2 C 4 CK SA A C 0 1075,1 B-7 BDC M3 CO M3 Valve Name RHR PUMP A MIN FLOW LINE CHECK VLV Revision Date: 06/28110

Clinton Station IST PROGRAM PLAN Residual Heat Removal-.(Pageq5)

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class ,Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1E12-F046B 2 C 4 CK SA A C 0 1075,2 B-2 BDC M3 CO M3 Valve Name RHR PUMP B MIN FLOW LINE CHECK VALVE 1E12-F046C 2 C 4 CK SA A C 0 1075,3 B-2 BDC M3 CO M3 Valve Name RHR PUMP C MIN FLOW LINE CHK VALVE 1E12-F047A 2 B 14 G MO A 0 0 1075,4 C-2 DIA MOV EX Y2 2201 Valve Name RHR HX 1A SHELL SIDE INLET VALVE 1E12-F047B 2 6 14 G MO A 0 0 1075,4 C-8 DIA MOV EX Y2 2201 Valve Name RHR HX 1B SHELL SIDE INLET VALVE 1E12-F048A 2 B 14 GL MO A 0 O/C 1075,1 C-8 DIA MOV EX M3 2201 Valve Name RHR HX 1A SHELL SIDE BYPASS VALVE 1E12-FO48B 2 B 14 GL MO A 0 O/C 1075,2 C-1 DIA MOV EX M3 2201 Valve Name RHR HX 1B SHELL SIDE BYPASS VALVE 1E12-F049 2 A 3 G MO A C C 1075,2 E-1 DIA MOV EX Y2 2201 LT Y2 Valve Name RHR SYS 1B RADWASTE DRAIN INBD ISOL VALVE 1E12-F050A 2 A/C 10 CK SA A C C 1075, 1 D-5 BDO CS CSJ-105 CC CS CSJ-105 PIV Y2 Valve Name RHR ASHUTDOWN COOLING RETURN LINE CHECK VLV 1E12-F050B 2 A/C 10 CK SA A C C 107.5,2 E-5 BDO CS CSJ-105 CC CS CSJ-105 PIV Y2 Valve Name RHR B SHUTDOWN COOLING RETURN LINE CHECK VLV 1E12-F051A 2 A 6 G AO P C C 1075,4 F-2 LT Y2 Valve Name SPLY STEAM TO RHR HT EXCH 1A PRESSURE CONTROL VLV 1E12-FO51B 2 A 6 G AO P C C 1075,4 F-6 LT Y2 Valve Name SUPP STEAM TO RHR HT EXCH 1B PRESS CONTROL VALVE 1E12-F053A 2 A 10 GL MO A C C 1075, 1 D-6 DIA MOV EX Y2 2201 LTJ AJ PIV Y2 Valve Name RHR SHUTDOWN COOLING INJECTION VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Residual Heat Removal (Page 6)

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1E12-F053B 2 A 10 GL MO A C C 1075,2 E-4 DIA MOV EX Y2 2201 LTJ AJ PIV Y2 Valve Name RHR SHUTDOWN COOLING INJECTION VALVE 1E12-F055A 2 A 8x12 RV SA P C C 1075,4 C-2 LTJ AJ Valve Name RHR HEAT EXCHANGER 1A STEAM SUPPLY RELIEF VALVE 1E12-F0558 2 A 8x12 RV SA P C C 1075,4 C-7 LTJ AJ Valve Name RHR HEAT EXCHANGER 18 STEAM SUPPLY RELIEF VALVE 1E12-FO60A 2 B 0.75 G SO A C C 1075,4 B4 FC M3 PI Y2 Valve Name RHR A HX OUT TO PROCESS SAMP PNL VALVE 1E12-F060B 2 B 0.75 G SO A C C 1075,4 B-5 FC M3 PI Y2 Valve Name RHR B HX OUTLT TO PROCESS SMPL PNL VALVE 1E12-F063A 2 A 3 G M P C C 1075,1 E6 LTJ AJ Valve Name CY to RHR FILL VALVE 1E12-F063B 2 A 3 G M P C C 1075,2 F4 LTJ AJ C. Valve Name CY TO RHR FILL VALVE 1E12-F063C 2 A 3 G M P C C 1075,3 F5 LTJ AJ Valve Name CY to RHR FILL VALVE 1E12-F064A 2 A 4 G MO A 0 O/C 1075,1 8-8 DIA MOV EX Y2 2201 LTJ AJ Valve Name RHR PUMP 1A MINIMUM FLOW VALVE 1E12-F064B 2 A 4 G MO A 0 OIC 1075,2 B-1 DIA MOV EX Y2 2201 LTJ AJ Valve Name RHR PUMP 1B MINIMUM FLOW VALVE 1E12-F064C 2 A 4 G MO A 0 O/C 1075,3 B-1 DIA MOV EX Y2 2201 LTJ AJ Valve Name RHR PUMP IC MINIMUM FLOW VALVE 1E12-FO68A 3 B 18 G MO A C 0 1052, 1 C-1 DIA MOV EX M3 2201 Valve Name RHR HX 1A SSW OUTLET VALVE 1E12-F068B 3 B 18 G MO A C 0 1052,2 C-1 DIA MOV EX M3 2201 Valve Name RHR HX 18 SSW OUTLET VALVE i .,dL W'* Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Residual Heat Removal- (Page:7)

Test Test Relief Deferred Tech.

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Class Type Type Passive Position Position Cloor. Type Freq. Request Just. Pos.

1E12-F075A 2 B 0.75 G SO A C C 1075,4 8-4 FC M3 PI Y2 Valve Name RHR AHX OUTLT TO PROCESS SAMP PNL VALVE 1E12-F075B 2 B 0.75 G SO A C C 1075,4 B-5 FC M3 PI Y2 Valve Name RHR B HX OUTLT TO PROCESS SAMP PNL VALVE 1E12-F084A 2 C 2 CK SA A 0 O/C 1075, 1 8-7 CC M3 CO M3 Valve Name LPCS WATER LEG PUMP DISCH CHK VLV TO RHR A 1E12-F084B 2 C 2 CK SA A 0 O/C 1075,2 B-2 CC M3 CO M3

'Valve Name RH C WATER LEG PUMP DISCH CHK VLV TO RHR B 1E12-F084C 2 C 2 CK SA A 0 O/C 1075,3 E-2 CC M3 CO M3 Valve Name RH C WATER LEG PUMP DISCH CHK VLV TO RHR C 1E12-F085A 2 C 2 CK SA A 0 O/C 1075,1 B-8 CC M3 CO M3 Valve Name LPCS WATER LEG PUMP DISCH CHK VLV TO RHR A 1E12-F085B 2 C 2 CK SA A 0 O/C 1075,2 B-1 CC M3 .3 Valve Name RH C WATER LEG PUMP DISCH CHK VLV TO RHR B CO M3 w

1E12-FO85C 2 C 2 CK SA A 0 O/C 1075,3 E-1 CC M3 CO M3 Valve Name RH C WATER LEG PUMP DISCH CHK VLV TO RHR C 1E12-F086 2 A 3 G M P C C 1075,2 C4 LTJ AJ Valve Name CY to RHR FILL VALVE 1E12-F087A 2 A 6 G M P C C 1075,4 E-3 LTJ AJ Valve Name RCIC STEAM TO RHR HEAT EXCH IAVALVE 1E12-F087B 2 A 6 G M P C C 1075,4 E-7 LTJ AJ Valve Name RCIC STEAM TO RHR HEAT EXCH 1B VALVE 1E12-F094 3 A 4 G MO A C O/C 1075,4 E-7 DIA MOV EX M3 2201 LT Y2 Valve Name RHR SSW CROSS TIE VALVE 1E12-F096 2 A 4 G MO A C O/C 1075,4 E-7 DIA MOV EX M3 2201 LTJ AJ Valve Name RHR/SSW CROSS TIE VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Residual Heat Removal (Page 8)

Valve EPN Safety Category Size Valve Act. Active / Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1E12-F098 2 C 4 CK SA A C 0 1075,4 D-7 BDC M3 CO M3 Valve Name RHR CONTAINMENT FLOODING LINE CHECK VALVE 1E12-F101 2 AIC lxl.5 RV SA A C O/C 1075,3 C-5 LTJ AJ RT Y10 Valve Name RHR PUMP C SUCTION RELIEF VALVE 1E12-F105 2 A 20 G MO a 0 O/C 1075,3 B-5 DIA MOV EX Y2 2201 LTJ AJ Valve Name RHR PUMP IC SUCTION VALVE 1E12-F112A 2 A/C 0.75xl RV SA A C O/C 1075,4 C-2 LTJ AJ RT YiO Valve Name RHR AHX Thermal Relief Valve 1E12-F1I2B 2 A/C 0.75xl RV SA A C O/C 1075,4 C-7 LTJ AJ RT Y10 Valve Name RHR B HX Thermal Relief Valve 1E12-F495A 2 A/C 2 CK SA A C O/C 1075, 2 E-3 CC CMP CO CMP PIV Y2 Valve Name RHR TO FEEDWATER KEEP FILL CHECK VALVE 1E12-F495B 2 A/C 2 CK SA A C O/C 1075,2 E-3 CC CMP CO CMP PIV Y2 Valve Name RHR TO FEEDWATER KEEP FILL CHECK VALVE 1E12-F496 2 A 2 GL MO A C O/C 1075,2 E-4 DIA MOV EX Y2 2201 LTJ AJ PIV Y2 Valve Name RHR TO FEEDWATER "B"KEEP FILL VALVE 1E12-F497 2 A 2 GL MO A C O/C 1075,1 E-7 DIA MOV EX Y2 2201 LTJ AJ PIV Y2 Valve Name RHR TO FEEDWATER "A"KEEP FILL VALVE 1E12-F499A 2 A/C 2 CK SA A C O/C 1075, 1 E-7 CC CMP CO CMP PIV Y2 Valve Name RHR TO FEEDWATER KEEP FILL CHECK VALVE W'0 Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Residual: Heat.Removal-.:(Page:9)_..

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1E12-F499B 2' A/C 2 CK SA A C O/C 1075, 1 E-7 CC CMP CO CMP PIV Y2 Valve Name RHR TO FEEDWATER KEEP FILL CHECK VALVE Revision Date: 06/28/10

a ,

Clinton Station IST PROGRAM PLAN Reactor Core Isolation Cooling (Page 1)

. Valve EPN Safety Class Category Size Valve Type Act.

Type Active /

Passive Normal Position Safety Position P&ID P&ID Coor.

Test Test Type Freq.

Relief Request Deferred Just.

Tech.

Pos.

1E51-C002E 2 B 4 GA MO A 0 C 1079,1 D3 PI Y2 SC M3 Valve Name RCIC TURB TRIP &THROTTLE VALVE 1E51-0001 2 D 8 RPD SA A C O/C 1079,1 F1 DT Y5 Valve Name RCIC VENT/DRAIN LINE RUPTURE DISC (DRAIN SIDE) 1E51-D002 2 D 8 RPD SA A C O/C 1079,1 F1 DT Y5 Valve Name RCIC VENT/DRAIN LINE RUPTURE DISC(VENT SIDE) 1E51-F004 2 B I GL AO A 0 C 1079,1 B-1 FC M3 PI Y2 Valve Name RCIC TURBINE EXHAUST DRAIN CONTROL VALVE 1E51-F005 2 B 1 GL AO A C C 1079,1 B-2 FC M3 PI Y2 Valve Name RCIC TURBINE EXHAUST DRAIN CONTROL VALVE 1E51-FOIO 2 B 6 GA MO A 0 O/C 1079,2 A6 DIA MOV EX Y2 2201 LTJ AJ Valve Name RCIC SUCTION FROM RCIC STOR TANK VALVE 1E51-F011 2 C 6 CK SA A SYS 0 1079,2 A4 BDC M3 CO M3 Valve Name RCIC PUMP SUCTION TESTABLE CHECK VALVE 1E51-F013 1 A 6 GA MO A C O/C 1079,2 F6 DIA MOV EX CS 2201 CSJ-111 LTJ AJ PIV Y2 Valve Name RCIC INJECTION SHUT OFF VALVE 1E51-F018 2 C 2x3 RV SA A C O/C 1079,2 C5 RT Y10 Valve Name RCIC TURBINE LUBE OIL COOLING CIRCUIT PRESS RELIEF 1E51-F019 2 A 3 GL MO Aý C O/C 1079,2 D6 DIA MOV EX M3 2201 LTJ AJ Valve Name RCIC RECIRC TO SUPP POOL VALVE 1E51-F021 2 C 2,5 CK SA A SYS 0 1079,2 D5 BDC M3 CO M3 Valve Name RCIC RECIRC TO SUPPRESSION POOL CHECK VALVE 1E51-F022 2 B 4 GL MO P C C 1079,2 E5 PI Y2 Valve Name RCIC TEST RETURN TO RCIC STOR TANK VALVE 1E51-F025 2 B 1 GL AO A SYS C 1079,1 D5 FC M3 PI Y2 Valve Name RCIC CONDENSATE RETURN ISOLATION CONTROL VALVE Revision Date: 06/28/10

0 Clinton Station IST PROGRAM PLAN Reactor Core-!solation,.Coolingw (Page 2)

Test Test Relief Deferred Tech.

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Class I Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1E51-F026 2 B 1 GL AO A SYS C 1079, 1 D5 FC M3 PI Y2 Valve Name RCIC CONDENSATE RETURN ISOLATION CONTROL VALVE 1E51-F030 2 C 6 CK SA A SYS 0 1079,2 84 BDC M3 CO M3 Valve Name RCIC PUMP SUCTION CHECK VALVE FROM SUPP POOL 1E51-F031 2 A 6 GA MO A C O/C 1079,2 C6 DIA MOV EX M3 2201 LTJ AJ Valve Name RCIC PUMP SUCTION FROM SUPP POOL VALVE 1E51-F040 2 A/C 12 CK SA A SYS O/C 1079, 1 C4 CC M3 CO M3 LTJ AJ Valve Name RCIC TURBINE EXHAUST LINE CHECK VALVE 1E51-F045 2 B 4 GL MO A C O/C 1079, 1 D4 DIA MOV EX M3 2201 Valve Name RCIC STEAM TO TURBINE VALVE 1E51-F046 2 B 2 GL MO A C 0 1079,2 C3 DIA MOV EX M3 2201 Valve Name RCIC TURBINE LUBE OIL COOLING WATER SUPPLY VALVE 1E51-F059 2 A 4 GA MO A C C 1079,2 E5 DIA MOV EX Y2 2201 LT Y2 LTJ AJ Valve Name RCIC TEST RETURN TO RCIC STOR TANK VALVE 1E51-F061 2 C 2.5 CK SA A SYS 0 1079,2 B4 BDC M3 CO M3 Valve Name RCIC WTR LEG PUMP DISCHG CHECK VALVE 1E51-F062 2 C 2 SCK SA A SYS 0 1079,2 84 BDC M3 CO M3 Valve Name RCIC WATER LEG DISCHARGE STOP CHECK VALVE 1E51-F063 A 8 GA MO A 0 O/C 1079, 1 E8 DIA MOV EX CS 2201 CSJ-108 LTJ AJ Valve Name RCIC STEAM LINE INBOARD ISOLATION VALVE 1E51-F064 1 A 8 GA MO A 0 O/C 1079, 1 E5 DIA MOV EX CS 2201 CSJ-108 LTJ AJ Valve Name RCIC STEAM LINE OUTBOARD ISOLATION VALVE Revis'ion Date: 06/28/10

Clinton Station IST PROGRAM PLAN Reactor Core Isolation Cooling (Page 3)

.

Valve EPN Safety Class Category Size Valve Type Act.

Type Active I Passive Normal Position Safety Position P&ID P&ID Coor.

Test Test Type Freq.

Relief Request Deferred Just.

Tech.

Pos.

1E51-F065 1 C 4 CK SA A SYS 0 1079,2 E6 9DC CS CSJ-110 CO CS CSJ-110 Valve Name RCIC PUMP DISCHARGE HEADER CHECK VALVE 1E51-F066 1 A/C 4 CK SA A SYS 0 1079,2 F8 CC RR RFJ-002 CO CS CSJ-105 PIV Y2 Valve Name RCIC RPV ISOLATION CHECK VALVE 1E51-F068 2 A 12 GA MO A 0 O/C 1079,1 C5 DIA MOV EX Y2 2201 LTJ AJ Valve Name RCIC TURBINE EXHAUST TO SUPP POOL VALVE 1E51-F076 1 A 1 GL MO A C C 1079,1 E8 DIA MOV EX Y2 2201 LTJ Ad Valve Name RCIC STM LINE WARMUP INBOARD ISOL VALVE 1E51-F077 2 A 1.5 GL MO A 0 O/C 1079,1 C5 DIA MOV EX Y2 2201 LTJ AJ Valve Name RCIC EXHAUST VACUMM BKR OUTBOARD ISOL VALVE 1E51-F078 2 A 3 GA MO A 0 O/C 1079,1 C6 DIA MOV EX Y2 2201 LTJ AJ Valve Name RCIC EXH VACUUM BKR INBOARD ISOL VALVE 1E51-F079 2 C 2 CK SA A C O/C 1079,1 C6 CC CMP CO CMP RT Y2 Valve Name RCIC TURB EXH VAC BRKR CHECK VALVE 1E51-F081 2 C 2 CK SA A C O/C 1079,1 C6 *CC CMP CO CMP RT Y2 Valve Name RCIC TURB EXH VAC BRKR CHECK VALVE 1E51-F090 2 A/C 0.75xl RV SA A C O/C 1079,2 E5 LTJ AJ RT Y10 Valve Name RCIC STORAGE TANK BYPASS LINE RELIEF ANGLE VALVE Wi"0 Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Reactor Recirculation. (Page 1)

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1B33-F019 2 B 0.75 GL AO A 0 C 1072, 1 E5 FC CS CSJ-115 PI Y2 Valve Name RR SAMPLE LINE DRYWELL INBOARD ISOL. VALVE 1B33-F020 2 B 0.75 GL AO A 0 C 1072, 1 E8 FC CS CSJ-115 PI Y2 Valve Name RR SAMPLE LINE DRYWELL OUTBOARD ISOL. VALVE Revision Date: 06/28110

-1 1 Clinton Station IST PROGRAM PLAN Reactor Water Cleanup (Page 1)

.O Valve EPN Safety Class Category Size Valve Type Act.

Type Active I Passive Normal Position Safety Position P&ID P&ID Coor.

Test Test Type Freq.

Relief Request Deferred Just.

Tech.

Pos.

IG33-FOO1 1 A 6 GA MO A 0 C 1076,4 B8 DIA MOV EX CS 2201 CSJ-112 LTJ AJ Valve Name RWCU PUMP SUCTION INBOARD ISOL VALVE 1G33-F004 1 A 6 GA MO A 0 C 1076,4 B5 DIA MOV EX CS 2201 CSJ-112 LTJ AJ Valve Name RWCU PUMP SUCTION OUTBOARD ISOL VALVE 1G33-F028 2 A 4 GA MO A C C 1076,4 E8 DIA MOV EX Y2 2201 LTJ AJ Valve Name RWCU TO CONDENSER INBOARD ISOL VALVE 1G33-F034 2 A 4 GA MO A C C 1076,4 E7 DIA MOV EX Y2 2201 LTJ AJ Valve Name RWCU TO CONDENSER OUTBOARD ISOL VALVE 1G33-F039 2 A 4 GA MO A 0 C 1076,4 D7 DIA MOV EX Y2 2201 LTJ AJ C. 1G33-F040 2 A Valve Name RWCU RETURN LINE OUTBOARD ISOLATION VALVE 4 GA MO A 0 C 1076,4 D8 DIA MOV EX Y2 2201 LTJ AJ Valve Name RWCU RETURN LINE INBOARD ISOL VALVE 1G33-F051 2 C 4 CK SA A 0 C 1076,4 D6 CC CMP CO CMP Valve Name RWCU CK VLV TO RHR SHUTDOWN COOLING RETURN 1G33-F052A 2 C 4 CK SA A 0 C 1076,4 D5 CC CMP CO CMP Valve Name RWCU CHECK VALVE TO RHR SUCTION STRAINER 1G33-F052B 2 C 4 CK SA A 0 C 1076,4 D5 CC CMP CO CMP Valve Name RWCU CHECK VALVE TO RHR SUCTION STRAINER 1G33-F053 2 A 4 GA MO A 0 C 1076,4 C8 DIA MOV EX Y2 2201 LTJ AJ Valve Name RWCU PUMP DISCH INBOARD ISOL VALVE

'0 Revision Date: 06/28/10

. L Clinton Station IST PROGRAM PLAN Reactor, Water. ,Ceanup:(Page 2).

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1G33-F054 2 A 4 GA MO A 0 C 1076,4 C7 DIA MOV EX Y2 2201 LTJ AJ Valve Name RWCU PUMP DISCH OUTBD ISOLATION VALVE Revision Dale: 06/28/10

Clinton Station IST PROGRAM PLAN Service Air (Page 1)

Safety Category Size Valve Act. Active/ Normal Safety P&ID P&ID Test Test Relief Deferred* Tech.

Valve EPN Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1SA029 2 A 3.0 GL AO A 0 C 1048,6 D2 *FC M3 LTJ AJ PI Y2 Valve Name CNMT SA OUTBOARD ISOLATION VALVE 1SA030 2 A 3.0 GL AO A 0 C 1048,6 03 FC M3 LTJ AJ PI Y2 Valve Name CNMT SA INBOARD ISOLATION VALVE 1SA031 2 B 3.0 GL AO A C C 1048,6 D4 FC M3 P1 Y2 Valve Name DRYWELL SA OUTBOARD ISOLATION CONTROL VALVE 1SA032 2 B 3.0 GL AO A C C 1048,6 D5 FC CS CSJ 103 PI Y2 Valve Name DRYWELL SA INBOARD ISOLATION VALVE W'0 Revision Date: 06/28/10O

. L Clinton Station IST PROGRAM PLAN Standby Liquid:Control- (Page 1) e.-N Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1C41-FO01A 2 3 GL MO A C 0 1077 C6 DIA MOV EX Y2 2201 Valve Name STANDBY LIQUID CONTROL TANK OULET VALVE A 1C41-F001B 2 B 3 GL MO A C 0 1077 E6 DIA MOV EX Y2 2201 Valve Name STANDBY LIQUID CONTROL TANK OULET VALVE B 1C41-F004A 1 D 1.5 SHR EXP A C 0 1077 C3 DT S2 Valve Name SLC PUMP A DISCHARGE EXPLOSIVE VALVE 1C41-F004B 1 D 1,5 SHR EXP A C 0 1077 D3 DT S2 Valve Name SLC PUMP 8 DISCHARGE EXPLOSIVE VALVE IC41-F006 I C 3 CK SA A C O/C 1077 D2 CC RR RFJ-001 CO RR RFJ-001 Valve Name STBY LIQUID CONTROL PUMP DISCHARGE CK VLV 1C41-F029A 2 C 1.5x2 RV SA A C 01C 1077 C4 RT Y10 Valve Name STBY LIQUID CONTROL PUMP 1A RELIEF VALVE 1C41-F029B 2 C 1.5x2 RV SA A C O/C 1077 E4 RT YIO Valve Name STBY LIQUID CONTROL PUMP 1B RELIEF VALVE 1C41-F033A 2 C 1.5 CK SA A SYS 0/C 1077 C4 CC RR RFJ-011 CO RR RFJ-011 Valve Name STBY LIQUID CONTROL PUMP 1A DISCHARGE CK VLV 1C41-F033b 2 C 1.5 CK SA A SYS O/C 1077 04 CC RR RFJ-011 CO RR RFJ-011 Valve Name STBY LIQUID CONTROL PUMP IB DISCHARGE CK VLV 1C41-F336 1 C 4 CK SA A SYS O/C 1077 El CC RR RFJ-012 CO RR RFJ-012 Valve Name STBY LIQUID CONTROL INJECTION CHECK VALVE Revision.Date: 06128/10

Clinton Station IST PROGRAM PLAN Suppression Pool Cleanup & Transfer (Page 1)

. Valve EPN Safety Class Category Size Valve Type Act.

Type Active)

Passive Normal Position Safety Position P&ID P&ID Coor.

Test Test Type Freq.

Relief Request Deferred Just.

Tech.

Pos, ISF001 2 A 10 GA MO A C C 1060 E5 DIA MOV EX Y2 2201 LTJ AJ Valve Name SF RETURN LINE OUTBOARD ISOLATION 1SF002 2 A 10 GA MO A C C 1060 E5 DIA MOV EX Y2 2201 LTJ AJ Valve Name SF RETURN LINE INBOARD ISOLATION 1SF004 2 A 12 GA MO A C C 1060 C5 DIA MOV, EX Y2 2201 LTJ AJ Valve Name SF SUCTION LINE OUTBOARD ISOLATION VALVE Revision Date: 06128/10

p-Clinton Station IST PROGRAM PLAN Suppression Pool Makeup. (Page 1),

Test Test Relief Deferred Tech.

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1SM001A 2 B 24 BTF MO A C 0 1069 D5 DIA MOV EX Y2 2201 Valve Name SUP POOL MAKE-UP SYS DUMP SHUTOFF VALVE ISM001B 2 B 24 BTF MO A C 0 1069 D4 DIA MOV EX Y2 2201 Valve Name SUP POOL MAKE-UP SYS DUMP SHUTOFF VALVE 1SM002A 2 B 24 BTF MO A C 0 1069 D5 DIA MOV EX Y2 2201 Valve Name SUP POOL MAKE-UP SYS DUMP SHUTOFF VALVE 1SM002B 2 B 24 BTF MO A C 0 1069 04 DIA MOV EX Y2 2201 Valve Name SUP POOL MAKE-UP SYS DUMP SHUTOFF VALVE 1SM003A 2 C 0.75xl RV SA A C 0 1069 D5 RT , Y10 Valve Name SUPP POOL MAKE-UP FUEL POOL DUMP LINE RELIEF VALVE 1SMO03B 2 C 0.75x1 RV SA A C 0 1069 .D4 RT Y10 Valve Name SUPP POOL MAKE-UP FUEL POOL DUMP LINE RELIEF VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Shutdown Service Water (Page 1)

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1SX001A 3 C 30 CK SA A SYS O/C 1052,1 D7 CC CMP CO CMP Valve Name SHUTDOWN SERV WATER PUMP 1A DISCHG CHK VALVE 1SX001B 3 C 30 CK SA A SYS 0/C 1052,2 D7 CC CMP CO CMP Valve Name SHUTDOWN SERV WATER PUMP 1B DISCHG CHK VALVE 1SX001C 3 C 10 CK SA A SYS O/C 1052,3 D7 CC CMP CO CMP Valve Name SHUTDOWN SERV WATER PUMP 1C DISCHG CHK VALVE 1SX003A 3 B 30 BTF MO P 0 0 1052,1 D6 PI Y2 Valve Name SSW STRAINER 1A INLET VALVE 1SX003B B 30 BTF MO. P 0 0 1052,2 D6 PI Y2 Valve Name SSW STRAINER 16 INLET VALVE 1SX003C B 10 BTF MO P 0 0 1052,3 D6 P1 Y2 Valve Name SSW STRAINER 1C INLET VALVE 1SX004A B 30 BTF MO P 0 0 1052,1 D5 PI Y2 Valve Name SSW STRAINER 1A OUTLET VALVE II 1SX0048 B 30 BTF MO P 0 0 1052,2 D5 P1 Y2 Valve Name SSW STRAINER 1B OUTLET VALVE 1SX004C B 10 BTF MO P 0 0 1052,3 05 PI Y2 Valve Name SSW STRAINER IC OUTLET VALVE I I 1SX006C B 8 BTF MO A C 0 1052,3 D2 DIA MOV EX M3 2201 Valve Name DG 1C HEAT EXCHANGER OUTLET VALVE 1SX008A 3 B 20 BTF MO A C 0 1052,1 E6 DIA MOV EX Y2 2201 Valve Name SSW STRAINER 1A BYPASS VALVE 1SX008B 3 B 20 BTF MO A C 0 1052,2 E6 DIA MOV EX Y2 2201 Valve Name SSW STRAINER 1B BYPASS VALVE 1SX008C 3 B 8 BTF MO A C 0 1052,3 E6 DIA MOV EX Y2 2201 Valve Name SSW STRAINER 1C BYPASS VALVE 1SX010A 3 B 2 GL AO A C 0 1052,1 E3 FO M3 Valve Name 1VHO0SA FLOW CONTROL VALVE 1SX010B 3 B 2 GL AO A C 0 1052,2 E3 FO M3 Valve Name 1VH07SB FLOW CONTROL VALVE Revision Date: 06/28/10O

I f, Clinton Station IST PROGRAM PLAN Shutdwn q Service Water (Page 2),

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1SX010C 3 B 1.5 GL AO A C 0 1052,3 E4 FO M3 Valve Name 1VH07SC SX PUMP RM IC FLOW CONTROL VALVE 1SX011A 3 A 16 BTF MO P C C 1052,1 D3 LT Y2 PI Y2 Valve Name DIV I CROSS TIE VALVE 1SX011B 3 A 16 BTF MO P C C 1052,2 E3 LT Y2 PI Y2 Valve Name DIV 2 CROSS TIE VALVE 1SX012A 3 B 14 BTF MO A C 0 1052,1 C3 DIA MOV EX Y2 2201 Valve Name FC HX 1A SSW INLET VALVE 1SX012B 3 B 14 BTF MO A C 0 1052,2 C3 DIA MOV EX Y2 2201 Valve Name FC HX 18 SSW INLET VALVE 1SX013D 3 6 3 PLG MO A C 0 1052,1 D5 DIA MOV EX Y2 2201 Valve Name SSW STRAINER 1A BACKWASH VALVE 1SXO13E 3 B 3 PLG MO A C 0 1052,2 D5 DIA MOV EX Y2 2201 Valve Name SSW STRAINER 1B BACKWASH VALVE 1SX013F 3 B 2 PLG MO A C O/C 1052,3 C5 DIA MOV EX Y2 2201 Valve Name SSW STRAINER 1C BACKWASH VALVE 1SX014A 3 A 20 BTF MO A 0 C 1052,1 F3 DIA MOV EX M3 2201 LT Y2 Valve Name SSW SYSTEM 1A ISOLATION VALVE 1SX014B 3 A 20 BTF MO A 0 C 1052,2 F3 DIA MOV EX M3 2201 LT Y2 Valve Name SSW SYS 1B ISOLATION VALVE 1SX014C 3 A 8 BTF MO A 0 C 1052,3 E4 DIA MOV EX M3 2201 LT Y2 Valve Name SSW SYS IC ISOLATION VALVE 1SX016A 3 B 2.5 GA MO A C OIC 1052, 1 D3 . DIA MOV EX Y2 2201 Valve Name DIV 1 FUEL POOL MAKE-UP INLET VALVE Revision Date: 06/28/10

j .

Clinton Station IST PROGRAM PLAN Shutdown Service Water (Page 3)

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1SX016B 3 B 2.5 GA MO A C O/C 1052,2 D3 DIA MOV EX Y2 2201 Valve Name DIV 2 FUEL POOL MAKE-UP INLET VALVE 1SX017A 3 B 8 BTF MO P 0 0 1052,1 B8 PI Y2 Valve Name HVAC UNIT 1A HEAT EXCH INLET VALVE 1SX017B 3 B 8 BTF MO P 0 0 1052, 2 B8 PI Y2 Valve Name HVAC UNIT 16 HEAT EXCH INLET VALVE 1SX020A 3 A 12 BTF MO A 0 C 1052, 1 C4 DIA MOV EX Y2 2201 LT Y2 Valve Name DIV I DRYWELL CHILLER ISOLATION VALVE 1SX0208 3 A 12 BTF MO A 0 C 1052,2 C4 DIA MOV EX Y2 2201 LT Y2 Valve Name DIV 2 DRYWELL CHILLER ISOLATION VALVE 1SX023A 3 B 2 GL AO A C 0 1052,1 C2 FO M3 Valve Name 1VY03S FLOW CONTROL VALVE 1SX023B 3 B 2 GL AO A C 0 1052,2 C2 FO M3 Valve Name 1VY05S FLOW CONTROL VALVE 1SX027A 3 B 2.5 GL AO A C 0 1052,4 D6 FO M3 Valve Name 1VY02S FLOW CONTROL VALVE 1SX027B 3 B 2.5 GL AO A C 0 1052,4 D2 FO M3 Valve Name 1VY06S FLOW CONTROL VALVE 1SX027C 3 B 2.5 GL AO A C 0 1052,4 C2 FO M3 Valve Name 1VY07S FLOW CONTROL VALVE 1SX033 3 6 2.5 GL AO A C 0 1052,4 C6 FO M3 VaNe Name 1VY01S FLOW CONTROL VALVE 1SX037 3 B 1.5 GL AO A C 0 1052,4 86 FO M3 Valve Name 1VY04S FLOW CONTROL VALVE 1SX041A 3 B 2.5 GL AO A C 0 1052,3 C2 FO M3 Valve Name 1VY08SA HPCS PUMP ROOM SX OUTLET FLOW CONTROL VLV 1SX041B 3 B 2.5 GL AO A C 0 1052,3 B2 FO M3 Valve Name 1VY08SB HPCS RMEAC 18 SX OUTLET FLOW CONTROL VLV 1SX062A 3 B 14 BTF MO A C 0 1052, 1 B4 DIA MOV EX Y2 2201 Valve Name FCHX 1A SSW OUTLET VALVE Revision Date: 06/28110

L Clinton Station IST PROGRAM PLAN Shutdown ServiceWater (Page. 4).

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech. (,

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1SXO62B B 14 BTF MO A C 0 1052,2 B4 DIA MOV EX Y2 2201 Valve Name FC HX 1B SSW OUTLET VALVE 1SX063A 3 B 8 BTF MO A C 0 1052,1 C2 DIA MOV EX M3 2201 Valve Name DIESEL GEN 1A HEAT EXCH OUTLET VALVE 1SX063B 3 B 8 BTF MO A C 0 1052,2 C2 DIA MOV EX M3 2201 Valve Name DIESEL GEN 1B HEAT EXCH OUTLET VALVE 1SX071A 3 B 3 GA MO P C C 1052,5 F7 PI Y2 Valve Name SBGT TRAIN A FIRE PROTECT DELUGE VALVE 1SX071B 3 B 3 GA MO P C C 1052,5 F3 P1 Y2 Valve Name SBGT TRAIN B FIRE PROTECT DELUGE VALVE 1SX073A 3 A 3 GA MO P C C 1052,5 F5 LT Y2 P1 Y2 Valve Name SBGT TRAIN A FIRE PROTECT DELUGE VALVE 1SX073B 3 A 3 GA MO P C C 1052,5 F2 LT Y2 P1 Y2 Valve Name SBGT TRAIN B FIRE PROTECT DELUGE VALVE 1SX074A 3 B 3 GA MO P C C 1052,5 E7 PI Y2 Valve Name CONT RM TRAIN A SUPPLY FILTER FP DELUGE VALVE 1SX074B 3 B 3 GA MO P C C 1052,5 E3 PI Y2 Valve Name CONT RM TRAIN B SUPPLY FILTER FP DELUGE VALVE 1SX076A 3 A 3 GA MO P C. C 1052,5 D7 LT Y2 PI Y2 Valve Name CONT RM TRAIN ASUPPLY FILTER FP DELUGE VALVE 1SX076B 3 A 3 GA MO P C C 1052,5 D3 LT Y2 PI Y2 Valve Name CONT RM TRAIN B SUPPLY FILTER FP DELUGE VALVE 1SX082A 3 A 3 GA MO A 0 C 1052,1 D1 DIA MOV EX Y2 2201 LT Y2 Valve Name RHR HX 1A DEMIN WATER INLET VALVE 1SX082B 3 A 3 GA MO A 0 C 1052,2' Dl DIA MOV EX Y2 2201 LT Y2 Valve Name RHR HX 18 DEMIN WATER INLET VALVE Re vision Datle: 06/28/10

Clinton Station IST PROGRAM PLAN Shutdown Service Water (Page 5)

' Valve EPN Safety Class Category Size Valve Type Act.

Type Active) - Normal Passive Position Safety Position P&ID P&ID Coor.

Test Test Type Freq.

Relief Request Deferred*

Just.

Tech.

Pos.

1SX105A 3 B 3 GA MO P C C 1052,5 D7 PI, Y2 Valve Name CONT RM TRAIN AMAKEUP FILTER FP DELUGE VALVE 1SX105B 3 B 3 GA MO P C C 1052,5 D3 Pt Y2 Valve Name CONT RM TRAIN B MAKEUP FILTER FP DELUGE VALVE 1SX107A 3 A 3 GA MO P C C 1052,5 D7 LT Y2 PI Y2 Valve Name CONT RM TRAIN A MAKEUP FILTER FP DELUGE VALVE 1SX107B 3 A 3 GA MO P C C 1052,5 D3 LT Y2 PI Y2 Valve Name CONT RM TRAIN B MAKEUP FILTER FP DELUGE VALVE 1SX149 3 C 0.75xl RV SA A C 0 105214 C6 RT Y10 Valve Name LPCS PUMP ROOM COOLER RELIEF VALVE 1SX150 0.75x1 RV SA A C 0 1052,4 B6 RT Y10 Valve Name RCIC PUMP ROOM COOLER RELIEF VALVE 1SX151A 0.75x1 RV SA A C 0 1052,4 E6 RT Y1 Valve Name RHR PUMP ROOM COOLER 1A RELIEF VALVE 1SX151B 0.75xl RV SA A C 0 1052,4 E2 RT Y10 Valve Name RHR PUMP ROOM COOLER 1B RELIEF VALVE 1SX151C 0.75x1 RV SA A C 0 1052,4 C2 RT Y10 Valve Name RHR PUMP ROOM COOLER 1C RELIEF VALVE 1SX152A 0.75xA RV SA A C 0 1052,1 C3 RT Y10 Valve Name RHR HX ROOM 1A COOLER RELIEF VALVE 1SX152B 0.75xA RV SA A C 0 1052,2 C2 RT Y10 Valve Name RHR HX ROOM 1B COOLER RELIEF VALVE 1SX153A 0.75xl RV SA A C 0 1052, 1 C7 RT Y10 Valve Name CONTROL ROOM CHILLER RELIEF VALVE 1Sx153B 0.75xl RV SA A C 0 1052,2 C6 RT Y10 Valve Name CONTROL ROOM CHILLER RELIEF VALVE 1SX154A 0.7sxl RV SA A C 0 1052,4 E6 RT Y10 Valve Name SWGR HEAT REMOVAL UNIT RELIEF VALVE 1SX154B 3 C 0.75x1 RV SA A C 0 1052,4 E2 RT. Y10 Valve Name SWGR HEAT REMOVAL UNIT RELIEF VALVE 1SX154C 3 C 0.75x0 RV SA A C 0 1052,3 C2 RT Y10 Valve Name DIV IIISWGR COND UNIT SX OUTLET RELIEF VALVE 1SX155A 3 C 0.75x1 RV SA A C 0 1052,1 E4 RT Y10 Valve Name SX PUMP ROOM 1A COOLER RELIEF VALVE Revision Date: 06/28110

. k Clinton Station IST PROGRAM PLAN Shutdown Service Water (Page 6)-

Valve EPN Safety Category Size Valve Act. Active / Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1SX155B 3 C 0.75xl RV SA A C 0 1052,2 E3 RT Y10 Valve Name SX PUMP ROOM 1B COOLER RELIEF VALVE 1SX155C C 0.75xl RV SA A C 0 1052,3 D4 RT Y10 Valve Name SX PUMP ROOM 1C COOLER RELIEF VALVE 1SX156A C 0.75xl RV SA A C 0 1052,3 B2 RT Y10 Valve Name HPCS PUMP ROOM COOLER 1A RELIEF VALVE 1SX1568 C 0.75xl RV SA A C 0 1052,3 82 RT Y10 Valve Name HPCS PUMP ROOM COOLER 1B RELIEF VALVE 1SX169A 3 C 0,75xl RV SA A C 0 1052, 1 C3 RT Y10 Valve Name DIV 1 DIG HX RELIEF VALVE 1SX169B C 0.75xl RV . SA A C O 1052,2 C3 RT Y10 Valve Name DIV 2 D/G HX RELIEF VALVE 1SX169C C 0.75xl RV SA A C O 1052,3 D2 RT Y10 Valve Name DIV 3 D/G HX RELIEF VALVE 1SX170A C 0.75xl RV SA A C O 1052,1 B3 RT Y10 Valve Name DIV 1 D/G HX RELIEF VALVE 1SX170B C 0.75xl RV . SA A C O 1052,2 B3 RT Y10 1SX181A B Valve Name DIV 2 DIG HX RELIEF VALVE 2.5 GA AO A C O 1052,1 F1 FO M3 4/

Valve Name OVG05SA FLOW CONTROL VALVE 1SX181B B 2.5 GA AO A C O 1052,2 F1 FO M3 Valve Name OVG05SB FLOW CONTROL VALVE 1SX185A B 2.5 GL AO A C O 1052,1 El FO M3 Valve Name OVG07SA FLOW CONTROL VALVE 1SX185B 3 B 2.5 GL AO A C 0 1052,2 El FO M3 Valve Name OVG07SB FLOW CONTROL VALVE 1SX189 3 B 2.5 GL AO A C 0 1052, 2 A4 FO M3 Valve Name DIV IVINVERTER RM COOLER CONTROL VALVE 1SX193A 3 B 1.5 GL AO A C 0 1052,1 B7 FO M3 Valve Name DIV I INVERTER RM COOLING COIL CONTROL VALVE 1SX193B 3 B 1.5 GL AO A C 0 1052,2 64 FO M3 Valve Name DIV IIINVERTER RM COOL COIL CONTROL VALVE 1SX197 3 B 2 GL AO A C 0 1052,1 B4 FO M3 Valve Name 1VY09S FLOW CONTROL VALVE 1SX200A 3 C 0.75xl RV SA A C 0 1052, 1 F1 RT Y10 Valve Name SBGT RM 1A COOLING COIL RELIEF VALVE Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Shutdown Service Water (Page 7)

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1SX200B 3 C 0.75xA RV SA A C 0 1052,2 F1 RT Y10 Valve Name SBGT RM 1B COOLING COIL RELIEF VALVE I m ISX201A 0.75xl RV SA A C 0 1052, 1 El RT Y10 Valve Name H2 RECOMB RM 1A COOLING COIL RELIEF VALVE III 1SX201B 0.75xl RV SA A C 0 1052,2 El RT Y10 Valve Name H2 RECOMB RM 1B COOLING COIL RELIEF VALVE 1SX202A 0.75x1 RV SA A C 0 1052, 1 A7 RT Y10 Valve Name INVERTER RM 1A COOLING COIL RELIEF VALVE 1SX202B 0.75xl RV SA A C 0 1052,2 C5 RT Y10 Valve Name INVERTER RM 1B COOLING COIL RELIEF VALVE 1SX203 0.75xl RV SA A C 0 1052,2 B5 RT Y10 Valve Name DIV IVINVERT RM COOLING COIL RELIEF VALVE 1SX204 0.75xl RV SA A C 0 1052,1 65 RT Y10 Valve Name SX OUTLET RELIEF MSIV LEAKAGE RM COOLING COIL

'1SX207 0.75xl RV SA A C 0 1052,2 B2 RT Y10 Valve Name MSIV LEAKAGE OUTBD RM COOLING COIL RELIEF VALVE 1SX208A 4x6 RV SA A C 0 1052,1 C1 RT Y10 Valve Name RHR HX 1A RELIEF VALVE

(. 1SX2088 4x6 RV SA A Valve Name RHR HX 16 RELIEF VALVE C 0 1052,2 D1 RT Y10 1SX209 1.5 GL AO A C 0 1052,2 Al FO M3 Valve Name 1VY10A FLOW CONTROL VALVE 1SX225 3.00 GA M P C C 1052,3 D4 LT Y2 Valve Name PASS SYSTEM SX INLET ISOLATION VALVE 1SX294 0.75xl RV SA A C 0 1052, 1' D7 RT Y10 Valve Name OPR13A SX RELIEF VALVE 1SX303A 4 CK SA A SYS O/C 1052, 1 B7 CC cmp CO cmp Valve Name OVC13CA SSW INLET LINE VACUUM BREAKER VALVE 1SX303B 3 B 4 CK SA A SYS O/C 1052,2 C6 CC cmp CO cmp Valve Name OVC13CB SSW INLET LINE VACUUM BREAKER VALVE 1SX315A 3 C 3/4 CK SA A SYS O/C 1052,3 C2 CC CMP CO CMP Valve Name DIV. IIISG RM COND. SX OUTLET VACUUM BRKR VALVE W(* Revision Date: 06/28/10

a 4 Clinton Station IST PROGRAM PLAN Shutdown Service Water* (Page* ),

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1SX315B 3 C 3/4 CK SA A SYS O/C 1052,3 C2 CC CMP CO CMP Valve Name DIV. Ill SG RM COND. SX OUTLET VACUUM BRKR VALVE 1SX316A 3 C 3/4 CK SA A SYS O/C 1052,3 C3 CC CMP CO CMP Valve Name DIV. IIISG RM COND. SX INLET VACUUM BRKR VALVE 1SX316B 3 C 3/4 CK SA A SYS O/C 1052,3 C3 CC CMP CO. CMP Valve Name DIV. IIISG RM COND. SX INLET VACUUM BRKR VALVE 1SX346A 3 C 4 CK SA A O/C 1052,4 F7 CC CMP CO CMP Valve Name IVX06CA SSW INLET LINE VACUUM BREAKER VALVE 1SX346B 3 C 4 CK SA A O/C 1052,4 E3 CC CMP CO CMP Valve Name 1VX06CB SSW INLET LINE VACUUM BREAKER 1SX348A 3 C 4 CK SA A O0C 1052,4 F5 CC CMP CO CMP Valve Name 1VX06CA SSW OUTLET LINE VACUUM BREAKER VALVE 1SX348B 3 C 4 CK SA A O/C 1052,4 F2 CC CMP CO CMP Valve Name 1VX06CB SSW OUTLET LINE VACUUM BREAKER Revision Date: 06/28110

Clinton Station IST PROGRAM PLAN Control Room Ventilation (Page 1)

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

OVC010A 3 B 2 GL AO A 0 0 1102,5 A7 FO M3 Valve Name AUTO FLOW REGULATOR VALVE 0VC010B 3 B 2 GL AO A 0 0 1102,6 A7 FO M3 Valve Name AUTO FLOW REGULATOR VALVE OVC016A 3 B 2 GL M A C O/C 1102,5 F6 ET Y2 Valve Name MCR CWS M/U MANUAL ISOL VALVE 0VCO16B 3 B 2 GL M A C O/C 1102,6 F6 ET Y2 Valve Name MCR CWS M/U ISOL VALVE OVC017A 3 C 2 CK SA A SYS 0 1102,5 F7 BDC M3 CO M3 Valve Name MCR CWS M/U CHECK VALVE OVCO17B 3 C 2 CK SA A SYS 0 1102,6 F7 BDC M3 CO M3 Valve Name MCR CWS M/U CHECK VALVE OVC020A 3 C 2 CK SA A SYS C 1102,5 F7 BDO M3 CC M3 Valve Name MCR CWS MAKE UP CHECK VALVE OVC020B 3 C 2 CK SA A SYS C 1102,6 F7 BDO M3 CC M3 Valve Name MC MAKE UP CHECK VALVE OVC022A 3 B 1.5 GL AO A C 0 1102,5 F7 FO M3 Valve Name MCR CHILLED M/U WATER CONTROL VALVE OVC022B 3 B 1.5 GL AO A C 0 1102,6 F7 FO M3 Valve Name MCR CHILLED M/U WATER CONTROL VALVE OVC025A 3 C lxl.5 RV SA A C 0 1102,5 E6 RT Y10 Valve Name COMPRESSION TANK ARELIEF VALVE OVC025B 3 C lxl.5 RV SA A C 0 1102,6 E6 RT Y10 Valve Name COMPRESSION TANK B RELIEF VALVE Revision Date: 06/28/10

& t Clinton Station IST PROGRAM PLAN Drywell Cooling (Page 1)

Test Test Relief Deferred Tech. ___

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1VP004A 2 A 10 GA MO A 0 C 1109,2 D3 DIA MOV EX Y2 2201 LTJ AJ Valve Name DRYWELL CHILLED WATER A SUPPLY OUTBOARD ISOLATION 1VP004B 2 A 10 GA MO A 0 C 1109,3 D3 DIA MOV EX Y2 2201 LTJ AJ Valve Name DRYWELL CHILLED WATER B SUPPLY OUTBOARD ISOLATION 1VP005A 2 A 10 GA MO A 0 C 1109,2 D2 DIA MOV EX Y2 2201 LTJ AJ Valve Name DRYWELL CLG 1A SPLY INBOARD ISOL VALVE 1VP005B 2 A 10 GA MO A 0 C 1109,3 D2 DIA MOV EX Y2 2201 LTJ AJ Valve Name DRYWELL CHILLED WATER B SUPPLY INBOARD ISOLATION 1VP014A 2 A 10 GA MO A 0 C 1109,2 E3 DIA MOV EX Y2 2201 LTJ AJ Valve Name DRYWELL CHILLED WATER A RETURN INBOARD ISOLATION 1VPO14B 2 A 10 GA MO A 0 C 1109,3 E2 DIA MOV EX Y2 2201 LTJ AJ Valve Name DRYWELL CLG 1B RTRN INBOARD ISOL VALVE 1VP015A 2 A 10 GA MO A 0 C 1109,2 E3 DIA MOV EX Y2 2201 LTJ AJ Valve Name DRYWELL CHILLED WATER ARETURN OUTBOARD ISOLATION IVPO15B 2 A 10 GA MO A 0 C 1109,3 E3 DIA MOV EX Y2 2201 LTJ AJ Valve Name DRYWELL CHILLED WATER B RETURN OUTBOARD ISOLATION 1VP023A 2 A/C 0.75xl RV SA A C O/C 1109,2 D3 LTJ AJ RT Y10 Valve Name DW CHILLED WATER A SUPPLY LINE RELIEF VALVE IVP023B 2 A/C 0.75xl RV SA A C O/C 1109,3 D3 LTJ AJ RT Y10 Valve Name DW CHILLED WATER B SUPPLY LINE RELIEF VALVE Revision Date: 06/28/10

4 0 ,p Clinton Station IST PROGRAM PLAN Drywell Cooling (Page 2)

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1VPO'27A 2 A/C 0.75xl RV SA A C O/C 1109,2 F3 LTJ AJ RT Y10 VaIVe Name DW COOL SYS COIL CAB 1C RELIEF VALVE 1VPO27B 2 A/C 0.75x0 RV SA A C O/C 1109,3 F3 LTJ AJ RT Y10 Valve Name DW COOL SYS COIL CAB 10 RELIEF VALVE W"-O Revision Date: 06/28/10

Clinton Station IST PROGRAM PLAN Primary Containment Purge (Page 1)

Valve EPN Safety Category Size Valve Act. Active ! Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1VQ001A 2 B 24 BTF AO P C C 1110,2 C8 PI Y2 Valve Name DW PURGE TO CONTAINMENT EXHAUST FAN ISOLATION DMPR 1VQ001B 2 B 24 BTF AO P C C 1110,2 C7 PI Y2 Valve Name DW PURGE MOIST SEP 8 INLET DRN VALVE 1VQ002 2 B 24 BTF AO P C C 1110,2 C6 PI Y2 Valve Name DRYWELL PURGE SYS EXHAUST DRYWELL ISOLATION VALVE 1VQ003 2 8 36 BTF AO A C C 1110,2 C5 FC CS CSJ-104 PI Y2 Valve Name EXHAUST OUTBOARD DRYWELL ISOLATION VALVE

.1VQ004A 2 A 36 BTF AO A C C 1110,2 D4 FC CS CSJ-107 LTJ AJ PI Y2 Valve Name DW PURGE CONTAINMENT OUTBOARD ISOLATION DAMPER 1VQ004B 2 A. 36 BTF AO A C C 1110,2 D5 FC CS CSJ-107 LTJ AJ PI Y2 Valve Name CONTAINMENT BUILDING EXH PURGE INBOARD ISOL VALVE 1VQ005 2. B 10 BTF AO P C C 1110,2 D6 PI Y2 Valve Name EXHAUST INBOARD SYSTEM DRYWELL ISOL VALVE 1VQ006A 2 A 4 GL MO P C C 1110,2 C4 LTJ AJ PI Y2 Valve Name CNMT EXHAUST OUTBOARD ISOLATION BYPASS VALVE 1VQ006B 2 A 4 GL MO P C C 1110,2 C4 LTJ AJ PI Y2 Valve Name CNMT EXHAUST INBOARD ISOLATION BYPASS VALVE Revision Date: 06/28/!10

Clinton Station IST PROGRAM PLAN Containment Building Ventilation (Page 1)

Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

. Valve EPN Safety Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1VRO01A 2 A 36 BTF AD A C C 1111,1 E2 FC CS CSJ-107 LTJ AJ PI Y2 Valve Name CONTAINMENT VENT OUTBOARD ISOLATION VALVE 1VR001B 2 A 36 BTF AO A C C 1111,1 El FC CS CSJ-107 LTJ AJ PI Y2 Valve Name CONTAINMENT VENT INBOARD ISOLATION VALVE IVRO02A 2 A 4 GL MO P C C 1111,1 E2 LTJ AJ PI Y2 Valve Name FUEL BLDG VR SUPPLY OUTBOARD ISOL. BYPASS VALVE IVRO02B 2 A 4 GL MO P C C 1111,1 El LTJ AJ P! Y2 Valve Name CNMT VR SUPPLY INBOARD ISOLATION BYPASS VALVE 1VRO06A 2 A 12 BTF AD A 0 C 1111,5 E3 FC CS CSJ-104 LTJ AJ PI Y2 Valve Name CONTINUOUS CNMT HVAC SUPPLY OUTBOARD ISOLATION 1VR006B 2 A 12 BTF AD A 0 C 1111,5 E2 FC CS CSJ-104 LTJ AJ PI Y2 Valve Name CONTINUOUS CNMT HVAC SUPPLY INBOARD ISOLATION 1VRO07A 2. A 12 BTF AO A 0 C 1111,5 B7 FC CS CSJ-104 LTJ AJ PI Y2 Valve Name CCP OUTBOARD EXHAUST ISOLATION VALVE 1VR007B 2 A 12 BTF AO A 0 C 1111,5 B7 FC CS CSJ-104 LTJ AJ PI Y2 Valve Name CCP INBOARD EXHAUST ISOLATION VALVE 1VR035 2 A 0.75 PLG SO A 0 C IS 1111,3 822 FC CS CSJ-104 LTJ AJ PI Y2 Valve Name IPDCVRO20 AIR LINE ISOLATION VALVE 1VR036 2 A 0.75 PLG SO A 0 C IS 1111,3 822 FC CS CSJ-104 LTJ AJ PI Y2 Valve Name 1PDCVR020 CNMT PURGE AIR LINE ISOLATION VALVE Revision Date: 06/28/10

ýw 15 .*

Clinton Station IST PROGRAM PLAN Containment Building-Ventilation:ý (page 2),

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

IVRO40 2 A 0.75 PLG SO A 0 C IS 1111,3 822 FC CS CSJ-104 LTJ AJ PI Y2 Valve Name CCP AIR LINE ISOLATION VALVE 1VR041 2 A 0.75 PLG SO A 0 C IS 1111,3 822 FC CS CSJ-104 LTJ AJ PI Y2 Valve Name 1TSVR166 ISOLATION VALVE Revision Date: 06/28/10

40 rl Clinton Station IST PROGRAM PLAN Plant Chilled Water (Page 1)

Safety Category Size Valve Act. Active / Normal Safety P&ID P&ID Test Test Relief Deferred

. Valve EPN Class Type Type Passive Position Position Coor. Type Freq. Request Just.

Tech.

Pos.

IWO001A 2 A 6 GA MO A 0 C 1117,19 E5 DIA MOV EX Y2 2201 LTJ AJ Valve Name PLANT CHILLED WATER OUTBOARD ISOLATION VALVE 1WO001B 2 A 6 GA MO A 0 C 1117,19 E6 DIA MOV EX Y2 2201 LTJ AJ Valve Name PLANT CHILLED WATER INBOARD ISOLATION VALVE 1WO002A 2 A 6 GA MO A 0 C 1117,19 F5 DIA MOV EX Y2 2201 LTJ AJ Valve Name PLANT CHILLED WATER OUTBOARD ISOLATION VALVE 1WO002B 2 A 6 GA MO A 0 C 1117,19 F6 DIA MOV EX Y2 2201 LTJ AJ Valve Name PLANT CHILLED WATER INBOARD ISOLATION VALVE e-.. 1WO551A 1WO551B 2

2 B

B 4 GA MO A Valve Name DRYWELL OUTBOARD ISOL VALVE 4 GA MO A Valve Name DRYWELL INBOARD ISOL VALVE 0

0 C

C 1117,26 1117,26 E7 E7 DIA EX DIA EX MOV Y2 MOV Y2 2201 2201 1WO552A 2 B 4 GA MO A 0 C 1117,26 D7 DIA MOV EX Y2 2201 Valve Name PLANT CHILL WATER OUTBOARD ISOLATION VALVE 1W0552B 2 B 4 GA MO A 0 C 1117,26 D7 DIA MOV EX Y2 2201 Valve Name PLANT CHILL WATER INBOARD ISOLATION VALVE 1WO570A 2 C 0.75xl RV SA A C O/C 1117,26 F7 RT Y10 Valve Name PLANT CHILLED WATER SYSTEM SAFETY RELIEF VLV 1WO570B 2 C 0.75x1 RV SA A C O/C 1117,26 D7 RT Y10 Valve Name PLANT CHILLED WATER SAFETY RELIEF VLV Revision .Date: 06/28/10

w k

Clinton Station IST PROGRAM PLAN Solid Radwaste:Reprocessing and Disposal (Page 1)

Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&ID P&ID Test Test Relief Deferred Tech.

Class Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.

1WX019 2 A 2 PLG AO A 0 C 1089,2 F6 FC M3 LTJ AJ PI Y2 Valve Name INBOARD CNMT ISOLATION VALVE 1WX020 2 A 2 PLG AO A 0 C 1089,2 F5 FC M3 LTJ AJ" PI Y2 Valve Name OUTBOARD CNMT ISOLATION VALVE 1WX080 2 A/C 3/4 RV SA A C O/C 1089,2 F5 LTJ AJ RT Y10 Valve Name RADWASTE CONT. PEN RELIEF VALVE Revision Date: 06/28/10

U-603967, Submittal of Inservice Testing Program Plan for the Third Ten-Year Interval

Text

Subject:

1.0 INTRODUCTION

1.0 INTRODUCTION

2. Applicable Code Edition and Addenda

3. Applicable Code Requirement

4. Reason for Request

Response

Response

Response

Response

Response

Response

Response

2. Applicable Code Edition and Addenda

3. Applicable Code Requirement

Description:

2. Applicable Code Edition and Addenda

3. Applicable Code Requirement

4. Reason for Request

Response

Title:

Background:

References:

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Background:

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Title:

Background:

References:

Title:

Background:

References:

Title:

Background:

References:

Title:

Background:

References:

Title:

Background:

References:

Title:

Background:

References:

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