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{{Adams
#REDIRECT [[TMI-14-069, Submittal of the Fifth Ten-Year Interval Inservice Testing Program]]
| number = ML14147A018
| issue date = 05/16/2014
| title = Three Mile Island, Unit 1 - Submittal of the Fifth Ten-Year Interval Inservice Testing Program
| author name = Barstow J
| author affiliation = Exelon Generation Co, LLC
| addressee name =
| addressee affiliation = NRC/Document Control Desk, NRC/NRR
| docket = 05000289
| license number = DPR-050
| contact person =
| case reference number = TMI-14-069
| document type = Inservice/Preservice Inspection and Test Report, Letter
| page count = 234
}}
 
=Text=
{{#Wiki_filter:AdnowAdENOW200 Exelon WayKennett Square, PA 19348www.exeloncorp.comExelon Generation,10CFR50.55aTMI-14-069May 16, 2014U.S. Nuclear Regulatory CommissionATTN: Document Control DeskWashington, DC 20555-0001Three Mile Island Nuclear Station, Unit 1Renewed Facility Operating License No. DPR-50NRC Docket No. 50-289
 
==Subject:==
Submittal of the Fifth Ten-Year Interval Inservice Testing ProgramIn accordance with the ASME OM Code-2004 Edition, with Addenda through OMb-2006(ISTA-3200(a)), attached for your information is a copy of the fifth ten-year interval InserviceTesting (IST) Program Plan for the Three Mile Island Nuclear Station, Unit 1. This copy ofthe program plan is being supplied for information only.There are no regulatory commitments contained within this letter.If you have any questions or require additional information, please contact Tom Loomis(610-765-5510).Sincerely,James BarstowDirector -Licensing & Regulatory AffairsExelon Generation Company, LLC
 
==Attachment:==
Three Mile Island Nuclear Station, Unit 1 Inservice Testing (IST) Program PlanFifth Ten-Year Intervalcc: Regional Administrator, Region I, USNRCUSNRC Senior Resident Inspector, TMIProject Manager, USNRC#L47 ATTACHMENTThree Mile Island Nuclear Station, Unit 1Inservice Testing (IST) Program PlanFifth Ten-Year Interval Exelon Nuclear Generation, LLC.200 Exelon WayKennett Square, PA 19348Three Mile Island Unit #1NRC Docket Number 50-289Three Mile Island Unit #1Route 441 SouthMiddletown, Pennsylvania 17057-0480Commercial Service Date:September 2, 1974Inservice Testing (IST) ProgramProgram PlanFifth Ten-Year IntervalOctober 25, 2013 -September 22, 2024Revision 0October 25, 2013 Three Mile Island Unit #1Inservice Testing Program PlanREVISION RECORDEffective Revision Description Sign & DateDate Prepared: Reviewed: Approved;Site IST Corporate Engr.Engineer IST Programs, A .1 Engineer Manager10/25/2013Revision 0:Program revised in its entirety for fifth 10-yearinterval to comply with ASME OM Code-2004, including OMa Code-2005 and OMbCode-2006 Addenda's.Masoero10/2312013RuffMark'-1--f--4. +Revision 0October 25, 2013 Three Mile Island Unit #1Inservice Testing Program PlanTABLE OF CONTENTSSECTION
 
==1.0 INTRODUCTION==
1.1 Purpose1.2 Scope1.3 Discussion1.4 References2.0 INSERVICE TESTING PLAN FOR PUMPS2.1 Pump Inservice Testing Plan2.2 IST Plan Pump Table Description3.0 INSERVICE TESTING PLAN FOR VALVES3.1 Valve Inservice Testing Plan3.2 IST Plan Valve Table Description4.0 ATTACHMENTS1. System and P&ID Listing2. Pump Relief Request Index3. Pump Relief Requests4. Valve Relief Request Index5. Valve Relief Requests6. Relief Request RAI Responses and SERs7. Code Case Index8. Cold Shutdown Justification Index9. Cold Shutdown Justifications10. Refueling Outage Justification Index11. Refueling Outage Justifications12. Technical Position Index13. Technical Positions14. Inservice Testing Pump Table15. Inservice Testing Valve Table16. Check Valve Condition Monitoring Plan IndexRevision 0October 25, 2013 Three Mile Island Unit #1Inservice Testing Program Plan
 
==1.0 INTRODUCTION==
1.1 PurposeThe purpose of this Inservice Testing (IST) Program Plan is to provide a summarydescription of the Three Mile Island Unit #1 IST Program in order to document itscompliance with the requirements of 10 CFR 50.55a(f) for the 5th 10-year ISTinterval.1.2 ScopeThis Inservice Testing Program Plan identifies all of the testing performed on thecomponents included in the Three Mile Island Unit #1 Inservice Testing (IST) Programfor the 5th ten-year IST interval, which will begin on October 25, 2013 and isscheduled to end on September 22, 2024. (Note: The Fourth Ten-Year Intervalbegan on September 23, 2004, and was originally scheduled to conclude onSeptember 22, 2014. The Fifth Ten-Year Interval scheduled end date maintains theoriginal 10-year pattern of intervals in accordance with ISTA-3120(d).)The Code of Federal Regulations, 10 CFR 50.55a(f)(4), requires that throughout theservice life of a boiling or pressurized water-cooled nuclear power facility, pumps andvalves which are classified as ASME Code Class 1, Class 2, and Class 3 must meetthe inservice test requirements set forth in the ASME OM Code and addenda that areincorporated by reference in paragraph 10 CFR 50.55a(b)(3) for the initial and eachsubsequent 120-month interval.Based on the start date identified above, the IST Program for the 5th ten-year intervalis required by 10 CFR 50.55a(f)(4)(ii) to comply with the requirements of the ASMEOM Code-2004, Code for Operation and Maintenance of Nuclear Power Plants,including addenda through the OMb-2006, except where relief from suchrequirements has been granted in writing by the NRC.The scope of the OM Code is defined in paragraph ISTA-1100 as applying to:(a) pumps and valves that are required to perform a specific function in shuttingdown a reactor to the safe shutdown condition, in maintaining the safeshutdown condition, or in mitigating the consequences of an accident;(b) pressure relief devices that protect systems or portions of systems that performone or more of the functions listed in (a), above; and(c) dynamic restraints (snubbers) used in systems that perform one or more of thefunctions listed in (a).NOTE: This IST Program Plan addresses only those components included in (a) and(b) above. Dynamic restraints (snubbers) are addressed in a separate test program.In order to determine the scope of the IST Program at Three Mile Island Unit #1, anextensive scope evaluation was performed. This scope evaluation determined all ofthe functions required to be performed by all ASME Class 1, 2 and 3 systems inshutting down the reactor to the safe shutdown condition, in maintaining the safeshutdown condition or in mitigating the consequences of an accident. TheRevision 0October 25, 2013 Three Mile Island Unit #1Inservice Testing Program Plandetermination of those functions was accomplished by a thorough review of licensingbases documents such as the UFSAR/FSAR, Plant Technical Specifications andTechnical Specification Bases documents, etc. Next, a component-by-componentreview was performed to determine what function each pump and valve in the systemwas required to perform in order to support the safety function(s) of the system orsubsystem. The results of these efforts are documented in the Station's IST BasesDocument. In addition to a description of each component's safety function(s), theBases Document identifies the tests and examinations that are performed on eachcomponent to provide assurance that they will be operationally ready to performthose safety function(s). The Bases Document identifies those ASME Class 1, 2,and 3 pumps and valves that are in the scope of the IST Program, including thosethat do and those that do not have required testing. It also identifies those ASMEClass 1, 2 and 3 pumps and valves that are outside the scope of the IST Program onthe basis that they are not required to perform any specific safety function.As stated at the beginning of this Section, the scope of this IST Program Plan is toidentify all of the testing performed on those components within the scope of the ISTProgram. This is accomplished primarily by means of the IST Pump and IST ValveTables contained in Attachments 14 and 15. The remaining Sections andAttachments of this document provide support information to that contained in theTables. Components that do not require testing are not included in the IST ProgramPlan document.In addition to those components that are required to perform specific safetyfunction(s), the scope evaluation often determines that there are also ASME SafetyClass 1, 2 and 3 components that are not required to perform a licensing-basedsafety function but which, nonetheless, may be relied upon to operate to perform afunction with some significance to safety. It may also identify non-ASME SafetyClass pumps or valves that have a safety function or may be relied upon to operateto perform a function with some significance to safety. None of these componentsare required by 10 CFR 50.55a to be included in the IST Program. However, suchcomponents may require testing in a manner which demonstrates their ability toperform their functions commensurate with their importance to safety per theapplicable portions of 10 CFR 50, Appendix A or B. One option is to include pumpsor valves that fit these conditions in the IST Program as augmented components.Three Mile Island Unit #1 is licensed with the Hot Standby condition as the safeshutdown condition. Therefore, the scope of the IST Program must include, as aminimum, all of those ASME Class 1, 2, and 3 pumps and valves which are requiredto shut down the Reactor to the Hot Standby condition, maintain the Hot Standbycondition, or mitigate the consequences of an accident.1.3 DiscussionA summary listing of all the pumps and valves that are tested in accordance with theIST Program is provided in the IST Pump and IST Valve Tables contained inAttachments 14 and 15. The Pump and Valve Tables also identify each test that isperformed on each component, the frequency at which the test is performed, and anyRelief Request or Technical Position applicable to the test. For valves, the ValveRevision 0October 25, 2013 Three Mile Island Unit #1Inservice Testing Program PlanTable also identifies any Cold Shutdown Justification or Refueling OutageJustification that is applicable to the required exercise tests. Additional information isprovided for both pumps and valves. All of the data fields included in the IST Pumpand Valve Tables are listed and described in Sections 2 and 3 of this document.Following Sections 2 and 3 are several Attachments which provide informationreferenced in the Pump and Valve Tables.Attachment 1 includes a listing of P&ID's on which a depiction of the pump or valvemay be located.Attachment 2 provides an index of the Pump Relief Requests that apply to any of thepumps in the IST Program for this ten-year interval.Attachment 3 includes a copy of each of those Relief Requests.Attachment 4 provides an index of the Valve Relief Requests that apply to any of thevalves in the IST Program for this ten-year interval.Attachment 5 includes a copy of each of those Relief Requests.Attachment 6 contains the Safety Evaluation Report(s) (SER) that documentapproval of the Relief Requests contained in Attachments 3 and 5.Attachment 7 includes a list of the ASME OM Code Cases that are being invoked forthis ten-year interval.Attachment 8 provides an index of Cold Shutdown Justifications that apply to theexercise testing of any valves in the IST Program for this ten-year interval.Attachment 9 includes a copy of each of those Cold Shutdown Justifications.Attachment 10 provides an index of Refueling Outage Justifications that apply to theexercise testing of any valves in the IST Program for this ten-year interval.Attachment 11 includes a copy of each of those.Refueling Outage Justifications.Attachment 12 provides an index of Technical Positions that apply to the ISTProgram for this ten-year interval. Technical Positions provide detailed informationregarding how Exelon satisfies certain ASME OM Code requirements, particularlywhen the Code requirement may be ambiguous or when multiple options forimplementation may be available. Technical Positions do not take exception to orprovide alternatives to Code requirements.Attachment 13 includes a copy of each Technical Position listed in Attachment 12.As described previously, Attachments 14 and 15 include the IST Pump and ValveTables.Attachment 16 provides a listing of Check Valve Condition Monitoring (CVCM)Program Plans. These condition monitoring plans are generated from informationcontained in the IST Program database -Inservice Testing Program Assistant(ISTPa-2003). Implementation and Maintenance of the Condition MonitoringProgram is addressed in T&RM procedure ER-AA-321-1005, "Condition Monitoringfor Inservice Testing of Check Valves.".Revision 0October 25, 2013 Three Mile Island Unit #1Inservice Testing Program PlanThis IST Program Plan is a quality-related document and is controlled andmaintained in accordance with approved Exelon Corporate Engineering and RecordsManagement procedures.Revision 0October 25, 2013 Three Mile Island Unit #1Inservice Testing Program Plan1.41.4.11.4.21.4.31.4.4ReferencesTitle 10, Code of Federal Regulations, Part 50, Section 55a (10 CFR 50.55a)ASME OM Code-2004, Code for Operation and Maintenance of Nuclear PowerPlant Components, including Addenda through OMb-2006.Three Mile Island Unit #1Technical SpecificationExelon Corporation Administrative Procedure ER-AA-321, AdministrativeRequirements for Inservice TestingRevision 0October 25, 2013 Three Mile Island Unit #1Inservice Testing Program Plan2.0 INSERVICE TESTING PLAN FOR PUMPS2.1 Pump Inservice Testing PlanThe Three Mile Island Unit #1 Inservice Testing Program for Pumps meets therequirements of Subsections ISTA and ISTB of the ASME OM Code-2004 with OMb-2006 addenda, with the exception of those specific applications identified in theRelief Requests contained in Attachment 3.2.2 IST Plan Pump Table DescriDtionThe pumps included in the Three Mile Island Unit #1 Inservice Testing Program arelisted in Attachment 14. The information contained in that table identifies thosepumps required to be tested to the requirements of the ASME OM Code, theparameters measured, associated Relief Requests and comments, and otherapplicable information. The column headings for the Pump Table are listed belowwith an explanation of the content of each column.Pump EPNThe unique identification number for thedesignated on the System P&ID or Flow Diagrampump, asTest GroupSafety ClassPump TypePump DriverNominal SpeedP&IDRevision 0October 25, 2013A or B, as defined in Reference 1.4.2 (or applicable Relief)The ASME Safety Class (i.e., 1, 2 or 3) of the pump. Non-ASME Safety Class pumps are designated "N/A".An abbreviation used to designate the type of pump:C CentrifugalPDN Positive Displacement -Non-ReciprocatingPDR Positive Displacement -ReciprocatingVLS Vertical Line ShaftThe type of driver with which the pump is equipped:A Air-motorD DieselM Motor (electric)T Turbine (steam)The normal rotational speed of the pump at IST referenceconditions.The Piping and Instrumentation Diagram or Flow Drawing onwhich the pump is shown Three Mile Island Unit #1Inservice Testing Program PlanP&ID Coor.Test TypeTest Freq.Coordinates on the P&ID or Flow Diagram where the pump isshownLists each of the test parameters which are required to bemeasured for the specific pump. These include:N Speed (for variable speed pumps, only)AP Differential PressureP Discharge Pressure (positive displacementpumps)Q Flow Rate,Vd Vibration (displacement)Vv Vibration (velocity)An abbreviation which designates the frequency at which theassociated test is performed:Q QuarterlyY2 Once every 2 yearsNOTE: All tests are performed at the frequenciesspecified by Code unless specifically documented by aRelief Request.Identifies the number of the Relief Request applicable to thespecified test.Provides the Technical Position identification numberapplicable to the pump or test.Any appropriate reference or explanatory information (e.g.,technical positions, etc.)The descriptive name of the pump shown on the bottom linefor each pump entry. [use PIMS, Passport, etc. names forconsistency)Relief RequestTech. Pos.CommentsPump NameRevision 0October 25, 2013 Three Mile Island Unit #1Inservice Testing Program Plan3.0 INSERVICE TESTING PLAN FOR VALVES3.1 Valve Inservice Testing PlanThe Three Mile Island Unit #1 Inservice Testing Program for Valves meets therequirements of Subsections ISTA and ISTC of the ASME OM Code-2004 withOMb-2006 addenda, with the exception of those specific applications identified in theRelief Requests contained in Attachment 5.3.2 IST Plan Valve Table DescriptionThe valves included in the Three Mile Island Unit #1 Inservice Testing Program arelisted in Attachment 15. The information contained in that table identifies thosevalves required to be tested to the requirements of the ASME OM Code, the testingmethods and frequency of testing, associated Relief Requests, comments, and otherapplicable information. The column headings for the Valve Table are delineatedbelow with an explanation of the content of each column.Valve EPN The unique identification number for the valve, asdesignated on the System P&ID or Flow Diagram.Safety Class The ASME Safety Class (i.e., 1, 2 or 3) of the valve.Non-ASME Safety Class valves are designated by''N/A".Categroy The ASME Code category or categories of the valve asdefined in Reference 1.4.2.Size The nominal size of the valve in inches.Valve Type An abbreviation used to designate the body style of thevalve:3W 3-Way4W 4-WayBAL BallBTF ButterflyCK CheckDIA DiaphragmGA GateGL GlobePLG PlugRPD Rupture DiskRV ReliefSCK Stop-CheckSHR Shear (SQUIB)XFC Excess Flow CheckRevision 0October 25, 2013 Three Mile Island Unit #1Inservice Testing Program PlanAct. TypeActive/PassiveValve Normal andSafety PositionsP&IDP&ID Coord.An abbreviation which designates the type of actuatoron the valve. Abbreviations used are:AO Air OperatorDF Dual Function (Self and Power)EXP ExplosiveHO Hydraulic OperatorM ManualMO Motor OperatorSA Self-ActuatingSO Solenoid Operator"A" or "P", used to designate whether the valve is activeor passive in fulfillment of its safety function. The terms"active valves" and "passive valves" are defined inReference 1.4.2.Abbreviations used to identify the normal, fail, andsafety-related positions for the valve. Abbreviationsused are:Al As IsC ClosedCKL Closed/Actuator Key LockedD De-energizedD/E De-energized or EnergizedE EnergizedLC Locked ClosedLO Locked OpenLT Locked ThrottledO OpenO/C Open or ClosedOKL Open/Actuator Key LockedSYS System Condition DependentT ThrottledThe Piping and Instrumentation Diagram or FlowDrawing on which the valve is shown.The Sheet coordinates on the P&ID or Flow Diagramwhere the valve is shown.A listing of abbreviations used to designate the types oftesting which are required to be performed on the valvebased on its category and functional requirements.Abbreviations used are:BDC Bidirectional Check Valve test (non-safetyTest TypeRevision 0October 25, 2013 Three Mile Island Unit #1Inservice Testing Program Planrelated closure test)BDO Bidirectional Check Valve test (non-safetyrelated open test)002 Check Valve Exercise Test -ClosedCO2  Check Valve Exercise Test -OpenCP2  Check Valve Partial Exercise TestDT Category D TestEC Exercise Test -Closed (manual valve)EO Exercise Test -Open (manual valve)FC Fail-Safe Exercise Test -ClosedFO Fail-Safe Exercise Test -OpenLT1  Leak Rate TestPI Position Indication Verification TestRT Relief Valve TestSC Exercise Closed (without stroke-timing)SO Exercise Open (without stroke-timing)SP Partial Exercise (Cat. A or B)STC Exercise/Stroke-Time ClosedSTO Exercise/Stroke-Time Open1 A third letter, following the "LT" designation for leakagerate test, may be used to differentiate between the tests.For example, Appendix J leak tests will be designatedas "LTJ", low pressure (non-Appendix J) leak tests as"LTL", and high pressure leak tests as "LTH".2 Three letter designations should be used for checkvalve tests to differentiate between the various methodsof exercising check valves. The letter following "CC","CO" or "CP" should be "A" for acoustics, "D" fordisassembly and inspection, "F" for flow indication, "M"for magnetics, "R" for radiography, "U" for ultrasonics, or"X" for manual exercise.Revision 0October 25, 2013 Three Mile Island Unit #1Inservice Testing Program PlanTest FreqAn abbreviation which designates the frequency atwhich the associated test is performed. Abbreviationsused are:AJ Per Appendix JCM Per Check Valve Condition MonitoringProgramCS Cold ShutdownM[n] Once Every n MonthsQ QuarterlyRR Refuel OutageR[n] Once Every n Refuel OutagesSA Sample Disassemble & InspectTS Per Technical Specification RequirementsY[n] Once Every n YearsOP Operational FrequencyIdentifies the number of the Relief Request applicable tothe specified test.A cross-reference to the applicable Cold ShutdownJustification or Refuel Outage Justification whichdescribes the reasons why reduced-frequency exercisetesting is necessary for the applicable valve.Provides the Technical Position identification numberapplicable to the pump or test.The descriptive name for the valve [use PIMS,Passport, etc. names for consistency].Relief RequestDeferred Just.Tech. Pos.Valve NameRevision 0October 25, 2013 Three Mile Island Unit #1Inservice Testing Program PlanSECTION 4.0ATTACHMENTSRevision 0October 25, 2013 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT ISYSTEM AND P&ID LISTINGRevision 0October 25, 2013Al -1 Three Mile Island Unit #1Inservice Testing Program PlanSystem NameSystemP&IDAH Reactor Building PurgeBS Reactor Building SprayCA Reactor Plant Chemical AdditionCF Core FloodCH Control Building Chilled WaterCM Containment MonitoringCO CondensateDC Decay Heat Closed Cycle Cooling WaterDF Emergency Diesel Generators Fuel SystemsDH Decay Heat RemovalDR Decay Heat River WaterEF/AS Emergency Feedwater/Auxiliary SteamEG Emergency Diesel Generator Support SystemsFS Fire Service WaterFW Main FeedwaterHM Containment Hydrogen MonitoringHP Hydrogen Purge DischargeHR Post LOCA Hydrogen RecombinerIA Instrument AirIC Intermediate Closed Cooling WaterMS Main SteamMU Makeup & PurificationNI Nuclear Plant Nitrogen SupplyNR Nuclear Services River WaterNS Nuclear Services Closed Cooling WaterPP Penetration PressurizationReactor Building Emergency Cooling Water/ReactorRB/RR RiverRC Reactor CoolantSA Station Service AirSF Spent Fuel Pool CoolingWDG Gaseous Waste DisposalWDL Liquid Waste DisposalRevision 0October 25, 2013 Al -2302-831, 847302-712302-671302-711302-847302-721302-101302-645302-283, 351302-640302-202, 645302-011, 082, 611302-351, 353, 354302-231302-081302-674302-721302-722302-271, 273302-620302-011302-660, 661302-720302-202302-610, 645302-706302-611302-650302-271302-630302-694302-196, 690 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 2PUMP RELIEF REQUEST INDEXRevision 0October 25, 2013A2 -1 Three Mile Island Unit #1Inservice Testing Program PlanRELIEF REQUEST TITLERELIEFREQUESTNUMBERPR-01PR-02APPROVAL DATENuclear Services Closed Cooling Water Flow RateMeasurement During Group A TestsProposed Alternative to Utilize Code Case OMN-18 In Accordance with 10 CFR 50.55a(a)(3)(i).Note: The ASME Code committee has approvedCode Case OMN-18, "Alternate TestingRequirements for Pumps Tested Quarterly within+/- 20% of Design Flow." However, this Code Casehas not been approved for use in RegulatoryGuide 1.192, Operation and Maintenance CodeCase Acceptability, ASME OM Code, June 2003and therefore, requires NRC relief.08/15/201308/15/2013Revision 0October 25, 2013A2 -2 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 3PUMP RELIEF REQUESTSRevision 0October 25, 2013A3- 1 Three Mile Island Unit #1Inservice Testing Program Plan10 CFR 50.55a Request Number: PR-01Revision 0Relief Request Concerning Nuclear Services Closed Cooling Water Flow RateMeasurement During Group A Tests In Accordance with 10 CFR 50.55a(f)(5)(iii)1. ASME Code Component(s) AffectedNS-P-1A, Nuclear Services Closed Cooling Water (NSCCW) Pump 1A, (Centrifugal / Group A/ Class 3)NS-P-1 B, Nuclear Services Closed Cooling Water Pump 1 B, (Centrifugal / Group A / Class 3)NS-P-1 C, Nuclear Services Closed Cooling Water Pump 1 C, (Centrifugal I Group A / Class 3)Component/System FunctionThe NSCCW system includes four 33.33 percent capacity nuclear services coolers, and three50-percent capacity NSCCW pumps. This system, along with the intermediate coolingsystem, satisfies the cooling requirements of all nuclear-oriented services other than decayheat and reactor building emergency cooling. In the event of a loss-of-coolant accident, 100-percent redundancy of all nuclear services equipment may be obtained by isolating non-essential items so that flow requirements are reduced to approximately half that of normaloperation.2. Applicable Code Edition and AddendaASME OM Code-2004 Edition, with Addenda through OMb-20063. Applicable Code Requirement(s)ISTB-5121 (b) -"Group A Test Procedure" -"The resistance of the system shall be varied untilthe flow rate equals the reference point ...... Alternatively, the flow rate shall be varied until thedifferential pressure equals the reference point..."4. Impracticality of CompliancePursuant to 10 CFR 50.55a(f)(5)(iii), relief is requested from the requirement of ASME OMCode ISTB-5121(b). Due to system design and plant operating requirements, it is notpractical to reduce the number of pumps in service to one to allow for single-pump testingduring power operation. Also, individual pump flow rates cannot be measured during theGroup A test. The flow instrumentation for this system is located in the common dischargeheader for all three of the subject pumps. The piping configuration does not contain, norwould the system design permit the installation of accurate individual pump flow measuringdevices due to the turbulence caused by the valving and elbow configuration on the dischargeof the pumps. There were no provisions originally designed in the system to measureindividual pump flow rate.Revision 0October 25, 2013 A3 -2 Three Mile Island Unit #1Inservice Testing Program Plan5. Burden Caused by ComplianceIndividual pump flow cannot be measured during normal quarterly operations since individualflow instrumentation does not exist. Also, two pumps are normally required to be in service toprovide adequate cooling for system components.To comply with the ISTB requirement for measuring individual pump flow rates on a quarterlybasis, a modification of the system would be required.6. Proposed Alternative and Basis for UseIndividual suction and discharge pressure gauges are installed at each pump allowing formeasurement of differential pressure for inservice testing. A flow instrument is installed in thecommon discharge header.The proposed test would test (as approved previously in PR-02 for the fourth interval)NSCCW pumps in pump pairs. As stated previously, individual pump flow cannot bemeasured during quarterly operations since individual flow instrumentation does not exist.Also, two (2) pumps are normally required to be inservice to provide adequate cooling forsystem components. The NSCCW pumps are centrifugal pumps (not vertical line shaft). Thecurrent quarterly inservice procedure tests all combinations of paired-pumps (A-B, B-C, A-C).During these tests, pump dP [differential pressure] is set and combined pump flow rate ismeasured.Individual pump flow rates will be calculated and compared against individual pump flow ratereference values. Corrective actions will be taken in accordance with ISTB-6200, "CorrectiveAction," in the event that these criteria are not met. The pumps will continue to be testedindividually in accordance with ISTB-5123, "Comprehensive Test Procedure," during refuelingoutages.Additionally, vibration data on the pump will be recorded and compared to the referencevalues. Any deviation from the reference value will be compared to the Code acceptancecriteria. The current testing methodology of testing paired-combinations of pumps near two-pump design flow rate provides an adequate basis for identifying and evaluating degradedpump performance. Therefore, this testing method provides reasonable assurance of pumpoperational readiness.Summary of proposed alternative testing:a. TMI, Unit 1 will continue to perform quarterly testing using a modified Group A testprocedure as described above. With two paired-pumps in service, the required group Atest parameters will be measured except for individual pump flow rate. Individual pumpflow rates will be calculated and compared against calculated individual pump flow ratereference values. During this test the differential pressure for each pump will be throttledto the reference value.b. Vibration measurements will be recorded and compared to their reference values.Deviations from the reference value will be compared with the ranges specified in TableISTB-5121-1 for Group A tests. Corrective actions will be taken in accordance withISTB-6200.c. During testing of the subject pumps (quarterly and refueling), TMI, Unit 1 will perform fullspectrum vibration analysis, which is above Code required vibration testing.d. The pumps will continue to be tested individually in accordance with ISTB-5123,"Comprehensive Test Procedure," during refueling outages.Revision 0October 25, 2013 A3 -3 Three Mile Island Unit #1Inservice Testing Program PlanUsing the provisions of this relief request as an alternative to the specific requirements ofISTB-5121(b) will provide reasonable assurance of pump operational readiness. Therefore,pursuant to 10 CFR 50.55a(f)(5)(iii), TMI, Unit 1 requests relief from the specific ISTBrequirements identified in this request.7. Duration of Proposed AlternativeThe proposed alternative identified will be utilized during the fifth IST interval which isscheduled to begin October 15, 2013'and conclude on October 14, 2023.8. PrecedentsA similar Relief Request (P5) was approved for TMI, Unit 1 for the third 10-year interval asdocumented in the US Nuclear Regulatory Commission's Safety Evaluation Report dated July2, 2004 (ML041670196).A similar Relief Request (PR-02) was approved for TMI, Unit 1 for the fourth 10-year interval,as documented in the U.S. Nuclear Regulatory Commission's Safety Evaluation Report datedJuly 7, 2005 (ML051530406).Revision 0October 25, 2013 A3 -4 Three Mile Island Unit #1Inservice Testing Program Plan10 CFR 50.55a Request Number: PR-02Revision 0Proposed Alternative to Utilize Code Case OMN-18In Accordance with 10 CFR 50.55a(a)(3)(i)1. ASME Code Component(s) AffectedAH-P-3A&B, Control Building Chilled Water Supply Pumps (Centrifugal / Group A / Class 3)BS-P-1A&B, Reactor Building Spray Pumps (Centrifugal / Group AB / Class 2)DC-P-1A&B, Decay Heat Closed Cooling Water Pumps (Centrifugal / Group A / Class 3)DR-P-1iA&B, Decay Heat River Water Pumps (Vertical Line Shaft / Group A / Class 3)SF-P-1A&B, Spent Fuel Cooling Pumps (Centrifugal / Group A / Class 3)Component/System FunctionProvide minimum flow to meet system requirements under accident conditions2. Applicable Code Edition and AddendaASME OM Code-2004 Edition, with Addenda through OMb-20063. Applicable Code Requirement(s)" ISTB-3300, "Reference Values," states, in part, that "Reference values shall beestablished within +/-20 percent of pump design flow rate for the comprehensive test," and"Reference values shall be established within +/-20 percent of pump design flow for theGroup A and Group B tests, if practicable."" ISTB-3400, "Frequency of Inservice Tests", states that an inservice test shall be run oneach pump as specified in Table ISTB-3400-1.* Table ISTB-3400-1 requires Group A and Group B tests to be performed quarterly and acomprehensive test to be performed biennially.* Table ISTB-3510-1, "Required Instrument Accuracy," specifies the instrument accuraciesfor Group A, Group B, comprehensive, and preservice tests.* Table ISTB-5121-1 "Centrifugal Pump Test Acceptance Criteria" defines the requiredacceptance criteria for Group A, Group B, and Comprehensive tests for centrifugal pumps.* Table ISTB-5221-1 "Vertical Line Shaft Centrifugal Pumps Test Acceptance Criteria"defines the required acceptance criteria for Group A, Group B, and Comprehensive testsfor Vertical Line Shaft centrifugal pumps.4. Reason for RequestThe ASME Code committees have approved Code Case OMN-18, "Alternate TestingRequirements for Pumps Tested Quarterly within +/- 20% of Design Flow." This Code CaseRevision 0October 25, 2013 A3 -5 Three Mile Island Unit #1Inservice Testing Program Planhas not been approved for use in Regulatory Guide 1.192, "Operation and Maintenance CodeCase Acceptability, ASME OM Code," June 2003.This Code Case allows the Owner to not perform the Comprehensive Pump Test (CPT) withthe associated acceptance criteria, if the quarterly test is performed at +/- 20% of design flowand the instrumentation meets the accuracy requirements of Table ISTB-3510-1 for thecomprehensive and preservice tests. The basis for the testing strategy in this Code Case isthat a quarterly Group A pump test, performed at the CPT flow rate with more accurateinstrumentation, is more effective in assessing a pump's operational readiness, throughtrending, than a standard Group A test in conjunction with a biennial CPT.Additionally, ISTB allows the Owner to categorize the pumps in their program. As such, anOwner could categorize a pump that otherwise meets the requirements of Group B, as aGroup A (or AB) pump, and test according to the provisions of Code Case OMN-18. In doingthis, they are obtaining additional data (vibration and flow or differential pressure) quarterly,rather than once every two years.As a result of the increased requirements on the parameters imposed by the proposedalternative during applicable quarterly tests, there is no added value in performing the biennialcomprehensive test on the subject pumps.5. Proposed Alternative and Basis for UseTMI, Unit 1 is proposing to utilize the provisions of Code Case OMN-18 and performing amodified Group A test in lieu of performing the Code-required CPT. The modified Group Atest will be run at +/-20% of the pump's design flow rate using +/-1/2% accurate gauges todetermine the pump differential pressure. Vibration tests will be performed and the vibrationacceptance criteria for the proposed alternative test will remain identical to the standard GroupA test. Additionally, TMI, Unit 1 will utilize an Acceptable Range High limit of 106% or lowerfor quarterly testing, which is also consistent with the planned Code change applicable toCPT.The use of more accurate pressure gauges and a more limiting Acceptable Range duringevery modified quarterly Group A test compensates for the elimination of the CPT (with itsmore limiting Acceptable Range upper bound for differential pressure or flow of 103%).Regular testing with more accurate instrumentation and tighter acceptance criteria will providefor better trending of pump performance. Instead of performing seven tests with pressureinstruments with +/-2% accuracy and then performing the eighth test with pressure instrumentswith +/-1/2% accuracy, all eight tests will be performed with the same +/-1/2% accurateinstruments. Due to the improved accuracy, consistent testing methodology, and the additionof quarterly vibration monitoring on Group AB pumps, deviations in actual pump performanceindicative of impending degradation are more easily recognized during quarterly performancetrending activities.Using the provisions of this request as an alternative to the requirements of ISTB-3400 andTables ISTB-3400-1, ISTB-5121-1, & ISTB-5221-1 provides a reasonable alternative to theCode requirements based on the determination that the proposed alternative will provideadequate indication of pump performance, permit detection of component degradation, andcontinue to provide an acceptable level of quality and safety. Therefore, pursuant to 10 CFR50.55a(a)(3)(i), TMI, Unit 1 requests approval of this alternative to the specific ISTBrequirements identified in this request.Revision 0October 25, 2013 A3 -6 Three Mile Island Unit #1Inservice Testing Program Plan6. Duration of Proposed AlternativeThe proposed alternative identified will be utilized during the fifth IST interval which isscheduled to begin October 15, 2013 and conclude on October 14, 2023.7. PrecedentsA similar Relief Request (PR-01) was approved for the Oyster Creek Nuclear GeneratingStation as discussed in the U.S. Nuclear Regulatory Commission's Safety Evaluation Reportdated June 21, 2012 (ML120050329).A similar Relief Request (PR-9) was approved for the St. Lucie, Units 1 and 2 as discussed inthe U.S. Nuclear Regulatory Commission's Safety Evaluation Report dated July 1, 2011(ML1 1 143A077).A similar Relief Request (PR-3) was approved for the Perry Nuclear Power Plant, Unit 1, asdiscussed in the U.S. Nuclear Regulatory Commission's Safety Evaluation Report datedOctober 8, 2009 (ML092640690).Revision 0October 25, 2013 A3 -7 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 4VALVE RELIEF REQUEST INDEXRevision 0October 25, 2013A4- 1 Three Mile Island Unit #1Inservice Testing Program PlanRELIEF REQUEST TITLERELIEFREQUESTNUMBERAPPROVAL DATEVR-01VR-02Proposed Alternative Concerning Testing ofthe Pressurizer Pilot operated Relief Valve(PORV) in Accordance with 10 CFR50.55a(a)(3)(i)8/28/2013Proposed Alternative Concerning ASME OM 8/15/2013Code Test Frequencies In Accordance with10 CFR 50.55a(a)(3)(ii)Revision 0October 25, 2013A4 -2 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 5VALVE RELIEF REQUESTSRevision 0October 25, 2013A5- 1 Three Mile Island Unit #1Inservice Testing Program Plan10 CFR 50.55a Request Number: VR-01Revision 0Proposed Alternative Concerning Testing of the Pressurizer Pilot operated ReliefValve (PORV) in Accordance with 10 CFR 50.55a(a)(3)(i)1. ASME Code Component(s) Affected1-RC-RV-2, Pressurizer Pilot Operated Relief Valve (PORV), Class 1, Category B/CComponent/System FunctionThe PORV is used to control Reactor Coolant System (RCS) pressure as discussed in ThreeMile Island Generating Station (TMI), Unit 1 Updated Final Safety Analysis Report, Section4.2.4 ("Pressure Control and Protection").2. Applicable Code Edition and AddendaASME OM Code-2004 Edition, with Addenda through OMb-20063. Applicable Code Requirement(s)* ISTC-3310, Effects of Valve Repair, Replacement, or Maintenance on Reference Values"-This section requires post-maintenance valve exercising following replacement.* ISTC-3510, "Exercising Test Frequency" -"Power operated relief valves shall be exercisetested once per fuel cycle."4. Reason for RequestPursuant to 10 CFR 50.55a(a)(3)(i), approval of a proposed alternative is requested to theabove listed requirements of the OM Code. During the current fourth IST interval, the OMCode required testing for the PORV is satisfied by manually stroking the valve once everyoperating cycle. This is performed during plant startup following a refueling outage. Thevalve must be stroke timed during this exercise test. TMI, Unit 1 is proposing an alternative tothis required in-situ testing for several reasons.There are several disadvantages to the in-situ testing of the PORV. The PORV is a 2.5 inchDresser Electromatic, solenoid actuated, pilot operated relief valve. Operation of the pilotvalve vents the chamber under the main valve disc which causes the main valve to open. ThePORV requires steam pressure for the main disc to open. Stroke testing the PORV duringcold shutdown conditions would not exercise the main valve disc, which would not satisfy theASME OM Code requirements. To test the PORV in-place, the RCS must be pressurized tosupply the necessary fluid (steam) pressure to open the main valve disc.Also, since the PORV design does not provide direct obturator position indication, the valvedisc position must be inferred from alternate indications (tailpipe AT, acoustic monitor, RCSpressure decrease, or quench tank pressure or level rise).Revision 0October 25, 2013 A5 -2 Three Mile Island Unit #1Inservice Testing Program PlanIn-situ testing of the PORV would also result in an in-surge of cooler water from the hot leg ofthe RCS into the pressurizer. The resulting thermal cycle on the pressurizer surge line wouldbe a thermal stress concern, as described in NRC Bulletin 88-08 ("Thermal Stresses in PipingConnected to Reactor Coolant Systems") and should be avoided.Requiring that the PORV be tested in-place prevents plant personnel from verifying properreseating of the main valve disc because its discharge is not accessible as it is during benchtesting. Minor leakage would not be readily evident before it would cause damage to the mainvalve disc/seat. Excessive leakage from the pilot valve can lead to inadvertent opening of themain valve, and impair its ability to re-close.The proposed alternative will allow testing of the PORV that is appropriate to demonstratefunctionality without cycling the valve in place using reactor steam pressure. This isconsistent with NUREG-0737, "Clarification of TMI Action Plan Requirements," Item I1.K.3.16,"Reduction of Challenges and Failures of Relief Valves," which recommended that the numberof relief valve openings be reduced as much as possible and that unnecessary challengesshould be avoided.5. Proposed Alternative and Basis for UseThe following alternatives to the requirements stated above are proposed.1) Bench testing of the PORV to satisfy valve exercise and stroke time requirements isperformed at the vendor test facility prior to installation. Exercising of the valve at both thenormal power operation set point and the Low Temperature Overpressure Protection(LTOP) set point (as provided in Technical Specification 3.1.12, "Pressurizer PowerOperated Relief Valve (PORV), Block Valve, and Low Temperature OverpressureProtection (LTOP)") will be verified during this testing. Measured stroke time will be basedon the pressure response indication of main disc opening.2) The installed valve will be removed and replaced each refueling outage, with a spare valvethat has been previously bench tested.3) The removed valve will be bench tested within one year of removal from the system.4) In-situ exercising of the PORV will be performed only as necessary to reestablishoperational readiness after maintenance on an installed valve.Requiring in-situ testing of the PORV unnecessarily increases the number of challenges to thePORV and results in an overall reduction in plant safety. Bench testing is preferable over in-situ testing for several reasons. Bench testing is performed at normal steam inlet conditions.Both the power operation set point and the Low Temperature Overpressure Protection (LTOP)set point (as provided in Technical Specification 3.1.12, "Pressurizer Power Operated ReliefValve (PORV), Block Valve, and Low Temperature Overpressure Protection (LTOP)") areverified. The measurement of PORV stroke time, verification of main disc movement, andseat leakage check can be verified more precisely under bench testing conditions.Performing a bench test under controlled conditions allows the opportunity for accomplishingrepairs to the valve while there is sufficient time for any needed repairs or additional testingwithout these activities affecting the unit's operating/outage schedule and without theadditional dose that could result by having to remove or perform work on the valve while it isattached to the RCS. If a test failure during plant startup were to occur that required coldRevision 0October 25, 2013 A5 -3 Three Mile Island Unit #1Inservice Testing Program Planshutdown conditions, this would result in an additional thermal cycle on the unit and additionalpersonnel radiation exposure that could otherwise have been avoided.Valve testing will be performed at a steam test facility, where the entire valve assembly (i.e.,main valve, pilot valve, and solenoid) will be installed on a steam header in the same (vertical)orientation as the plant installation. The test conditions in the test facility will be similar tothose in the plant installation, including ambient temperature, valve insulation, and steamconditions. The valve will then be leak tested, and functionally exercised at the normal poweroperation set point and the LTOP pressure limit to ensure the valve is capable of opening andclosing (including stroke timing), and leak tested a final time. Valve seat tightness will beverified by a cold bar test, and if not free of fog, leakage will be measured and verified to bebelow design limits. If required, based on the results of "As-found" testing, the valve will berefurbished and recertified ("As-left" tested). The valve will then be shipped to the plant. If"As-found" testing is satisfactory and refurbishment is not necessary, the valve will be returnedwithout any disassembly or alteration of the main valve or pilot valve components. A receiptinspection will be performed in accordance with the requirements of the Exelon QualityAssurance Program. The storage requirements in effect at TMI, Unit 1 ensure the valve isprotected from moisture and physical damage. Prior to installation, the valve will again beinspected for foreign material and damage. The valve will be installed, and electricallyconnected in accordance with a TMI, Unit 1 maintenance procedure. The procedure ensuresproper reinstallation of the PORV and proper connection of controls. The post-maintenancetesting then verifies operation of the solenoid-actuated pilot valve.The proposed alternative also provides adequate assurance that the valve stroke time will beconsistently measured at the test facility. The test facility replicates the control signals to thepilot solenoid allowing it to be actuated at the pressures corresponding to when it would beactuated in the plant. Stroke timing of the solenoid-actuated pilot valve will start with theinitiation of the signal to the solenoid and be based on the initial main valve obturatormovement as determined by the change in steam pressure when exercised at both the normalreactor coolant system pressure limit and the lower LTOP pressure. Stroke timing will beused to ensure that the valve performs acceptably compared to its baseline and designrequirements. Observation of the main disc movement at the test facility is indirect, based onevidence of steam pressure response, as it is in-situ at the plant, since here is no directindication of the main valve position. Although this difference may result in minor differencesin measured stroke time compared to those measured when installed in the plant, the stroketimes measured at the test facility will be under conditions identical to when the referencevalues were established, making the results comparable and trendable for detecting anyabnormality in valve performance. The IST reference values for the PORV stroke time areless than 2 seconds, and the stroke timing will be measured to at least tenths of a secondeven though the OM Code only requires it to be measured to the nearest second.The following is a review of PORV test history from the steam test facility which demonstratesthat the PORV pilot valve opens well within the 2-second limiting stroke time allowed byASME OM Code Section ISTC-5 114(c) for rapid-acting valves:Revision 0October 25, 2013 A5 -4 Three Mile Island Unit #1Inservice Testing Program PlanRC-RV-2 First and Second LTOP First and SecondSerial # Test Date Pressure Stroke times Normal RCS Pressure(seconds) Stroke times (seconds)BS03989 11/04/2011 0.182, 0.196 0.095, 0.108BS03989 11/11/2009 0.188, 0.232 0.128, 0.130BS03989 10/28/2007 0.126, 0.142 0.130, 0.124BL08905 10/22/2007 0.116, 0.176 0.132, 0.172BL08905 08/10/2006 0.144, 0.146 0.116, 0.118BS03839 05/07/2004 0.158, 0.156 0.094, 0.110BL08905 05/24/2002 0.166, 0.160 0.110, 0.100BS03989 08/31/2000 0.182, 0.176 0.084, 0.076As demonstrated above, using the provisions of this relief request as an alternative to thelisted ISTC requirements will provide: 1) assurance of PORV functional capability; 2) permitdetection of component degradation, and; 3) continue to provide an acceptable level of qualityand safety.6. Duration of Proposed AlternativeThe proposed alternative identified will be utilized during the fifth IST interval which isscheduled to begin October 15, 2013 and conclude on October 14, 2023.7. PrecedentsNoneRevision 0October 25, 2013 A5 -5 Three Mile Island Unit #1Inservice Testing Program Plan10 CFR 50.55a Request Number: VR-02Revision 0Proposed Alternative Concerning ASME OM Code Test FrequenciesIn Accordance with 10 CFR 50.55a(a)(3)(ii)1. ASME Code Component(s) AffectedAll Pumps and Valves contained within the Inservice Testing Program (IST) scope.2. Applicable Code Edition and AddendaASME OM Code-2004 Edition, with Addenda through OMb-20063. Applicable Code Requirement(s)This request applies to the frequency specifications of the ASME OM Code. Thefrequencies for tests given in the ASME OM Code do not include a tolerance band (graceperiod).ISTA-3120(a) -"The frequency for the inservice testing shall be in accordance with therequirements of Section IST."ISTB-3400 -"Frequency of Inservice Tests" -"An inservice test shall be run on eachpump as specified in Table ISTB-3400-1 ." Table ISTB-3400-1 lists two frequencies -quarterly and biennially.ISTC-3510 -"Exercising Test Frequency" -"Active Category A, Category B, andCategory C check valves shall be exercised nominally every 3 months ...."ISTC-3540 -"Manual Valves" -"Manual Valves shall be full-stroke exercised at leastonce every 2 years, except where adverse conditions may require the valve to be testedmore frequently to ensure operational readiness."* ISTC-3630(a) -"Frequency" -"Tests shall be conducted at least once every 2 years."* ISTC-3700 -"Position Verification Testing" -"Valves with remote position indicators shallbe observed locally at least once every 2 years to verify that valve operation isaccurately indicated."ISTC-5221(c)(3) -"At least one valve from each group shall be disassembled andexamined at each refueling outage; all valves in a group shall be disassembled andexamined at least once every 8 years."* Appendix 1, 1-1320 -"Test Frequencies, Class 1 Pressure Relief Valves" -"Class 1pressure relief valves shall be tested at least once every 5 years..."* Appendix 1, 1-1330 -"Test Frequency, Class 1 Nonreclosing Pressure Relief Devices" -"Class 1 nonreclosing pressure relief devices shall be replaced every 5 years..."Revision 0October 25, 2013 A5 -6 Three Mile Island Unit #1Inservice Testing Program Plan* Appendix 1, 1-1340 -"Test Frequency, Class 1 Pressure Relief Valves that are used forThermal Relief Application" -This section refers to 1-1320 for test frequency.* Appendix 1, 1-1350 -"Test Frequency, Classes 2 and 3 Pressure Relief Valves" -"Classes 2 and 3 pressure relief valves, with the exception of PWR main steam safetyvalves, shall be tested every 10 years,* Appendix 1, 1-1360 -"Test Frequency, Classes 2 and 3 Nonreclosing Pressure ReliefDevices" -"Classes 2 and 3 nonreclosing pressure relief devices shall be replaced every5 years, ..."* Appendix I, 1-1370 -"Test Frequency, Classes 2 and 3 Primary Containment VacuumRelief Valves" -"Tests shall be performed on all Classes 2 and 3 containment vacuumrelief valves at each refueling outage or every 2 years, ..."* Appendix 1, 1-1380 -"Test Frequency, Classes 2 and 3 Vacuum Relief Valves Except forPrimary Containment Vacuum Relief Valves" -"All Classes 2 and 3 vacuum relief valvesshall be tested every 2 years,* Appendix 1, 1-1390 -"Test Frequency, Classes 2 and 3 Pressure Relief Devices that areused for Thermal Relief Application" -"Tests shall be performed on all Classes 2 and 3relief devices used in thermal relief application every 10 years.* Appendix II, 11-4000(a)(1 )(e) -"Performance Improvement Activities" -Subparagraph(1)(e) requires the identification of the interval for each activity.* Appendix II, 11-4000(b)(1)(e) -"Optimization of Condition Monitoring Activities" -Subparagraph (1)(e) requires the identification of the interval for each activity.4. Reason for RequestPursuant to 10 CFR 50.55a(a)(3)(ii), an alternative is requested from the frequencyspecifications of the ASME OM Code. The basis of the relief request is that the Coderequirement presents an undue hardship without a compensating increase in the level ofquality or safety.ASME OM Code Section IST establishes the inservice test frequency for all componentswithin the scope of the Code. The frequencies (e.g., quarterly) have always beeninterpreted as "nominal" frequencies (generally as defined in the Table 3.2 of NUREG 1482,Revision 1) and Owners routinely applied the surveillance extension time period (i.e., graceperiod) contained in the plant Technical Specifications (TS) Surveillance Requirements(SRs). The TS typically allow for a less than or equal to 25% extension of the surveillancetest interval to accommodate plant conditions that may not be suitable for conducting thesurveillance. However, regulatory issues have been raised concerning the applicability ofthe TS "Grace Period" to ASME OM Code required inservice test frequencies.The lack of a tolerance band (grace period) on the ASME OM Code inservice test frequencyrestricts operational flexibility. There may be a conflict where a surveillance test could berequired (i.e., its Frequency could expire), but where it is not possible or not desired that itbe performed until sometime after a plant condition or associated Technical Specification isapplicable. Therefore, to avoid this conflict, the surveillance test should be performed whenit can be and should be performed.The NRC recognized this potential issue in the TS by allowing a frequency tolerance asdescribed in the TMI, Unit 1 TS SR 4.0.1. The lack of a similar tolerance applied to OMCode testing places an unusual hardship on the plant to adequately schedule work taskswithout operational flexibility.Revision 0October 25, 2013 A5 -7 Three Mile Island Unit #1Inservice Testing Program PlanThus, just as with TS required surveillance testing, some tolerance is needed to allowadjusting OM Code testing intervals to suit the plant conditions and other maintenance andtesting activities. This assures operational flexibility when scheduling surveillance tests thatminimize the conflicts between the need to complete the surveillance and plant conditions.5. Proposed Alternative and Basis for UseASME OM Code establishes component test frequencies that are based either on elapsedtime periods (e.g., quarterly, 2 years, etc.) or on the occurrence of plant conditions or events(e.g., cold shutdown, refueling outage, upon detection of a sample failure, followingmaintenance, etc.).a. Components whose test frequencies are based on elapsed time periods shall betested at the frequencies specified in ASME OM Code Section IST with a specifiedtime period between tests as shown in the table below and as defined in TMI, Unit 1TS Section 1.25.b. The specified time period between tests may be reduced or extended as follows:1) For periods specified as less than 2 years, the period may be extended by up to25% for any given test. This is consistent with TMI, Unit 1 TS Section 1.25,"FREQUENCY NOTATION."2) For periods specified as greater than or equal to 2 years, the period may beextended by up to 6 months for any given test.3) All periods specified may be reduced at the discretion of the owner (i.e., there is nominimum period requirement).4) Period extensions may also be applied to accelerated test frequencies (e.g.,pumps in Alert Range).Specified Time Period Between TestsFrequency (all values are 'not to exceed'; nominimum periods are specified)Quarterly 92 days(or every 3 months)Semiannually 184 days(or every 6 months)Annually 366 days(or every year)x Years x calendar yearswhere 'x' is a whole number of years > 2c. Components whose test frequencies are based on the occurrence of plant conditionsor events (e.g., cold shutdown, refueling outage, upon detection of a sample failure,following maintenance, etc.) may not have their period between tests extended exceptas allowed by the ASME OM Code.Revision 0October 25, 2013 A5 -8 Three Mile Island Unit #1Inservice Testing Program PlanPeriod extension is to facilitate test scheduling and considers plant operating conditions thatmay not be suitable for performance of the required testing (e.g., performance of the testwould cause an unacceptable increase in the plant risk profile due to transient conditions orother ongoing surveillance test or maintenance activities). Period extensions are notintended to be used repeatedly merely as an operational convenience to extend testintervals beyond those specified. This request is not applicable to frequencies in SubsectionISTD.Using the provisions of this request as an alternative to the specific frequency requirementsof the OM Code identified above will provide operational flexibility and still continue toprovide an acceptable level of quality and safety. Therefore, pursuant to 10 CFR50.55a(a)(3)(ii) TMI, Unit 1 requests approval of the alternative to the specific OM Codefrequency requirements identified in this request.6. Duration of Proposed AlternativeThe proposed alternative identified will be utilized during the fifth IST interval which isscheduled to begin October 15, 2013 and conclude on October 14, 2023.7. PrecedentsA similar Relief Request was submitted to the U.S. Nuclear Regulatory Commission forQuad Cities Nuclear Power Station, Units 1 and 2 for the fifth 10-year interval, asdocumented in Letter RS-12-026 dated February 15, 2012.8. ReferencesTMI, Unit 1 TS Section 1.25- "FREQUENCY NOTATION"TMI, Unit 1 TS Section 4.2 -"Reactor Coolant System Inservice and Testing"Revision 0October 25, 2013 A5 -9 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 6RELIEF REQUEST RAI RESPONSES AND SERsRevision 0October 25, 2013A6 -1 Three Mile Island Unit #1Inservice Testing Program Plant'I: .! ] r , .i l ". ;+AIVMW Exe.on Oeneration.10 CFR 50.55aTMI-13-043March 15, 2013U.S. Nuclear Regulatory CommissionAttn: Document Control DeskWashington, DC 20555-0001Three Mile Island Nuclear Station, Unit 1Renewed Facility Operating License No. DPR-50NRC Docket No. 50-289Subject Response to Request for Additional Information -Relief Request VR-01Associated with the Fifth Inservice Testing (IST) Interval
 
==References:==
: 1) Letter from M. Jesse (Exelon Generation Company, LLC) to U.S. NuclearRegulatory Commission, "Submittal of Relief Request VR-01 Associatedwith the Fifth Inservice Testing (IST) Interval," dated October 18, 20122) Letter from P. Bamford (U.S. Nuclear Regulatory Commission) toM. Pacilio (Exelon Generation Company, LLC), 'Three Mile IslandNuclear Station, Unit 1 -Request for Additional Information RegardingRelief Request VR-01, Associated with the Fifth Inservice Testing Interval(TAC No. ME9819)," dated February 25, 2013In the Reference I letter, Exelon Generation Company, LLC (Exelon) submitted for yourreview and approval Relief Request VR-01 associated with the Fifth Inservice Testing (IST)interval for Three Mile Island Nuclear Station (TMI), Unit 1. In the Reference 2 letter, theU.S. Nuclear Regulatory Commission Staff requested additional information. Attached is ourresponse.There are no regulatory commitments in this letter.If you have any questions concerning this letter, please contact Tom Loomis at (610) 765-5510.Respectfully,*lihae/ D. Jesse /+ -/Director -Licensir(g +& uelatory AffairsExelon Generation' bompany, LLCRevision 0October 25, 2013 A6 -2 Three Mile Island Unit #1Inservice Testing Program PlanResponse to Request for Additional Information -RR VR-01 Associated with the Fifth Inservice Testing (IST) IntervalMarch 15, 2013Page 2
 
==Attachment:==
Response to Request for Additional Information -Relief Request VR-01cc: Regional Administrator, Region I, USNRCUSNRC Senior Resident Inspector, TMIProject Manager, [TMI] USNRCRevision 0October 25, 2013 A6 -3 Three Mile Island Unit #1Inservice Testing Program PlanAttachmentResponse to Request for Additional Information -Relief Request VR-01Revision 0October 25, 2013 A6 -4 Three Mile Island Unit #1Inservice Testing Program PlanResponse to Request for Additional InformationRelief Request VR-01Page 1 of 2Question:1.) The PORV, 1-RC-RV-2, is categorized as a B/C valve in the referenced request. In additionto the requirements of the OM Code, ISTC-3310 and ISTC-3510 (for which relief is beingrequested), are any other ASME OM Code ISTC or Mandatory Appendix I test requirementsapplicable to this valve? Please provide any specific ASME OM Code test requirements forthis valve type, but don't provide general test requirements from the OM Code.Response:Exelon Generation Company, LLC (Exelon) has determined that the following specificASME OM Code requirements also apply to the Three Mile Island Nuclear Station (TMI),Unit 1 pressurizer Pilot Operated Relief Valve (PORV) and is not requesting relief from anyof these:* ISTC-51 10, "Power-Operated Relief Valves (PORVs)." -"Power-operated reliefvalves shall meet the requirements of ISTC-5100 for the specific Category B valvetype and ISTC-5240 for Category C valves." This paragraph specifies theapplicable testing for the type of power operator and that Mandatory Appendix I hasadditional test requirements invoked by ISTC-5240. These requirements areoutlined in the following items.* ISTC-51 11, "Valve Testing Requirements" -This requirement specifies thesequence of the individual tests -seat tightness / leakage testing, stroke testing,and position indication testing. It also requires calibration of the pressure-sensingdevice in accordance with the Owner's QA program. Position indication testing hasbeen determined to not apply to the TMI, Unit l's PORV design.* ISTC-5112, "Leak Testing" -This requirement specifies that seat tightness of thePORV shall be verified by leak testing in accordance with the requirements ofMandatory Appendix I. This paragraph directs leak testing using the testmethodology and requirements for relief valves.* ISTC-5113, "Valve Stroke Testing" -This requirement provides the Category Bexercising requirements, which include stroke time measurement, establishment oflimiting stroke time, and testing at normal operating conditions.* 1-8110, "Steam Service" -This requirement specifies the detailed testingrequirements for exercising the valve. Those that apply to TMI, Unit l's PORVtesting are: test media, thermal equilibrium, and ambient temperature.* 1-8200, "Seat Tightness Testing" -This requirement specifies that seat tightnesstesting shall be performed in accordance with the Owner's valve test procedure.Consideration shall be given to test media, temperature stability, and ambienttemperature, as required in 1-8100. Seat tightness testing shall be performed usingRevision 0October 25, 2013 A6 -5 Three Mile Island Unit #1Inservice Testing Program PlanResponse to Request for Additional InformationRelief Request VR-01Page 2 of 2the same fluid used for set-pressure testing, except as provided by 1-8300. Thisparagraph and associated subparagraphs (1-8210, 1-8220, and 1-8230) specify seattightness testing using relief valve requirements (specified in 1-8100). The plant'sPORV is not tested with alternative media.The PORV testing described in Exelon's relief request complies with these requirements toensure the operational readiness of the valve.Question:2.) Is the Pressurizer PORV block valve included in the TMI-1 1ST program? If not, pleaseprovide the basis for not including this valve in the program.Response:The pressurizer PORV block valve is identified as 1-RC-V-2 in the TMI, Unit 1 IST ProgramPlan, and this valve is included in the scope of the program with both open and closed safetyfunctions.Revision 0October 25, 2013 A6 -6 Three Mile Island Unit #1Inservice Testing Program PlanExeon Generat ion, .10 CFR 50.55aTMI-13-068April 17, 2013U.S. Nuclear Regulatory CommissionAttn: Document Control DeskWashington, DC 20555-0001Three Mile Island Nuclear Station, Unit 1Renewed Facility Operating License No. DPR-50NRC Docket No. 50-289Subject Response to Request for Additional Information -Relief Request PR-01Associated with the Fifth Inservice Testing (IST) Interval
 
==References:==
: 1) Letter from M. Jesse (Exelon Generation Company, LLC) to U.S.Nuclear Regulatory Commission, "Submittal of Relief Requests Associatedwith the Fifth Inservice Testing (IST) Interval," dated November 7, 20122) Letter from P. Bamford (U.S. Nuclear Regulatory Commission) toM. Pacilio (Exelon Generation Company, LLC), 'Three Mile IslandNuclear Station, Unit 1 -Request for Additional Information RegardingFifth Inservice Test Interval Relief Request PR-01 Nuclear ServicesClosed Cooling Water Flow Measurement (TAC No. MF0046)," datedMarch 19, 2013In the Reference 1 letter, Exelon Generation Company, LLC (Exelon) submitted for yourreview and approval Relief Request PR-01 associated with the fifth Inservice Testing (IST)interval for Three Mile Island Nuclear Station (TMI), Unit 1. In the Reference 2 letter, theU.S. Nuclear Regulatory Commission Staff requested additional information. Attached is ourresponse.There are no regulatory commitments in this letter.If you have any questions concerning this letter, please contact Tom Loomis at (610) 765-5510.Respectfully,David P. HelkerManager -LicensingExelon Generation Company, LLCRevision 0October 25, 2013 A6 -7 Three Mile Island Unit #1Inservice Testing Program PlanResponse to Request for Additional Information -RR PR-01 Associated with the Fifth Inservice Testing (IST) IntervalApril 17, 2013Page 2Attachments: 1) Response to Request for Additional Information -Relief Request PR-012) Relief Request PR-01, Revision 2cc: Regional Administrator, Region I, USNRCUSNRC Senior Resident Inspector, TMIProject Manager, [TMI] USNRCRevision 0October 25, 2013 A6 -8 Three Mile Island Unit #1Inservice Testing Program PlanAttachment 1Response to Request for Additional Information -Relief Request PR-01Revision 0October 25, 2013 A6 -9 Three Mile Island Unit #1Inservice Testing Program PlanResponse to Request for Additional InformationRelief Request PR-01Page 1 of 2Question:1.) In the attachment to letter dated November 7, 2012, Relief Request PR-01, Section 6,"Proposed Alternative and Basis for Use," it is stated that, "Individual pump flow rates willbe calculated and compared against individual pump flow rate reference values." Pleasedescribe the methodology used to calculate the individual pump flow rates and how thereference values were established.Response:The quarterly Group A testing of the three Nuclear Services Closed Cooling Water pumps isdone during normal plant operation. The procedure operates the pumps in the three differentcombinations of pump pairs. For each test, the two operating pumps are throttled, using thedischarge isolation valves for the individual pumps, to a test condition of 58 psid (pounds persquare inch differential) pump head. The pump head (differential pressure) is determined fromthe local suction and discharge pressure gauge readings for each pump. These three flowreadings are designated as AB, AC, and BC in the equations below and individual pump flows ingallons per minute (gpm) are calculated using the following equations:MethodNS-P-1A flow (AB + AC -BC)/2 = -gpmNS-P-1B flow (AB + BC -AC)/2 = __ gpmNS-P-1C flow (BC + AC -AB)/2 = __ gpmThe Inservice Testing (IST) reference values were established using this test methodology. Thefollowing table summarizes the raw data and results from those tests:Test Date Pump Pairs Discharge Suction Pump TotalTest De u Pi Pressure Pressure Head FlowNS-P-1A 116 psig 58 psig 58 psi 6400Test 1 NS-P-1 C 117 psig 59 psig 58 psi gpmMarch 5, NS-P-1A 116 psig 58 psig 58 psi 63002007 Test 2 NS-P-1B 117 psig 59 psig 58 psi gpmTest 3 NS-P-11B 117 psig 59 psig 58 psi 6000NS-P-1C 117 psig 59 psig 58 psi gpmThe individual pump flow rates were determined from this data as follows:* NS-P-1A flow = (6300 + 6400 -6000) /2 = 3350 gpm* NS-P-1B flow = (6300 + 6000 -6400) /2 = 2950 gpm* NS-P-1Cflow= (6000+6400-6300)/2 = 3050gpmThese individual pump flow rates were used as the initial reference values.Revision 0October 25, 2013 A6 -10 Three Mile Island Unit #1Inservice Testing Program PlanResponse to Request for Additional InformationRelief Request PR-01Page 2 of 2Subsequently, a new reference value for the NS-P-1A pump was established using the followingdata:Discharge Suction Pump TotalTest Date Pump Pairs Pressure Pressure Head FlowNS-P-1A 117 psig 59 psig 58 psi 5875Test 1NS-P-1C 116.5 psig 58.5 psig 58 psi gpmMarch14, NS-P-1A 117.5 psig 59.5 psig 58 psi 58752008 14, B1Test 22008 NS-P-1 B 116.5 psig 58.5 psig 58 psi gpmNS-P-1 B 116 psig 58 psig 58 psi 5750Test 3NS-P-1C 116.5 psig 58.5 psig 58 psi gpmThe individual pump flow rates were determined from this data as follows:* NS-P-1 A flow = (5875 + 5875 -5750) / 2 = 3000 gpm* NS-P-1 B flow = (5875 + 5750 -5875) / 2 = 2875 gpm* NS-P-1Cflow= (5750+5875-5875)/2 = 2875gpmThe NR-P-1 B and NR-P-1 C flows were slightly lower than the existing reference values, butwithin the ASME OM Code +/-10% acceptance criteria limit. Therefore, the reference valueswere not revised for these pumps.Based on the described methodology, the flow reference values for each pump are as follows(except as noted):* NS-P-1A flow = (5875 + 5875 -5750) / 2 = 3000 gpmNS-P-1 B flow = (6300 + 6000 -6400) / 2 = 2950 gpm (the current value forNS-P-1 B was later revised to 2949 gpm based on additional analysis)* NS-P-1C flow = (6000 + 6400 -6300) / 2 = 3050 gpmThese reference values provide substantial margin over the minimum design flow requirementof 1972 gpm for each of the NS-P-1A/B/C pumps.In addition to the above discussion, Relief Request PR-01 has been revised (seeAttachment 2) to reflect a proposed alternative in accordance with 10 CFR 50.55a(a)(3)(i).Revision 0October 25, 2013 A6 -11 Three Mile Island Unit #1Inservice Testing Program PlanAttachment 2Relief Request PR-01, Revision 2Revision 0October 25, 2013A6 -12 Three Mile Island Unit #1Inservice Testing Program Plan10 CFR 50.55a RELIEF REQUEST: PR-01Revision 1(Page 1 of 3)Relief Request Concerning Nuclear Services Closed Cooling Water Flow RateMeasurement During Group A Tests In Accordance with 10 CFR 50.55a(a)(3)(i)1. ASME Code Component(s) AffectedNS-P-1A, Nuclear Services Closed Cooling Water (NSCCW) Pump lA (Centrifugal /Group A / Class 3)NS-P-I B, Nuclear Services Closed Cooling Water Pump lB (Centrifugal / Group A /Class 3)NS-P-IC, Nuclear Services Closed Cooling Water Pump IC (Centrifugal / Group A /Class 3)Component/System FunctionThe NSCCW system includes four 33.33-percent capacity nuclear services coolers, andthree 50-percent capacity NSCCW pumps. This system, along with the intermediatecooling system, satisfies the cooling requirements of all nuclear-oriented services otherthan decay heat and reactor building emergency cooling. In the event of a loss-of-coolantaccident, 100-percent redundancy of all nuclear services equipment may be obtained byisolating nonessential items so that flow requirements are reduced to approximately halfthat of normal operation.2. Applicable Code Edition and AddendaASME OM Code-2004 Edition, with Addenda through OMb-20063. Applicable Code Requirement(s)ISTB-512 I(b) -"Group A Test Procedure" -"The resistance, of the system shall be varieduntil the flow rate equals the reference point ...... Alternatively, the flow rate shall bevaried until the differential pressure equals the reference point..."4. Reason for RequestPursuant to 10 CFR 50.55a(a)(3)(i), TMI, Unit 1 requests approval of this alternative to therequirement of ASME OM Code ISTB-5121(b). Due to system design and plant operatingrequirements, it is not practical to reduce the number of pumps in service to one to allowfor single-pump testing during power operation. Also, individual pump flow rates cannotbe measured during the Group A test. The flow instrumentation for this system is locatedin the common discharge header for all three of the subject pumps. The pipingconfiguration does not contain, nor would the system design permit the installation ofaccurate individual pump flow measuring devices due to the turbulence caused by theRevision 0October 25, 2013 A6 -13 Three Mile Island Unit #1Inservice Testing Program Plan10 CFR 50.55a RELIEF REQUEST: PR-01Revision 1(Page 2 of 3)valving and elbow configuration on the discharge of the pumps. There were no provisionsoriginally designed in the system to measure individual pump flow rate.To comply with the ISTB requirement for measuring individual pump flow rates on aquarterly basis, a modification of the system would be required.5. Proposed Alternative and Basis for UseIndividual suction and discharge pressure gauges are installed at each pump allowing formeasurement of differential pressure for inservice testing. A flow instrument is installed inthe common discharge header.The proposed test would test (as approved previously in PR-02 for the fourth interval)NSCCW pumps in pump pairs. As stated previously, individual pump flow cannot bemeasured during quarterly operations since individual flow instrumentation does not exist.Also, two (2) pumps are normally required to be in service to provide adequate cooling forsystem components. The NSCCW pumps are centrifugal pumps (not vertical line shaft).The current quarterly inservice procedure tests all combinations of paired-pumps (A-B,B-C, A-C). During these tests, pump dP (differential pressure) is set, and combined pumpflow rate is measured.Individual pump flow rates will be calculated and compared against individual pump flowrate reference values. Corrective actions will be taken in accordance with ISTB-6200,"Corrective Action," in the event that these criteria are not met. The pumps will continueto be tested individually in accordance with ISTB-5123, "Comprehensive Test Procedure,"during refueling outages.Additionally, vibration data on the pump will be recorded and compared to the referencevalues. Any deviation from the reference value will be compared to.the Code acceptancecriteria. The current testing methodology of testing paired-combinations of pumps neartwo-pump design flow rate provides an adequate basis for identifying and evaluatingdegraded pump performance. Therefore, this testing method provides reasonable assuranceof pump operational readiness.The following is a summary of proposed alternative testing:a. TMI, Unit 1 will continue to perform quarterly testing using a modified Group A testprocedure as described above. With two paired-pumps in service, the required Group Atest parameters will be measured except for individual pump flow rate. Individualpump flow rates will be calculated and compared against calculated individual pumpflow rate reference values. During this test, the differential pressure for each pump willbe throttled to the reference value.Revision 0October 25, 2013 A6 -14 Three Mile Island Unit #1Inservice Testing Program Plan10 CFR 50.55a RELIEF REQUEST: PR-01Revision 1(Page 3 of 3)b. Vibration measurements will be recorded and compared to their reference values.Deviations from the reference value will be compared with the ranges specified inTable ISTB-5121-1 for Group A tests. Corrective actions will be taken in accordancewith ISTB-6200.c. During testing of the subject pumps (quarterly and refueling), TMI, Unit I will performfull spectrum vibration analysis, which is above Code required vibration testing.d. The pumps will continue to be tested individually in accordance with ISTB-5123,"Comprehensive Test Procedure," during refueling outages.Using the provisions of this relief request as an alternative to the specific requirements ofISTB-5121(b) will provide reasonable assurance of pump operational readiness. Therefore,pursuant to CFR 50.55a(a)(3)(i), TMI, Unit 1 requests approval of this alternative to thespecific ISTB requirements identified in this request.6. Duration of Proposed AlternativeThe proposed alternative identified will be utilized during the fifth IST interval which isscheduled to begin October 15, 2013 and conclude on October 14, 2023.7. PrecedentsA similar Relief Request (P5) was approved for TMI, Unit 1 for the third 10-year intervalas documented in the U.S. Nuclear Regulatory Commission's Safety Evaluation Reportdated July 2, 2004 (ML041670196).A similar Relief Request (PR-02) was approved for TMI, Unit 1 for the fourth 10-yearinterval as documented in the U.S. Nuclear Regulatory Commission's Safety EvaluationReport dated July 7, 2005 (ML051530406).Revision 0October 25, 2013 A6 -15I Three Mile Island Unit #1Inservice Testing Program Plan,f UNITED STATESNUCLEAR REGULATORY COMMISSIONWASHINGTON, D.C. 20555-00010August 15, 2013Mr. Michael J. PacilioPresident and Chief Nuclear OfficerExelon Nuclear4300 Winfield RoadWarrenville, IL 60555
 
==SUBJECT:==
THREE MILE ISLAND NUCLEAR STATION, UNIT 1 -RELIEF REQUESTSPR-01, PR-02, AND VR-02, ASSOCIATED WITH THE FIFTH 10-YEARINSERVICE TEST INTERVAL (TAC NOS. MF0046, MF0047 AND MF0048)
 
==Dear Mr. Pacilio:==
By letter dated November 7, 2012 (Agencywide Documents Access and Management System(ADAMS) Accession No. ML12313A344), supplemented by letter dated April 17, 2013 (ADAMSAccession No. ML1 3108A003), Exelon Generation Company, LLC (the licensee) submittedproposed alternative requests PR-01, PR-02, and VR-02, associated with the fifth 10-yearinservice test (IST) interval, at Three Mile Island, Unit I (TMI-1). These proposed alternativesapply to certain requirements of the American Society of Mechanical Engineers (ASME) Codefor Operation and Maintenance of Nuclear Power Plants (OM Code). PR-01 relates to aproposed alternative method for flow measurement during testing of the Nuclear ServicesClosed Cooling Water Pumps, submitted pursuant to Title 10 of the Code of FederalRegulations (10 CFR), Part 50, Section 55a(a)(3)(i). PR-02 requests approval for the use ofASME OM Code Case OMN-18, "Alternate Testing Requirements for Pumps Tested QuarterlyWithin +/-20 percent of Design Flow," for various pumps in the TMI-1 IST program, also submittedpursuant to 10 CFR 50.55a(a)(3)(i). OMN-18 would allow the licensee to not perform theComprehensive Pump Test under certain conditions, and for certain pumps, as specified in therequest. VR-02 requests approval for the licensee to utilize a tolerance band (grace period) forthe intervals specified in the ASME OM Code, similar to the tolerance band allowed forsurveillances in the plant technical specifications. This request was submitted pursuant to10 CFR 50.55a(a)(3)(ii).The U.S. Nuclear Regulatory Commission (NRC) staff has completed its review of the proposedalternatives as discussed in the enclosed safety evaluation. The NRC staff review concludesthat for alternative requests PR-01 and PR-02, the proposed alternatives provide an acceptablelevel of quality and safety. For proposed alternative VR-02, the proposed alternative providesreasonable assurance that the components are operationally ready. Therefore, the NRC staffauthorizes proposed alternative requests PR-01, PR-02 and VR-02, as proposed, at TMI-1, forthe fifth 10-year IST program interval, which begins on October 15, 2013, and is scheduled toend on October 14, 2023.Revision 0October 25, 2013 A6 -16 Three Mile Island Unit #1Inservice Testing Program PlanM. Pacilio-2-If you have any questions, please contact the TMI-1 Project Manager, Mr. Peter J. Bamford, at301-415-2833.Sincerely,Veronica RodrigueiefPlant Licensing Branch 1-2Division of Operating Reactor LicensingOffice of Nuclear Reactor RegulationDocket No. 50-289
 
==Enclosure:==
Safety Evaluationcc w/encl: Distribution via ListServRevision 0October 25, 2013A6 -17 Three Mile Island Unit #1Inservice Testing Program PlanUNITED STATES0 NUCLEAR REGULATORY COMMISSIONWASHINGTON, D.C. 20555-0001SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATIONREGARDING RELIEF REQUESTS PR-01, PR-02, AND VR-02ASSOCIATED WITH THE FIFTH 10-YEAR INSERVICE TEST INTERVALEXELON GENERATION COMPANY, LLCTHREE MILE ISLAND NUCLEAR STATION, UNIT IDOCKET NO. 50-28
 
==91.0 INTRODUCTION==
By letter dated November 7, 2012 (Agencywide Documents Access and Management System(ADAMS) Accession No. ML12313A344), as supplemented by letter dated April 17, 2013(ADAMS Accession No. ML13108A003), Exelon Generation Company, LLC (the licensee)submitted proposed alternative requests PR-01, PR-02, and VR-02 to the U.S. NuclearRegulatory Commission (NRC). The licensee proposed alternatives to certain inservice testing(IST) requirements of the American Society of Mechanical Engineers (ASME) Code for Operationand Maintenance of Nuclear Power Plants (OM Code), for the IST program at the Three MileIsland Nuclear Station, Unit 1 (TMI-1), for the fifth 10-year IST program interval.Specifically, PR-01 relates to a proposed alternative method for flow measurement during testingof the Nuclear Services Closed Cooling Water (NSCCW) Pumps. PR-02 requests approval forthe use of ASME OM Code Case OMN-18, "Alternate Testing Requirements for Pumps TestedQuarterly within +/-20 Percent of Design Flow," for various pumps in the TMI-1 IST program.OMN-18 would allow the licensee to not perform the Comprehensive Pump Test (CPT) undercertain conditions, applicable to certain pumps, as specified in the request. VR-02 would allowthe licensee to utilize a tolerance band (grace period) to the intervals specified in the ASME OMCode, similar to the tolerance band allowed for surveillances in the plant technical specifications.Pursuant to Title 10 of the Code of Federal Regulations (10 CFR) 50.55a(a)(3)(i), the licenseeproposed the use of the alternatives in PR-01 and PR-02 on the basis that the alternativesprovide an acceptable level of quality and safety. Pursuant to 10 CFR 50.55a(a)(3)(ii), thelicensee proposed the use of the alternative in VR-02, on the basis that the ASME OM Coderequirement presents an undue hardship without a compensating increase in the level of qualityor safety.
 
==2.0 REGULATORY EVALUATION==
Pursuant to 10 CFR 50.55a(f), "Inservice Testing Requirements," IST of certain ASME CodeClass 1, 2, and 3 components must meet the requirements of the ASME OM Code and applicableaddenda.EnclosureRevision 0October 25, 2013 A6 -18 Three Mile Island Unit #1Inservice Testing Program Plan-2-Pursuant to 10 CFR 50.55a(a)(3), alternatives to ASME Code requirements may be authorized bythe NRC if the licensee demonstrates that: (i) the proposed alternatives provide an acceptablelevel of quality and safety, or (ii) compliance with the specified requirements would result inhardship or unusual difficulty without a compensating increase in the level of quality and safety.Based on the above, and subject to the NRC's findings with respect to authorizing the proposedalternatives to the ASME OM Code given below, the NRC staff finds that regulatory authorityexists for the licensee to request, and the NRC staff to authorize, the alternatives requested bythe licensee.The Code of Record for the TMI-1 fifth 10-year IST program is the ASME OM Code, 2004 Editionwith Addenda through OMb-2006. The TMI-1 fifth 10-year IST interval begins onOctober 15, 2013, and is currently scheduled to end on October 14, 2023.
 
==3.0 TECHNICAL EVALUATION==
3.1 Alternative Request PR-01. Nuclear Service Closed Coolinq Water Flow RateMeasurement During Group A TestsIn this alternative, the licensee proposed the use of a modified quarterly Group A test for the ISTof the NSCCW pumps. The NSCCW pumps have plant identification designators NS-P-1A, NS-P-1B, and NS-P-1C.3.1.1 The Licensee's Proposed AlternativeThe ASME OM Code, Section ISTB-5121, "Group A Test Procedure," (b), states that "Theresistance of the system shall be varied until the flow rate equals the reference point. Thedifferential 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 flowrate determined and compared to the reference flow rate value."According to the licensee, it is not practical to reduce the number of pumps in service to one toallow for single-pump testing during power operation due to the system design and plantoperating requirements. The licensee also states that individual pump flow rates cannot bemeasured during the Group A test because the flow instrumentation for this system is located inthe common discharge header for all three of the subject pumps. Further, according to thelicensee, the piping configuration does not contain, nor would the system design permit, theinstallation of accurate individual pump flow measuring devices due to the turbulence caused bythe valve and elbow configuration on the discharge of the pumps.As an alternative to meeting the ASME OM Code requirements, the licensee proposes:a. TMI, Unit 1 will continue to perform quarterly testing using a modified Group Atest procedure as described above [in the application dated November 7,2012, supplemented on April 17, 2013]. With two paired-pumps in service,the required Group A test parameters will be measured except for individualpump flow rate. Individual pump flow rates will be calculated and comparedagainst calculated individual pump flow rate reference values. During thistest, the differential pressure will be throttled to the reference value.Revision 0October 25, 2013 A6 -19 Three Mile Island Unit #1Inservice Testing Program Plan-3-b. Vibration measurements will be recorded and compared to their referencevalues. Deviations from the reference value will be compared with the rangesspecified in Table ISTB-5121-1 for Group A tests. Corrective actions will betaken in accordance with ISTB-6200.c. During testing of the subject pumps (quarterly and refueling), TMI, Unit 1 willperform full spectrum vibration analysis, which is done above Code requiredvibration testing.d. The pumps will continue to be tested individually in accordance ISTB-5123,"Comprehensive Test Procedure," during refueling outages.3.1.2 NRC Staff EvaluationThe ASME OM Code, Table ISTB-3400-1, notes that Group A and Group B tests shall beperformed quarterly, and CPTs shall be performed biennially. ISTB-5121(b) requires that forGroup A tests, the resistance of the system shall be varied until the flow rate equals the referencepoint. 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 pointand the flow rate determined and compared to its reference value.The three NSCCW pumps are centrifugal pumps. The flow instrumentation for this system islocated in the common discharge header for all three of the subject pumps. Due to the systemdesign and plant operating requirements, it is not practical to reduce the number of pumps inservice to one to allow for single-pump testing during power operation. The licensee states thatthe piping configuration does not contain, nor would the system design permit the installation of,accurate individual pump flow measuring devices due to the turbulence caused by the valve andelbow locations in the piping configuration on the discharge of the pumps. Compliance with theOM Code requirement to measure individual pump flow rate would require installation of newpiping or certain system modifications. As such, the licensee requests an alternative to thequarterly requirements of individual flow measurement, and proposes to calculate the individualpump flow rate from the combined flow measurements of three paired-pump tests (A-B, B-C, andA-C). The calculated individual pump flow rates will be compared against individual pump flowrate calculated reference values. The pump will continue to be tested individually in accordancewith ISTB-5123 for CPTs during refueling outages. In addition, for the quarterly Group A testsand CPTs, TMI-1 will also perform a full spectrum vibration analysis for the affected pumps.The NRC staff finds that the method of calculating individual flow rate from three-paired pumptests (A-B, B-C, and A-C) provides similar and equally acceptable flow rates for each affectedpump, as opposed to individually measured flow rates. On the basis that direct measurements ofindividual pump flow rate is not available, and that the modified quarterly Group A test providessimilar and equally acceptable results, the NRC concludes that the proposed alternative providesan acceptable level of quality and safety for testing the NSCCW pumps.3.2 Alternative Request PR-02, Use of Code Case OMN-18In this alternative, the licensee proposed the use of ASME OM Code Case OMN-18, "AlternateTesting Requirements for Pumps Tested Quarterly within +/-20% [percent] of Design Flow," for thefollowing pumps:Revision 0October 25, 2013 A6 -20 Three Mile Island Unit #1Inservice Testing Program Plan-4-Pump Description CategoryAH-P-3A Control Building Chilled Water Supply Pump A Group AAH-P-3B Control Building Chilled Water Supply Pump B Group ABS-P-1A Reactor Building Spray Pump A Group ABBS-P-1B Reactor Building Spray Pump B Group ABDC-P-1A Decay Heat Closed Cooling Water Pump A Group ADC-P-1 B Decay Heat Closed Cooling Water Pump B Group ADR-P-1A Decay Heat River Water Pump A Group ADR-P-1B Decay Heat River Water Pump B Group ASF-P-1A Spent Fuel Cooling Pump A Group ASF-P-1B Spent Fuel Cooling Pump B Group AThe ASME OM Code Committee has approved Code Case OMN-18, which allows licensees toperform a Group A test in lieu of the biennial CPT if the Group A tests are conducted at +/-20percent of the design flow rate and pressure instruments that meet the CPT accuracyrequirement of +/-1/2 percent are used. This Code Case was not reviewed for approval inRegulatory Guide (RG) 1.192, "Operation and Maintenance Code Case Acceptability, ASME OMCode," dated June 2003.3.2.1 The Licensee's Proposed AlternativeThe licensee proposes that in lieu of the CPT requirements of the ASME OM Code, TableISTB-3400-1, Group A tests will be performed quarterly within +/-20 percent of the pump designflow rate, with pressure measuring instrumentation meeting the (+/-1/2 percent) instrumentaccuracy requirements of Table ISTB-3510-1 specified for the biennial CPT. In addition, thelicensee has elected to restrict the upper limit for acceptable range to 106 percent of thereference value (flow rate or differential pressure), which is more conservative than the 110percent upper limit established in Tables ISTB-5121-1 and ISTB-5221-1 for Group A tests.Vibration testing will continue to be performed under the proposed modified Group A test and theacceptance criteria for vibration will be the same as required for Group A tests as shown inTables ISTB-5121-1 and ISTB-5221-1.The licensee states that using the provisions of the request as an alternative to the requirementsspecified in ISTB-3400 and Tables ISTB-3400-1, ISTB-5121-1, and ISTB-5221-1, will provide areasonable alternative to the ASME OM Code requirements based on the determination that theproposed alternative will provide adequate indication of pump performance, permit consistentdetection of component degradation, and continue to provide an acceptable level of quality andsafety.3.2.2 NRC Staff EvaluationThe licensee is proposing to perform a quarterly IST for all the pumps listed above in accordancewith a modified Group A test procedure, in lieu of a quarterly Group A test and a biennial CPT.The ASME OM Code requires that for Group A pumps, a Group A test be performed everyquarter, and a CPT be performed biennially. The Group A test is performed within +/-20 percent ofthe pump design flow rate and the pressure instrument accuracy is +/-2 percent. The upper limitRevision 0October 25, 2013 A6 -21 Three Mile Island Unit #1Inservice Testing Program Plan-5-for the "Acceptable Range" for flow rate and differential pressure is 110 percent of the referencevalues, and the high value for the "Required Action Range" for flow rate and differential pressureis greater than 110 percent of the reference values. The CPT is performed within +/-20 percent ofthe pump design flow rate, the pressure instrument accuracy is +/-1/2 percent, and the upper limitof the "Acceptable Range" and the high value for the "Required Action Range" for flow rate anddifferential pressure is 103 percent of the reference values. Vibration monitoring is performedduring both the Group A tests and the CPTs.The licensee proposes that for the pumps covered by this proposed alternative, a modifiedGroup A quarterly test will be performed using ASME OM Code Case OMN-1 8, with modified"Acceptable" and "Required Action" ranges, and the biennial CPT will not be performed. Themodified Group A quarterly test would be performed within +/-20 percent of the pump design flowrate, using more accurate pressure instrumentation that is required for a CPT (+/-1/2 percentinstead of +/-2 percent). The licensee will use a more limiting upper bound of 106 percent of thereference value for the "Acceptable Range" for flow rate and differential pressure, in lieu of 110percent of the reference value that is normally required by the ASME OM Code for Group A tests.However, this upper bound of 106 percent is greater than the upper bound value of 103 percentfor the biennial CPT. Using more accurate pressure gauges and a more limiting "AcceptableRange" (compared to the Group A test "Acceptable Range") during every modified quarterlyGroup A test compensates for the elimination of the CPT with its more limiting "AcceptableRange" upper bound value of 103 percent.OMN-1 8 was published in the 2009 Edition of ASME OM Code. This edition of the ASME OMCode has not been incorporated by reference into 10 CFR 50.55a, and OMN-18 has not beenincorporated into RG 1.192. However, the NRC staff has reviewed OMN-18, and currently has noconcerns with its use, providing that the upper end values of the Group A test "AcceptableRanges" for flow and differential pressure are 106 percent of the respective reference values, andthe high values of the "Required Action Ranges" for flow and differential pressure are greater than106 percent of the respective reference values. The NRC staff considers the proposedalternative acceptable because all of the tests will be performed with pressure gauges with +/-1/2percent accuracy. The elimination of the CPT, with its more limiting "Acceptable Range" upperbound of 103 percent of the reference value, is compensated for by using more accuratepressure instrumentation on every quarterly test. Regular testing with more accurateinstrumentation and tighter acceptance criteria will provide for better trending of pumpperformance. Therefore, the NRC finds that the proposed alternative provides an acceptablelevel of quality and safety for testing and acceptance criteria for the pumps specified in thisproposed alternative.3.3 Alternative Request VR-02, ASME OM Code Test FrequenciesThis request applies to the frequency specifications of the ASME OM Code. The frequencies fortests are provided in various sections of the ASME OM Code, but do not include a toleranceband.3.3.1 The Licensee's Proposed AlternativeAccording to the licensee:ASME OM Code Section IST establishes the inservice test frequency for allcomponents within the scope of the Code. The frequencies (e.g., quarterly) havealways been interpreted as "nominal" frequencies (generally as defined in theTable 3.2 of NUREG-1482, Revision 1) and Owners routinely applied theRevision 0October 25, 2013 A6 -22 Three Mile Island Unit #1Inservice Testing Program Plan-6-surveillance extension time period (i.e., grace period) contained in the plantTechnical Specifications (TS) Surveillance Requirements (SRs). The TS typicallyallow for a less than or equal to 25% extension of the surveillance test interval toaccommodate plant conditions that may not be suitable for conducting thesurveillance. However, regulatory issues have been raised concerning theapplicability of the TS "Grace Period" to ASME OM Code required inservice testfrequencies.The lack of a tolerance band (grace period) on the ASME OM Code inservice testfrequency restricts operational flexibility. There may be a conflict where asurveillance test could be required (i.e., its Frequency could expire), but where itis not possible or not desired that it be performed until sometime after a plantcondition or associated Technical Specification is applicable. Therefore, to avoidthis conflict, the IST should be performed when it can be and should beperformed.The NRC recognized this potential issue in the TS by allowing a frequencytolerance as described in the TMI Unit 1 TS SR 4.0.1. The lack of a similartolerance applied to the OM Code testing places an unusual hardship on theplant to adequately schedule work tasks without operational flexibility.Thus, just as with TS required surveillance testing, some tolerance is needed toallow adjusting ASME OM Code testing intervals to suit the plant conditions andother maintenance and testing activities. This assures operational flexibilitywhen scheduling surveillance tests that minimize the conflicts between the needto complete the surveillance and plant conditions.The licensee's alternative proposes to adopt wording equivalent to the ASME Board of NuclearCodes and Standards (BNCS)-approved OM Code Case OMN-20, for determining acceptabletolerances for pump and valve test frequencies. This Code Case was approved by the ASMEOM Code Standards Committee in February 2012. The proposed alternative applies to thevarious frequency specifications of the ASME OM Code for all pumps and valves contained withinthe IST Program scope.The licensee's proposal states:ASME OM Code establishes component test frequencies that are based either onelapsed time periods (e.g., quarterly, 2 years, etc.) or on the occurrence of plantconditions or events (e.g., cold shutdown, refueling outage, upon detection of asample failure, following maintenance, etc.).a. Components whose test frequencies are based on elapsed time periods shallbe tested at the frequencies specified in ASME OM Code Section IST with aspecified time period between tests as shown in the table below and asdefined in TMI, Unit 1 TS Section 1.25.b. The specified time period between tests may be reduced or extended asfollows:1) For periods specified as less than 2 years, the period may be extended byup to 25% for any given test. This is consistent with TMI, Unit 1 TS Section1.25, "FREQUENCY NOTATION."Revision 0October 25, 2013 A6 -23 Three Mile Island Unit #1Inservice Testing Program Plan-7-2) For periods specified as greater than or equal to 2 years, the period maybe extended by up to 6 months for any given test.3) All periods specified may be reduced at the discretion of the owner (i.e.,there is no minimum period requirement).4) Period extensions may also be applied to accelerated test frequencies(e.g., pumps in Alert Range).Specified Time Period Between Tests (allFrequency values are 'not to exceed'; no minimumperiods are specified)Quarterly 92 days(or every 3 months)Semiannually 184 days(or every 6 months)Annually 366 days(or every year)x Years x calendar yearswhere 'x' is a whole number of years ? 2c. Components whose test frequencies are based on the occurrence of plantconditions or events (e.g., cold shutdown, refueling outage, upon detection of asample failure, following maintenance, etc.) may not have their period betweentests extended except as allowed by the ASME OM Code.Period extension is to facilitate test scheduling and considers plant operatingconditions that may not be suitable for performance of the required testing (e.g.,performance of the test would cause an unacceptable increase in the plant riskprofile due to transient conditions or other ongoing surveillance test ormaintenance activities). Period extensions are not intended to be used repeatedlymerely as an operational convenience to extend test intervals beyond thosespecified. This request is not applicable to frequencies in Subsection ISTD.3.3.2 NRC Staff EvaluationHistorically, licensees have applied, and the NRC staff has accepted, the standard TS definitionsfor IST intervals (including allowable interval extensions) to ASME OM Code required testing(Reference NUREG-1482, "Guidelines for Inservice Testing at Nuclear Power Plants," Revision 1,Section 3.1.3). Recently, the NRC staff reconsidered the allowance of the TS testing intervalsand interval extensions, for IST not associated with TS SRs. As noted in Regulatory IssueSummary (RIS) 2012-10, "NRC Staff Position on Applying Surveillance Requirements 3.0.2 and3.0.3 to Administrative Controls Program Tests," the NRC determined that programmatic testfrequencies can't be extended in accordance with the Improved Standard TS SR 3.0.2. Thisincludes all IST described in the ASME OM Code not specifically required by the TS SRs.Following this development, the NRC staff sponsored and co-authored an ASME OM Codeinquiry and Code Case to modify the ASME OM Code to include TS-tike test interval definitionsand interval extension criteria. The resultant BNCS-approved Code Case OMN-20, wasRevision 0October 25, 2013 A6 -24 Three Mile Island Unit #1Inservice Testing Program Plan-8-approved by the ASME Operation and Maintenance Standards Committee on February 15, 2012,with the NRC representative voting in the affirmative on this proposed Code Case. The licenseeproposed to adopt language equivalent to the BNCS-approved Code Case OMN-20.The NRC staff finds that requiring the licensee to meet the ASME OM Code requirements,without an allowance for defined frequency and frequency extensions for IST of pumps andvalves, results in a hardship without a compensating increase in the level of quality and safety.Based on the prior acceptance by the NRC staff of the similar TS test interval definitions andinterval extension criteria, the staff finds that implementation of the test interval definitions andinterval extension criteria contained in the ASME BNCS-approved OM Code Case OMN-20 isacceptable. Allowing usage of an alternative equivalent to Code Case OMN-20 providesreasonable assurance of operational readiness of pumps and valves subject to the ASME OMCode IST.
 
==4.0 CONCLUSION==
As set forth above, the NRC staff has determined that for alternative requests PR-01 and PR-02,the proposed alternatives provide an acceptable level of quality and safety. For alternative VR-02, the proposed alternative provides reasonable assurance that the components areoperationally ready. Accordingly, the NRC staff concludes that the licensee has adequatelyaddressed all of the regulatory requirements set forth in 10 CFR 50.55a(a)(3)(i) for requests PR-01 and PR-02. The NRC staff also concludes that the licensee has adequately addressed all ofthe regulatory requirements set forth in 10 CFR 50.55a(a)(3)(ii) for request VR-02. All otherASME OM Code requirements for which relief was not specifically requested and approvedremain applicable. Therefore, the NRC staff authorizes alternative requests PR-01, PR-02 andVR-02, as proposed, at TMI-1, for the fifth 10-year IST program interval, which begins onOctober 15, 2013, and is scheduled to end on October 14, 2023.Principle Contributors: J. Huang, NRRR. Wolfgang, NRRJ. Billerbeck, NRRDate: August 15, 2013Revision 0October 25, 2013 A6 -25 Three Mile Island Unit #1Inservice Testing Program PlanM. Pacilio-2-If you have any questions, please contact the TMI-1 Project Manager, Mr. Peter J. Bamford, at301-415-2833.Sincerely,Ira/Veronica Rodriguez, Acting ChiefPlant Licensing Branch 1-2Division of Operating Reactor LicensingOffice of Nuclear Reactor RegulationDocket No. 50-289
 
==Enclosure:==
Safety Evaluationcc w/encl: Distribution via ListServDISTRIBUTION:PUBLICLPLI-2 R/FRidsNrrDeEpnb ResourceRWolfgang, NRRJBillerbeck, NRRRidsAcrsAcnw MailCTR ResourceRidsNrrPMThreeMilelsland ResourceRidsNrrDorlDpr ResourceVCampbell, OEDO, Region IRidsNrrLAABaxter ResourceRidsRgn1MailCenter ResourceRidsNrrDorlLpll-2 ResourceJHuang, NRRADAMS Accession Number: ML13227A024
* by emailOFFICE LPLI-2/PM LPLI-2/LA EPNBIBC*- LPLI-2/BC(A)INAME PBamford ABaxter TLupold VRodriguezDATE 08/14113 08/114113 07/25/113 08/1513OFFICIAL RECORD COPYRevision 0October 25, 2013A6 -26 Three Mile Island Unit #1Inservice Testing Program PlanUNITED STATESNUCLEAR REGULATORY COMMISSIONWASHINGTON, D.C. 20555-0001August 28, 2013Mr. Michael J. PacilioPresident and Chief Nuclear OfficerExelon Nuclear4300 Winfield RoadWarrenville, IL 60555
 
==SUBJECT:==
THREE MILE ISLAND NUCLEAR STATION, UNIT 1 -RELIEF REQUESTVR-01, PROPOSED ALTERNATIVE TESTING OF THE PRESSURIZER PILOTOPERATED RELIEF VALVE (TAC NO. ME9819)
 
==Dear Mr. Pacilio:==
By letter dated October 18, 2012 (Agencywide Documents Access and Management System(ADAMS) Accession No. ML12292A585), supplemented by letter dated March 15, 2013(ADAMS Accession No. ML13074A700), Exelon Generation Company, LLC (the licensee)submitted proposed alternative request VR-01, associated with the fifth 10-year inservice test(IST) interval at Three Mile Island, Unit 1 (TMI-1). This proposed alternative applies to certainrequirements of the American Society of Mechanical Engineers (ASME) Code for Operation andMaintenance of Nuclear Power Plants (OM Code). VR-01 proposes an alternative method fortesting of the Pressurizer Pilot Operated Relief Valve (PORV), submitted pursuant to Title 10 ofthe Code of Federal Regulations, Part 50, Section 55a(a)(3)(i).The U.S. Nuclear Regulatory Commission (NRC) staff has completed its review of the proposedalternative, as discussed in the enclosed safety evaluation. The NRC staff review concludesthat alternative request VR-01 provides an acceptable level of quality and safety, and that itprovides reasonable assurance that the PORV is operationally ready. Therefore, the NRC staffauthorizes proposed alternative request VR-01, as proposed, for the fifth 10-year IST programinterval at TMI-1, which begins on October 15, 2013, and is scheduled to end onOctober 14, 2023.Revision 0October 25, 2013 A6 -27 Three Mile Island Unit #1Inservice Testing Program PlanM. Pacilio-2-If you have any questions, please contact the TMI-1 Project Manager, Mr. Peter J. Bamford, at301-415-2833.Sincerely,Veronica Rodriguez, Actin hiefPlant Licensing Branch 1-2Division of Operating Reactor LicensingOffice of Nuclear Reactor RegulationDocket No. 50-289
 
==Enclosure:==
Safety Evaluationcc w/encl: Distribution via ListServRevision 0October 25, 2013A6 -28 Three Mile Island Unit #1Inservice Testing Program PlanS,.UNITED STATES0 A REGULATORY COMMISSION, WASHINGTON, D.C. 20555-0001SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATIONREGARDING RELIEF REQUEST VR-01PROPOSED ALTERNATIVE TESTING OF THE PRESSURIZERPILOT OPERATED RELIEF VALVEEXELON GENERATION COMPANY, LLCTHREE MILE ISLAND NUCLEAR STATION, UNIT 1DOCKET NO. 50-28
 
==91.0 INTRODUCTION==
By letter dated October 18, 2012 (Agencywide Documents Access and Management System(ADAMS) Accession No. ML12292A585), supplemented by letter dated March 15, 2013 (ADAMSAccession No. ML13074A700), Exelon Generation Company, LLC (the licensee) submittedproposed alternative request VR-01, associated with the fifth 10-year inservice test (IST) interval,at Three Mile Island, Unit 1 (TMI-1). The proposed alternative applies to certain requirements ofthe American Society of Mechanical Engineers (ASME) Code for Operation and Maintenance ofNuclear Power Plants (OM Code). VR-01 relates to a proposed alternative method for testing ofthe Pressurizer Pilot Operated Relief Valve (PORV), submitted pursuant to Title 10 of the Code ofFederal Regulations (10 CFR), Part 50, Section 55a(a)(3)(i). Specifically, the proposedalternative would utilize a bench testing protocol for the PORV in lieu of certain provisions of theASME OM Code that require in-situ testing.
 
==2.0 REGULATORY EVALUATION==
Pursuant to 10 CFR 50.55a(f), "Inservice Testing Requirements," IST of certain ASME CodeClass 1, 2, and 3 components must meet the requirements of the ASME OM Code and applicableaddenda.Pursuant to 10 CFR 50.55a(a)(3), alternatives to ASME Code requirements may be authorized bythe NRC if the licensee demonstrates that: (i) the proposed alternatives provide an acceptablelevel of quality and safety, or (ii) compliance with the specified requirements would result inhardship or unusual difficulty without a compensating increase in the level of quality and safety.Based on the above, and subject to the NRC's findings with respect to authorizing the proposedalternative to the ASME OM Code given below, the NRC staff finds that regulatory authority existsfor the licensee to request, and the NRC staff to authorize, the alternative requested by thelicensee.EnclosureRevision 0October 25, 2013 A6 -29 Three Mile Island Unit #1Inservice Testing Program Plan-2-The Code of Record for the TMI-1 fifth 10-year IST program is the ASME OM Code, 2004 Editionwith Addenda through OMb-2006. The TMI-1 fifth 10-year IST interval begins onOctober 15, 2013, and is currently scheduled to end on October 14, 2023.
 
==3.0 TECHNICAL EVALUATION==
3.1 Licensee's Alternative RequestThe ASME OM Code requirements that apply to the TMI-1 PORV (1-RC-RV-2), applicable to thisrequest, include requirements to exercise the valve after replacement, and requirements toperform exercise testing of the valve once per fuel cycle.Currently, the licensee satisfies these requirements by manually stroking the valve once everyoperating cycle. This is performed during plant startup following a refueling outage. The valvemust also be stroke-timed during this exercise test. The licensee is proposing an alternative tothis required in-situ testing for several reasons, stated as follows in the submittal datedOctober 18, 2012:There are several disadvantages to the in-situ testing of the PORV. The PORV isa 2.5 inch Dresser Electromatic, solenoid actuated, pilot operated relief valve.Operation of the pilot valve vents the chamber under the main valve disc whichcauses the main valve to open. The PORV requires steam pressure for the maindisc to open. Stroke testing the PORV during cold shutdown conditions does notexercise the main valve disc which, therefore, does not satisfy the subject ASMEOM Code requirements. To test the PORV in-place, the RCS [reactor coolantsystem] must be pressurized to supply the necessary fluid (steam) pressure toopen the main valve disc.Also, since the PORV design does not provide direct obturator position indication,the valve disc position must be inferred from alternate indications (tailpipe AT,acoustic monitoring, RCS pressure decrease, or quench tank pressure or levelrise).In-situ testing of the PORV also results in an in-surge of cooler water from theRCS hot leg into the pressurizer. The resulting thermal cycle on the pressurizersurge line is a thermal stress concern, as described in NRC Bulletin 88-08("Thermal Stresses in Piping Connected to Reactor Coolant Systems") and shouldbe avoided.Requiring that the PORV be tested in-place prevents plant personnel fromverifying proper reseating of the main valve disc because the discharge is notvisible as it is during bench testing. Minor leakage would not be readily evidentbefore it would cause damage to the main valve disc/seat. Excessive leakagefrom the pilot valve can lead to inadvertent opening of the main valve and impairits ability to re-close.The proposed alternative will allow testing of the PORV that is appropriate todemonstrate functionality without cycling the valve in place using reactor steampressure. This is consistent with NUREG-0737, "Clarification of TMI Action PlanRequirements," Item II.K.3.16, "Reduction of Challenges and Failures of ReliefRevision 0October 25, 2013 A6 -30 Three Mile Island Unit #1Inservice Testing Program Plan-3-Valves," which recommended that the number of relief valve openings be reducedas much as possible and that unnecessary challenges should be avoided.The licensee proposes the following alternatives to the requirements regarding stroking followingreplacement, and once per refueling cycle, for the fifth IST interval at TMI-1:1) Bench testing of the PORV to satisfy valve exercise and stroke timerequirements is performed at the vendor test facility prior to installation.Exercising of the valve at both the normal power operation set point and theLow Temperature Overpressure Protection (LTOP) set point (as provided inTechnical Specification 3.1.12, "Pressurizer Power Operated Relief Valve(PORV), Block Valve, and Low Temperature Overpressure Protection (LTOP)")will be verified during this testing. Measured stroke time will be based on thepressure response indication of main disc opening.2) The installed valve will be removed and replaced each refueling outage, with aspare valve that has been previously bench tested.3) The removed valve will be bench tested within one year of removal from thesystem.4) In-situ exercising of the PORV will be performed only as necessary toreestablish operational readiness after maintenance on an installed valve.In the application, the licensee provided a detailed justification for the use of bench testing in lieuof in-situ testing. Included in this justification was a table showing bench test stroke time historybetween August 31, 2000, and November 4, 2011, for both the LTOP function and the normalreactor coolant system pressure function of the PORV. According to the licensee, these results.consistently show that the valve opens well within the 2-second limiting stroke time allowed byISTC-5114(c) for rapid acting valves.3.2 NRC Staff EvaluationThe licensee has categorized the Pressurizer PORV, 1-RC-RV-2, as OM Code category B/C and,therefore, the valve is subject to the applicable test requirements of both ASME OM CodeSubsection ISTC for power-operated valves and Mandatory Appendix I for pressure reliefdevices.The requirements of Mandatory Appendix I allow the valve to be removed from the system fortesting and do not specifically require that the valve be exercised when it is returned to thesystem. However, paragraphs ISTC-3310 and ISTC-3510 could be interpreted to require in-situexercising of the valve following replacement (ISTC-3310) or routinely at a once per fuel cyclefrequency (ISTC-351 0).The licensee has determined that exercising the PORV in-situ is undesirable for a number ofreasons. The NRC staff finds that exercising the PORV in-situ at normal steam pressures doespresent undesirable circumstances. There is some precedent in ASME OM Code itself for notexercising relief devices following reinstallation after testing. For Boiling Water Reactor (BWR)Class 1 Main Steam Pressure Relief Valves with Auxiliary Actuating Devices, MandatoryAppendix 1-3410(d) allows that after removal and reinstallation for testing, the electrical andRevision 0October 25, 2013 A6 -31 Three Mile Island Unit #1Inservice Testing Program Plan-4-pneumatic connections may be verified by inspection in lieu of test, and that valve main diskmovement (i.e., exercise) is not required. While this ASME OM Code example is not specificallyapplicable to Pressurized Water Reactor PORVs, it is analogous.There is further precedent in a number of prior licensing actions wherein the NRC staff hasapproved technical specification changes for various licensees to remove routine in-situ exerciserequirements for BWR Class 1 safety/relief valves for the same and similar reasons as presentedby this licensee.The licensee has proposed alternatives, which include a series of verifications and controls todemonstrate the operational readiness of the valve:Multiple bench test verifications performed in the same orientation as the plantinstallation and using test conditions similar to those in the plant installation, includingambient temperature, valve insulation, and steam conditions:0 exercising the pilot and main valve disk as a unitN set point verificationM obturator movement verification0 stroke time testing0 seat leakage verificationa refurbishment, as neededThe licensee indicates, and the NRC staff agrees, that performing some of these tests on thebench is actually preferred over in-situ testing because they can be performed more precisely.Additional steps taken by the licensee to ensure operational readiness of the PORV are:0 Receipt inspection and storage in accordance with quality procedures to ensureprotection against physical damage and moisture upon return to the plant site0 Pre-installation inspection for foreign material and damage* Installation and connection in accordance with quality maintenance procedures0 Operation of the solenoid-actuated pilot valve (which controls the actuation of thevalve main disk) in-situ to verify electrical power and control connectionsThe licensee has further stated that if maintenance is ever required on an installed valve, in-situexercising will be performed to reestablish operational readiness.The NRC staff has reviewed the licensee's proposed alternative and concludes thatimplementation of these alternatives will continue to meet the fundamental intent of ASME OMCode to assure the PORV operational readiness and to permit detection of PORV degradation.The proposed alternative demonstrates proper PORV operation without the need for in-situtesting with reactor steam, and therefore provides an acceptable level of quality and safety.Revision 0October 25, 2013 A6 -32 Three Mile Island Unit #1Inservice Testing Program Plan-5-
 
==4.0 CONCLUSION==
As set forth above, the NRC staff determines that for alternative request VR-01, the proposedalternative provides an acceptable level of quality and safety and also provides reasonableassurance that the PORV is operationally ready. Accordingly, the NRC staff concludes that thelicensee has adequately addressed all of the regulatory requirements set forth in10 CFR 50.55a(a)(3)(i). All other ASME OM Code requirements for which relief was notspecifically requested and approved remain applicable. Therefore, the NRC staff authorizesalternative request VR-01, to be implemented at TMI-1 for the fifth 10-year IST program interval,which is scheduled to begin on October 15, 2013, and conclude on October 14, 2023.Principle Contributor: John Billerbeck, NRRDate: August 28, 2013Revision 0October 25, 2013 A6 -33 Three Mile Island Unit #1Inservice Testing Program PlanM. Pacilio-2-If you have any questions, please contact the TMI-1 Project Manager, Mr. Peter J. Bamford, at301-415-2833.Sincerely,IralVeronica Rodriguez, Acting ChiefPlant Licensing Branch 1-2Division of Operating Reactor LicensingOffice of Nuclear Reactor RegulationDocket No. 50-289
 
==Enclosure:==
Safety Evaluationcc w/encl: Distribution via ListServDISTRIBUTION:PUBLICLPLI-2 R/FRidsNrrDeEpnb ResourceJBillerbeck, NRRRidsAcrsAcnwMailCTR ResourceRidsNrrPMThreeMilelsland ResourceRidsNrrDorlDpr ResourceVCampbell, OEDO, Region IRidsNrrLAABaxter ResourceRidsRgnlMailCenter ResourceRidsNrrDorlLpll-2 ResourceADAMSO FFICENAMEDATEAccession No.: ML13232A051LPLI-2/PM LPLI-2/LA* EPBamford ABaxter 108/20113 08127/13 CEPNBIBC*rLupold* by emailLPLI-2/1BC/AVRodriguez08/28/13-II18114113OFFICIAL RECORD COPYRevision 0October 25, 2013A6 -34 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 7CODE CASE INDEXRevision 0October 25, 2013A7- 1 Three Mile Island Unit #1Inservice Testing Program PlanCODE CASENUMBERTITLEOMN-18The ASME Code committee has approved Code Case OMN-18,"Alternate Testing Requirements for Pumps Tested Quarterly within +20% of Design Flow".Revision 0October 25, 2013A7 -2 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 8COLD SHUTDOWN JUSTIFICATION INDEXRevision 0October 25, 2013A8 -1 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 8COLD SHUTDOWN JUSTIFICATION INDEXDesignator RevCS-01CS-02CS-03CS-04CSJ-05CSJ-06CSJ-07CSJ-08CSJ-09CSJ-10CSJ-11CSJ-12CSJ-13CSJ-14CSJ-15CSJ-16CSJ-17CSJ-18Title/DescriptionIntermediate Cooling Water Valves (IC-V-2,3,4,6) Exercise Close,Fail CloseDecay Heat Suction Isolation Valve (DH-V-1/2) ExerciseOpen/CloseCharging Line Iso Valve (MU-V-18) Exercise Close and Fail CloseRCP Seal Water Iso Valve (MU-V-20) Exercise Close and FailCloseRCP Seal Water Return Iso Valves (MU-V-25/26) Exercise Closeand Fail CloseLetdown Iso Valves (MU-V-2A/B, 3) Exercise Close and Fail CloseRC Motor Return Iso Valve (NS-V-1 5) Exercise CloseRC Motor Return Iso Valves (NS-V-35/4) Exercise CloseReactor Building Cooling Water Iso Valves (RB-2A/7) ExerciseCloseFW Isolation Valves (FW-V-16A/B, 17A/B,5A/B,92A/B) ExerciseClosePressurizer Vent Valves (RC-V-28/44) Exercise Close and FailCloseRC Vent Valves (RC-V-40A/B, 41A/B) Exercise Close and FailCloseReactor Vessel Vent Valves (RC-V-42/43) Exercise Close and FailCloseDH Discharge Isolation Valves (DH-V-4A/B) Exercise Open/CloseCA-T-1 To Makeup System Check Valve (CA-V-1 77) ExerciseOpen/CloseMain Steam Isolation Valves (MS-V-1A-D) Exercise ClosePressurizer Spray Line Isolation Valve (RC-V-3) Exercise CloseDecay Heat Pressurizer Spray Line Isolation Valve (RC-V-4)Exercise Open/CloseRevision 0October 25, 2013A8 -2 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 9COLD SHUTDOWN JUSTIFICATIONSRevision 0October 25, 2013A9 -1 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 9COLD SHUTDOWN JUSTIFICATION CSJ-01Valve Number System Safety Class CategoryIC-V-2 IC 2 AIC-V-3 IC 2 AIC-V-4 IC 2 AIC-V-6 IC 2 AFunctionThese power operated valves close to isolate containment from the IC System on 1) receiptof any ESAS signal concurrent with a IC Surge Tank low level signal or 2) on a 30 psigReactor Building pressure ESAS signal, regardless of IC Surge Tank level. These air-operated valves (IC-V-3, 4, and 6) also fail closed on loss of electrical power or pneumaticsupply.These valves have no safety function to open. The IC System inside the Reactor Buildingis non-ASME Safety Class, Seismic Category II and does not serve any components whichare required for the safe shutdown of the reactor or for the mitigation of any Design Basisaccidents.Test RequirementExercise test to the closed position in accordance with ISTC-3510.JustificationIt is not practical to full stroke exercise or fail safe test these valves closed during normalpower operation since closure testing at normal power imposes a significant risk ofequipment damage.Exercising these valves closed during power operation will isolate the cooling water supplyto the Control Rod Drive Cooling Coils, Primary Letdown Coolers and Reactor CoolantPump Heat Exchangers. Interruption of cooling water flow to these components wouldcause equipment damage and a potential trip of the reactor.Alternative TestThese valves will be exercised closed (IC-V-2, 3, 4, 6) and fail safe tested closed (IC-V-6)during cold shutdowns when cooling water supplied to the Control Rod Drive Cooling Coils,Primary Letdown Coolers and Reactor Coolant Pump Heat Exchangers is not required.These valves will be partial stroke exercised quarterly during normal power operations.Revision 0October 25, 2013 A9 -2 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 9COLD SHUTDOWN JUSTIFICATION CSJ-02Valve Number System Safety Class CategoryDH-V-1 DH 1 ADH-V-2 DH 1 AFunctionThese normally-closed motor-operated valves are required to open to allow use of the dropline to circulate water through the Core following a cold-leg LOCA in order to prevent theconcentration of boron from exceeding its solubility limit. Precipitation of boron could resultin clogged flow channels, limiting the ability to remove heat.These valves are also opened in order to use the DH System as the normal and preferredmethod of placing and maintaining the Reactor in the Cold Shutdown condition, includingthose times when it is necessary to do so in response to a Technical Specification required-action statement.These valves receive an automatic signal to close and cannot be reopened if RCS pressureexceeds 400 psig in order to prevent over-pressurization of the lower pressure-rated DHSystem pump suction piping.Test RequirementFull-stroke exercise to the open and closed positions in accordance with ISTC-351 0.JustificationIt is not practical to full stroke exercise or partial stroke exercise these valves open orclosed during normal power operation since opening the valves during normal poweroperation would cause over pressurization of the lower pressure DH system. Additionally,these valves are interlocked with reactor coolant system pressure such that they can not beopened while reactor coolant system pressure is greater than 400 psig.Alternative TestThese valves will be exercised open and closed during cold shutdowns when the reactorcoolant system is depressurized.Revision 0October 25, 2013 A9 -3 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 9COLD SHUTDOWN JUSTIFICATION CSJ-03Valve Number System Safety Class CategoryMU-V-18 MU 2 AFunctionThis normally-open, air-operated valve is required to close on an ESAS actuation signal of1600 psig RCS pressure or 4 psig Reactor Building pressure to 1) assure adequate,balanced HPI flow to the RCS and to isolate containment. An ESAS backup initiationsignal is also provided at 500 psig RCS pressure. Closure of this valve prevents HPI flowfrom bypassing the cavitating venturi at the B HPI nozzle. The valve fails closed on loss ofair and open on loss of power. Loss of DC power is the identified limiting single failureassociated with the closing safety function of this valve.This valve is normally in the open (i.e., throttled) position to provide makeup flow to theRCS. This open function is not required for safe shutdown or accident mitigation.Test RequirementExercise test to the closed position in accordance with ISTC-3510.JustificationIt is not practical to full stroke exercise or fail safe test this valve closed during normalpower operation since closure testing at normal power operations would lead to a potentialloss of reactor coolant system inventory control and potential trip of the reactor.Closing this valve for testing during normal power operations would interrupt makeup flowto the reactor coolant system which could cause a loss of inventory control and subsequenttrip of the reactor. This valve is required to be open for throttling and maintaining RCSinventory control during power operations.Alternative TestThis valve will be exercised closed and fail safe tested during cold shutdowns when thereactor coolant system makeup control is not required. The valve will be partial strokeexercised quarterly during normal power operations.Revision 0October 25, 2013 A9 -4 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 9COLD SHUTDOWN JUSTIFICATION CSJ-04Valve Number System Safety Class CategoryMU-V-20 MU 2 AFunctionThis valve is normally-open providing shaft seal injection for the reactor coolant (RC)pumps. This air-operated valve is closed by remote manual operation to isolate theReactor Building (containment) following an accident. It does not receive an ESAS signalto close because of the importance of seal injection to the integrity of the RC pumps shaftseals. Loss of seal injection due to an erroneous actuation of ESAS or by a non-LOCAevent such as RCS overcooling could cause significant damage to the associated shaftseal or pump shaft. The valve fails closed on loss of electrical power or pneumatic supply.Test RequirementExercise test to the closed position in accordance with ISTC-351 0.JustificationIt is not practical to full stroke exercise or fail safe test this valve closed during normalpower operation since closure testing at normal power operations could cause significant.damage to the reactor coolant pumps shafts and shaft seals.Closing this valve for testing during normal power operations would interrupt seal injectionflow to the reactor coolant pumps shaft seals and risk permanent damage to the reactorcoolant pump seals and cause subsequent Reactor Coolant system leakage.Additionally, partial stroke exercising of the valve during operation would involvemanipulation of the manual hand-wheel to position the "block" so that adequate RC pumpseal injection is maintained. The air operator design is such that excessive use of thehand-wheel tends to wear the shaft seals, resulting in increased leakage of the air that'srequired to maintain the valve open upon failure of the air source. Therefore, quarterlypartial stroke exercising of the valve presents a premature failure vulnerability without asignificant benefit in monitoring valve performance.Alternative TestThis valve will be exercised closed and fail safe tested during cold shutdowns when thereactor coolant pumps are not in service and seal injection is not required.Revision 0October 25, 2013 A9 -5 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 9COLD SHUTDOWN JUSTIFICATION CSJ-05Valve Number System Safety Class CategoryMU-V-25 MU 2 AMU-V-26 MU 2 AFunctionThese normally open valves close automatically on a 30 psig Reactor Building ESAS signalto isolate the Reactor Building makeup and purification system. The high pressure signal isused to ensure that sealing water flow remains available through the mechanical seals ofthe Reactor Coolant Pumps for those events in which continued operation of the pumpsprovides an advantage in maintaining flow through the Core. Valve MU-V-26 also failsopen on loss of electrical power and closed on loss of pneumatic supply.These valves are normally open to provide a return flow path for the seal leakoff of theReactor Coolant Pumps. This function is not required for safe shutdown or accidentmitigation.Test RequirementExercise test to the closed position in accordance with ISTC-3510.JustificationIt is not practical to full stroke exercise or fail safe test these valves closed during normalpower operation since closure testing at normal power operations could cause significant.damage to the reactor coolant pump seals.Closing these valves for testing during normal power operations would disrupt seal leakoffflow from the reactor coolant pumps and would present an inventory management issuesince upstream relief valve, MU-V-180, will lift and pass seal return flow to the RC draintank. This creates a significant risk of permanent damage to the reactor coolant pump.seals, with the potential to cause subsequent Reactor Coolant system leakage.Alternative TestThese valves will be exercised closed (MU-V-25/26) and failsafe tested (MU-V-26) duringcold shutdowns when the reactor coolant pumps are not in service and seal leakoff flow isnot required. The valves will be partial stroke exercised quarterly during normal poweroperations.Revision 0October 25, 2013 A9 -6 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 9COLD SHUTDOWN JUSTIFICATION CSJ-06Valve Number System Safety Class CategoryMU-V-2A MU 1 AMU-V-2B MU 1 AMU-V-3 MU 2 AFunctionThese normally open valves receive an ESAS signal to close automatically on HPI initiationat 1600 psig RCS pressure or 4 psig Reactor Building pressure in order to isolate the MUSystem letdown line. Valve MU-V-3 also fails closed on loss of electrical power orpneumatic supply.The valves are open during normal Plant operation to provide letdown flow from the RCS tothe MU System for chemical and radiological control. This function is not required for safeshutdown or accident mitigation.Test RequirementExercise test to the closed position in accordance with ISTC-351 0.JustificationClosing these valves for testing during normal power operations would interrupt letdownflow from the reactor coolant system.It is not practical to full stroke exercise or fail safe test these valves closed during normalpower operation since closure testing at normal power operations would cause: (1) a minortransient in pressurizer level control, and (2) thermal cycling of the letdown coolers. Theletdown coolers are a unique "helicoil" design, and avoiding transients is necessary toprolong their life. Unnecessary cycling would lead to premature damage of the letdowncoolers, whose repair would also become a significant ALARA concern.Alternative TestThese valves will be exercised closed (MU-V-2A/B and MU-V-3) and fail safe tested (MU-V-3) during cold shutdowns when the letdown coolers are not in service and RCS letdownflow may be isolated. The valves will be partial stroke exercised quarterly during normalpower operations.Revision 0October 25, 2013 A9 -7 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 9COLD SHUTDOWN JUSTIFICATION CSJ-07Valve Number System Safety Class CategorvNS-V-15 NS 2 AFunctionThis normally open motor operated valve closes on receipt of any ESAS signal coincidentwith a low level signal in Nuclear Services Closed Cooling Water Surge Tank (NS-T-1), oron a 30 psig Reactor Building pressure signal to isolate the NS supply header to theReactor Coolant Pump Motor Air and Oil Coolers.Cooling water to the components listed above is required during normal plant operation.ESAS initiation circuitry is set up to keep this valve open during initial actuation, unlessthere is a low level Surge Tank signal concurrent with the ESAS signal, or until ReactorBuilding pressure reaches 30 psig. This open function allows for the continuous supply ofcooling water to the RCP motors in the event that the pumps continue to run. This openfunction is not required for safe shutdown or accident mitigation.Test RequirementExercise test to the closed position in accordance with ISTC-3510.JustificationIt is not practical to full stroke exercise this valve closed during normal power operationsince closure testing at normal power operations would lead to eventual damage of theReactor Coolant Pump Motor Air and Oil Coolers.Closing this valve for testing during normal power operations would interrupt cooling waterflow to the Reactor Coolant Pump Motor Air and Oil Coolers and would cause a brieftemperature transient, and ultimately eventual damage, to the associated coolers.Quarterly partial stroking of the valve verifies that it will perform its function to close.Alternative TestThis valve will be exercised closed during cold shutdowns when the Reactor Coolant PumpMotor Air and Oil Coolers are not in service and Nuclear Services cooling water flow maybe isolated. The valve will be partial stroke exercised quarterly during normal poweroperations.Revision 0October 25, 2013 A9 -8 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 9COLD SHUTDOWN JUSTIFICATION CSJ-08Valve Number System Safety Class CategoryNS-V-35 NS .3 ANS-V-4 NS 3 AFunctionThese normally open motor operated valves close automatically upon receipt of any ESASsignal coincident with a low level signal in Nuclear Services Closed Cooling Water SurgeTank NS-T-1, or on a 30 psig Reactor Building pressure signal to isolate the NS returnheader from the Reactor Coolant Pump Motor Air and Oil Coolers.Cooling water to the components listed above is required during normal plant operation.ESAS initiation circuitry is set up to keep this valve open during initial actuation, unlessthere is a low level Surge Tank signal concurrent with the ESAS signal, or until ReactorBuilding pressure reaches 30 psig. This open function allows for the continuous supply ofcooling water to the RCP motors in the event that the pumps continue to run. This openfunction is not required for safe shutdown or accident mitigation.Test RequirementExercise test to the closed position in accordance with ISTC-3510.JustificationIt is not practical to full stroke exercise these valves closed during normal power operationsince closure testing at normal power operations would lead to eventual damage of theReactor Coolant Pump Motor Air and Oil Coolers.Closing these valves for testing during normal power operations would interrupt coolingwater flow to the Reactor Coolant Pump Motor Air and Oil Coolers and would cause a brieftemperature transient, and ultimately eventual damage, to the associated coolers.Quarterly partial stroking of the valves verifies that they will perform their function to close.Alternative TestThese valves will be exercised closed during cold shutdowns when the Reactor CoolantPump Motor Air and Oil Coolers are not in service and Nuclear Services cooling water flowmay be isolated. The valves will be partial stroke exercised quarterly during normal poweroperations.Revision 0October 25, 2013 A9 -9 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 9COLD SHUTDOWN JUSTIFICATION CSJ-09Valve Number System Safety Class CategoryRB-V-2A RB 2 ARB-V-7 NS 2 AFunctionThese normally open motor operated valves close on receipt of an ESAS Reactor Buildingisolation signal on high Reactor Building Pressure (4 psig) or low RCS pressure (1600 psigor 500 psig backup) to isolate the non-safety, non-seismically qualified normal ReactorBuilding Industrial Cooling Water System and allow for shifting to the Reactor BuildingEmergency Cooling Water System.These valves are open to allow cooling water to be supplied to the non-safety relatedReactor Building Industrial Cooling Coils during normal operation. This function is notrequired for safe shutdown or accident mitigation.Test RequirementExercise test to the closed position in accordance with ISTC-3510.JustificationIt is not practical to full stroke exercise these valves closed during normal power operationsince closure testing at normal power operations would isolate cooling to the ReactorBuilding normal cooling coils. Isolation of the RB cooling coils at any time of the year wouldchallenge the plant's ability to maintain compliance with Reactor Building TemperatureLimits (Tech Spec 3.17). Additionally, if either of these valves were to fail in the closedposition during the cycling test, this would cause a loss of the system function and likelyrequire a plant shutdown to avoid exceeding temperature limits within containment. Thisjustifies deferral of testing to cold shutdown. Quarterly partial stroking of the valves verifiesthat they will perform their function to close.Alternative TestThese valves will be exercised closed during cold shutdowns when the Reactor BuildingIndustrial Cooling Coils are not required to be in service and reactor building emergencycooling water may be isolated. The valves will be partial stroke exercised quarterly duringnormal power operations.Revision 0October 25, 2013 A9 -10 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 9COLD SHUTDOWN JUSTIFICATION CSJ-10Valve Number System Safety Class CategoryFW-V-5A FW N/A BFW-V-5B FW N/A BFW-V-16A FW N/A BFW-V-16B FW N/A BFW-V-17A FW N/A BFW-V-17B FW N/A BFW-V-92A FW N/A BFW-V-92B FW N/A BFunctionThese normally open valves must close to isolate the OTSG's from the feedwater system inthe event of a main steam line break. The valves are powered from an EngineeredSafeguards Control Center (Class 1 E) and receive an HSPS signal to close on Hi-Hi OTSGlevel or a Feedwater or Main Steam line break (low OTSG pressure). Downstream checkvalves FW-V-12A/B are relied upon for closure during a feedwater line break and forcontainment isolation.The valves are open during normal power operation to provide a flow path from thefeedwater system to the OTSG's. This function is not required for safe shutdown oraccident mitigation.Test RequirementExercise test to the closed position in accordance with ISTC-3510.JustificationIt is not practical to full stroke or partial stroke exercise these valves closed during normalpower operation since closure of any of these valves would interrupt feedwater flow whichwould result in a plant transient due to a mismatch in feedwater/main steam line flow. Thistransient would result in a subsequent trip of the reactor and potentially injection ofemergency feedwater.Injection of emergency feedwater would result in an unacceptable thermal shock to thesteam generators which could result in a degradation of the primary containment systemboundary (OTSG tubes).Alternative TestThese valves will be exercised closed during cold shutdowns when the feedwater system. isnot required to be in service.Revision 0October 25, 2013 A9- 11 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 9COLD SHUTDOWN JUSTIFICATION CSJ-11Valve Number System Safety Class CateaoryRC-V-28 RC 1 BRC-V-44 RC 1 BFunctionThese normally closed valves are opened to vent steam and noncondensible gases fromthe pressurizer steam space to the reactor coolant drain tank. This function assures thatthe pressurizer is available for pressure and volume control. This venting capabilitysupports core cooling for events beyond the design basis. The ability to vent post accidentincreases the ability of the plant to deal with large quantities of noncondensible gas whichcould interfere with natural circulation (i.e., core cooling). The valve is also used during anOTSG tube rupture to minimize sub cooling margin and during RCS superheat conditions.These functions mitigate the consequences of a design basis SGTR accident.When the required venting iscompleted, the valves are closed by remote manual operationto maintain the RCS pressure boundary and inventory. These valves do not receive anyautomatic actuation or isolation signals.The individual vent path lines are sized such that an inadvertent opening of any valve willnot constitute a LOCA. This design feature provides a high degree of assurance that thevents will be available when needed, and that inadvertent operation or failures will notsignificantly hamper the safe operation of the plant [TS 3.1.13].Test RequirementFull-stroke exercise to the open and closed positions in accordance with ISTC-3510.JustificationIt is not practical to full or partial stroke exercise or fail safe test these valves during normalpower operation. Exercising either of these valves during power operations places theplant in an undesirable configuration by reducing the reactor coolant system isolationbarrier to only a single valve. Exercising either valve during normal power operationsleaves only the other valve as a single valve isolation barrier. During normal operationthese valves are maintained closed at all times, they also fail closed.Alternative TestThese valves will be full stroke exercised closed (RC-V-28/44) and fail safe tested closed(RC-V-44) during cold shutdowns when the Pressurizer and Reactor Coolant system isdepressurized below 200 psig.Revision 0October 25, 2013 A9 -12 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 9COLD SHUTDOWN JUSTIFICATION CSJ-12Valve Number System Safety Class CategoryRC-V-40A RC 1 BRC-V-40B RC 1 BRC-V-41A RC 1 BRC-V-41 B RC 1 BFunctionThese normally closed solenoid operated valves are opened to vent steam andnoncondensible gases from the reactor coolant system hot leg high points which cannot bevented through the reactor vessel or pressurizer steam space vents. These vents relieve tothe reactor building atmosphere through a rupture disk. Technical Specification 3.1.13.1.crequires the RCS high point vent flow paths to be operable when the reactor is critical. Thisventing capability supports core cooling for events beyond the design basis. The ability tovent post accident increases the ability of the plant to deal with large quantities ofnoncondensible gas which could interfere with natural circulation (i.e., core cooling).When the required venting is completed, the valves are closed by remote manual operationto maintain the RCS pressure boundary and inventory. These valves do not receive anyautomatic actuation or isolation signals however they fail closed on loss of electrical power.The individual vent path lines are sized such that an inadvertent opening of any valve willnot constitute a LOCA. This design feature provides a high degree of assurance that thevents will be available when needed, and that inadvertent operation or failures will notsignificantly hamper the safe operation of the plant [TS 3.1.13].Test RequirementFull-stroke exercise to the open and closed positions in accordance with ISTC-3510.JustificationIt is not practical to full or partial stroke exercise or fail safe test closed these valves duringnormal power operation. Exercising either of these valves during power operations placesthe plant in an undesirable configuration by reducing the reactor coolant system isolationbarrier to only a single valve in the respective path. Exercising either valve during normalpower operations leaves only the other valve as a single valve isolation barrier. Duringnormal operation these valves are maintained closed at all times, they also fail closed.Alternative TestThese valves will be full stroke exercised to the open and closed positions and fail-safetested closed during cold shutdowns when the Reactor Coolant system is depressurizedbelow 200 psig.Revision 0October 25, 2013 A9 -13 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 9COLD SHUTDOWN JUSTIFICATION CSJ-13Valve Number System Safety Class CategoryRC-V-42 RC 1 BRC-V-43 RC 1 BFunctionThese normally closed solenoid operated valves are opened to vent steam andnoncondensible gases from the reactor vessel head and hot and cold legs to the reactorbuilding. Technical Specification 3.1.13.1.a requires the associated reactor vessel headvent (RC-V-42/43) flow path to be operable when the reactor is critical. This ventingcapability supports core cooling for events beyond the design basis. The ability to ventpost accident increases the ability of the plant to deal with large quantities ofnoncondensible gas which could interfere with natural circulation (i.e., core cooling).When the required venting is completed, the valves are closed by remote manual operationto maintain the RCS pressure boundary and inventory. These valves do not receive anyautomatic actuation or isolation signals however they fail closed on loss of electrical power.The individual vent path lines are sized such that an inadvertent opening of any valve willnot constitute a LOCA. This design feature provides a high degree of assurance that thevents will be available when needed, and that inadvertent operation or failures will notsignificantly hamper the safe operation of the plant [TS 3.1.13].Test RequirementFull-stroke exercise to the open and closed positions in accordance with ISTC-3510.JustificationIt is not practical to full or partial stroke exercise or fail safe test closed these valves duringnormal power operation. Exercising either of these valves during power operations placesthe plant in an undesirable configuration by reducing the reactor coolant system isolationbarrier to only a single valve. Exercising either valve during normal power operationsleaves only the other valve as a single valve isolation barrier. During normal operationthese valves are maintained closed at all times, they also fail closed.Alternative TestThese valves will be full stroke exercised to the open and closed positions and fail-safetested closed during cold shutdowns when the Reactor Coolant system is depressurizedbelow 200 psig.Revision 0October 25, 2013 A9 -14 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 9COLD SHUTDOWN JUSTIFICATION CSJ-14Valve Number System Safety Class CategorvDH-V-166A DH 2 CDH-V-166B DH 2 CFunctionThese check valves must open to allow pressure between the seats and portions of pipingof certain valves to equalize with downstream (RCS) pressure in order to prevent pressure-locking of the boundary valves allowing them to be opened when required.The valves close to prevent back flow of RCS fluid into the area between the seats andportions of piping to prevent pressure-locking of the respective valves. However, the abilityof the check valves to close is not required to achieve or maintain safe shutdown or foraccident mitigation.Test Requirement:Exercise test to the open and closed positions in accordance with ISTC-3522.JustificationIt is not practical to full flow open exercise these valves during normal power operationsince the open test requires the DH system in service and also requires partially openingisolation valves DH-V-4AIB. Opening the isolation valves (DH-V-4A/B), with the DH pumpsin service during normal power operation, could disturb the downstream check valves andcause over pressurization of the lower pressure DH system, subjecting the system topressures in excess of its design pressure.Exercising these valves closed requires a hydro pump to pressurize downstream of thecheck valves to verify the bi-directional closure capability of the subject valves. This test isessentially a leakage rate test which requires significant test setup. This justifies deferral oftesting to cold shutdown.Alternative TestThese valves will be exercised open and verified to close during cold shutdowns when thereactor coolant system is depressurized and the DH system can be placed inservice. Aspermitted by ASME OM Code ISTC-3522(a) both the open and closed check valveexercise tests will be performed during cold shutdowns when it is practicable to performboth tests.Revision 0October 25, 2013 A9 -15 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 9COLD SHUTDOWN JUSTIFICATION CSJ-15Valve Number System Safety Class CateciorvCA-V-1 77 CA 3 CFunctionThis valve performs a safety function in the open position to provide a flow path foralternate emergency boration of the RCS from the Boric Acid Mix Tank, CA-T-1, via BoricAcid Injection Pump, CA-P-1A or CA-P-1B, to the Makeup (MU) System. In the openposition, this valve also provides a flow path for addition of boron to the Reactor CoolantSystem for reactivity control during normal operation.This valve performs no safety function in the closed position. In the closed position, thisvalve isolates the non-nuclear, Seismic II portion of the CA System from the ASME Class 3,Seismic I portion. However, downstream manual isolation valve MU-V-51 also performsthe same function. It is normally closed isolating this flow path when not in use.Test RequirementExercise test to the open position in accordance with ISTC-3522.JustificationIt is not practical to full stroke exercise or partial stroke exercise this valve open duringnormal power operation since this results in injection of concentrated boric acid into theRCS. Opening the valve during normal power operation requires running a boric acidpump to put flow through the valve. This evolution adds concentrated boric acid from BoricAcid Mix Tank CA-T-1 to Makeup Tank MU-T-1, the suction source of the running makeuppump. Changing MU tank boron concentration during normal power operation in thismanner is not practical due to the negative reactivity added to the RCS and the significanteffect it will have on RCS reactivity control. This justifies deferral of testing to coldshutdown.Alternative TestThis valve will be exercised open during cold shutdowns when the addition of concentratedboric acid to the reactor coolant system is not a concern.Revision 0October 25, 2013 A9 -16 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 9COLD SHUTDOWN JUSTIFICATION CSJ-16Valve Number System Safety Class CategoryMS-V-1A MS 2 B/CMS-V-1B MS 2 B/CMS-V-1C MS 2 B/CMS-V-1 D MS 2 B/CFunctionThese normally open motor operated stop check valves receive no automatic isolationsignal in order to allow for optimum RCS heat removal during most accidents and non-accident reactor trips. These valves are required to be closed from the Control Roomfollowing a large-break LOCA, small-break LOCA, Main Steam line break, SteamGenerator tube rupture, or if a loss of OTSG integrity results in Containment pressureabove OTSG pressure. In these cases, the valve would be closed by the motor operator,resulting in the Category B classification. These valves function as check valves in closingto prevent blowdown of both OTSG's in the event of a Main Steam line break upstream.Therefore, they are also classified as Category C.Although the open position is preferred under most accident and normal shutdownconditions (and is required for Plant operation), these valves do not have any safetyfunction in the open position. These valves are considered Containment Isolation Valves:however, they are exempt from Type C testing since they are connected to a closed loopinside containment (OTSG).Test RequirementExercise test to the closed position in accordance with ISTC-3510.JustificationIt is not practical to full stroke exercise or partial stroke exercise these valves closed duringnormal power operation (see TSCR 246) since closure testing at normal power operationscould cause a plant trip.Closing these valves for testing during normal power operations would interrupt steam flowfrom the steam generator to the main steam/turbine systems. Exercising these valvesclosed would isolate the steam generator which would result in a severe power transient inthe steam and reactor coolant systems which would lead to a subsequent trip of the plant.To perform this testing quarterly would create a condition with a high potential to cause areactor trip (NUREG-1482, revision 1, section 2.4.5). This justifies deferral of testing tocold shutdowns.Revision 0October 25, 2013 A9 -17 Three Mile Island Unit #1Inservice Testing Program PlanAlternative TestThese valves will be exercised closed (Category B) and stroke timed during coldshutdowns (see TSCR 246) when the main steam system is not required to be in operation.Revision 0October 25, 2013 A9 -18 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 9COLD SHUTDOWN JUSTIFICATION CSJ-17Valve NumberRC-V-3SystemRCSafety Class1Categorv.B .FunctionThis valve provides a backup means of securing flow in the event that the spray valveshould stick open. This valve also provides a backup means of post LOCA boronprecipitation control for the normal method using the decay heat drop line.Test RequirementExercise test to the closed position in accordance with ISTC-3510.JustificationIt is not practical to full stroke exercise this valve during power operation because closingthis valve isolates the minimum flow used to prevent thermal shock to the piping nozzle.This justifies deferral of testing to cold shutdown.Alternative TestThis valve will be exercised closed during cold shutdowns when there is not a concern ofthermal shock to the piping nozzle.Revision 0October 25, 2013 A9 -19 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 9COLD SHUTDOWN JUSTIFICATION CSJ-18Valve Number System Safety Class CateciorvRC-V-4 RC 1 AFunctionThis valve is opened by remote manual operation to initiate auxiliary spray to providefurther pressure reduction or complete depressurization of the RCS after the OTSG's andRC Pumps have been removed from service. The auxiliary spray system cannot be placedin service until the reactor coolant system is below 200 psig. Auxiliary spray is an alternatemethod to DH drop-line flow to prevent boron precipitation post-LOCA. It is a backup to thedrop leg method, which is not single-failure proof.In the closed position, this valve is one of two valves in series that isolate the RCS from thelower design pressure Decay Heat Removal System. The valve must close / remain closedto isolate the reactor coolant system from the DH System. The valve is a Reactor CoolantPressure Boundary (RCPB) Pressure Isolation Valve (PIV).Test Requirement:Exercise test to the open and closed positions in accordance with ISTC-351 0.JustificationIt is not practical to full stroke exercise this valve open and closed during normal poweroperation since injection into the RCS through this line is not possible with the RCSpressurized, and opening of RC-V-4 during operation would leave only a single check valveas the isolation protecting low-pressure injection piping from RCS pressure. The DecayHeat discharge pressure is approximately 200 psig while the normal RCS pressure isgreater than 2100 psig. RC-V-4 is procedurally required to be closed when the RCS is>400 psig. To perform this testing quarterly would require major plant or hardwaremodifications (NUREG-1482, revision 1, section 2.4.5). This justifies deferral of testing tocold shutdown.Alternative TestThis valve will be exercised open and closed during cold shutdowns when the reactorcoolant system is depressurized.Revision 0October 25, 2013 A9 -20 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 10REFUELING OUTAGE JUSTIFICATION INDEXRevision 0October 25, 2013A10 -1 Three Mile Island Unit #1*Inservice Testing Program PlanATTACHMENT 10REFUEL OUTAGE JUSTIFICATION INDEXDesignator RevRJ-01RJ-02RJ-03RJ-04RJ-05RJ-06RJ-07RJ-08RJ-09RJ-10RJ-11RJ-12RJ-13RJ-14RJ-15RJ-16RJ-17RJ-18RJ-19RJ-20RJ-21RJ-22RJ-23Revision 0October 25, 2013Title/DescriptionDH Pump Discharge Check Valves (DH-V-16A/B) Exercise OpenDELETEDDELETED (Replaced by Cold Shutdown Justification CSJ-16)DH to CFT Check Valves (DH-V-22A/B) Exercise Open/ClosedEF Pump Discharge Check Valves (EF-V-1i1A/B) and EF to OTSGCheck Valves (EF-V-1 2A/B) Exercise Open/ClosedIA Check Valves (IA-V-1 628A/B and 1631A/B) Exercise Open/ClosedEF Pump 1 Discharge Check Valve (EF-V-13) Exercise Open/Closed2-Hour Backup Air Valves (IA-V-1625A/B, 1626A/B) Exercise and FailOpenDELETEDMS Isolation Check Valves (MS-V-1A-D) Exercise ClosedRB Emergency Cooling Water Valves (RR-9A/B/C) ExerciseOpen/ClosedMU Tank Outlet Check Valve (MU-V-1 12) Exercise ClosedMU Pump BWST Check Valves (MU-V-14A/B) Exercise Open/ClosedRB Emergency Cooling Water Valves (RR-8A/B) Exercise OpenMU Pump Discharge Check Valves (MU-V-73A-C) ExerciseOpen/ClosedDELETEDDELETEDRB Emergency Cooling Water Valves (RR-7A/B) Exercise Open/ClosedDELETEDDH Pump from BWST Check Valve (DH-V-14A/B) ExerciseOpen/ClosedRB Sump to DH Pump Suction Valves (DH-V-6A/B) ExerciseOpen/ClosedDH Equalizing Check Valves (DH-V-170/171,172) ExerciseOpen/ClosedDH Pressurizer Spray Line Check Valve (RC-V-23) Exercise OpenA10-2 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 10REFUEL OUTAGE JUSTIFICATION INDEXDesignator Rev Title/DescriptionRJ-24 Spent Fuel Return Check Valve (DH-V-50) Exercise Open/ClosedRJ-25 CST De-Icing Supply Check Valves (CO-V-25A/B) ExerciseOpen/ClosedRJ-26 DELETEDRJ-27 MU Pump Minimum Flow Valves (MU-V-193A/B/C) Exercise Open IClosedRJ-28 Reactor Vessel Internal Vent Valves (RC-V-144A thru 144H) ExerciseOpenRevision 0October 25, 2013 A10 -3 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATIONSRevision 0October 25, 2013All -1 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-01Valve Number System Safety Class CateaoryDH-V-16A DH 2 CDH-V-16B DH 2 CFunctionThese check valves are required to open to permit flow from the Decay Heat RemovalPumps to the reactor coolant system or makeup pumps suction when required duringaccident conditions.In the event of a Core Flood System line break, DH Pump discharge cross-connect valvesDH-V-38A and DH-V-38B would need to be opened to provide balanced flow to the Core.If the corresponding DH pump fails to start, the associated check valve must close in orderto prevent bypassing flow back to the Reactor Building Sump through the idle train.Test Requirement:Exercise test to the open and closed positions in accordance with ISTC-3522.JustificationIt is not practical to full stroke exercise these valves open during operations or during cold.shutdown. The open exercise requires a full flow test. Performance of a full stroke forwardflow test is not possible during normal operations since the decay heat removal pumpscannot overcome reactor coolant system pressure. A part stroke open test is performed aspart of the pump quarterly operability test using the recirculation line to the RWST. Aforward flow test during cold shutdowns is not always possible since the reactor coolantsystem pressure may still be at a level which prevents exercising the valves full open.Additionally, the injection of DH system flow into the reactor coolant system during normaloperations or cold shutdowns would effect boron concentration and reactivity.It is not practical to exercise these valves closed during normal power operations. Theclosure test of these valves requires a reverse flow or leakage test. A reverse flow test canonly be performed when the cross tie isolation valves DH-V-38A/B are both open and onepump is in operation. The corresponding idle pump discharge check valve can then bereverse flow tested. This test can only be performed during cold shutdown periods whenthe cross tie isolation valve may be opened. These valves are maintained closed duringnormal power operation to maintain train separation.Alternative TestThese check valves will be exercised open and closed during refueling outages. Thevalves are verified to open with full flow during refueling outages when the DH pump candeliver the required flow rates into the reactor coolant system and closed when the cross-tie isolation valves may be opened. As permitted by ASME OM Code ISTC-3522(a) bothRevision 0October 25, 2013 All -2 Three Mile Island Unit #1Inservice Testing Program Planthe open and closed check valve tests will be performed during refueling outages when it ispracticable to perform both tests.Revision 0October 25, 2013 All -3 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-02 -DELETEDValve NumberCA-V-448ACA-V-448BSystemCACASafety Class22CategoryCCFunctionThe steam generator blowdown/sampling modification, ECR TM 07-00259, installedseparate relief valves on the 2 penetrations, thereby eliminating the need for these checkvalves. Therefore, CA-V-448A/B have been removed from the plant and from the IST and10CFR50 Appendix J programs.Revision 0October 25, 2013 All -4 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-03Valve NumberMS-V-1AMS-V-1 BMS-V-l CMS-V-1 DSystemMSMSMSMSSafety Class2222Cate-goryB/CB/CB/CB/CThis Refueling Outage Justification has been replaced by Cold Shutdown Justification CSJ-16.Revision 0October 25, 2013 All -5 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-04Valve Number System Safety Class CategoryCF-V-5A CF 1 A/CCF-V-5B CF 1 A/CDH-V-22A DH 1 A/CDH-V-22B DH 1 A/CFunctionThese check valves are Reactor Coolant Pressure Boundary Pressure Isolation Valves(RCPB PIV). In the closed position, the valves prevent leakage from the high pressureRCS to the lower pressure rated Core Flood and Decay Heat Removal Systems. Two ofthe valves are considered containment isolation valves; however, they are exempt fromAppendix J Type C testing since no potential atmospheric leakage path from containmentexists.The valves are required to open to admit borated water from the discharge of the CoreFlood Tanks or the Decay Heat Removal Pumps to the Reactor Coolant System during theinjection and recirculation phases following an intermediate to large-break LOCA.Test Requirement:Exercise test to the open and closed positions in accordance with ISTC-3522.JustificationIt is not practical to exercise these valves during normal power operation or during coldshutdown conditions. Exercising these valves requires the performance of a leakage testto verify the closed position and forward flow test to verify the open position.Performance of a forward flow test is not possible during normal operations since the coreflood tanks and the decay heat removal pumps cannot overcome reactor coolant systempressure. This forward flow test during cold shutdowns is not always possible since thereactor coolant system pressure may still be at a level which prevents exercising the valvesopen. Additionally, injection into the reactor coolant system during normal operations orcold shutdowns would effect boron concentration and reactivity.To perform a leakage test to verify closure during normal operations or cold shutdowns,requires temporary test equipment to be installed inside containment to establish adifferential pressure across the valve to verify closure. This test is not practical to beperformed during normal power operations or during cold shutdowns since the DH systemwould be required to be out of service. Additionally, containment entry to perform thenecessary test setup, performance and restoration would cause an increase in personnelradiation exposure. To perform this testing quarterly would require major plant or hardwareRevision 0October 25, 2013 All -6 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-04 (Cont.)modifications (NUREG-1482, revision 1, section 2.4.5). This justifies deferral of testing torefueling outages.Alternative TestThese check valves will be exercised closed during refueling outages in conjunction withtheir respective Pressure Isolation Valve seat leakage test. This test is performed when theCF and DH systems are not required to be in service, the reactor coolant system isdepressurized, and containment entry is possible. The valves are verified to open with fullflow during refueling outages when the CF tanks and the DH pumps can deliver therequired flow rates into the reactor coolant system.Revision 0October 25, 2013 All -7 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-05Valve Number System Safety Class Cate-goryEF-V-11A EF 3 CEF-V-11B EF 3 CEF-V-12A EF 2 CEF-V-12B EF 2 CFunctionThese check valves open to permit the Emergency Feedwater Pump to deliver EmergencyFeedwater to either or both OTSG's when Emergency Feedwater is required.Valves EF-V-1 1A/B must close to prevent diversion of flow through an idle or faultedemergency feedwater pump. Valves EF-V-12A/B must close to prevent reverse flowthereby maintaining OTSG inventory.Test Requirement:Exercise test to the open and closed positions in accordance with ISTC-3522.JustificationIt is not practical to exercise these valves open or closed during normal power operation orduring cold shutdown conditions. Exercising these valves requires the performance of aleakage test to verify the closed position and forward flow test to verify the open position.Performance of a forward flow test is not possible during normal operations since flowthrough the valves during power operation would inject cold water into a hot steamgenerator.. This is impractical because injecting cold water from the Condensate StorageTank into the hot Steam Generator during operations would thermally cycle the tubes andEmergency Feedwater nozzles. Further, injection from the Condensate Storage Tank willintroduce oxygenated water into the Steam Generators. The exposure of the SteamGenerator tubes to oxygenated water, especially during short shutdowns, must beminimized.To perform a leakage test to verify closure during normal operations or cold shutdowns,requires temporary test equipment to be installed to establish a differential pressure acrossthe valve to verify closure. This closed test requires isolation of one injection line to theOTSG and the cross connecting of two of the three Emergency Feedwater Pumps. Thiseffectively removes two pumps from service. This configuration is not desirable nor is itpermitted by the Tech Specs when the plant is operating. During short duration orunplanned Cold Shutdowns, the test could extend the outage due to the amount of timenecessary. for test setup, performance and restoration. To perform this testing quarterlywould require. major plant or hardware modifications (NUREG-1482, revision 1, section2.4.5). This justifies deferral of testing to refueling outages.Revision 0October 25, 2013 All -8 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-05 (Cont.)Alternative TestThese check valves will be exercised open and closed during refueling outages when theEF pumps are able to deliver the required flow to the OTSG. The closure test performed bya differential pressure leakage test will be performed during refueling outages when the EFsystem and OTSG's are not required to be in service.Revision 0October 25, 2013 All -9 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-06.Valve Number System Safety Class CategoryIA-V-1628A IA NC CIA-V-1628B IA NC CIA-V-1631A IA NC CIA-V-1631B IA NC CFunctionThe IA-V-1628A/B check valves must close to isolate the non-safety related instrument airsupply from the 2-Hour Backup Air system.Check valve IA-V-1631A is required to open to provide air from the 2-Hour Backup Airsystem to be supplied to the essential equipment in the event of a loss of the Instrument AirCompressors. This valve closes to prevent backflow when the A train is out of servicewhile the B train is required to supply PC-5 and MS-V-6.Check valve IA-V-1 631 B is required to open to provide a flow path from the 2-Hour BackupAir system to MS-V-6 and the PC-5 Controller.Test Requirement:Exercise test to the open and closed positions in accordance with ISTC-3522.JustificationIt is not practical to full stroke exercise these valves open or closed during normal poweroperation or during cold shutdowns since the closure test requires a backflow leakage test.This testing would require rendering all of the associated essential components inoperablewhile performing the back flow leakage or respective forward flow tests. The required fullflow and backflow leakage tests can only be performed during refueling outages when it ispossible to declare the associated instrument air supplied components inoperable. Toperform this testing quarterly would require major plant or hardware modifications (NUREG-1482, revision 1, section 2.4.5). This justifies deferral of testing to refueling outages.Alternative TestThese check valves will be exercised open and closed during refueling outages when theInstrument Air System is not required to be in service. As permitted by ASME OM CodeISTC-3522(a) both the open and closed check valve tests will be performed duringrefueling outages when it is practicable to perform both tests.Revision 0October 25, 2013 All -10 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-07Valve Number System Safety Class CategorvEF-V-13 EF 3 CFunctionThis check valve opens to permit the turbine-driven Emergency Feedwater Pump EF-P1 todeliver Emergency Feedwater to either or both OTSG's when emergency feedwater isrequired to be in operation. The valve must open to provide a minimum of 350 gpm duringdesign accident conditions.This valve closes to prevent diversion of flow by recirculation through EF-P1 if idle orfaulted.Test Requirement:Exercise test to the open and closed positions in accordance with ISTC-3522.JustificationIt is not practical to exercise this valve open or closed during normal power operation orduring cold shutdown conditions. Exercising the valve requires the performance of a pumpfull flow test to verify the open position.Performance of a forward flow test is not possible during normal operations since flowthrough the valves during power operation would inject cold water into a hot steamgenerator. This is impractical because injecting cold water from the Condensate StorageTank into the hot Steam Generator during operations would thermally cycle the tubes andEmergency Feedwater nozzles. Further, injection from the Condensate Storage Tank willintroduce oxygenated water into the Steam Generators. The exposure of the SteamGenerator tubes to oxygenated water, especially during short shutdowns, must beminimized.The closed test requires that part of the EF system is inoperable and removes redundancyfor providing Emergency Feedwater to each Steam Generator. This configuration is notpermitted by the Technical Specifications when the plant is operating. To perform thistesting quarterly would require major plant or hardware modifications (NUREG-1482,revision 1, section 2.4.5). This justifies deferral of testing to refueling outages.Alternative TestThis check valve will be exercised open during refueling outages when the EF pump is ableto deliver the required flow to the OTSG. The closure test, performed by a differentialpressure test, will be performed during refueling outages when the EF system and OTSG'sare not required to be in service. As permitted by ASME OM Code ISTC-3522(a) both theopen and closed check valve tests will be performed during refueling outages when it ispracticable to perform both tests.Revision 0October 25, 2013 All -11 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-08Valve Number System Safety Class CategoryIA-V-1625A IA NC BIA-V-1625B IA NC BIA-V-1626A IA NC BIA-V-1 626B IA NC BFunctionIA-V-1625A/BThese normally open air operated 3-way valves must remain open to provide a flow pathfrom the 2-Hr Backup Supply Air Bottle Rack to the essential EF and MS air actuators andpositioners. The valves are normally aligned in their safety-related position from the TrainA 2-Hr Backup Supply Air Bottle Rack to the supply header to assure a 2 hour supply ofactuating air in the event of a loss of the IA Compressors. In the event of a loss of supplypressure, the valves fail to the vented position, causing the downstream valves to fail totheir safe position.IA-V-1626A/BThese normally open 3-Way valves must open to provide a flow path from the 2-Hr BackupSupply Air Bottle Rack to the essential EF and MS air actuators and positioners. Thevalves are normally aligned from the discharge of the Instrument Air Compressors (normalsupply) to the supply header for EF-V 030A, EF-V 030C, MS-V 004A, MS-V 006 and thePC-5 Controller. Upon a loss of IA System pressure, they shift to the safety-related supplysource from the Train A 2-Hr Backup Supply Air Bottle Rack.Test Requirement:Exercise test to the open and closed positions in accordance with ISTC-351 0.JustificationIt is not practical to exercise open or fail open these valves during normal power operationsor during cold shutdowns. To exercise these valves requires the normal instrument airsupply to be isolated to the Emergency Feedwater and Main Steam valves actuators andpositioners thereby rendering them inoperable. The components supplied by the 2-HrBackup Air Bottles are required to be operable during normal operations and during coldshutdowns when the EF and MS systems are still required to be inservice. To perform thistesting quarterly would require major plant or hardware modifications (NUREG-1482,revision 1, section 2.4.5). This justifies deferral of testing to refueling outages.Alternative TestThese valves will be exercised and fail-safe tested open during refueling outages when theEF and MS systems are not required to be inservice and the 2-Hour backup air system isnot required.Revision 0October 25, 2013 All -12 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-09 -DELETEDValve NumberMU-V-79SystemMUSafety Class2CateaoryFunctionThis check valve has been classified as a passive valve based on upstream manual valveMU-V-78 being administratively maintained in the locked closed position and relied upon forisolation of the letdown/purification system. The valve has been determined to not performa safety function and has been removed from the IST Program.Revision 0October 25, 2013 All -13 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-10Valve Number System Safety Class CategoryMS-V-1A MS 2 B/CMS-V-1 B MS 2 B/CMS-V-iC MS 2 B/CMS-V-1D MS 2 B/CFunctionThese normally open motor operated stop check valves receive no automatic isolationsignal in order to allow for optimum RCS heat removal during most accidents and non-accident reactor trips. These valves are required to be closed from the Control Roomfollowing a large-break LOCA, Small-break LOCA, Main Steam line break, or SteamGenerator tube rupture, or if a loss of OTSG integrity results in Containment pressureabove OTSG pressure. In these cases, the valve would be closed by the motor operator,resulting in the Category B classification. These valves function as check valves in closingto prevent blowdown of both OTSG's in the event of a Main Steam line break upstream.Therefore, they are also classified as Category C.Although the open position is preferred under most accident and normal shutdownconditions and is required for Plant operation, the valves do not have any safety function inthe open position. These valves are considered Containment Isolation Valves; however,they are exempt from Type C testing since it is connected to a closed loop insidecontainment (OTSG).Test Requirement:Exercise test to the closed position in accordance with ISTC-3522.JustificationIt is not practical to exercise these valves closed with flow (category C function) duringnormal power operation or during cold shutdowns.Closing these valves for testing during normal power operations would interrupt steam flowfrom the steam generator to the main steam/turbine systems. Exercising these valvesclosed would isolate the steam generator which would result in a severe power transient inthe steam and reactor coolant systems which would lead to a subsequent trip of the plant.The closure test of the check valve function requires that one OTSG be depressurizedwhile pressure on the other is monitored. Effectively, the closed function is verified by adifferential pressure test to verify closure. This test can only be done during refuelingoutages when the steam generators may be isolated. To perform this testing quarterlywould create a condition with a high potential to cause a reactor trip (NUREG-1482,revision 1, section 2.4.5). This justifies deferral of testing to refueling outages.Revision 0October 25, 2013 All -14 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-10 (Cont.)Alternative TestThese valves will be exercised closed (Category C) during refueling outages when the mainsteam system is not required to be in operation. The open (Category C) check valvefunction is verified during normal operations with system flow.Revision 0October 25, 2013 All -15 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-11Valve Number. System Safety Class CategoryRR-V-9A RR 3 CRR-V-9B RR 3 CRR-V-9C RR 3 CFunctionThese check valves must open to provide a return flow path to the River from theEmergency RB Cooling Coil for post-accident cooling and pressure control of the ReactorBuilding.The valves close to prevent reverse flow through a faulted cooling coil, howeverdownstream motor operated valves RR-V-4A-D are relied upon for isolation of the coolingcoil. Therefore this closed function is not required for safe shutdown or accident mitigation.Test Requirement:Exercise test to the open position in accordance with ISTC-3522.JustificationIt is not practical to exercise these check valves open or closed during normal poweroperation or during cold shutdowns. Exercising the valves open requires the performanceof a full flow test to verify the open position. Exercising the valves closed requires aleakage or reverse flow test.Performance of a full flow test through these valves requires the RBEC pump to introduceriver water into the Reactor Building Emergency Cooling Coils. Since river water containssilt and microorganisms, the system must be drained to the Reactor Building sump andrefilled with Nuclear Services Closed Cooling Water. Approximately 5,000 gallons of watermust be processed through the Liquid Waste Disposal System. This is not practical for aquarterly or cold shutdown frequency. Additionally, test performance will discharge aquantity of corrosion inhibitor to the river, an environmental release that should beminimized.To perform a leakage test or reverse flow test to verify closure during normal operations orduring cold shutdown, requires temporary test equipment to be setup to establish adifferential pressure across the valve to verify closure. This test is not practical to beperformed during normal power operations or during cold shutdowns since the RBEmergency Cooling Water system would be required to be vented and out of service.Additionally, the necessary test setup, performance and restoration could cause anincrease in personnel radiation exposure and delay startup from a cold shutdown condition.To perform this testing quarterly would require major plant or hardware modifications(NUREG-1482, revision 1, section 2.4.5). This justifies deferral of testing to refuelingoutages.Revision 0October 25, 2013 All -16 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-11 (Cont.)Alternative TestThese check valves will be exercised open and verified to close (bi-directional test) duringrefueling outages when full forward and reverse flow testing can be performed and thereactor building emergency cooling coils are not required to be in service.Revision 0October.25, 2013 All -17 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-12Valve Number System Safety Class CategoryMU-V-112 MU 2 A/CFunctionThis check valve is required to close to prevent pumping post-accident liquid from the RBSump into the Makeup Tank when operating the DH and MU Systems in the "piggyback"mode. This valve is located in the outlet line of Makeup Tank MU-T-1 and forms aboundary. between the portion of the MU System which is required for safeshutdown/accident mitigation and the non-safety related makeup tank.This valve opens to allow makeup flow from Makeup Tank MU-T-1 to the suction of theoperating Makeup Pump (normally MU-P-1B) during normal operation. It also opens toallow flow from Makeup Tank MU-T-1 to the suction of the operating Makeup Pump tosupport alternate emergency boration requirements. Downstream motor-operated isolationvalve, MU-V12, does not receive any signal to close in the event of an accident.Test Requirement:Exercise test to the closed position in accordance with ISTC-3522.JustificationIt is not practical to exercise this valve closed during normal power operation or during coldshutdowns. Exercising the valve requires the performance of a leakage or reverse flow testto verify the closed position.To perform a leakage test or reverse flow test to verify closure during normal operations orcold shutdowns, requires temporary test equipment to be installed to establish a differential,pressure across the valve to verify closure. This test is not practical to be performed duringnormal power operations or during cold shutdowns since the MU system and DH systemwould be required to be vented and out of service to perform a leakage test. To perform areverse flow test using the DH system to pressurize the valve would require removing boththe MU and DH system from service. Removing both systems is not practical duringnormal power operations or during cold shutdown conditions. To perform this testingquarterly would require major plant or hardware modifications (NUREG-1482, revision 1,section 2.4.5). This justifies deferral of testing to refueling outages.Alternative TestThis valve will be exercised closed during refueling outages when the MU and DH systemsare not required to be in service. The open direction is verified using normal system flowduring normal power operations.Revision 0October 25, 2013 All -18 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-13.Valve Number -System Safety Class CategoryMU-V-14A MU 2 A/CMU-V-14B MU 2 A/CFunctionThese motor operated stop check valves are required to open on an ESAS actuation signalof 1600 psig RCS pressure or 4 psig Reactor Building pressure to provide suction from theBWST to the MU Pumps for HPI initiation. An ESAS backup initiation signal is alsoprovided at 500 psig RCS pressure.The valves are required to close following the post-LOCA injection phase to isolate theBWST during the recirculation phase. In the "piggyback" mode, this is the only valve thatseparates the BWST from the discharge of the DH Pumps.Test Requirement:Exercise test to the open and closed positions in accordance with ISTC-3522.JustificationIt is not practical to exercise these valves open or closed during normal power operation orduring cold shutdowns. Exercising the valves requires the performance of a leakage orreverse flow test to verify the closed position and full flow test to verify the open position.To perform a leakage test or reverse flow test to verify closure during normal operations orcold shutdowns, requires temporary test equipment to be installed to establish a differentialpressure across the valve to verify closure. This test is not practical to be performed duringnormal power operations or during cold shutdowns since the test lineup requires isolation ofthe Makeup Tank and observation of level decrease over time. This procedure cansignificantly lengthen an unplanned Cold Shutdown. To verify the full open position, a fullflow test using the BWST as a suction source is required. Injection of highly borated waterfrom the BWST into the reactor coolant system is not practical during normal operations orduring cold shutdown due the significant effect it will have on reactivity and RCS inventorycontrol. Additionally, performance of this full flow test may lengthen the time to reachcriticality. The delay would occur because the boron concentration would. need to bediluted by water from a Reactor Coolant Bleed Tank. To perform this testing quarterlywould require major plant or hardware modifications (NUREG-1482, revision 1, section2.4.5). This justifies deferral of testing to refueling outages.Revision 0October 25, 2013 All -19 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-13 (Cont.1Alternative TestThese valves will be exercised closed during refueling outages in conjunction with therespective leakage test when the MU system is not required to be in service. The valveswill be exercised open during refueling outages with flow by injecting BWST water into thereactor coolant system.Revision 0October 25, 2013 All -20 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-14Valve Number System Safety Class CatenorvRR-V-8A RR 3 CRR-V-8B RR 3 CFunctionThese check valves must open to provide flow from the RBEC Pumps to the ReactorBuilding Emergency Cooling Coils for post-accident cooling and pressure control. Thevalves may also be required to open to provide a safety-related, seismically-qualifiedbackup suction source to the Emergency Feedwater Pumps.These valves are required to close to prevent diversion of flow in the event of a failure ofthe RBEC Pump to start or continue running or in the event of an upstream pipe break.Test Requirement:Exercise test to the open position in accordance with ISTC-3522.JustificationIt is not practical to exercise these check valves open during normal power operation orduring cold shutdowns. Exercising the valves open requires the performance of a full flowtest to verify the open position.Performance of a full flow test through these valves requires the RBEC pump to introduceriver water into the Reactor Building Emergency Cooling Coils. Since river water containssilt and microorganisms, the system must be drained to the Reactor Building sump andrefilled with Nuclear Services Closed Cooling Water. Approximately 5,000 gallons of watermust be processed through the Liquid Waste Disposal System. This is not practical for aquarterly or cold shutdown frequency. Additionally, test performance will discharge aquantity of corrosion inhibitor to the river, an environmental release that should beminimized. To perform this testing quarterly would require major plant or hardwaremodifications (NUREG-1482, revision 1, section 2.4.5). This justifies deferral of testing torefueling outages.Alternative TestThese check valves will be exercised open during refueling outages when full flow testingcan be performed and the reactor building emergency cooling coils are not required to be inservice. The closure test is performed quarterly using reverse flow from the NuclearServices Closed Cooling Water system.Revision 0October 25, 2013 All -21 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-15Valve Number System Safety Class CategoryMU-V-73A MU 2 CMU-V-73B MU 2 CMU-V-73C MU 2 CFunctionIn the open position, these check valves allow required HPI flow to be supplied by theMakeup Pumps to the Reactor Coolant System (RCS) in response to an ESAS initiation at1600 psig RCS pressure or 4 psig Reactor Building pressure, or by a backup signal at 500psig RCS pressure.In the closed position, the valves prevent diversion of flow by recirculation through thepump in the event that the pump fails to start or is secured by the operator during the laterstages of the accident or for post-accident recirculation (i.e., "piggyback") operation.Test Requirement:Exercise test to the open and closed positions in accordance with ISTC-3522.JustificationIt is not practical to exercise these check valves open during normal power operation orduring cold shutdowns. Exercising. the valves open requires the performance of a full flowtest to verify the open position.Full flow testing of these valves requires injection into the RCS. During normal poweroperations or during cold shutdowns the injection flow into the RCS is limited to avoidpressure transients in the RCS. Attaining full flow requires that additional injection valvesbe opened. Tech Spec 3.1.12.3 will not permit opening of the injection valves (MU-V16A,B, C, D) when RCS temperature is below 275 degrees F with the Reactor Head in place.This means testing at Cold Shutdown is not possible and that the test must be performedas the plant shuts down or restarts. To perform this testing quarterly would require majorplant or hardware modifications (NUREG-1482, revision 1, section 2.4.5). This justifiesdeferral of testing to refueling outages.Due to the design of the MU pumps (9 stage high pressure centrifugal), positive verificationof closure of the discharge check valves cannot be ascertained during quarterly testing ofthe pumps on minimum recirculation flow.Alternative TestThese check valves will be exercised open and closed during refueling outages wheninjection to the reactor coolant system is possible and the system alignment allows forpositive verification that the valves are exercised closed by reverse flow.Revision 0October 25, 2013 All -22 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-16 -DELETEDValve NumberNR-V-20ANR-V-20BNR-V-20CSystemNRNRNRSafety Class333CateaorvCCCDeleted this justification after revising the quarterly testing in 2008 to use a flow thatsatisfies design basis requirements.Revision 0October 25, 2013All -23 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-17 -DELETEDValve NumberRC-V-2SystemRCSafety Class1.Categiory.BThis Refueling Outage Justification has been determined to not be necessary and has beendeleted.Revision 0October 25, 2013 All -24 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-18Valve Number System Safety Class CategoryRR-V-7A RR 3 CRR-V-7B RR 3 CFunctionThese check valves must open to provide a flow path from the RBEC Pumps to the ReactorBuilding Emergency Cooling Coils for post-accident cooling and pressure control. Thevalves may also be required to open to provide a safety-related, seismically-qualifiedbackup suction source to the Emergency Feedwater Pumps.These valves close to prevent reverse flow through a faulted or idle RBEC pump, however,downstream valves RR-V-8A/B and RR-V-lA/B are relied upon for this function. Thereforethe closed function is not required for safe shutdown or accident mitigation.Test Requirement:Exercise test to the open position in accordance with ISTC-3522.JustificationIt is not practical to exercise these check valves open during normal power operation orduring cold shutdowns. Exercising the valves open requires the performance of a full flowtest to verify the open position.Performance of a full flow test through these valves requires the RBEC pump to introduceriver water into the Reactor Building Emergency Cooling Coils. Since river water containssilt and microorganisms, the system must be drained to the Reactor Building sump andrefilled with Nuclear Services Closed Cooling Water. Approximately 5,000 gallons of watermust be processed through the Liquid Waste Disposal System. This is not practical for aquarterly or cold shutdown frequency. Additionally, test performance will discharge aquantity of corrosion inhibitor to the river, an environmental release that should beminimized. To perform this testing quarterly would place undue stress on components andcause unnecessary cycling of equipment (NUREG-1482, revision 1, section 2.4.5). Thisjustifies deferral of testing to refueling outages.Alternative TestThese check valves will be exercised open during refueling outages when full flow testingcan be performed and the reactor building emergency cooling coils are not required to be inservice. Bi-directional closure testing is performed each refueling using non-intrusiveequipment (ultrasonic instrumentation) to verify water in the piping on the downstream sideof the valve.Revision 0October 25, 2013 All -25 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-19 -DELETEDValve NumberRC-RV-2SystemRCSafety Class1Category.B/CThis Refueling Outage Justification has been determined to not be necessary and has beendeleted.Revision 0October 25, 2013 All -26 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-20Valve Number System Safety Class CategoryDH-V-14A DH 2 A/CDH-V-14B DH 2 A/CFunctionThese check valves open to permit the Decay Heat Removal Pumps to take suction fromthe BWST.The valves are required to close to prevent potential flow from the Reactor Building Sumpinto the BWST in the event that DH-V 005A/B fail to close following an accident while theReactor Building is under pressure.Test Requirement:Exercise test to the open and closed positions in accordance with ISTC-3522.JustificationIt is not practical to exercise these valves during normal power operations or cold shutdownwhen DH system is required to be in service.To exercise the valves open requires full flow injection from the BWST into the reactorcoolant system. This test is not practical to perform during plant operation or during coldshutdown since full flow injection of borated water into the reactor coolant system wouldresult in severe reactor power oscillations and subsequent reactor trip during plantoperations. During cold shutdown, this test would result in delaying unit startup due to theamount time necessary to clean up the DH and RC systems along with refilling the BWST.To exercise the valve closed would require a leakage test. This test would require one trainof DH suction piping to be isolated and vented. The test would render the associated trainof the DH system inoperable during plant operations and during cold shutdown periods. Toperform this testing quarterly would require major plant or hardware modifications (NUREG-1482, revision 1, section 2.4.5). This justifies deferral of testing to refueling outages.Alternative TestThese valves will be exercised open and closed during refueling outages when the DH andRC systems are not required to be inservice to allow for full flow injection and leakagetesting of the subject valves.Revision 0October 25, 2013 All -27 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-21Valve Number System Safety Class CategoryDH-V-6A DH 2 BDH-V-6B DH 2 BFunctionThese valves must be capable of closure to provide long term Containment isolationfollowing an accident. However, since the Decay Heat Removal (DH) System is filled withwater and is a closed system outside Containment, it is very improbable that leakage wouldoccur through these valves. Furthermore, the valves will be opened and may remain openindefinitely following an accident. The valves are exempt from Type C leakage testingsince they are in penetrations which are continuously submerged in water during accidentconditions (water-sealed).The valves must be opened to shift suction of the DH Pumps from the BWST to theReactor Building Sump when the BWST inventory is depleted following a LOCA in order toinitiate the post-LOCA recirculation mode. The valves are closed by remote manualoperation.Test Requirement:Exercise test to the open and closed positions in accordance with ISTC-3510.JustificationIt is not practical to exercise these valves during normal power operations or coldshutdown.,Exercising these valves. would require. blanking the reactor building ECCS sump suctionpiping and would render the associated DH and Building Spray trains inoperable. Thistesting would require containment entry to install blank flanges on the DH system suctionpiping to perform the necessary testing. This would render the DH and BS systemsinoperable during normal operations and potentially delay unit startup from a cold shutdownto perform the necessary blank installation and removal.. To perform this testing quarterlywould require major plant or hardware modifications (NUREG-1482, revision 1, section2.4.5). This justifies deferral of testing to refueling outages.Alternative TestThese valves will be exercised open and closed during refueling outages when the DH andRC systems are not required. to be inservice and the reactor building sump level is suchthat radioactive fluid is not introduced into the DH system suction piping.Revision 0October 25, 2013 All -28 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION R.J-22Valve Number System Safety Class CategoryDH-V-170 DH 2 CDH-V-171 DH 2 CDH-V-172 DH 2 CFunctionThese check valves must open to allow pressure between the seats and portions of pipingof certain valves to equalize with downstream (RCS) pressure in order to prevent pressure-locking of the boundary valves allowing them to be opened when required.The valves close to prevent back flow of RCS fluid into the area between the seats andportions of piping to prevent pressure-locking of the respective valves. However, the abilityof the check valves to close is not required to achieve or maintain safe shutdown or foraccident mitigation.Test Requirement:Exercise test to the open and closed positions in accordance with ISTC-3522.JustificationIt is not practical to exercise these valves open or closed during normal power operationsor cold shutdown.Exercising these valves closed. requires venting of reactor coolant system fluid to performbackflow testing to verify closure capability of the subject check valves. This test isessentially a leakage rate test which would require. isolating and venting of the associatedportions of the reactor coolant system.. Additionally, increased personnel radiationexposure would be realized due to the location of these valves inside the reactor building.The full flow open test of these check valves is also not practical to perform during normalpower operations due to the need to partially open the associated main process lineisolation valve. Opening either of these valves (DH-V-1, DH-V-2) during normal poweroperation could cause over pressurization of the lower pressure DH system. To performthis testing quarterly would require major plant or hardware modifications (NUREG-1482,revision 1, section 2.4.5). This justifies deferral of testing to refueling outages.Alternative TestThese valves will be exercised open and verified to close during refueling outages whenthe DH and RC systems are not required to be inservice. As permitted by ASME OM CodeISTC-3522(a) both the open and. closed check valve exercise tests will be performed duringrefueling outages when it is practicable to perform both tests.Revision 0October 25, 2013 All -29 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-23Valve Number System Safety Class CategoryRC-V-23 RC 1 A/CFunctionThis check valve opens on initiation of flow from the DH System to allow circulation of waterthrough the auxiliary spray line to prevent the concentration of boron in the Core fromexceeding its solubility limit. The auxiliary spray system cannot be placed in service untilthe reactor coolant system is below 200 psig. Auxiliary spray is an alternate method to DHdrop-line flow to prevent boron precipitation post-LOCA. It is a backup to the drop legmethod, which is not single-failure proof.In the closed position, this valve is one of two valves in series that isolate the RCS from thelower design pressure Decay Heat Removal System. This valve would remain closed aslong as RCS pressure is higher than DH System pressure or would close for any conditionwhich caused flow to reverse. The valve is a Reactor Coolant Pressure Boundary (RCPB)Pressure Isolation Valve (PIV).Test Requirement:Exercise test to the open and closed positions in accordance with ISTC-3522.JustificationIt is not practical to full stroke exercise this valve open or closed during normal poweroperation since injection in to the RCS through this line is not possible with the RCSpressurized. The Decay Heat discharge pressure is approximately 200 psig while thenormal RCS pressure is greater than 2100 psig. The closure test of this check valve isperformed by using a back flow leakage test to verify disk closure. This test requires entryin to the reactor building to perform the necessary test setup and restoration. It is notpractical to perform this leakage test during normal power operations or during coldshutdowns. Entry in to the reactor building is not possible during normal power operationsdue to the elevated dose. Performance of a leakage test during cold shutdowns is notpractical since a significant amount of piping would be required to be vented along with anincrease to personnel radiation exposure. To perform this testing quarterly would requiremajor plant or hardware modifications (NUREG-1482, revision 1, section 2.4.5). Thisjustifies deferral of testing to refueling outages.Alternative TestThis valve will be exercised open and closed during refueling outages when the reactorcoolant system is depressurized and radiation levels are reduced.Revision 0October 25, 2013 All -30 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-24Valve Number System Safety Class CatenoryDH-V-50 DH 2 A/CFunctionClosure of this valve is important to ECCS bypass leakage. This valve is a potentialleakage path from the reactor building sump or associated system when contaminatedwater is circulated following a LOCA [C-1101-210-E270-014].This valve closes to prevent diversion of flow from the Decay Heat Removal Pump DH-P-1A suction in the event of a loss of upstream piping, however, upstream manual isolationvalve, SF-V-44 is maintained closed and is also classified as Seismic Class I. Additionally,the cleanup supply line from the spent fuel pool is maintained closed during normal poweroperations.This valve opens to provide a flow path from the spent fuel pool cleanup system to thesuction of the decay heat removal pump. This function is not required for safe shutdown oraccident mitigation.Test Requirement:Exercise test to the closed position in accordance with ISTC-3522.JustificationIt is not practical to full stroke exercise this valve open or closed during normal poweroperation or during cold shutdowns. An open exercise requires the spent fuel pool cleanupline to be opened and flow established from the spent fuel pool to the suction of the DHpumps. This evolution can only be performed during refueling outages when the DHsystem is in cleanup mode. The closure test of this valve requires pressurization of the DHsuction piping. This test can not be performed during normal power operations withoutrendering the DH system inoperable. To perform this testing quarterly would require major.plant or hardware modifications (NUREG-1482, revision 1, section 2.4.5). This justifiesdeferral of testing to refueling outages.Alternative TestThis valve will be exercised open (bi-directional test) and closed during refueling outageswhen the DH system can be lined up for spent fuel pool cooling. As permitted by ASMEOM Code ISTC-3522(a) both the open and closed check valve tests will be performedduring refueling outages when it is practicable to perform both tests.Revision 0October 25, 2013 All -31 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-25Valve Number System Safety Class CategoryCO-V-25A CO 3 CCO-V-25B CO 3 CFunctionThese check valves must close to prevent backflow from the associated condensatestorage tank to the non-safety related de-icing piping in the event that a pipe or alternatecondensate storage tank rupture occurs. This function ensures that the contents of therespective condensate storage tank will be available to the suction of the EFW pumps.The valve opens when the system is in the de-ice mode to provide a warm water flow pathfrom the suction of the condensate booster pumps to the condensate storage tank. Thisfunction is not required for safe shutdown or accident mitigation since the condensate andde-icing piping is non-safety related.Test Requirement:Exercise test to the closed position in accordance with ISTC-3522.JustificationIt is not practical to full stroke exercise these valves closed during normal power operation.The de-icing line manual valves from the condensate booster pumps (CO-V-26A/B) arethrottled during de-icing operations, and they also are not completely leak-tight when di-icing is secured. As such, they do not provide a zero leakage boundary from thecondensate booster pump suction pressure. During refueling outages with the condensatesystem out of service, the closed safety function of CO-V-25A/B can be verified by a backleakage test. To perform this testing every quarter would require major plant or hardwaremodifications (NUREG-1482, revision 1, section 2.4.5). This justifies deferral of testing torefueling outages.Alternative TestThese valves will be exercised closed during refueling outages using the head of thecondensate storage tanks. As permitted by ASME OM Code ISTC-3522(a) both the closedand non-safety (bi-directional) open check valve tests will be performed during refuelingoutages when it is practicable to perform both tests.Revision 0October 25, 2013 All -32 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-26 -DELETEDValve NumberNR-V-19SystemNRSafety Class3Cateplory.BThis Refueling Outage Justification has been determined to not be necessary and has beendeleted.Revision 0October 25, 2013 All -33 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11REFUELING OUTAGE JUSTIFICATION RJ-27Valve Number System Safety Class CategorvMU-V-i 93A MU 2 CMU-V-i 93B MU 2 CMU-V-193C MU 2 CFunctionThese check valves must open to allow recirculation of flow from the discharge of themakeup and purification pumps during low system flow conditions through the Seal ReturnCoolers and back to the Makeup (MU) Tank in order to prevent overheating and potentialdamage to the pumps.The valves close to ensure full MU Pump discharge flow is directed to the RCS for accidentmitigation on HPI initiation by preventing diversion of flow back through the makeup andpurification pumps in the event that a pump failed to start.Test Requirement:Exercise test to the open and closed positions in accordance with ISTC-3522.JustificationIt is not practical to full stroke exercise these check valves open during normal poweroperation or during cold shutdowns. The Makeup pump minimum flow lines are notinstrumented to allow flow measurement during quarterly testing.Check valve closure verification requires isolation of the pump suction, Due to the designof the MU pumps (9 stage high pressure centrifugal), positive verification of closure of theminimum flow line check valves (and discharge check valves) cannot be ascertained duringquarterly testing of the pumps on minimum recirculation flow.Alternative TestThese check valves will be exercised open and closed during refueling outages wheninjection to the reactor coolant system is possible (full forward flow testing can beperformed) and system alignment will allow the pump suctions to be isolated for positiveverification that the valves are exercised closed by reverse flow. These valves are partialstroked open during pump testing quarterly.Revision 0October 25, 2013 All -34 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 11ATTACHMENT 11REFUELINGOUTAGE JUSTIFICATION RJ-28Valve NumberRC-V-144ARC-V-144BRC-V-144CRC-V-144DRC-V-144ERC-V-144FRC-V-144GRC-V-144HSystemRCRCRCRCRCRCRCRCSafety Class11111111CategorvCCCCCCCCFunctionThe RC-V-144 series internals vent valves have an open safety function to ensureadequate core cooling in the event of a reactor coolant cold leg piping LOCA. The normallyclosed position is passive and not a safety function.The RC-V-144 series valves consist of eight 14 inch inside diameter vent valve assembliesinstalled in the cylindrical wall of the reactor internals core support shield. The internalsvent valves are normally closed check valves with a safety function to open, in the event ofa pipe rupture in the reactor coolant cold leg piping, to permit steam generated in the coreto flow directly to the leak. This will permit the core to be rapidly recovered and adequatelycooled after emergency core coolant has been supplied to the reactor vessel.Test Requirement:Exercise test to the open position in accordance with ISTC-3522.JustificationIt is not practical to exercise these valves open during normal power operation or duringcold shutdowns since these valves are located inside the reactor vessel. Exercising thevalves open requires removing the reactor vessel head and the upper plenum assembly toallow access to the valves. This is only practical during refueling outages.Alternative TestThe check valves will be exercised open during refueling outages when the reactor vesselhead and the upper plenum assembly can be removed to allow access to the valves.Revision 0October 25, 2013 All -35 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 12TECHNICAL POSITION INDEXRevision 0October 25, 2013A12- 1 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 12TECHNICAL POSITION INDEXTechnical PositionNumberCTP-IST-001CTP-IST-002CTP-IST-003CTP-IST-004CTP-IST-005CTP-IST-006CTP-IST-007CTP-IST-008CTP-IST-009CTP-IST-010CTP-IST-01 1CTP-IST-012CTP-IST-013CTP-IST-014RevisionTitle/DescriptionPreconditioning of IST Program ComponentsQuarterly Pump Testing Under Full-Flow ConditionsQuarterly Testing of Group B PumpsClassification of Pumps: Centrifugal vs. Vertical LineShaftPreservice Testing of PumpsClassification and Testing of Class 1 Safety/Relief ValvesWith Auxiliary Actuating DevicesSkid-Mounted ComponentsPosition Verification TestingASME Class 2 & 3 Relief Valve Testing RequirementsERV and PORV Testing RequirementsExtension of Exercise Testing Frequencies to ColdShutdown or Refueling OutageUse of ASME OM Code Cases for Inservice TestingExercise Testing Requirements for Valves with Fail-SafeActuatorsBi-directional Testing of Check Valves to Their Safetyand Non-Safety Related PositionsRevision 0October 25, 2013A12 -2 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 13TECHNICAL POSITIONSRevision 0October 25, 2013A13- 1 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 13Number: CTP-IST-001, Rev. 1Title: Preconditioning of IST Program ComponentsApplicability: All Exelon IST Programs. This issue also applies to other Technical Specificationsurveillance testing where preconditioning may affect the results of the test. ThisTechnical Position may be adopted optionally by other Exelon organizations.
 
==Background:==
There are no specified ASME Code requirements regarding preconditioning or thenecessity to perform as-found testing, with the exception of setpoint testing ofrelief valves and MOV testing performed in accordance with Code Case OMN-1 orMandatory Appendix Ill. Nevertheless, there has been significant concern raisedby the NRC, and documented in numerous publications, over this issue. Section3.5 of Reference 2 provides guidance on preconditioning as it relates to IST;Section 3.6 provides additional guidance on as-found testing. It is the intent ofthis Technical Position to provide a unified, consistent approach to the issue ofpreconditioning as it applies to IST Programs throughout the Exelon fleet.The purpose of IST is to confirm the operational readiness of pumps and valveswithin the scope of the IST Program to perform their intended safety functionswhenever called upon. This is generally accomplished by testing usingquantifiable parameters which provide an indication of degradation in theperformance of the component. Preconditioning can diminish or eradicate theability to obtain any meaningful measurement of component degradation, thusdefeating the purpose of the testing.Preconditioning is defined as the alteration, variation, manipulation, or adjustmentof the physical condition of a system, structure, or component before TechnicalSpecification surveillance or ASME Code testing. Since IST is a component-levelprogram, 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 necessaryfor the protection of personnel or equipment, which has been evaluated ashaving insufficient impact to invalidate the results of the surveillance test, orwhich provides performance data or information which is equivalent orsuperior to that which would be provided by the surveillance test.* Unacceptable preconditioning is preconditioning that could potentially maskdegradation of a component and allow it to be returned to or remain in servicein a degraded condition.In most cases, the best means to eliminate preconditioning concerns is to performtesting in the as-found condition. When this is not practical, an evaluation mustbe performed to determine if the preconditioning is acceptable. Appendix 1 to thisTechnical Position may be used to document this evaluation.The acceptability or unacceptability of preconditioning must be evaluated on acase-by-case basis due to the extensive variability in component design,operation, and performance requirements. Preconditioning of pumps may includefilling and venting of pump casings, venting of discharge piping, speedadjustments, lubrication, adjustment of seals or packing, etc. Preconditioning ofRevision 0October 25, 2013 A13 -2 Three Mile Island Unit #1Inservice Testing Program Planvalves 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 includecomponent size and type, actuator or driver type, design requirements, requiredsafety functions, safety significance, the nature, benefit, and consequences of thepreconditioning activity, the frequencies of the test and preconditioning activities,applicable service and environmental conditions, previous performance data andtrends, etc.Lubrication of a valve stem provides an example of the variability of whether ornot a preconditioning activity is acceptable. For example, lubrication of the valvestem of an AC-powered MOV during refueling outages for a valve that is exercisetested quarterly would normally be considered acceptable, unless service orenvironmental conditions could cause accelerated degradation of its performance.Lubrication of a valve stem each refueling outage for an MOV that is exercisetested on a refueling outage frequency may be unacceptable if the lubrication isalways performed prior to the exercise test. Lubrication of a valve stem for anAOV prior to exercise testing is likely to be unacceptable, unless it can bedocumented that the preconditioning (i.e., maintenance or diagnostic testing) canprovide equal or better information regarding the as-found condition of the valve.Manipulation of a check valve or a vacuum breaker that uses a mechanicalexerciser to measure breakaway force prior to surveillance testing would beunacceptable preconditioning. Additional information regarding preconditioning ofMOVs may be found in Reference 4.Position:1. Preconditioning SHALL be avoided unless an evaluation has been performedto determine that the preconditioning is acceptable. Appendix 1 to thisTechnical Position may be used to document this evaluation. In cases wherethe same information applies to more than one component, a singleacceptability evaluation may be performed and documented.2. Evaluations SHALL be prepared, reviewed and approved by persons with theappropriate level of knowledge and responsibility. For example, personspreparing an evaluation should hold a current certification in the area relatedto the activity. Reviewers should be certified in a related area.3. The evaluation SHALL be approved by a Manager or designee.4. If it is determined that an instance of preconditioning has occurred withoutprior evaluation, the evaluation SHALL be performed as soon as practicablefollowing discovery. If the evaluation concludes that the preconditioning isunacceptable, an IR shall be written to evaluate the condition and identifycorrective actions.Revision 0October 25, 2013 A13 -3 Three Mile Island Unit #1Inservice Testing Program Plan
 
==References:==
: 1. NRC Information Notice 97-16, "Preconditioning of Plant Structures, Systems, andComponents before ASME Code Inservice Testing or Technical Specification SurveillanceTesting".2. NUREG-1482, Revision 1 (January, 2005), Section 3.5 "Pre-Conditioning of Pumps andValves".3. NRC Inspection Manual Part 9900: Technical Guidance, "Maintenance -Preconditioning ofStructures, Systems and Components Before Determining Operability".4. ER-AA-302-1006, "Generic Letter 96-05 Program Motor-Operated Valve Maintenance andTesting Guidelines"5. ER-AA-321, "Administrative Requirements for Inservice Testing"Revision 0October 25, 2013 A13 -4 Three Mile Island Unit #1Inservice Testing Program PlanCTP-IST-001 APPENDIX 1EVALUATION OF PRECONDITIONING ACCEPTABILITYDescription of activity:Secion1: RC n~secton anual-Part.9006 Review:Answer the following questions to determine the acceptability of the preconditioning activity based on Section D.2 ofReference 3.Question Yes No Not Determined1. Does the alteration, variation, manipulation or adjustment ensure that the Elcomponent will meet the surveillance test acceptance criteria?2. Would the component have failed the surveillance without the alteration, variation, 0 E0manipulation or adjustment?3. Does the practice bypass or mask the as-found condition? 0 El4. Is the alteration, variation, manipulation or adjustment routinely performed justbefore the testing?5. Is the alteration, variation, manipulation or adjustment performed only for schedulingconvenience?If all the answers to Questions I thru 5 are No, the activity is acceptable; go to Section 3.Otherwise, continue to Section 2.Section 2::AdditionaliEValuationThe following questions may be used to determine if preconditioning activities that do not meet the screening criteria ofSection 1 are acceptableQuestion Yes No6. Is the alteration, variation, manipulation or adjustment required to prevent personnel injury or Eequipment damage? If yes, explain below.7. Does the alteration, variation, manipulation or adjustment provide performance data orinformation that is equivalent or superior to that provided by the surveillance test? If yes, explainbelow.8. Is the alteration, variation, manipulation or adjustment being performed to repair, replace, inspector test an SSC that is inoperable or is otherwise Unable to meet the surveillance test acceptancecriteria? If yes, explain below.9. Is there other justification to support classification of the alteration, variation, manipulation oradjustment as acceptable preconditioning? If yes, explain below and provide references.Explanation / Details: (attach additional sheets as necessary)Conclusion: The preconditioning evaluated herein (is / is not) acceptable. (Circle one)Section 3"Review i-Approve::Prepared by: Date:Reviewed by: Date:Approved by: Date:Revision 0October 25, 2013A13- 5 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 13Number: CTP-IST-002, Rev. ITitle: Quarterly Pump Testing Under Full Flow ConditionsApplicability: ASME OM-1995 Code and Later, Subsection ISTB
 
==Background:==
Pumps included in the scope of the IST Program are classified as Group A orGroup B. The OM Code defines a Group A pump as a pump that is operatedcontinuously or routinely during normal operation, cold shutdown, or refuelingoperations. A Group B pump is defined as a pump in a standby system that is notoperated 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 Atest procedure is intended to satisfy quarterly testing requirements for Group Apumps, a. Group. B test procedure is intended to satisfy quarterly testingrequirements for Group B pumps and a comprehensive test procedure is requiredto be performed on a frequency of once every two years for all Group A andGroup B pumps. The Code states that when a Group A test is required acomprehensive test may be substituted; when a Group B test is required acomprehensive test or a Group A test may be substituted. A preservice test maybe substituted for any inservice test. The Corporate Exelon position on preservicetesting 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 andreciprocating positive displacement pumps, for Group A, Group B and.comprehensive pump tests. In each case, the acceptance bands for flow anddifferential or discharge pressure for the comprehensive test are narrower thanthose 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 ofcomprehensive tests is once every two years, most stations have a limited historyof comprehensive pump test performance. Thus, pumps. that have demonstratedsatisfactory results during quarterly testing over a period of several years may faila 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 pumpthat is operated routinely for any purpose, except for the performance ofinservice testing, is a Group A pump. A pump cannot be classified as Group Afor certain modes of operation and Group B for other modes of operation (e.g.,pumps used for shutdown cooling are Group A pumps), unless authorized bymeans of an NRC-approved Relief Request.2. Under certain circumstances, similar or redundant pumps may be classifieddifferently. For example, if a station has four identical RHR pumps with twoused for shutdown cooling and two dedicated to ECCS service, the shutdowncooling pumps would be Group A, whereas the dedicated ECCS pumps wouldbe Group B provided they were maintained in standby except whenperforming inservice testing.Revision 0October 25, 2013 A13 -6 Three Mile Island Unit #1Inservice Testing Program Plan3. Quarterly testing of Group A pumps shall be performed in accordance with aGroup A or comprehensive test procedure. Post-maintenance testing ofGroup A pumps shall be performed in accordance with a Group A, acomprehensive, or a preservice test procedure.4. Quarterly testing of Group B pumps shall be performed in accordance with aGroup B, Group A, or comprehensive test procedure. Post-maintenancetesting of Group B pumps shall be performed in accordance with a Group A, acomprehensive, or a preservice test procedure.5. Credit can only be taken for a comprehensive test if all of the OM Coderequirements for a comprehensive test are met, including flow, instrumentrange and accuracy, and acceptance limits.Regardless of test conditions, quarterly pump testing. is required to meet theacceptance criteria specified for Group A or Group B pumps, as applicable, in theedition/addenda of the OM Code in effect at the Plant. More restrictiveacceptance criteria may be applied optionally if desired to improve trending oradministrative control.The ASME OM Code has identified quarterly and comprehensive pump testing asdistinctly separate tests with separate frequency and instrumentationrequirements and separate acceptance criteria. When performing a quarterly(Group A or Group B) test under full flow conditions, it may be apparent that acomprehensive test limit was exceeded. In such cases, ISSUE an IR to describeand evaluate the condition and potential compensatory measures (e.g.,establishing new reference values) prior to the next scheduled comprehensivetest. No additional corrective actions are required.
 
==References:==
: 1. ASME OM Code, Code for Operation and Maintenance of Nuclear Power Plants, 1995 Editionand later, Subsection ISTB.Revision 0October 25, 2013 A13 -7 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 13Number: CTP-IST-003, Rev. 0Title: Quarterly Testing of Group B PumpsApplicability: ASME OM-1995 Code and Later
 
==Background:==
Pumps included in IST Programs that must comply with the 1995 Edition of theASME OM Code and later are required to be classified as either Group A orGroup B pumps. The OM Code defines a Group A pump as a pump that isoperated continuously or routinely during normal operation, cold shutdown, orrefueling operations. A Group B pump is defined as a pump in a standby systemthat 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 testprocedure is intended to satisfy quarterly testing requirements for a Group Apump, a Group B test procedure is intended to satisfy quarterly testingrequirements for a Group B pump, and a comprehensive test procedure isrequired to be performed on a frequency of once every two years for all Group Aand Group B pumps. A Group A test procedure may be substituted for a Group Bprocedure and a comprehensive or preservice test procedure may be substitutedfor a Group A or a Group B procedure at any time.A Group A test procedure is essentially identical to the quarterly pump test thatwas performed in accordance with OM-6 and earlier Code requirements. Group Btesting 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 theGroup B test was to provide assurance that safety related-pumps that sit idleessentially all of the time (e.g. ECCS pumps) would be able to start on demandand achieve a pre-established reference condition. The requirements for Group Btesting were significantly relaxed when compared with the Group A (traditional)pump test requirements based on the assumption that there were no mechanismsor conditions that would result in pump degradation while the pump sat idle.Strong differences of opinion regarding the intent and requirements for Group Btesting developed and have persisted since the beginning. These differencesspan the industry, the NRC, and even members of the OM Code Subgroup-ISTBwho 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 orpressure, and then stopped. The opposing opinion is that the Group B testrequires the pump to be brought to the reference flow or pressure followed byrecording and evaluation of both the flow and pressure readings. Both opinionscan be supported by the applicable OM Code verbiage. However, NRC personnelhave 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 beRevision 0October 25, 2013 A13-8 Three Mile Island Unit #1Inservice Testing Program Planmeasured and evaluated in accordance with the applicable Coderequirements for the pump type.2. Vibration measurements are not required for Group B pump tests. Vibrationmeasurements may continue to be taken optionally. In the event that avibration reading exceeds an alert or required action limit for thecomprehensive test for the pump being tested, an IR shall be written andcorrective action taken in accordance with the CAP process.
 
==References:==
: 1. ASME OM Code, Code for Operation and Maintenance of Nuclear Power Plants, 1995 Editionand later, Subsection ISTBRevision 0October 25, 2013 A13 -9 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 13Number: CTP-IST-004, Rev. 1Title: Classification of Pumps: Centrifugal vs. Vertical Line ShaftApplicability: All Exelon IST Programs
 
==Background:==
Early Code documents that provided requirements for inservice testing of pumpsdid not differentiate between pump types. Subsection IWP of the ASME Boilerand Pressure Vessel Code, Section Xl, required the measurement of flow,differential pressure and vibration and comparison of the measured data withreference values, similar to the way in which centrifugal pump testing is currentlyperformed. Some additional measurements were required (e.g., bearingtemperature, lubrication level or pressure) which were later determined to be ofminimal value to IST. A major limitation in the earlier Code was that the sameparameters and acceptance criteria were specified for all pumps.With the development of the OM Standards (OM-1, OM-6, OM-10, etc.), it wasrecognized that pumps of different design performed differently and requireddifferent measurement criteria to determine acceptable performance. Forexample, discharge pressure was determined to be a more representativemeasurement of performance for a positive displacement pump than differentialpressure. Part 6 of the OM Standards (OM-6), also introduced different criteria forinservice testing of centrifugal and vertical line shaft pumps. Unfortunately, it didnot provide any definition for a vertical line shaft pump.The definition of "vertical line shaft" pump was first incorporated into the OM-1 998Edition of the OM Code as "a vertically suspended pump where the pump driverand pump element are connected by a line shaft within an enclosed column."This definition failed to eliminate much of the uncertainty in determining whethercertain pumps were vertically-oriented centrifugal pumps or vertical line shaftpumps. Further confusion was created by the choice of wording used in the OMCode Tables that specify the acceptance criteria for centrifugal and vertical lineshaft pumps.Position: Code requirements for vibration measurement provide the clearest indication ofthe difference between a centrifugal pump and a vertical line shaft pump. Oncentrifugal pumps, vibration measurements are required to be taken in a planeapproximately perpendicular to the rotating shaft in two approximately orthogonaldirections on each accessible pump-bearing housing and in the axial direction oneach accessible pump thrust bearing housing. On vertical line shaft pumps,measurements are required to be taken on the upper motor-bearing housing inthree approximately orthogonal directions, one of which is the axial direction.Therefore, a pump which is connected to its driver by a vertically-oriented shaft inwhich vibration measurements must be taken on the pump motor due to theinaccessibility of the pump bearings will be classified as a vertical line shaft pump.For plants using the 1998 Edition of the OM Code through the OMb-2003addenda, Table ISTB-5100-1 applies to all horizontally and vertically-orientedcentrifugal pumps; Table ISTB-5200-1 applies to vertical line shaft pumps. Forplants using the 2004 Edition of the OM Code and later, Table ISTB-5121-1Revision 0October 25, 2013A13 -10 Three Mile Island Unit #1Inservice Testing Program Planapplies to all horizontally and vertically-oriented centrifugal pumps; Table ISTB-5221-1 applies to vertical line shaft pumps.
 
==References:==
.1. ASME OMa-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 Editionand later, Subsection ISTB.Revision 0October 25, 2013 A13- 11 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 13Number: CTP-IST-005, Rev. 1Title: Preservice Testing of PumpsApplicability: OM-1995 Code and Later
 
==Background:==
Requirements for preservice testing of pumps have been stated in ASME Codedocuments since the beginning. However, the 1995 Edition of the OM Codesignificantly expanded the scope of preservice testing by introducing therequirement that centrifugal and vertical line shaft pumps in systems whereresistance can be varied establish a pump curve by measuring flow anddifferential pressure at a minimum of five points. These points are required to befrom pump minimum flow to at least design flow, if practicable. At least one pointis 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 determineif preservice testing requirements apply when reference values may have beenaffected by repair, replacement, or maintenance on a pump. A new referencevalue or set of values is required to be determined or the previous referencevalue(s) reconfirmed by a comprehensive or Group A test prior-to declaring thepump operable.Position: Whenever a pump's [hydraulic] reference values may have been affected byrepair, replacement, or maintenance, a preservice test SHALL be performed inaccordance with the preservice test requirements of Reference 1 of this CTP forthe applicable pump design. If it is determined through evaluation that themaintenance activity did not affect the existing reference values, then the previousreference value(s) SHALL be reconfirmed. by a comprehensive or Group A testprior to declaring the pump operable. Evaluation that the maintenance activity didnot affect the pump's reference values SHALL BE DOCUMENTED.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 testscope or schedule and would provide valuable information for subsequentevaluations of pump performance.For centrifugal and vertical line shaft pumps in systems with variable resistance,one of the five points on the preservice test curve (preferably one between 100%and 120% of design flow but in no case less than 80% of design flow) SHALL beselected as the reference point for the comprehensive tests. If quarterly testingwill be performed at full flow, then the same point should be selected for thequarterly pump tests. If quarterly testing cannot be performed at full flow, thenanother point on the preservice test curve SHALL be selected as the referencepoint for the quarterly tests.
 
==References:==
: 1. ASME OM Code, Code for Operation and Maintenance of Nuclear Power Plants, 1995 Editionand later, Subsection ISTB.Revision 0October 25, 2013 A13- 12 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 13Number: CTP-IST-006, Rev. 0Title: Classification and Testing of Class 1 Safety/Relief Valves With AuxiliaryActuating DevicesApplicability: All Exelon IST Programs
 
==Background:==
he definition for valve categories in the ASME Codes has been consistent sincethe beginning. Category A, B, C and D valves are basically defined the same nowas they were in early editions/addenda of Section Xl of the ASME Boiler andPressure Vessel Code. Likewise, the requirement that valves meeting thedefinition for more than one category be tested in accordance with all theapplicable categories has been consistent over time.Due to a lack of clear testing requirements for Class 1 Safety/Relief Valves WithAuxiliary Actuating Devices in early ASME Codes, these valves were historicallyclassified as Category B/C. As relief valves, they were required to meet theCategory C testing requirements; and since the auxiliary operators essentially putthem in the classification of power-operated valves, Category B requirementswere imposed to address stroke-time and position indication testingconsiderations.Position: The B/C categorization of these valves was initially made due to a lack of specificCode requirements. However, with the publication of ASME OM Standard OM-1in 1981, which identified specific requirements for these valves, it becameirrelevant. All applicable testing requirements for these valves were specified inOM-1, which has been superseded by Appendix I of the ASME OM Code. Effortsof the Code to exempt these valves from Category B testing requirements furtherdemonstrate their inapplicability. Therefore, these valves should be classified asCategory 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 ReliefDevices.2. ASME OM Code, Code for Operation and Maintenance of Nuclear Power Plants, 1995 Editionand later, Subsection ISTC and Appendix I.Revision 0October 25, 2013 A13- 13 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 13Number: CTP-IST-007, Rev. ITitle: Skid-Mounted ComponentsApplicability: 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 operationof a supported component in such a way that their proper functioning is confirmedby the operation of the supported component. For example, the successfuloperation of an emergency diesel-generator set confirms that essential supportequipment, such as cooling water and lube oil pumps and valves, are functioningas required. The concept of "skid-mounted" is actually irrespective of physicallocation.Position: Components that are required to perform a specific function in shutting down areactor to the safe shutdown condition, in maintaining the safe shutdowncondition, or in mitigating the consequences of an accident are required to testedin accordance with the ASME Code-in-effect for the station's IST Program. It isnot the intent of the skid-mounted exemption that it be used in cases where thespecific testing requirements of the Code for testing of pumps and valves can bemet. For example, if adequate instrumentation is provided to measure a pump'sflow and differential pressure, and if required points for vibration measurementcan be accessed, then invoking the skid-mounted exemption would beinappropriate.The "skid-mounted" exclusion as stated in references 2 and 3, below, may beapplied to pumps or valves classified as "skid-mounted" in the IST Programprovided that they are tested as part of the major component and are justified tobe adequately tested. Such components SHALL be listed in the Program Plandocument and identified as skid-mounted. Pump or Valve Data Sheets whichcontain the justification regarding the adequacy of their testing SHALL beprovided in the IST Bases Document.
 
==References:==
: 1. NUREG-1482 (Rev.0 and Rev.1), Section 3.4, Skid-Mounted Components and ComponentSubassemblies2. ASME OM Code, Code for Operation and Maintenance of Nuclear Power Plants, 1995 EditionOMa-1996 Addenda, ISTA 1.7, ISTC 1.2.3. ASME OM Code, Code for Operation and Maintenance of Nuclear Power Plants, 1998 Editionand later, ISTA-2000 and ISTC-1200.Revision 0October 25, 2013 A13- 14 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 13CTP-IST-008, Rev. 0Position Verification TestingNumber:Title:Applicability:
 
==Background:==
Position:
 
==References:==
All Exelon IST ProgramsValves with remote position indicators are required to be observed locally at leastonce every two years to verify that valve operation is accurately indicated. Thislocal observation should be supplemented by other indications to verify obturatorposition. Where local observation is not possible, other indications shall be usedfor verification of valve operation.All valves within the scope of the IST Program that are equipped with remoteposition indicators, shall be tested. The testing shall clearly demonstrate that theposition indicators operate as required and are indicative of obturator position.For example, a valve that has open and closed indication shall be cycled todemonstrate 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 theindicator is energized/de-energized when appropriate. These requirements applyto all IST valves, regardless of whether they are classified as active or passive.1. ASME OM Code, Code for Operation and Maintenance of Nuclear Power Plants, 1995 Editionwith OMa-1996 Addenda, para ISTC 4.1.2. ASME OM Code, Code for Operation and Maintenance of Nuclear Power Plants, 1998 Editionand later, para ISTC-3700.3. NUREG-1482, Rev. 1, Section 4.2.8Revision 0October 25, 2013A13 -15 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 13Number: CTP-IST-009, Rev. 0Title: ASME Class 2 & 3 Relief Valve Testing RequirementsApplicability: All Exelon IST Programs
 
==Background:==
The ASME OM Code, Appendix I, provides requirements for Inservice Testing ofASME Class 1, 2, and 3 Pressure Relief Devices. The requirements for Class 1pressure relief devices are identified separately from those for Classes 2 and 3.The requirements for Class 2 and 3 pressure relief devices are identified together.This Technical Position applies only to ASME Class 2 and 3 safety and reliefvalves. It does not include vacuum breakers or rupture discs. Class 2 PWR MainSteam Safety Valves are also not included in this Technical Position because theyare required to be tested in accordance with ASME Class 1 safety valverequirements.Position: This Technical Position applies to the classification, selection, scheduling andtesting of ASME Class 2 and 3 safety and relief valves only. For the purposes ofthis Technical Position, the term "relief valve" will be used to apply to both types.ClassificationDETERMINE whether or not the valve may be classified as a thermal relief. Athermal relief valve is one whose only over-pressure protection function is toprotect isolated components, systems, or portions of systems from fluid expansioncaused by changes in fluid temperature. If a relief valve is required to performany other function in protecting a system or a portion of a system that is required..to place the reactor in the safe shutdown condition, to maintain the safe shutdowncondition, or to mitigate the consequences of an accident, it cannot be classifiedas a thermal relief Valve.Class 2 and Class 3 thermal relief valves are required to be TESTED orREPLACED every 10 years unless performance data indicates the need for morefrequent testing or replacement. Details regarding whether a Class 2 or Class 3thermal relief valve is tested or replaced and the bases for the associatedfrequency SHALL be documented in the IST Bases Document.Grouping, sample expansion and the requirement to test 20% of the valves withinany 48-month period. do not apply to Class 2 and. Class 3 thermal relief Valves.Class 2 and 3 thermal relief valves may be optionally tested in accordance withthe more conservative requirements for non-thermal relief valves if desired.'Non-thermal relief valves shall be grouped in accordance with the groupingcriteria of Appendix I (same manufacturer, type, system application, and servicemedia). Groups may range in size from one valve to all of the valves'meeting thegrouping criteria. Grouping criteria SHALL be documented in the IST BasesDocument or other document that controls Class 2 and 3 IST relief valve testing.If two valves are manufactured at the same facility to the same specifications,dimensions, and materials of construction but under a different manufacturer'sname due to a merger or acquisition, the valves may be considered to meet therequirement for same manufacturer.Revision 0October 25, 2013 A13 -16 Three Mile Island Unit #1Inservice Testing Program PlanValves in systems containing air or nitrogen may be considered to have the sameservice media.SelectionValves SHALL be selected for testing such that the valve(s) in each group withthe longest duration since the previous test are chosen first. This SHALLINCLUDE any valves selected due to sample expansion..IF an exception to this requirement is necessary due to accessibility or schedulingconsiderations, DOCUMENT the reason and that the valves that should havebeen selected will not come due prior to the next opportunity to test them (e.g.,the next outage).SchedulingGrace is NOT permitted for relief valve testing, unless authorized by an NRC-approved relief request.All frequency requirements are test-to-test (i.e., they begin on the most recentdate on which the valve was tested per Appendix I requirements and end. on thedate of the next Appendix I test).All Class 2 or Class 3 relief valves in any group must be tested at least once every10 years.Valves within each group must be tested such that a minimum of 20% of thevalves are tested within any given 48-month period.If all of the valves in a group are removed for testing and replaced with pretestedvalves, the removed valves shall be tested within 12 months of removal from thesystem.If less than all of the valves in a group are removed for testing and replaced withpretested valves, the removed valves shall be tested within 3 months of removalfrom the system or before resumption of electric power generation, whichever islater.Testing of pretested valves must have been performed such that they will meetthe 10 year and 20% /48-month requirements for the entire time they are inservice.Testing of relief valves that is required to be performed during an outage SHALLBE PERFORMED as early in the outage as practicable in order to allow forcontingency testing of additional valves in the event a scheduled valve fails its as-found test.TestingTesting SHALL BE PERFORMED using the same service media wherein thevalve was installed.Testing of additional valves due to failure of a scheduled valve to meet its as-found setpoint acceptance criteria SHALL BE PERFORMED in accordance withall applicable OM Code and Technical Specification requirements.
 
==References:==
1 .ASME OM Code, 1995 Edition and later, Mandatory Appendix I, Inservice Testing of PressureRelief Devices in Light-Water Reactor Nuclear Power PlantsRevision 0October 25, 2013 A13 -17 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 13Number: CTP-IST-010, Rev. 0Title: ERV and PORV Testing RequirementsApplicability: Exelon Stations with Electromatic Relief Valves or Power-Operated Relief Valves
 
==Background:==
Electromatic Relief Valves (ERVs) and Power-Operated Relief Valves (PORVs)are used at nuclear plants to protect the Reactor Coolant pressure boundary fromoverpressure under various conditions. This may include preventing excessivechallenges to BWR Main Steam Safety Valves and PWR Pressurizer SafetyValves during operation at power or preventing low temperature overpressure(LTOP) conditions from exceeding brittle fracture limits when the plant is cooleddown.ERVs and PORVs come in a variety of designs, which can make theircategorization and testing in accordance with OM Code requirements challenging.Some are actual relief valves that are equipped with air operators to open thevalves against spring force upon actuation by some pressure-sensing apparatusin the primary coolant system. Others may be motor-operated gate valves thatopen and close as a result of signals generated at predetermined pressuresettings. The key to determining the proper category of the ERV or PORV is notthe nomenclature of the valve (i.e., "relief valve"), but the actual physical design ofthe valve and its actuator.Power-operated relief valves were not addressed by the ASME Codes until theOMa-1996 Addenda. Even then, they were only alluded to by the addition of anexclusion to paragraph ISTC 1.2 which stated: "Category A and B safety and reliefvalves are excluded from the requirements of ISTC 4.1, Valve Position Verificationand ISTC 4.2, Inservice Exercising Test." Up to this point, Owners typicallycategorized these valves as Category B/C, assigned the position verification andexercise test requirements for the Category B portion, and then obtained Relieffrom the NRC to not perform them due to their impracticability. The ReliefRequests provided a detailed description of the proposed alternative techniques,which generally matched Category C requirements for valves with auxiliaryactuators.Paragraph ISTC-5110 was introduced in the OM-1998 Edition of the OM Codewhich stated: "Power-operated relief valves shall meet the requirements of ISTC-5100 for the specific Category B valve type and ISTC-5240 for Category Cvalves." This essentially added no value, since this was already the practice.OMb-2000 added the following definition of a power-operated relief valve toparagraph ISTC-2000, Supplemental Definitions: "a power-operated valve thatcan perform a pressure relieving function and is remotely actuated by either asignal from a pressure sensing device or a control switch. A power-operated reliefvalve is not capacity certified under ASME Section III overpressure protectionrequirements." In addition, OMb-2000 added the following to paragraph ISTC-3510: "Power-operated relief valves shall be exercise tested once per fuel cycle."The addition of exclusions, definitions and test requirements to the Code for thesevalves has only tended to make actual testing requirements more conflicting orconfusing. These valves are still being categorized as Category B, C or B/C (withRevision 0October 25, 2013A13 -18 Three Mile Island Unit #1Inservice Testing Program Plana few A's or A/C's) throughout the industry with testing requirements assignedaccordingly and relief still being sought where deemed appropriate.Each Station MUST DETERMINE the proper valve category or categories for itsERVs and/or PORVs based on valve and actuator design, and IDENTIFYappropriate testing requirements and methodologies appropriate to thatcategorization. The following table summarizes the possible categories that canbe applied to an ERV or PORV, whether or not the valve meets the definition of aPORV as defined in ISTC-2000, and the .associated test requirements:Position:MeetsCategory PORV Test Requirements CommentsDef.B C B CValve is not a safety or relief valve;X No ISTC-3700 actuator is MO, AO or HO. Does notISTC-5120* meet Code definition of PORV (ISTC-ISTC-5130* 2000). Exercise test quarterly per ISTC-ISTC-5140" 00.Eecs et urel e SC3510, or defer to Cold Shutdown or RFOper ISTC-3521.X Yes ISTC-3700 Valve meets Code definition of PORVISTC-5110 (ISTC-2000). Exercise test once per fuelcycle per ISTC-3510 and ISTC-5110.Valve is a relief valve with AO or HOSTC-5240 actuator. Does not meet Code definitionApp. I of PORV (ISTC-2000). Exempt from CatB testing (ISTC-3500/ISTC-3700) perISTC-1200.X X No Valve is a relief valve with AO or HOISTC-5240 actuator. Does not meet Code definitionApp. I of PORV (ISTC-2000). Exempt from CatB testing (ISTC-3500/ISTC-3700) perISTC-1200.X X Yes ISTC-3700 Should not be classified Category C.ISTC-5110 Relief valves do not meet the Codedefinition of PORV (ISTC-2000).* As applicableA Relief Request SHALL BE SUBMITTED for any ERV or PORV that does notmeet the applicable test requirements specified in the above table.A detailed description of the rationale behind the category designation, theassignment of testing requirements, and how they are satisfied SHALL BEPROVIDED on the applicable IST Bases Document Valve Data Sheets.
 
==References:==
: 1. ASME OM Code, 1995 Edition and later, Subsection ISTC, Inservice Testing of Valves inLight-Water Reactor Nuclear Power Plants2. ASME OM Code, 1995 Edition and later, Mandatory Appendix I, Inservice Testing of PressureRelief Devices in Light-Water Reactor Nuclear Power PlantsRevision 0October 25, 2013 A13 -19 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 13Number: CTP-IST-011, Rev. 0Title:. Extension of Valve Exercise Test Frequencies to Cold Shutdown orRefueling OutageApplicability: All Exelon IST Programs
 
==Background:==
Requirements for exercise testing of Category A and B power-operated valvesand check valves (Category C) are stipulated in the OM Code as follows:ISTC-3510 states: "Active Category A, Category B and Category C check valvesshall be exercised nominally every 3 mo, except as provided by paras. ISTC-3520, ISTC-3540, ISTC-3550, ISTC-3570, ISTC-5221 and ISTC-5222." PlantTechnical Specifications for IST identify the 3 month frequency as once per 92days with allowance for a 25% extension.ISTC-3520 is divided into ISTC-3521 for Category A and Category B valves, andISTC-3522 for Category C check valves. ISTC-3521 states: "Category A and Bvalves shall be tested as follows:(a) full-stroke exercising of Category A and Category B valves during operationat power to the position(s) required to fulfill its function(s).(b) if full-stroke exercising during operation at power is not practicable, it may belimited to part-stroke during operation at power and full-stroke during coldshutdowns.(c) if exercising is not practicable during operation at power, it may be limited tofull-stroke exercising during cold shutdowns.(d) if exercising is not practicable during operation at power and full-stroke duringcold shutdowns is also not practicable, it may be limited to part-stroke duringcold shutdowns and full-stroke during refueling outages.(e) if exercising is not practicable during operation at power or cold shutdowns, itmay be limited to full-stroke during refueling outages.Paragraphs (f) through (h) provide additional limitations on cold shutdown andrefueling outage exercise testing.ISTC-3522 provides essentially the same requirements for check valves exceptthat the requirement to consider partial-stroke exercising is not included.ISTC-3540 stipulates exercise testing frequency requirements for manual valves.ISTC-3550 discusses valves in regular use, ISTC-3570 addresses valves insystems out-of-service, ISTC-5221 addresses special frequency considerationsfor check valves in a sample disassembly and inspection program, and ISTC-5222addresses check valves in a condition monitoring program.ISTC-3521 makes it clear that the intent of the Code is for valves to be exercisedquarterly unless it is impracticable to do so. When it is impracticable, thegraduated approach of ISTC-3521 through cold shutdown and refuelingfrequencies and partial and full-stroke exercising impose an obligation on theowner to perform at least some testing as frequently as practicable.The determination of "practicability" is left to the owner. The industry hasuniversally adopted the practice of writing Cold Shutdown and Refueling OutageRevision 0October 25, 2013 A13 -20 Three Mile Island Unit #1Inservice Testing Program PlanJustifications to document conditions that they believe to be "impracticable".There are no Code or regulatory definitions of impracticability nor are there anyCode or regulatory requirements to prepare Cold Shutdown or Refueling OutageJustifications. However, Reference 2 provides a good deal of useful guidanceregarding a regulatory opinion of what constitutes it. Merriam-Webster defines"impracticable" as (1) impassable or (2) not practicable; incapable of beingperformed or accomplished by the means employed or at command".Position: The following direction SHALL BE IMPLEMENTED when establishing exercisetest frequencies for power-operated Category A and B valves and Category Ccheck valves:1. Stations SHALL DETERMINE the practicability of performing exercise testingof all valves in their IST Programs in accordance with the Code.2. When preparing or performing a technical revision to a Cold Shutdown orRefueling Outage Justification, the Station IST Engineer SHALL OBTAIN apeer review from the Corporate IST Engineer and at least one other Site ISTProgram Engineer.3. Cold Shutdown and Refueling Outage Justifications SHALL PROVIDE astrong, clear technical case for the testing deferral. References to NUREG-1482 may be made to support the justification; however, it is not to be citedas the justification itself.
 
==References:==
: 1. ASME OM Code, 1995 Edition and later, Subsection ISTC, Inservice Testing of*Valves inLight-Water Reactor Nuclear Power Plants2. NUREG 1482, Revision 1, Guidelines for Inservice Testing at Nuclear Power Plants, Sections2.4.5 and 3.1..Revision 0October 25, 2013 A13 -21 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 13Number: CTP-IST-012, Rev. 0Title: Use of ASME OM Code Cases for Inservice TestingApplicability: All Exelon IST Programs
 
==Background:==
Code Cases are issued to clarify the intent of existing Code requirements or toprovide alternatives to those requirements. Adoption of the alternativerequirements provided by Code Cases are optional; they only become mandatorywhen an owner commits to them. Code Cases are included as a separate sectionat the end of published editions/addenda of the OM Code for the user'sconvenience. They are not a part of any Code edition or addenda andendorsement of specific editions/ addenda of the OM Code by the NRC does notconstitute endorsement of the Code Cases.If the Code Committee desires to make the requirements of a Code Casemandatory, those requirements are incorporated into the Code at a later date. Forexample, Code Case OMN-1, Alternative Rules for Preservice and InserviceTesting of Active Electric Motor Operated Valve Assemblies in Light-WaterReactor Power Plants, was incorporated into the 2009 Edition of the OM Code asMandatory Appendix III. Appendix Ill will become mandatory for IST Programswhen 10 CFR 50.55a imposes the requirement that 10-year interval updates meetthe requirements of the 2009 Edition of the ASME Code or later. Until such time,plants may optionally implement OMN-1 or may continue to perform stroke-timetesting and position indication verification in accordance with Subsection ISTCrequirements.In order for an OM Code Case to be used in an Inservice Testing Program at anuclear power plant, it must be authorized by ASME and approved by the NRC. ACode Case. is authorized for use by ASME as soon as. it is published, providedcertain limitations included in the Code Case, such as the applicability statement,are met. OM Code Cases are published on the ASME Web site at http://cstools.asme.org and in Mechanical Engineering magazine as they are issued.Efforts to clarify or simplify the use of Code Cases have instead createdconflicting requirements which need to be addressed in order to avoidnoncompliance with the Code or CFR. These include:The Code of Federal Regulations, paragraph 10 CFR 50.55a(b)(6) states thatLicensees may apply ASME OM Code Cases listed in Regulatory Guide1.192 without prior NRC approval subject to certain conditions. Onecondition states that when a licensee initially applies a listed Code case, thelicensee shall apply the most recent version of the Code case "incorporatedby reference in this paragraph". A second condition states that if a licenseehas previously applied a Code case and a later version of the Code. case is"incorporated by reference in this paragraph", the licensee may continue toapply, to the end of the current 120-month interval, the previous Version ofthe Code case or may apply the later version of the Code case, including anyNRC-specified conditions placed on its use. A third condition restricts the useof annulled Code cases to those that were in use prior to their annulment.Revision 0October 25, 2013 A13-22 Three Mile Island Unit #1Inservice Testing Program PlanIt is not clear what "incorporated by reference in this paragraph" is referringto. If "this paragraph" means 10 CFR 50.55a(b)(6), this would refer to RegGuide 1.192. If it refers more broadly to 10 CFR 50.55a(b), this would alsoinclude 10CFR 50.55a(b)(3), which contains the endorsement of the latestedition/addenda of the OM Code approved for use by the NRC. In the firstcase, Reg Guide 1.192 was published in June 2003 with no revisions to date.Versions of the Code cases referenced therein have all exceeded theirexpiration dates and are not applicable to current Code editions. In the lattercase, since Code Cases are independent of Code editions/addenda, there isa disconnect between approval of Code versus Code Cases." Requirements for the use of Code Cases are stipulated in the body of the OMCode. In all cases from the OM-1995 Edition through the OMa-2011Addenda, it is required that "Code Cases shall be applicable to the editionand addenda specified in the inservice test plan" and " Code Cases shall bein effect at the time the inservice test plan is filed". These requirements arealmost never met." Code Cases provided as attachments up to and including the OMb-2006Addenda contained expiration dates. These dates are usually prior to thetime it is desired to use the Code Case." Each Code Case contains an applicability statement. Even in the latestEdition/addenda of the Code incorporated by reference in 10 CFR 50.55a,these statements usually indicate that the Code Case applies to earlierversions of the Code than what is required to be used.Despite the inconveniences in implementing Code Cases, they often providealternatives to the Code that are technically superior and highly desirable from acost-efficiency perspective. Therefore, each plant should review the potential useof Code Cases with Corporate Engineering, particularly when in the process ofperforming 10-year updates.Position: The following requirements SHALL BE IMPLEMENTED in order to use ASMEOM Code Cases at Exelon stations:1. All Code Cases used by a Station for their IST Program SHALL BE LISTED.in the IST Program Plan.2. Code Case expiration dates, applicability statements, and the Edition/addenda of the Code-in-effect for a Station's IST Program SHALL all becompatible for Code Cases implemented in an IST Program OR a ReliefRequest SHALL BE SUBMITTED to use the Code Case in accordance withReference 2 of this CTP.
 
==References:==
1 .ASME OM Code, 1995 Edition and later, Subsection ISTA, General Requirements2. ER-AA-321, Administrative Requirements for Inservice Testing.Revision 0October 25, 2013 A13 -23 Number:Title:Applicability:
 
==Background:==
Position:Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 13CTP-IST-013, Rev. 0Exercise Testing Requirements for Valves with Fail-Safe ActuatorsAll Exelon IST ProgramsValves with fail-safe positions usually have actuators that use the fail-safemechanism to stroke the valve to the fail-safe position during normal operation.For example, an air-operated valve that fails closed may use air to open the valveagainst spring pressure. When the actuator is placed in the closed position, air isvented from the diaphragm and the spring moves the obturator to the closedposition.The fail-safe test is generally an integral part of the stroke time exercise test andis thus performed at the same frequency. Where the exercise test is performedless frequent than every 3 months, a cold shutdown justification, refueling outagejustification, or relief request is required. The same justification for the stroke timeexercise test would also apply to the fail-safe test.In cases where normal valve operation moves the valve to the fail-safe position byde-energizing the operator electrically, by venting air, or both (e.g., a solenoidvalve in the air supply system of a valve operator moves to the vent position onloss of power), no additional fail-safe testing is required.In cases where a fail-safe actuator does not operate as an integral part of normalactuator operation, the fail-safe feature(s) must be tested in a manner thatdemonstrates proper operation of each component that contributes to the fail-safeoperation. The means used to meet this requirement shall be described in theIST Bases Document.Code, Code for Operation and Maintenance of Nuclear Power Plants, 1995 Edition
 
==References:==
: 1. ASME OMand later, Subsection ISTC.Revision 0October 25, 2013A13 -24 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 13Number: CTP-IST-014, Rev. 0Title: Bi-directional Testing of Check Valves to Their Safety and Non-SafetyRelated PositionsApplicability: All Exelon IST Programs
 
==Background:==
This CTP addresses those cases in which inservice testing of check valves isperformed in accordance with the requirements of ISTC-5221. It does notaddress these issues for check valves that are included in a Condition MonitoringProgram. References 2 and 3 of this CTP provide additional informationregarding check valve testing and Condition Monitoring.The OM Code changed the focus of inservice testing of check valves from theability to demonstrate that a check valve was capable of being in its safety-relatedposition to demonstrating that the obturator was capable of free, unobstructedmovement in both directions. This was accomplished by introducing abidirectional testing requirement to inservice testing of check valves. Confirmationof this change in focus is evidenced by the fact that the Code required frequencyfor bi-directional testing of check valves is the lesser of the frequencies that theopen direction and close direction tests can be performed. In other words, if acheck valve is capable of being tested in the open direction quarterly but can onlybe tested closed during refueling outages, the Code required frequency for thebidirectional test is every refueling outage irrespective of the valve's safetyposition(s).Condition Monitoring is the preferred method for check valve testing andinspection. For check valves that are not in a Condition Monitoring Program, theOM Code provides three options: flow/flow reversal, use of an externalmechanical exerciser, and sample disassembly/examination. Of these, the flowand mechanical exerciser methods are preferred; the Code limits sampledisassembly/ examination to those cases where the others are impractical. In allof these non-Condition Monitoring methods, demonstration of unobstructedobturator travel in the open and closed directions is required.Position: The following requirements SHALL BE MET when implementing this CTP:1. When using flow to demonstrate opening of a check valve with an opensafety function, OBSERVE that the obturator has traveled to EITHER the fullopen position OR to the position required to perform its intended safetyfunction(s).Travel to the position required to perform its intended safety function(s) isdefined as the minimum flow required to mitigate the system's most limitingaccident requirements. For example, if three different accident scenarioscalled for flows of 300, 600 and 1000 gpm respectively, the required test flowwould be 1000 gpm.The full open position is defined as the point at which the obturator isrestricted from further travel (e.g., hits the backstop). Methods fordemonstrating travel to the full open position must be qualified if less thanrequired accident flow is used.Revision 0October 25, 2013 A13 -25 Three Mile Island Unit #1Inservice Testing Program Plan2. When using flow to demonstrate that the obturator of a valve that does nothave an open safety function has *traveled open, the test MUSTDEMONSTRATE that the obturator is unimpeded.3. Tests for check valve closure MUST DEMONSTRATE that the check valvehas travelled to the closed position, not merely that it is in the closed position.4. Whenever design requirements are used for IST acceptance criteria,instrument accuracy MUST BE CONSIDERED. This can be accomplishedby determining that sufficient margin was included in the design calculation orby adding a correction to the IST acceptance criteria.*5. Non-intrusive methods used to credit obturator position SHALL BEQUALIFIED. Documentation of the means used to qualify the test method(s)shall be documented in the IST Bases Document.6. The Code requirement satisfied for each check valve, identification of themethod used to satisfy the Code requirement, and a description of how themethod satisfies the requirement SHALL BE PROVIDED OR REFERENCEDon the Valve Data Sheet in the IST Bases Document for each check valve..
 
==References:==
: 1. ASME OM Code, Code for Operation and Maintenance of Nuclear Power Plants, 1995 Editionand later, Subsection ISTC.2. ER-AA-321., Administrative Requirements for Inservice Testing3. ER-AA-321-1005, Condition Monitoring for Inservice Testing of Check ValvesRevision 0October 25, 2013 A13 -26 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 14INSERVICE TESTING PUMP TABLERevision 0October 25, 2013A14 -1 Three Mile Island Unit #1Inservice Testing Program PlanAttachment 14Inservice Testing Pump TableREACTOR BUILDING SPRAY (Page 1)Pump EPN Test Safety Pump Pump NominalGroup Class Type Driver SpeedP&ID P&IDCoor.Test Type Test Relief Tech. CommentsFreq. Request Pos.1-BS-P-1A AB 2 C M 3600 302-712 A-6ABABPump Name REACTOR BUILDING SPRAY PUMP "A"1-BS-P-1B AB 2 C M 3600 302-712 B-6ABABPump Name REACTOR BUILDING SPRAY PUMP "B"DifferentialPressure -Grp AFlow Rate -Grp AVibration -Grp ADifferentialPressure -Grp AFlow Rate -Grp AVibration -Grp AQQQQQQPR-02PR-02PR-02PR-02PR-02PR-02Revision 0October 25, 2013A14 -2 Three Mile Island Unit #1Inservice Testing Program Plan.Attachment 14Inservice Testing Pump TableREACTOR PLANT CHEMICAL ADDITION (Page 1)Pump EPN TestGroup1-CA-P-1A BSafetyClass3Pump Pump NominalType Driver SpeedPDR M 1725P&ID P&IDCoor.Test Type Test Relief Tech. CommentsFreq. Request Pos.302-670E-6BBBPump Name BORIC ACID INJECTION PUMP "A"3 PDR M 1725 302-670 E-5.DischargePressure -CompFlow Rate -CompFlow Rate -Grp BVibration -CompDischargePressure -CompFlow Rate -CompFlow Rate -Grp BVibration -CompY2Y2QY2Y2Y2QY21-CA-P-1BBBBPump Name BORIC ACID INJECTION PUMP "B"Revision 0October 25, 2013A14 -3 Three Mile Island Unit #1Inservice Testing Program PlanAttachment 14Inservice Testing Pump TableCONTROL BUILDING CHILLED WATER (Page 1)Pump EPN Test SafetyGroup ClassPump Pump Nominal P&ID P&IDType Driver Speed Coor.Test Type Test ReliefFreq. RequestTech. CommentsPos.1-AH-P-3A A 3 C M 1750 302-847 C-5 DifferentialPressure -Grp AA Flow Rate -Grp AA Vibration -Grp APump Name CONTROL BUILDING CHILLED WATER SUPPLY PUMP "A"1-AH-P-3B A 3 C M 1750 302-847 A-5 DifferentialPressure -Grp AA Flow Rate -Grp AA Vibration -Grp APump Name CONTROL BUILDING CHILLED WATER SUPPLY PUMP "B"Revision 0October 25, 2013 A14 -4Q PR-02QQPR-02.PR-02Q PR-020QPR-02PR-02 Three Mile Island Unit #1Inservice Testing Program PlanAttachment 14Inservice Testing Pump TableDECAY HEAT CLOSED CYCLE COOLING WATER (Page 1)Pump EPN Test Safety Pump Pump NominalGroup Class Type Driver SpeedP&ID P&IDCoor.Test Type Test ReliefFreq. RequestTech. CommentsPos.1-DC-P-1A A 3 C M 1150 302-645 D-3AAPump Name DH CLOSED COOLING WATER PUMP "A"1-DC-P-1B A 3 C M 1150 302-645 D-2AAPump Name DH CLOSED COOLING WATER PUMP "B"DifferentialPressure -Grp AFlow Rate -Grp AVibration -Grp AQ PR-02QQPR-02PR-02Differential Q PR-02Pressure -Grp AFlow Rate -Grp A Q PR-02Vibration -Grp A Q PR-02Revision 0October 25, 2013A14 -5 Three Mile Island Unit #1Inservice Testing Program PlanAttachment 14Inservice Testing Pump TableEMERGENCY DIESEL GENERATORS FUEL SYSTEMS (Page 1)Pump EPN Test Safety Pump Pump Nominal P&ID P&ID Test Type Test Relief Tech. CommentsGroup* Class Type Driver Speed Coor. Freq. Request Pos.1-DF-P-1A N/A PDN M 1750 .302-351 D-7 Flow Rate 0 IST-007Pump Name DIESEL FUEL OIL PUMP "A"1-DF-P-1B N/A PDN M 1750 302-351 D-6 Flow Rate Q IST-007Pump Name DIESEL FUEL OIL PUMP "B"1-DF-P-lC N/A PDN M 1750 302-351 D-3 Flow Rate Q IST-007Pump Name DIESEL FUEL OIL PUMP "C"1-DF-P-1D N/A PDN M 1750 302-351 D-2 Flow Rate Q IST-007Pump Name DIESEL FUEL OIL PUMP "D"Revision 0October 25, 2013 A14-6 Three Mile Island Unit #1Inservice Testing Program PlanAttachment 14Inservice Testing Pump TableDECAY HEAT REMOVAL (Page 1)Pump EPN Test SafetyGroup Class1-DH-P-1A A 2Pump Pump NominalType Driver SpeedP&ID P&IDCoor.Test Type Test Relief Tech. CommentsFreq. Request Pos.C M 1800 302-640D-5A.AAAAPump Name DECAY HEAT REMOVAL PUMP "A"1-DH-P-1B A 2 C M 1800 302-640AAAAAPump Name DECAY HEAT REMOVAL PUMP "B"DifferentialPressure -CompDifferentialPressure -Grp AFlow Rate -CompFlow Rate -Grp AVibration -CompVibration -Grp ADifferentialPressure -CompDifferentialPressure -Grp AFlow Rate -CompFlow Rate -Grp AVibration -CompVibration -Grp AY2QY2QY2QY2QY2QY2QD-3Revision 0October 25, 2013A14-7 Three Mile Island Unit #1Inservice Testing Program PlanAttachment 14Inservice Testing Pump TableDECAY HEAT RIVER WATER (Page 1)Pump EPN Test Safety Pump Pump NominalGroup Class Type Driver. SpeedP&ID
* P&IDCoor.Test Type Test Relief Tech. CommentsFreq. Request Pos.1-DR-P-1A A 3 VLS M 1175 302-202 A-7AAPump Name DECAY HEAT RIVER WATER PUMP "A"1-DR-P-1B A 3 VLS M 1175 302-202 A-6AAPump Name DECAY HEAT RIVER WATER PUMP "B"DifferentialPressure -GrpAFlow Rate -Grp AQaPR-02PR-02Vibration -Grp A Q PR-02Differential Q PR-02Pressure -Grp A* Flow Rate -Grp A Q. PR-02Vibration -Grp A Q PR-02Revision 0October 25, 2013A14 -8 Three Mile Island Unit #1Inservice Testing Program PlanAttachment 14Inservice Testing Pump TableEMERGENCY FEEDWATER (Page 1)Pump EPN TestGroup1-EF-P-1 BSafetyClass3Pump Pump NominalType .Driver SpeedP&ID P&IDCoor.Test Type Test Relief Tech. CommentsFreq. Request Pos.C T 3800 302-082 D-7BBBBBBPump Name Steam Driven Emergency Feed Water Pump1-EF-P-2A B 3 C M 3570 302-082 F-6BBBBPump Name Electric Driven Emergency Feed Pump1-EF-P-2B B 3 C M 3570 302-082 B-6BBBBPump Name Electric Driven Emergency Feed PumpDifferentialPressure -CompDifferentialPressure -Grp BFlow Rate -CompFlow Rate -Grp BSpeed -CompSpeed -Grp BVibration -CompDifferentialPressure -CompDifferentialPressure -Grp BFlow Rate -CompFlow Rate -Grp BVibration -CompDifferentialPressure -CompDifferentialPressure -Grp BFlow Rate -CompFlow Rate -Grp BVibration -CompY2QY2Q.Y2QY2Y2QY2QY2Y2QY2QY2Revision 0October 25, 2013A14 -9 Three Mile Island Unit #1Inservice Testing Program PlanAttachment 14Inservice Testing Pump TableMAKEUP & PURIFICATION (Page 1)Pump EPN Test Safety Pump Pump .NominalGroup Class Type Driver SpeedP&ID P&IDCoor.Test Type Test Relief Tech. CommentsFreq. Request Pos.1-MU-P-1A B 2 C M 6800 302-661 C-5BBBPump Name MAKEUP & PURIFICATIONPUMP "A"1-MU-P-1B A 2 C M 6800 302-661 C-4AAAAAPump Name MAKEUP & PURIFICATION PUMP "B"1-MU-P-lC B. 2 C M 6800 302-661 C-3BBBPump Name MAKEUP & PURIFICATION PUMP "C"DifferentialPressure -CompDifferentialPressure -Grp BFlow Rate -CompVibration -CompDifferentialPressure -CompDifferentialPressure -Grp AFlow Rate -CompFlow Rate -Grp AVibration -CompVibration -Grp A*DifferentialPressure -CompDifferentialPressure -Grp BFlow Rate -CompVibration -CompY2QY2Y2Y2QY2QY2QY2QY2Y2Revision 0October 25, 2013A14 -10 Three Mile Island Unit #1Inservice.Testing Program PlanAttachment 14Inservice Testing Pump TableNUCLEAR SERVICES RIVER WATER (Page 1)Pump EPN TestGroup.1-NR-P-1A ASafetyClass3 .Pump Pump NominalType Driver SpeedP&ID P&IDCoor.Test Type Test Relief Tech. CommentsFreq. Request Pos.VLS M 1200 .302-202 A-10AAAAAPump Name NUCLEAR SERVICE RIVER WATER PUMP "A"1-NR-P-1B A .3 VLS M 1200 302-202 A-9AAAAAPump Name NUCLEAR SERVICE RIVER WATER PUMP "B"1-NR-P-1C A 3 VLS M 1200 302-202 A-9AAAAAPump Name NUCLEAR SERVICE RIVER WATER PUMP 'C"* DifferentialPressure -CompDifferentialPressure -Grp AFlow Rate -CompFlow Rate -Grp AVibration -CompVibration -Grp ADifferentialPressure -CompDifferentialPressure -Grp AFlow Rate -CompFlow Rate -Grp AVibration -CompVibration -Grp ADifferentialPressure -CompDiffeirentialPressure -Grp AFlow Rate -CompFlow Rate -Grp AVibration -CompVibration -Grp AY2aY2Y2aY2Y2QY2QY2QY2QY2QRevision 0October 25, 2013A14- 11 Three Mile Island Unit #1Inservice Testing Program PlanAttachment 14Inservice Testing Pump TableNUCLEAR SERVICES CLOSED COOLING WATER (Page 1)Pump EPN TestGroupSafetyClassPump Pump NominalType Driver SpeedP&ID P&IDCoor.Test Type Test ReliefFreq. RequestTech. CommentsPos.1-NS-P-1A A 3 C M 1770 302-610 G-3 DifferentialPressure -CompA DifferentialPressure -Grp AA Flow Rate -CompA Flow Rate -Grp AA Vibration -CompA Vibration -Grp APump Name NUCLEAR SERVICE CLOSED COOLING WATER PUMP "A"1-NS-P-1B A 3 C M 1770 302-610 G-3 DifferentialPressure -CompA DifferentialPressure -Grp AA Flow Rate -CompA Flow Rate -Grp AA Vibration -CompA Vibration -Grp APump Name NUCLEAR SERVICE CLOSED COOLING WATER PUMP "B"Y2Q PR-01Y2QY2QPR-01PR-01Y2Q PR-01Y2QY2QPR-01PR-011-NS-P-1C A 3 C M 1770 302-610 G-2 DifferentialPressure -CompA DifferentialPressure -Grp AA Flow Rate -CompA Flow Rate -Grp AA Vibration -CompA Vibration -Grp APump Name NUCLEAR SERVICE CLOSED COOLING WATER PUMP "C"Revision 0October 25, 2013 A14 -12Y2Q PR-01Y2QY2QPR-01PR-01 Three Mile Island Unit #1Inservice Testing Program PlanAttachment 14Inservice Testing Pump TableREACTOR BUILDING EMERGENCY COOLING WATER (Page 1)Pump EPN Test SafetyGroup ClassPump PumpType DriverNominalSpeedP&ID P&IDCoor.Test Type1-RR-P-1A B 3 VLS M 1200 302-611. D-2 DifferentialPressure -CompB DifferentialPressure -Grp BB Flow Rate -CompB Vibration -CompPump Name RB EMERGENCY COOLING RIVER WATER PUMP "A"1-RR-P-1B B 3 VLS M 1200 301-611 D-2 DifferentialPressure -CompB DifferentialPressure -Grp BB Flow Rate -CompB Vibration -CompPump Name RB EMERGENCY COOLING RIVER WATER PUMP "B"Revision 0October 25, 2013 A14- 13Test Relief Tech. CommentsFreq. Request Pos.Y20Y2Y2Y2QY2Y2 Three Mile Island Unit #1Inservice Testing Program PlanAttachment 14Inservice Testing Pump TableSPENT FUEL COOLING (Page l)Pump EPN Test. Safety Pump .Pump NominalGroup Class Type Driver SpeedP&ID P&ID* Coor.Test Type Test Relief Tech. CommentsFreq. Request Pos.1-SF-P-1A A 3 C M 1800 302-630 F-6AAPump Name SPENT FUEL COOLING PUMP "A"A 3 C M 1800 302-630DifferentialPressure -Grp AFlow Rate -Grp AVibration -Grp ADifferential .Pressure -Grp AFlow Rate -Grp AVibration -Grp A1-SF-P-1BD-6Q PR-02QQQQQPR-02PR-02PR-02PR-02PR-02AAPump Name SPENT FUEL COOLING PUMP "B"Revision 0October 25, 2013A14 -14 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 15INSERVICE TESTING VALVE TABLERevision 0October 25, 2013A15- 1  5Inservice Testing Valve TableREACTOR BUILDING PURGE (Page 1)Valve EPN Safety Category Size Valve Act. Active i Normal Safety P&&ID P&&IDClass Type Type Passive Position Position Coor.I-AH-V-11A 3 B 5 3W AO A T 0 302-847 G-7Valve Name CONTROL BLDG VENT UNIT "A" COOLING COIL DISCH VLV5 3W AO A T 0 302-847 G-41-AH-V-11B .*3 BValve Name CONTROL BLDG VENT.UNIT "B" COOLING COIL DISCH VLV2 A 48 BTF. AO A C C .302-831 G-6I-AH-V-1A1-AH-V-1B1-AH-V- 1C1-AH-V-1DValve Name CONTAINMENT ISOLATION -RB PURGE OUTLET ISOL VALVE.48 BTF. MO A C C 302-831 F-6Test TestType Freq.FO :M3STO M3FO *M3STO M3FC M3LTJ AJPI Y2..STC M3LTJ AJPI Y2STC M3LTJ AJPI Y2STC M3FC M3LTJ AJPI Y2STC M3IST-013IST-01 3Relief .Deferred Tech.Request. Just. Pos.IST-0132 *AValve Name CONTAINMENT ISOLATION -RB PURGE OUTLET ISOL VALVE2 A 48 BTF MO A C *C 302-831
* C-6Valve Name CONTAINMENT ISOLATION -RB PURGE INLET ISOL VALVE2 A 48 BTF AO A C C 302-831 C-6Valve Name CONTAINMENT ISOLATION -RB PURGE INLET ISOL VALVEIST-013Revision 0October 25, 2013A15-2  5Inservice Testing Valve TableEMERGENCY FEEDWATER (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.1-AS-V-43 B/C 4 SCK MO P C .C 302-011 E-5 PI Y2Valve Name AUX STEAM STOP CHECK VALVE SUPPLY TO EF-UlRevision 0October 25, 2013A15 -3 Valve EPN1-BS-V-11031-BS-V-11041-BS-V-11051-BS-V-11061-BS-V-11071-BS-V-11081-BS-V-IA1-BS-V-1BSafetyClass222.2222Attachment 15Inservice Testing Valve TableREACTOR BUILDING SPRAY (Page 1)Category Size Valve Act. Active / Normal Safety P&&ID P&&IDType Type Passive Position Position Coor.C 0.5 XFC SA A 0 ..0 302-712 G-8Valve Name RB PRESSURE INSTRUMENT EXCESS FLOW CHECKC 0.5 XFC SA A 0 0 302-712 G-6Valve Name RB PRESSURE INSTRUMENT EXCESS FLOW CHECKC 0.5 XFC SA A 0 0 302-712 F-8Valve Name RB PRESSURE INSTRUMENT EXCESS FLOW CHECKC 0.5 XFC SA A 0 0 302-712 F-6Valve Name RB PRESSURE INSTRUMENT EXCESS FLOW CHECKC 0.5 XFC SA A 0 0 302-712 D-8Valve Name RB PRESSURE INSTRUMENT EXCESS FLOW CHECKC 0.5 XFC SA A 0 0 302-712 D-6Valve Name RB PRESSURE INSTRUMENT EXCESS FLOW CHECKB 8 GL MO A C O/C 302-712 A-7Valve Name BS-P1A DISCHARGE ISOLATION VALVE2 B 8 GL MO A CO/C 302-712 B-7Test Test Relief Deferred Tech.Type Freq. Request Just. Pos.CO M3CO M3CO M3CO M3CO M3CO M3PI Y2STC M3STO M3PI Y2STC M3STO M3CCD CMCOD CMCCD CMCOD CMPI Y2STC M3STO M3PI Y2STC M3STO M3RT Y10RT Y10LTH Y2Valve Name BS-P1B DISCHARGE ISOLATION VALVE1-BS-V-30A 2 C 8 CK SA A C O/C 302-712 A-7Valve Name CONTAINMENT ISOLATION -BS NOZZLE INLET CHECK VLV1-BS-V-30B 2 C 8 CK SA A C O/C 302-712 B-7Valve Name CONTAINMENT ISOLATION -BS NOZZLE INLET CHECK VLV1-BS-V-3A 2 B 10 GA MO A C O/C 302-712 A-3Valve Name BS-P1A SUCTION VALVE2 B 10 GA MO A1-BS-V-3B31-BS-V-45A1-B3S-V-45B31-BS-V-59C222CCAValve Name BS-P1B SUCTION VALVE1 RV SA A C.Valve Name BS-PlA SUCTION RELIEF1 RV SA A CValve Name BS-P1B SUCTION RELIEF6 GA M P LCValve Name TEST LINE ISOLATION VALVE TO BWSTO/C 302-712 B-3O/C 302-712 B-5O/C 302-712 C-5C 302-712 B-6Revision 0October 25, 2013A15-4 Valve EPN1-CA-V-131-CA-V-1771-CA-V-1891-CA-V-1921-CA-V-21-CA-V-4431-CA-V-4461-CA-V-449A1-CA-V-449B1-CA-V-4A1-CA-V-4BSaClAttachment 15Inservice Testing Valve TableREACTOR PLANT CHEMICAL ADDITION (Page 1)afety Category Size Valve Act. Active / Normal Safety P&&ID P&&IDlass Type Type Passive Position Position Coor.1 A 0.5 GL .MO A O/C C 302-671 D-7Valve Name CONTAINMENT ISOLATION -RCS LETDOWN SAMPLE VALVE3 C 1 CK SA A SYS 0 302-670 D-3Valve Name CA-T1 TO MAKEUP SYSTEM CHECK VALVE2 A 2 GA AO P C C 302-669 G4Valve Name CONTAINMENT INTEGRITY -RECLAIMED WATER TO RB VLV2 A/C 2 CK SA P *C C 302-669 G-3Valve Name CONTAINMENT ISOLATION -RECLAIMED FEED TO RB CHKA .1 GA AO A O/C C 302-671 D-7Valve Name CONTAINMENT ISOLATION -RC SAMPLE ISOLATION VALVE2 A/C 0.25 RV SA A C O/C 302-669 F-3Valve Name RECLAIMED WATER TO RB CONTAINMENT ISOL AND RELIEF2 A/C 0.5 RV SA .A C O/C 302-671 D-7Valve Name RC SAMPLE. CONTAINMENT ISOLATION AND RELIEF2 A/C 0.25 RV SA A C O/C 302710 G-4Valve Name PENETRATION 211 RELIEF VALVE2 A/C 0.25 RV SA A. C. O/C 302710 F4Valve Name PENETRATION 210 RELIEF VALVE2 A 2 GL MO A C C 302-701 G-5Valve Name CONTAINMENT ISOLATION -OTSG "A" FW SAMPLE VALVE2 A. 2 GL MO A C C 302-701 F-5Valve Name CONTAINMENT ISOLATION -OTSG "B" FW SAMPLE VALVETest Test Relief Deferred Tech.Type Freq. Request Just. Pos.LTJ AJPI Y2STC M3CC CS CSJ-15CO CS CSJ-15LTJ AJPI Y2BDO CMCCL CMLTJ AJFC .M3 IST-013LTJ AJPI Y2STC M3LTJ AJRT Y10*LTJ AJRT Y10LTJ AJRT Y10LTJ AJRT Y10LTJ AJPI Y2STC M3LTJ AJPI Y2STC M3Revision 0October 25, 2013A15 -5  5Inservice Testing Valve TableREACTOR PLANT CHEMICAL ADDITION (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.1-CA-V-5A2 A 2 GL AO A C C 302-701 G-4 FC M3LTJ AJPI Y2STC M3Valve Name CONTAINMENT ISOLATION -OTSG "A" FW SAMPLE VALVE2 A 2 GL AO A C C 302-701 F-4 FC M3LTJ AJPI Y2STC M3Valve Name CONTAINMENT ISOLATION -OTSG "B" FW SAMPLE VALVEIST-0131-CA-V-5BIST-013Revision 0October 25, 2013A15 -6  5Inservice Testing Valve TableCORE FLOOD (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.1-CF-V-12A 2. A/C 1 CK SA A O/C C 302-711 F-7 BDO CMCCL CMLTJ AJValve Name CONTAINMENT ISOLATION -CF-T1A MAKEUP CHECK VLV1-CF-V-12B 2 A/C 1 CK SA A O/C C 302-711 F-3 BDO CMCCL CMLTJ AJValve Name CONTAINMENT ISOLATION -CF-T1B MAKEUP CHECK VLV1-CF-V-19A 2 A 1 GA AO A O/C C 302-711 F-8 FC M3. IST-013LTJ AJPI Y2STC M3Valve Name CONTAINMENT ISOLATION -MU TO CF-T1A1-CF-V-19B 2 A 1 GA AO. *A O/C C 302-711 F-3 FC M3 .IST-013LTJ. AJPI Y2STC M3Valve Name CONTAINMENT ISOLATION -MU TO CF-T1B1-CF-V-1A 2 B 14 GA MO P 0 0 302-711 C-7 PI Y2Valve Name CORE FLOOD TANK A" -DISCHARGE ISOLATION VALVE1-CF-V-1B 2 B 1.4 GA MO P 0 0 302-711 C-3 PI Y2Valve Name CORE FLOOD TANK "B"- DISCHARGE ISOLATION VALVE1-CF-V-20A 2 *A 1 GA AO A O/C C 302-711 D-6 FC M3 IST-013LTJ AJPI Y2STC M3Valve Name CONTAINMENT ISOLATION -CF-T1A SAMPLE ISOL VLV1-CF-V-20B 2 A 1 GA AO A O/C C 302-711 D-5 FC M3 IST-013LTJ AJPI Y2STC M3Valve Name CONTAINMENT ISOLATION -CF-T1B SAMPLE ISOL VLV1-CF-V-21A 2 C 2 RV SA A C O/C 302-711 G-7 RT Y8Valve Name CORE FLOOD.TANK CF-T-1A RELIEF1-CF-V-21B 2 C 2 RV SA A C O/C 302-711 G-3 RT Y8Valve Name CORE FLOOD TANK.CF-T-1B RELIEFRevision 0October 25, 2013 A15 -7  5Inservice Testing Valve TableCORE FLOOD (Page 2)Valve EPN Safety Category Size Valve Act. Active / Normal Safety P&&ID P&&ID Test Test Relief Deferred Tech.Class2Type Type Passive Position Position Coor.A 1 GL MO A O/C C 302-711 D-71-CF-V-2A1-CF-V-2BType Freq. Request Just. Pos.LTJ AJPI Y2STC M3Valve Name CONTAINMENT ISOLATION -CF-T1A SAMPLE ISO VLV2 A 1 GL MO A C C 302-711D-4 LTJ AJPI Y2STC M3Valve Name CONTAINMENT ISOLATION -CF-T1 B SAMPLE ISO VLV1-CF-V-3A 2 B 1 GL MO P C C 31Valve Name CORE FLOOD TANK CF-T-1A REMOTE VENT1-CF-V-3B 2 B 1 GL MO P C C 31* Valve Name CORE FLOOD TANK CF-T-1B REMOTE VENT1-CF-V-46A 2 A/C 0.25 RV SA A C O/C 31Valve Name CONTAINMENT PENETRATION 348 RELIEF1-CF-V-46B 2 A/C 0.25 RV SA A C O/C 3'Valve Name CONTAINMENT PENETRATION 349 RELIEF1-CF-V-4A 1 A/C 14 CK SA A C O/C 3'Valve Name CORE FLOOD TANK "A" OUTLET CHECK VALVE1-CF-V-4B 1 A/C 14 CK SA A C O/C 3Valve Name CORE FLOOD TANK "B" OUTLET CHECK VALVE1-CF-V-5A 1 A/C 14 CK SA A C O/C 302-711 F-6 PI Y202-711 F-4 PI Y202-711 D-6 LTJ AJRT Y1002-711 D-4 LTJ AJRT Y1002-711 B-4 CCL CMCPF CMLTH Y202-711 B-7 CCL CMCPF CMLTH Y202-711 B-4 CCL RRCOF RRLTH Y2RJ-04RJ-04RJ-04RJ-041-CF-V-5BValve Name CF-T1A & DH PUMP DISCH CHECK VALVE1 A/C 14 CK SA A CValve Name CF-T1B & DH PUMP DISCH CHECK VALVEO/C 302-711 B-6 CCL RRCOF RRLTH Y2Revision 0October 25, 2013A15 -8
.Valve EPN1-CH-V-22A1-CH-V-22B1-CH-V-24SafetyClass333Attachment 15Inservice Testing Valve TableCONTROL BUILDING CHILLED WATER (Page 1)Category Size Valve Act. Active/I Normal. Safety .P&&ID P&&ID Test Test Relief Deferred Tech.Type Type Passive Position Position Coor. Type Freq. Request Just. Pos.C 4 CK SA A O/C .O/C 302-847 C-4 CC M3CO M3Valve Name AH-3CB CHILLED WATER DISCHARGE CHECK VALVEC 4 CK SA A 0/C o/C 302-847 B-4 CC M3CO M3Valve Name AH-3CB CHILLED WATER DISCHARGE CHECK VALVEC 1 .CK SA A C C 302-847 A-7 CC M3CO M3Valve Name NS SUPPLY TO RBCW CHECKRevision 0October 25, 2013A15- 9  5Inservice Testing Valve TableCONTAINMENT MONITORING (Page 1)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.1-CM-V-1 2 A 1 BALL AO A 0 C 302-721 F-7 FC M3 IST-013LTJ AJPI Y2STC M31-CM-V-21-CM-V-31-CM-V-4Valve Name CONTAINMENT ISOLATION -RB ATMOSPHERE SAMPLE VALVE2 A 1 BALL AO A 0 C 302-721 F-7 FC M3LTJ AJPI Y2STC M3Valve Name CONTAINMENT ISOLATION -RB ATMOS SAMPLE RETURN VLV2 A 1 BALL AO A 0 C 302-721 H-7 FC M3LTJ AJPI Y2STC M3Valve Name CONTAINMENT ISOLATION -RB ATMOSPHERE SAMPLE VALVE2 A 1 BALL AO A 0 C 302-721 H-7 FC M3LTJ AJPI Y2STC M3Valve Name CONTAINMENT ISOLATION -RB ATMOS SAMPLE ISOL VLVIST-013IST-013IST-013Revision 0October 25, 2013A15 -10  5Inservice Testing Valve TableCONDENSATE (Page 1)Valve EPN Safety Category Size Valve Act. Active / Normal Safety P&&ID P&&IDClass Type Type Passive Position Position Coor.Test Test Relief Deferred Tech.Type Freq. Request Just. Pos.1-CO-V-IlIA 3 B 4 GA MO A 0 C 302-101Valve Name CONDENSATE STORAGE TANK "A" ISOLATION TIE VALVE1-CO-V-111B 3 B 4 GA MO A 0 C 302-101Valve Name CONDENSATE STORAGE TANK "B" ISOLATION TIE VALVE1-CO-V-14A 3 B 12 GA MO A 0 C 302-101Valve Name CONDENSATE STORAGE TANK "A" ISOLATION VALVE1-CO-V-14B 3 B 12 GA MO A 0 C 302-101Valve Name CONDENSATE STORAGE TANK "B" ISOLATION VALVE1-CO-V-16A 3 C 10 .CK SA A SYS O/C 302-082Valve Name CONDENSATE CHECK VALVE -SUPPLY TO EFW PUMPS1-CO-V-16B 3 C 10 CK SA A SYS O/C" 302-082Valve Name CONDENSATE CHECK VALVE -SUPPLY TO EFW PUMPS1-CO-V-175A 3 C 2 CK SA A SYS: O/C 302-101VaIve Name EFW PUMP BEARING COOLING RETURN CHECK VALVE.1-CO-V-175B 3 C 2 CK SA.. A SYS O/C 302-101Valve Name EFW PUMP BEARING COOLING RETURN CHECK VALVE1-CO-V-25A 3 C 2 CK SA A. C C 302-101Valve Name CST-A DE-ICE LINE INLET CHECK1-CO-V-25B 3 C 4. CK SA A *C C 302-101Valve Name CST-B DE-ICE LINE INLET CHECKE-6 PISTCE-6 PISTCE-5 PISTCF-5 PISTCC-8 CCDCODCOFF-8 CCDCODCOFE-6 .CCDCODE-6. CCDCODC-4 BDOCCE-5 BDOCCY2M3Y2M3Y2M3Y2M3CMCM.Y2CMCMY2CMCMCMCMRRRRRRRRRJ-25 IST-014RJ-25RJ-25 .IST-014RJ-25Revision 0October 25, 2013A15- 11 Valve EPN1-DC-V-15A1-DC-V-15B1-DC-V-16A1-DC-V-16B1-I)C-V-17A1-DC-V-17B1-DC-V-18A1-[C-V-18B1-OC-V-52A1-DC-V-52BSafety.Class333333333Attachment 15Inservice Testing Valve TableDECAY HEAT CLOSED CYCLE COOLING WATER (Page 1)Category Size Valve Act. .Active I Normal Safety P&&ID P&&IDType Type Passive .Position Position Coor.C 0.5 RV SA "A C O/C .302-645 A-8Valve Name DH REMOVAL COOLER DH-C-1A SHELL SIDE RELIEFC 0.5 RV SA .A C O/C 302-645 C-9Valve Name DH REMOVAL COOLER DH-C-lB SHELL SIDE RELIEFC 0.5 RV SA A C O/C 302-645 C-6Valve Name BS-P-1A MOTOR AND BEARING COOLING.WATER RELIEFC 0.5 RV SA. A C. o/C 302-645 C-7Valve Name BS-P-1B MOTOR AND BEARING COOLING WATER RELIEFC 0.5 RV SA A C O/C 302-645 E-6Valve Name DH-P-1A MOTOR AND BEARING COOLING WATER RELIEFC 0.5 RV SA A C O/C 302-645 E-7Valve Name DH-P-1B MOTOR AND BEARING COOLING WATER RELIEFC 0.5 RV SA A C O/C 302-645. D-3Valve Name DC-P-1A BEARING COOLING WATER RELIEFC 0.5 RV SA
* A " C O/C 302-645 D-2Valve Name DC-P-1B BEARING COOLING WATER RELIEFC 0.75 RV SA A C O/C 302-645 F-10Valve Name DH SERVICE COOLER DC-C-2A RELIEFC 0.75 RV .SA A. C O/C 302-645 F-8Valve Name DH SERVICE COOLER DC-C-2B RELIEFTest Test Relief Deferred Tech.Type Freq. Request Just. Pos.RT Y10RT Y10RT Y10RT Y10RT Y10RT Y10RT Y10RT Y10RT Y10RT Y10Revision 0October 25, 2013A15 -12 Valve EPN1-DF-V-23A1-DF-V-23B1-DF-V-7A1-DF-V-7B1-DF-V-7C1-DF-V-7DSafetyClassN/AN/AN/AN/AN/AN/AAttachment 15Inservice Testing Valve TableEMERGENCY DIESEL GENERATORS FUEL SYSTEMS (Page 1)Category Size Valve Act. Active I Normal Safety P&&ID P&&ID Test Test Relief DeferredType Type Passive Position Position Coor. Type Freq. Request Just.C 2 SCK SA A C O/C 302-283 D-7 CC M3CO M3Valve Name DF-T1 FOOT VALVEC 2 SCK SA A C O/C 302-283 D-7 CC M3CO M3Valve Name DF-T1 FOOT VALVEC 1 CK SA A C O/C 302-351 D-7 CO M3Valve Name DF-PlA DISCHARGE CHECK VALVEC 1 CK SA A C O/C 302-351 D-6 CO M3Valve Name DF-P1B DISCHARGE CHECK VALVEC 1 CK SA A C O/C 302-351 D-3 CO M3Valve Name DF-PlC DISCHARGE CHECK VALVEC 1 CK SA A C O/C 302-351 D-3 CO M3Valve Name DF-P1D DISCHARGE CHECK VALVETech.Pos.IST-007IST-007IST-007IST-007IST-007IST-007IST-007IST-007Revision 0October 25, 2013A15-13  5Inservice Testing Valve TableDECAY HEAT REMOVAL (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.1-DH-VI- 1 A 12 GA MO A C ..O/C 302-640 E-7 LTH Y2PI Y2STC CS CSJ-02STO CS CSJ-02Valve Name DECAY HEAT SUCTION ISOLATION FROM "B" HOT LEG1-DH-V-13A 2 .C 0.75 .RV SA A C O/C 302-640 C-6 RT Y10Valve Name DH-P-1A SUCTION RELIEF1-DH-V-13B 2 C 0.75 RV SA A C O/C 302-640 C-4 RT, Y10Valve*Name DH-P-1B SUCTION RELIEF1-DH-V-14A 2 A/C 14 CK SA A C. O/C 302-640 C-3 CCL RR RJ-20COF RR RJ-20LT Y2Valve Name DH PUMP SUCTION FROM BWST CHECK VALVE1-DH-V-14B 2 A/C 14 CK SA A C O/C 302-640 B-4 CCL RR RJ-20COF RR RJ-20LT Y2Valve Name DH PUMP SUCTION FROM BWST CHECK VALVE1-DH-V-166A 2 C 0.5 CK SA A C O/C 302-640 G-7 CC CS CSJ-14CO CS CSJ-14Valve Name DH-V 004A INLET DISC PRESSURE EQUALIZATION CHECK1-DH-V-1666 2 C 0.5 CK SA A C O/C 302-640 H-7 CC CS CSJ-14CO CS CSJ-14Valve Name DH-V 004B INLET DISC PRESSURE. EQUALIZATION CHECK1-DH-V-16A 2 C 10 CK SA A SYS O/C 302-640 D-5 CC RR RJ-01'CO RR RJ-01Valve Name DH-P1A DISCHARGE CHECK VALVE1-DH-V-16B 2 C 10 CK SA A .SYS O/C 302-640 D-3 CC RR RJ-01CO RR RJ-01Valve Name DECAY HEAT PUMP "B" DISCHARGE CHECK VALVE1-DH-V-170 2 C 0.5 CK SA A C 0 302-640 E-7 BDC RR RJ-22CO RR RJ-22Valve Name DH-V 001 INTERDISC OVERPRESSURE RELIEF CHECK1-DH-V-171 2 C 0.5 CK SA A C 0 302-640 D-7 BDC RR RJ-22CO RR RJ-22Valve Name DH-V 002 INTERDISC OVERPRESSURE RELIEF CHECK1-DH-V-172 2 C 0.5 CK SA
* A C 0 302-640 D-7 BDC RR RJ-22CO RR RJ-22Valve Name DH-V1NV2 DEAD LEG PRESSURE EQUALIZATION RELIEF CHKRevision 0October 25, 2013 A15 -14 Valve EPN1-DH-V-18A1-DH-V-18B1-DH-V-21-DH-V-211-DH-V-22ASafetyClass221Attachment 15Inservice Testing Valve TableDECAY HEAT REMOVAL (Page 2)Category Size Valve ,Act. Active I Normal Safety P&&ID P&&IDType Type Passive Position Position Coor.C 0.75 RV .SA A C .O/C 302-640 F-5Valve Name DH LOOP A INJECTION HEADER RELIEFC 0.75 RV SA A C O/C 302-640 F-4Valve Name DH LOOP B INJECTION HEADER RELIEFA 12 GA MO A C o/C 302-640 E-7AA/CValve Name CONTAINMENT ISOLATION -DH DROP LINE/PUMP SUCTION3 .GL M P LC LC 302-640 H-5Valve Name DH PUMPS DISCHARGE TEST ISOLATION VALVE* 10 CK SA A C O/C 302-640 G-8Valve Name CONTAINMENT ISOLATION -DH-P1A DISCHARGE CHK TO CF1-DH-V-22B 1 A/C 10 CK SA A C O/C 302-640 G-8Valve Name CONTAINMENT ISOLATION -DH-P1 B DISCH CHK TO CF1-DH-V-3 2 .B 12 GA MO A C O/C 302-640 E-6Test TestType Freq.RT Y10RT Y10LTH Y2PI Y2STC CSSTO CSLT Y2CCL RRCOF RRLTH Y2CCL RRCOF RRLTH Y2PI Y2STC M3STO M3RT Y10EO Y2EO Y2PI Y2STC M3STO M3PI Y2STC M3STO M3BDO RRCC RRLT Y2Relief Deferred Tech.Request Just. Pos.CSJ-02CSJ-02RJ-04RJ-04RJ-04RJ-04RJ-24 IST-014RJ-241-DH-V-371-DH-V-38A1-DH-V-38B1-DH-V-4A1-DH-V-4B1-DH-V-502222CB.BBValve Name CONTAINMENT ISOLATION -DH DROP LINE VLV0.75 RV SA A C O/C 302-640 E-7Valve Name DECAY HEAT DROP LEG INTERVALVE RELIEF* 6 GA M A LC O/C " 302-640 F-5Valve.Name DECAY HEAT CROSSOVER VALVE6 GA M A LC o/C 302-640 F-5Valve Name DECAY HEAT CROSSOVER VALVE10 GA MO A C O/C 302-640 G-6Valve Name CONTAINMENT ISOLATION -DH-P1A DISCHARGE ISOL VLV2 B 10 GA MO A C O/C 302-640 G-6Valve Name CONTAINMENT ISOLATION -DH-P1B DISCHARGE ISOL VLV2 A/C 4 CK SA A C C 302-640 B-5*Valve Name SPENT FUEL RETURN CLEANUP CHECK VALVERevision 0October 25, 2013A15 -15  5Inservice Testing Valve TableDECAY HEAT REMOVAL (Page 3)Valve EPN Safety Category Size Valve Act. Active / Normal Safety P&&ID P&&ID Test TestClass Type Type Passive Position Position Coor. Type Freq.Relief Deferred Tech.Request Just. Pos.1-DH-V-57A1-DH-V-57B1-DH-V-5A1-DH-V-5B1-DH-V-60A1-DH-V-60B1-DH-V-641-DH-V-671-DH-V-691-DH-V-6A1-DH-V-6B2 C 0.75 RV SA A CValve Name DH-P-1A SUCTION FROM BWST RELIEF2 C 0.75 RV SA A CValve Name DH-P-1 B SUCTION FROM BWST RELIEF2 B 14 GA MO A 0Valve Name DECAY HEAT SUCTION VALVE FROM BWST2 B 14 GA MO A 0Valve Name DH PUMP SUCTION FROM BWSTNA C 0.5 RV SA A CValve Name CA SYSTEM TO DH-P-1A SUCTION RELIEFNA C 0.5 RV SA A CValve Name CA SYSTEM TO DH-P-1B SUCTION RELIEF2 A 2. GL M A LCO/C 302-640 D-3 RT Y10O/C 302-640 B-3 RT Y10O/C 302-640 C-2 PI Y2STC M3O/C 302-640 B-3 PI Y2STC M3O/C 302-640 C-5 RT Y10O/C 302-640 C-3 RT Y10O/C 302-640 F-6 EC Y2EO Y2LTJ AJ-AY.ISOL VLVO/C 302-640 F-7 RT Y10O/C 302-640 F-7 CCL CMCOF CMLTJ AJSPRAY LINE.O/C 302-640 C-7 PI Y2STC RRSTO RRRC SUCTION VLVO/C 302-640 B-7 Pl Y2STC RRSTO RR22CA/CValve Name CONTAINMENT ISOLATION -DH TO PZR SPR0.75 RV SA .A CValve Name PRESSURIZER SPRAY LINE RELIEF1.5 CK SA A CValve Name CONTAINMENT ISOLATION -DH TO PZR AUX2 1B 4 GA MO A .CValve Name CONTAINMENT ISOLATION -RB SUMP RECIF2 B 14 GA MO A CRJ-21RJ-21RJ-21RJ-21Valve Name CONTAINMENT ISOLATION -RB SUMP RECIRC SUCTIONI-DH-V-7A 2 B 4 GA MO A C 0 302-640 G-3Valve Name DH-CiA DISCHARGE VALVE TO MAKEUP SYSTEM1-DH-V-7B 2 B 4 GA MO A C 0 302-640 G-3Valve Name DH-ClB DISCHARGE VALVE TO MAKEUP SYSTEMRevision 0October 25, 2013 A15 -16PI Y2STO M3PI Y2STO :M3 Valve EPN1-DR-V-1A1-DR-V-1B1-DR-V-24A1-DR-V-24B1-DR-V-7A1-DR-V-7B1-DR-V-8A1-DR-V-8BAttachment 15Inservice Testing Valve TableDECAY HEAT RIVER WATER (Page 1)Safety Category Size Valve Act. Active Normal Safety P&&ID P&&IDClass Type Type Passive Position Position Coor.3 B 20 BTF" MO A C 0 0 302-202 C-7Valve Name DR-01A DISCHARGE.VALVEB 20 BTF. MO .A C 0 302-202 C-6Valve Name DR-P1B DISCHARGE VALVE3 B 3 BALL MO P 0 0 302-203 A-4Valve Name DR-S-1A BACKWASH VALVE3 B 3 BALL MO" P 0 0 302-203 A-4Valve Name DR-S-1B BACKWASH VALVE3 C 2 CK SA. A C o/C 302-202 B-7Valve Name DR-PlA COLUMN VACUUM BREAKER (Check Valve)3 C. .2 cK SA A C. O/C 302-202 B-6Valve Name DR-P1B COLUMN VACUUM BREAKER (Check Valve)3 C 1.5 RV SA A C O/C 302-202 G-7Valve Name DECAY HEAT SERVICE COOLER DC-C-2A RELIEF3 C 1.5 RV SA A C O/C 302-202 F-7Valve Name DECAY HEAT SERVICE COOLER DC-C-2B RELIEFTest Test Relief Deferred Tech.Type Freq. Request Just. Pos.P1 Y2STO M3PI Y2STO M3PI Y2PI Y2CC M3CO M3CC M3CO M3RT Yb0RT Y10Revision 0October 25, 2013A15 -17 Valve EPNI-EF-V-1 1A1-EF-V-11B1-EF-V-12A1-EF-V-12B1-EF-V-131-EF-V-19A1-EF-V-19B1-EF-V-211-EF-V-2A1-EF-V-2B1-EF-V-30ASafetyClass3322333333.2Attachment 15Inservice Testing Valve TableEMERGENCY FEEDWATER (Page 1)Category Size Valve Act. Active / Normal Safety P&&ID P&&IDType Type Passive Position Position Coor.C 4 CK SA A SYS O/C 302-082 F-6Valve Name EF-P2A DISCHARGE CHECK VALVEC 4 CK SA A SYS O/C 302-082 B-6Valve Name EF-P2B DISCHARGE CHECK VALVEC 6 CK SA A SYS O/C 302-082 D-4Valve Name CONTAINMENT ISOLATION -EFW TO OTSG "A" CHECK VLVC 6 CK SA A SYS O/C 302-082 B-3Valve Name CONTAINMENT ISOLATION -EFW TO OTSG "B" CHECK VLVC 6 CK SA A SYS O/C 302-082 E-6Valve Name EF-P1 DISCHARGE CHECK VALVEC 1.5 CK SA A SYS O/C 302-082 F-6Valve Name EF-P2A RECIRC LINE CHECK VALVEC 1.5 CK SA A SYS O/C 302-082 B-6Valve Name EF-P2B RECIRC LINE CHECK VALVEC 2 CK SA A SYS O/C 302-082 D-6Valve Name EF-P1 RECIRCULATION CHECK VALVEB 6 GA MO A 0 O/C 302-082 F-5Valve Name EFW PUMP DISCHARGE HEADER CROSS CONNECT VALVEB 6 GA MO A 0 O/C 302-082 D-5Valve Name EFW PUMP DISCHARGE HEADER CROSS CONNECT VALVEB 3 PLG AO A C O/C 302-082 F-4Test TestType Freq.CC RRCOF RRCC RRCOF RRCCF RRCOF RRCCF RRCOF RRCC RRCO RRCC M3CO M3CC M3CO M3CC M3CO M3PI Y2STC M3PI Y2STC M3EC Y2EO Y2FC M3STC M3STO M3Relief Deferred Tech.Request Just. Pos.RJ-05RJ-05RJ-05RJ-05RJ-05RJ-05RJ-05RJ-05RJ-07RJ-07IST-013Valve Name EFW TO OTSG "A" FLOW CONTROL VALVERevision 0October 25, 2013A15 -18  5Inservice Testing Valve TableEMERGENCY FEEDWATER (Page 2)Safety Category Size Valve Act. Active / Normal Safety P&&ID P&&IDClass Type Type Passive Position Position Coor.2 B 3 PLG AO A C O/C 302-082 B-5Valve EPN1-EF-V-30BValve Name EFW TO OTSG "B" FLOW CONTROL VALVE1-EF-V-30C 2 B 3 PLG AO A CValve Name EFW TO OTSG "A" FLOW CONTROL VALVE1-EF-V-30D 2 B 3 PLG AO A CO/C 302-082 B-5O/C 302-082 G-5Test Test Relief* Deferred Tech.Type Freq. Request Just. Pos.EC Y2EO Y2FC M3 IST-013STC M3STO M3EC Y2EO Y2FC M3 IST-013STC M3STO M3EC Y2EO Y2FC M3 IST-013STC M3STO M3RT Y4RT Y8RT Y8PI Y2STO M3PI Y2STO M31-EF-V-351-EF-V-39A1-EF-V-39B1-EF-V-41-EF-V-5Valve Name EFW TO OTSG "B" FLOW CONTROL VALVE3 C 2 RV SA A C O/C 302-082 F-1Valve Name EF-P1 BEARING COOLING WTR RETURN RELIEF3 C 1 RV SA A C O/C 302-082 F-3Valve Name EF-P2A BEARING COOLING WTR RETURN RELIEF3 C 1 RV SA A C O/C 302-082 F-2Valve Name EF-P2B BEARING COOLING WTR RETURN RELIEF3 B 6. GA MO A C O/C 302-611 E-1Valve Name EMERGENCY RIVER WATER SUPPLY TO EFW PUMPS3 B 6 GA MO A C 0/C 302-611 F-1Valve Name EMERGENCY RIVER WATER SUPPLY TO EFW PUMPSRevision 0October 25, 2013A15- 19  5Inservice Testing Valve TableEMERGENCY DIESEL GENERATORS SUPPORT SYST (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.1-EG-V-10A NA C 0.75 CK SA A C C 302-351 F-8 BDO. M3 IST-014CC M3 IST-007Valve Name EG-T1A-1 AIR START SYS. RECEIVER INLET CHECK1-EG-V-10B NA C 0.75 CK SA A C C 302-351 F-1 BDO M3 IST-014CC M3 IST-007Valve Name EG-T1B-1 AIR START SYS. RECEIVER INLET CHECK1-EG-V-10C NA C 0.75 CK SA A C C 302:351 D-8 BDO M3 IST-014CC M3 IST-007Valve Name EG-T1A-2 AIR START SYS. RECEIVER INLET CHECK1-EG-V-10D NA C 0.75 CK SA A C C 302-351 D-1 BDO M3 IST-014CC M3 IST-007Valve Name EG-T1B-2 AIR START RECEIVER INLET CHECK1-EG-V-16A N/A B 1.5 DIA SO A C O/C 302-351 F-6 STO M3 IST-007Valve Name AIR START FOR DIESEL GENERATOR 1A1-EG-V-16B N/A B 1.5 DIA SO A C O/C 302-351 F-3 STO M3 IST-007Valve Name AIR START FOR DIESEL GENERATOR 1B1-EG-V-16C N/A B 1.5 DIA SO A C O/C 302-351 E-6 STO M3 IST-007Valve Name AIR START FOR EG-Y1A1-EG-V-16D N/A B 1.5 DIA SO A C O/C 302-351 E-3 STO M3 IST-007Valve Name AIR START FOR EG-Y1B1-EG-V-2A N/A C 0.5 RV SA A C O/C 302-351 G-8 RT Y10Valve Name STARTING AIR RECEIVER EG-T-1A-1 RELIEF1-EG-V-2B N/A. C 0.5 RV SA A C O/C 302-351 G-1 RT Y10Valve Name STARTING AIR RECEIVER EG-T-1B-1 RELIEF1-EG-V-32A N/A C 4 CK .SA A SYS 0 302-354 C-6 D&I Y8Valve Name EG-C3AJA COOL RADIATOR OUTLET CHECK VALVE1-EG-V-32B N/A C 4 CK SA A SYS 0 302-354 C-3 D&I Y8Valve Name EG-C3B/A COOL RADIATOR OUTLET CHECK VALVERevision 0October 25, 2013 A15 -20  5Inservice Testing Valve TableEMERGENCY DIESEL GENERATORS SUPPORT SYST (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.1-EG-V-32C N/A C 4 CK SA A SYS 0 302-354Valve Name EG-C3A/B COOL RADIATOR OUTLET CHECK VALVEl-EG-V-32D N/A C 4 CK SA A SYS 0 302-354Valve Name EG-C3B/B COOL RADIATOR OUTLET CHECK VALVE1-EG-V-34A N/A C 5 CK SA A SYS C 302-354Valve Name JACKET COOLANT RADIATOR BYPASS CHECK VALVE1-EG-V-34B N/A C 5 CK SA A SYS C 302-354Valve Name JACKET COOLANT RADIATOR BYPASS CHECK VALVE1-EG-V-3A N/A C 0.5 RV SA A C O/C 302-351Valve Name STARTING AIR RECEIVER EG-T-1A-2 RELIEF1-EG-V-3B N/A *C 0.5 RV SA A C O/C 302-351Valve Name STARTING AIR RECEIVER EG-T-1B-2 RELIEF1-EG-V-48A N/A C 4 CK SA A .C O/C , 302-354Valve Name AIR COOLING PUMP "A" DISCHARGE CHECK VALVE.1-EG-V-48B N/A C 4 CK SA A C O/C 302-354Valve Name AIR COOLING PUMP "B' DISCHARGE CHECK VALVE1-EG-V-77A N/A C 0.5 CK. SA A SYS O/C 302-353Valve Name EG-Y-1A TURBO-CHARGER LUBE OIL SUPPLY CHECK1-EG-V-77B N/A C 0.5 CK SA A SYS O/C 302-353Valve Name EG-Y-1B TURBO-CHARGER LUBE OIL SUPPLY CHECK1-EG-V-7A N/A C RV SA A C O/C 302-353Valve Name EG-Y-1A ENGINE-DRIVEN FO PUMP EG-P-9A DISCH RELIEFC-5C-2E-5E-1E-8E-1F-6F-3G-7G-3D&ID&ID&ID&IRTRTD&ID&ID&IY8Y8Y8Y8Y10Y10Y8Y8Y8D&I Y8'.G-10 RT. Y10G-5 RT Y101-EG-V-7B N/A .C-RV SA A C O/C 302-353Valve Name EG-Y-1B ENGINE-DRIVEN FO PUMP EG-P-9B DISCH RELIEFRevision 0October 25, 2013A15 -21  5Inservice Testing Valve TableFIRE 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.1-FS-V-401 2 A 4 GL M P LC C 302-231-2 D-5 LTJ AJValve Name CONTAINMENT ISOLATION- FIRE SERVICE WATERRevision 0October 25, 2013 A15 -22  5Inservice Testing Valve TableFEEDWATER (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.1-FW-V-12A 2 C 20 CK SA A 0 C 302-081 B-6 BDO CMCCD CMValve Name CONTAINMENT ISOLATION -OTSG "A" INLET CHECK VALVE1-FW-V-12B 2 C 20 CK SA A 0 C 302-081 B-3 BDO CMCCD CMValve Name CONTAINMENT ISOLATION -OTSG "B" INLET CHECK VALVE1-FW-V-16A NA B 6 ANG AO A 0 C 302-081 B-6 PI Y2STC CS CSJ-10Valve Name MAIN FEEDWATER STARTUP FLOW CONTROL VALVE1-FW-V-16B NA B 6 ANG AO A 0 C 302-081 B-3 PI Y2STC CS CSJ-10Valve Name MAIN FEEDWATER STARTUP FLOW CONTROL VALVE1-FW-V-17A NA B 16 ANG AO A 0 C 302-081 C-6 PI Y2STC CS CSJ-10Valve Name MAIN FEEDWATER CONTROL VALVE1-FW-V-17B NA B 16 ANG AO A 0 C 302-081 C-3 PI Y2STC CS CSJ-10Valve Name MAIN FEEDWATER CONTROL VALVE1-FW-V-5A NA B 20 GA MO A 0 C 302-081 C-6 PI Y2STC CS CSJ-10Valve Name MAIN FEEDWATER "A" BLOCK VALVE1-FW-V-5B NA B 20 GA MO A 0 C 302-081 C-3 PI Y2STC CS CSJ-10Valve Name MAIN FEEDWATER "B" BLOCK VALVE1-FW-V-92A NA B 6 GA MO A 0 C 302-081 B-6 PI Y2STC CS CSJ-10Valve Name OTSG "A" STARTUP FEEDWATER BLOCK VALVE1-FW-V-92B NA B 6 GA MO A 0 C 302-081 B-3 PI Y2STC CS CSJ-10Valve Name OTSG "B" STARTUP FEEDWATER BLOCK VALVERevision 0October 25, 2013 A15-23  5Inservice Testing Valve TableCONTAIMENT HYDROGEN MONITORING (Page 1).Valve EPN Safety Category Size Valve Act. Active/ Normal Safety P&&ID P&&IDClass Type Type Passive Position Position Coor.1-HM-V-1A 2 A 1 GL -SO A C O/C 302-674 F-5Valve Name CONTAINMENT ISOLATION -H2 MONITOR "A" OUTLET ISOL1-HM-V-1B 2 A 1 GL SO A C O/C 302-674 C-5Valve Name CONTAINMENT ISOLATION -H2 MONITOR "B" OUTLET ISOL1-HM-V-2A 2 A 1 GL SO A C O/C 302-674 E-5Valve Name CONTAINMENT ISOLATION- "A" H2 MONITOR INLET ISOL1-HM-V-2B 2 A 1 GL SO A C O/C 302-674 C-5Valve Name CONTAINMENT ISOLATION -"B" H2 MONITOR INLET ISOL1-HM-V-3A 2 A 1 GL SO A C O/C 302-674 F-5Valve Name CONTAINMENT ISOLATION- "A" H2 MONITOR OUTLET ISOL1-HM-V-3B 2 A 1 GL SO A C O/C 302-674 C-5Test Test* Relief Deferred Tech.Type Freq. Request Just. Pos.FC M3 IST-013LTJ AJPI Y2STC M3STO M3FC M3LTJ AJPI Y2STC M3STO M3FC M3LTJ AJPI Y2STC M3STO M3FC M3LTJ AJPI Y2STC M3STO M3FC M3LTJ AJPI Y2STC M3STO M3FC M3LTJ AJPI Y2STC M3STO M3IST-013IST-013IST-013IST-013IST-013Valve Name CONTAINMENT ISOLATION -"B" H2 MONITOR INLET ISOLRevision 0October 25, 2013A15 -24  5Inservice Testing Valve TableCONTAIMENT HYDROGEN MONITORING (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.1-HM-V-4AA1 GL SO A C O/C 302-674 E-5 FC M3.* LTJ AJPI Y2STC M3STO M3Valve Name CONTAINMENT ISOLATION -"A" H2 MONITOR INLET ISOLIST-0131-HM-V-4B2 A 1 GL SO A C O/C 302-674 C-5 FC M3LTJ AJPI Y2STC M3STO M3Valve Name CONTAINMENT ISOLATION -"B"H2 MONITOR INLET ISOLIST-013Revision 0October 25, 2013A15 -25 Valve EPN1-HP-V-11-HP-V-6Attachment 15Inservice Testing Valve TableHYDROGEN PURGE DISCHARGE SYSTEM (Page 1)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.2 A 6 GA *M P LC C 302-721 *B-7 LTJ AJValve Name CONTAINMENT ISOLATION -H2 PURGE ISOLATION VALVE2 A 6 GA M P LC *C 302-721 B-7 LTJ AJValve Name CONTAINMENT ISOLATION -H2 PURGE RB ISOL VALVERevision 0October 25, 2013A15 -26  5Inservice Testing Valve TablePOST LOCA HYDROGEN RECOMBINER SYSTEM (Page 1)Valve EPN Safety Category Size Valve Act. Active! Normal Safety P&&ID P&&IDClass Type Type Passive Position Position Coor.1-HR-V-22A 2 A 2 GL SO P C C 302-722 D-7Valve Name CONTAINMENT ISOLATION -"RB EXHAUST TO H2 RECOMB1-HR-V-22B 2 A 2 GL SO P C, C 302-722 C-7Valve Name CONTAINMENT ISOLATION -RB EXHAUST TO H2 RECOMB1-HR-V-23A 2 A 2 GL SO P C C 302-722 C-7Valve Name CONTAINMENT ISOLATION -H2 RECOMB RETURN ISOL VLV1-HR-V-23B 2 A 2 GL SO P C C 302-722 B-7Valve Name CONTAINMENT ISOLATION -H2 RECOMB RETURN ISOL VLV1-HR-V-2A. 2 A 2 GL M P LC C 302-722 E-5Valve Name CONTAINMENT ISOLATION -HR-R1NAB RB SUPPLY VALVE1-HR-V-2B. 2 A 2 GL M P LC C 302-722 E-5Valve Name CONTAINMENT ISOLATION -HR-R1AIB RB SUPPLY1-HR-V-4A 2 A 2 GL M P. LC C 302-722 F-5Valve Name CONTAINMENT ISOLATION -HR-RIAB RB RETURN VALVE1-HR-V-4B 2 A 2 GL M P LC C 302-722 F-5Valve Name CONTAINMENT ISOLATION -HR-R1ANB RB RETURN VALVETest Test Relief Deferred Tech.Type Freq. Request Just. Pos.LTJ AJPI Y2LTJ AJPI Y2LTJ AJPI Y2LTJ AJPI Y2LTJ AJLTJ AJLTJ AJLTJ AJRevision 0October 25, 2013A15 -27  5Inservice Testing Valve TableINSTRUMENT AIR (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.1-IA-V-1621A N/A B 1 GA AO A T T 302-273 C-7 FO M3Valve Name 2-HR BACKUP AIR SYSTEM "A" PRESSURE REDUCER1-IA-V-1621B N/A B 1 GA AO A T T 302-273 C-3 FO M3Valve Name 2-HR BACKUP AIR SYSTEM "B" PRESSURE REDUCER1-IA-V-1624A N/A C 1.5 RV SA A C O/C 302-273 C-7 RT Y8Valve Name 2-HR BACKUP AIR SYSTEM "A" RELIEF1-IA-V-1624B N/A C 1.5 RV SA A C O/C 302-273 C-4 RT Y8Valve Name 2-HR BACKUP AIR SYSTEM "B" RELIEF1-IA-V-1625A N/A B 0.75 3W AO A 0 0 302-273 C-6 FO RR RJ-08 IST-013SO RR RJ-08Valve Name 2-HR BACKUP AIR SYSTEM "A" HEADER VENT VALVE1-IA-V-1625B N/A B 0.75 3W AO A 0 0 302-273 C-4 FO RR RJ-08 IST-013SO RR RJ-08Valve Name 2-HR BACKUP AIR SYSTEM "B" HEADER VENT VALVE1-IA-V-1626A N/A B 0.75 3W AO A 0 0 302-273 C-6 FO RR RJ-08 IST-013SO RR RJ-08Valve Name 2-HR BACKUP AIR SYSTEM HEADER SUPPLY VALVE1-IA-V-1626B N/A B 0.75 3W AD A 0 0 302-273 C-4 FO RR RJ-08 IST-013SO RR RJ-08Valve Name 2-HR BACKUP AIR SYSTEM HEADER SUPPLY VALVE1-IA-V-1628A NA C 1 CK SA A SYS C 302-273 C-6 BDO RR RJ-06 IST-014CC RR RJ-06Valve Name 2-HR BACKUP AIR SYSTEM "A" INST AIR SUPPLY CHECK1-IA-V-1628B NA C 1 CK SA A SYS C 302-273 C-5 BDO RR RJ-06 IST-014CC RR RJ-06Valve Name 2-HR BACKUP AIR SYSTEM "B" INST AIR SUPPLY CHECK1-IA-V-1631A N/A C. 1 CK SA A C O/C 302-273 D-6 CC RR RJ-06CO RR RJ-06Valve Name 2-HR BACKUP AIR SYSTEM "A" SUPPLY CHECK1-IA-V-1631B N/A C 1 CK SA A C 0 302-273 E-5 BDC RR RJ-06 IST-014CO RR RJ-06Valve Name 2-HR BACKUP AIR SYSTEM CROSSOVER CHECK1-IA-V-1632 N/A B 1 BALL M A C O/C 302-273 E-5 EO Y2Valve Name 2-HR BACKUP AIR SYSTEM CROSSOVER CHECK1-IA-V-20 2 A 2 GL M P LC LC 302-271 F-1 LTJ AJValve Name CONTAINMENT ISOLATION -IA INNER RB ISOL VALVE1-IA-V-6 2 A 2 GL M P LC LC 302-271 F-1 LTJ AJValve Name CONTAINMENT ISOLATION -RB INST AIR CONN VALVERevision 0October 25, 2013 A15 -28 Valve EPNl:iC-V-101-IC-V-1021-IC-V-161-IC-V-181-IC-V-21-IC-V-31-IC-V-41-IC-V-61-IC-V-761-IC-V-90A1-IC-V-90B1-IC-V-90C1-IC-V-90DAttachment 15Inservice Testing Valve TableINTERMEDIATE COOLING WATER SYSTEM (Page 1)Safety Category Size Valve Act. Active/. Normal Safety .P&&ID P&&ID Test TestClass Type Type Passive Position Position Coor. Type Freq.3 C 0.5 RV SA .A C '0 302-620 RT Y10Valve Name INTER CLG -RCDT COOLER RELIEF VALVE.2 A/C 0.25 RV SA A C O/C 302-620 C-5 LTJ AJRT Y10Valve Name CONTAINMENT PENETRATION RELIEF VALVE2 A/C 3 CK SA A 0 O/C 302-620 G-6 CCL CMCOF CMLTJ AJValve Name CONTAINMENT ISOLATION -CRD COOLING CHECK VALVE2 A/C. 6 CK SA A 0 O/C 302-620 H-6 CCL CMCOF CMLTJ AJValve Name CONTAINMENT ISOLATION -LETDOWN SUPPLY CHECK VLV2 A 6 GA MO A 0 C 302-620 C-6 LTJ AJPI Y2SP M3STC CSValve Name CONTAINMENT ISOLATION -ICCW COOLANT RETURN VALVE2 A 6 PLG AO A 0 C 302-620 C-5 LTJ AJP1 Y2SP M3STC CSValve Name CONTAINMENT ISOLATION -ICCW COOLANT RETURN VALVE2 A 6 PLG AO A 0 C 302-620 H-5 LTJ AJPI Y2SP M3STC CSValve Name CONTAINMENT ISOLATION -IC ISOL COOLANT SUPPLY2 A 3 GA AO A 0 C 302-620 G-5 FC CSLTJ AJPI Y2SP M3STC CSValve Name CONTAINMENT ISOLATION -IC COOLANT SUPPLY TO CRDM2 C 0 RV SA A C O/C 302-620 D-6 RT Y10Valve Name CRD COOLING COIL RELIEF VALVE3 C 0.75 RV SA A C O/C 302-620 E-8 RT Y10Valve Name RC PUMP 1A COOLER RELIEF VALVE3 C 0.75 RV SA A C O/C 302-620 D-8 RT Y10Valve Name RC PUMP 1B COOLER RELIEF VALVE3 C 0.75 RV SA A C O/C 302-620 D-8 RT Y10Valve Name RC PUMP 1A COOLER RELIEF VALVE3 C 0.75 RV SA A C O/C 302-620 C-8 RT Y10Valve Name RC PUMP 1A COOLER RELIEF VALVERelief Deferred Tech.Request Just. Pos.CSJ-01CSJ-01cSJ-01CSJ-01CSJ-01CSJ-01CSJ-01 IST-013CSJ-01CSJ-01Revision 0October 25, 2013A15-29  5Inservice Testing Valve TableMAIN STEAM (Page 1)Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&&ID P&&IDClass Type Type Passive Position Position Coor.Test Test Relief Deferred Tech.Type Freq. Request Just. Pos.1-MS-V-10A 3 B 6 GA MO A C C 302-011 F-3 PI Y2STO RRValve Name OTSG "A" TO EF-P1 JOG/THROTTLE VALVE1-MS-V-10B 3 B 6 GA MO A CValve Name OTSG "B" TO EF-P1 JOG/THROTTLE VALVE1-MS-V-13A 3 B 2 GL AO A CC 302-011 F-3 PISTOO 302-011 F-3 FOPISTOSTC"A"O 302-011 F-3 FOPISTOSTC"W"Valve Name MAIN STEAM SUPPLY TO EF-P1 FROM OTSG2 GL AO A C1-MS-V-13B 3 BValve Name MAIN STEAM SUPPLY TO EF-P1 FROM OTSG1-MS-V-17A 2 C 6 RV SAValve Name OTSG "A" MS RELIEF Vj1-MS-V-17B1-MS-V-17C1-MS-V-17D1-MS-V-18A1-MS-V-18B1-MS-V-18C1-MS-V-18D1-MS-V-19A1-MS-V-19B1-MS-V-19C1-MS-V-19DC 6 RV SAValve Name OTSG "A" MS RELIEF V,C 6 RV SAValve Name OTSG "B" MS RELIEF VC 10 RV SAValve Name OTSG MS RELIEF VAL'C 6 RV SAValve Name OTSG "A" MS RELIEF VC 6 RV SA.Valve Name OTSG "A" MS RELIEF V.C 6 RV SAValve Name OTSG "B" MS RELIEF V.C 6 RV SAValve Name OTSG "B" MS RELIEF VC 6 RV SAValve Name OTSG "A" MS RELIEF VC .6 RV SAValve Name OTSG "A" MS RELIEF VC 6 RV SAValve Name OTSG "B" MS RELIEF VC
* 6 RV SAValve Name OTSG "B" MS RELIEF VA C O/C 302-011 G-8rALVEA C O/C 302-011 G-84ALVEA C O/C 302-011 H-8ALVEA C O/C 302-011 H-8FEA
* C O/C 302-011 G-9ALVEA C O/C 302-011 G-9ALVEA C O/C 302-011 H-9ALVEA C O/C 302-011 H-9ALVEA C O/C 302-011 G-9ALVEA .C O/C 302-011 G-9ALVEA C O/C 302-011 H-9ALVEA C
* O/C 302-011 H-9RTRTRTRTRTRTRTRTRTRTY2RRM3Y2M3M3M3Y2M3M3Y5Y5Y5Y5Y5Y5Y5Y5Y5Y5Y5Y5IST-013IST-013RTRTRevision 0October 25, 2013A15-30  5Inservice Testing Valve TableMAIN STEAM (Page 2)Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&&ID P&&ID Test TestClass Type Type Passive Position Position Coor. Type Freq.1-MS-V-1A 2 B/C 24 SCK MO A 0 C 302-011 G-10 BDO M3CC RRPI Y2STC CSValve Name CONTAINMENT ISOLATION -OTSG "A" MS ISOL VALVE1-MS-V-lB 2 B/C 24 SCK MO A 0 C 302-011 G-10 BDO M3CC RRPI Y2STC CSValve*Name CONTAINMENT ISOLATION -OTSG "A" MS ISOL VALVE1-MS-V-1C 2 B/C 24 SCK MO A 0 C 302-011 G-10 BDO M3CC RRPI Y2.*.STC CSValve Name CONTAINMENT ISOLATION -OTSG "B" MS ISOL VALVE'.1-MS-V-1D 2 B/C 24 SCK MO A 0 C 302-011 H-10 BDO M3CC RRPI Y2STC CSValve Name CONTAINMENT ISOLATION -OTSG "B" MS ISOL VALVE1-MS-V-20A 2. C 6 RV SA A C O/C 302-011Oi G-9 RT Y5Valve Name OTSG "A" MS RELIEF VALVE1-MS-V-20B 2 C 6 RV SA. A C O/C 302-01, G-9 RT Y5Valve Name OTSG "A" MS RELIEF VALVE1-MS-V-20C 2 C 6 'RV "SA A C o/C- 302-011 H-9 RT Y5Valve Name OTSG "B" MS RELIEF VALVEI-MS-V-20D 2 C 6 RV SA A C O/C 302-011 H-9 RT Y5Valve Name OTSG "B" MS RELIEF VALVE1-MS-V-21A 2 C 3 RV SA A C O/C 302-011 G-9 RT Y5Valve Name OTSG "A" MS RELIEF VALVE1-MS-V-21B 2 C .3 RV SA A C O/C 302-011 H-9 RT Y5Valve Name OTSG "B" MS RELIEF VALVE.1-MS-V-22A 3 C 4 RV SA A C O/C 302-011 F-5 RT Y8Valve Name EMERGENCY FW PUMP EF-P1 STEAM SUPPLY RELIEF1-MS-V-22B 3 C. .4 RV SA .A C O/C. 302-011 F-5 RT Y8l..Vave Name EMERGENCY FW PUMP EF-P1 STEAM SUPPLY RELIEF1-MS-V-2A 2 B 12 GA MO A 0 O/C 302-011 F-4 PI :.Y2STC M3Valve Name OTSG "A" MS TO EF-Pi & TURBINE BYPASS VALVES1-MS-V-2B 2 B 12 GA MO A. 0 O/C 302-011 G-4 PI Y2STC M3Valve Name OTSG "B" MS TO EF-P1 & TURBINE BYPASS VALVESRevision 0October 25, 2013 A15 -31Relief Deferred Tech.Request Just. Pos.ISTr014RJ-10CSJ-16IST-014RJ-10CSJ-16IST-014RJ-10CSJ-16IST-014RJ-10CSJ-16 Valve EPN1-MS-V-33A1-MS-V-33B1-MS-V-33C1-MS-V-33D1-MS-V-42A1-MS-V-42B1-MS-V-4A1-MS-V-4B1-MS-V-61-MS-V-89A1-MS-V-89B1-MS-V-89C1-MS-V-89D1-MS-V-921-MS-V-9A1-MS-V-9BSafetyClass2222223AttachmentInservice Testing VMAIN STEAM (Page 3)Category Size Valve Act. Active / Normal SType Type Passive Position PoB 1 GL M A 0Valve Name MS LINE A TRAP INLET ISOLATIONB 1 GL M A 0Valve Name MS LINE B TRAP INLET ISOLATION .B 1 GL M A 0Valve Name MS LINE C TRAP INLET ISOLATIONB 1 GL M A 0.Valve Name MS LINE D TRAP INLET ISOLATIONB 1 GL M A 0.Valve Name MS HEADAER A TRAP INLET ISOLATIONB 1 GL M A 0Valve Name MS HEADAER B TRAP INLET ISOLATIONB 6 GL AO A CValve Name ATMOSPHERIC DUMP VALVE FOR OTSG "A"3 B 6 GL AO A CValve Name ATMOSPHERIC DUMP VALVE FOR OTSG "B"3 B 4 GL AO A 015'alve Tableafety P&&ID P&&ID Test Testsition Coor. Type Freq.C 302-121 D-6 EC Y2C 302-121 D-6 EC Y2C 302-121 D-6 EC Y2C 302-121 D-6 EC Y2C 302-121 D-5 EC Y2C 302-121 D-5 EC Y2C 302-011 F-4 FC M3PI Y2STC M3C 302-011 G-3 FC M3PI Y2STC M3O 302-011 F-5 EC Y2EO Y2FO M3STO M3L VALVEC 302-012 F-4 EC Y2C 302-012 D-4 EC Y2C 302-012 E-4 EC Y2C 302-012 B-4 EC Y2C 302-012 C-3 EC Y2O/C 302-011 F-3 CCD CMCOD CMCP CMU1O/C 302-011 F-3 CCD CMCOD CMCP .CMRelief Deferred Tech.Request Just. Pos.IST-013IST-007222223BBBBBCValve Name EF-Pi MS PRESSURE.REGULATOR CONTROL0.5 GL M A 0Valve Name MS LINE A POST HEATING TRAP ISOLATION0.5 GL M *A 0Valve Name MS LINE B POST HEATING TRAP ISOLATION0.5 GL. M A 0Valve Name MS LINE C POST HEATING TRAP ISOLATION0.5 G L M A 0Valve Name MS LINE 0 POST HEATING TRAP ISOLATION2 GL M A 0Valve Name COMMON POST HEATING DRAIN ISOLATION6 CK SA A SYSValve Name MAIN STEAM SUPPLY CHECK VALVE TO EF-U3 C 6 CK SA A SYSValve Name MAIN STEAM SUPPLY CHECK VALVE TO EF-UlRevision 0October 25, 2013A15 -32  5Inservice Testing Valve TableMAKEUP & PURIFICATION (Page 1)Valve EPN Safety Category Size Valve Act. Active / Normal Safety P&&ID P&&ID Test TestClass Type Type Passive Position Position Coor. Type Freq.Relief Deferred Tech.Request Just. Pos.1-MU-RV-13 C 2 RV SA AValve Name MAKEUP TANK MU-T-1 RELIEFC O/C 302-660 A-7 RT Y41-MU-V-107A 1 C 2.5 CK SA A C O/C 302-661 H-2 CCD CMCOD CMCOF CMValve Name CONTAINMENT ISOLATION -HPI TO RC "A" SUPPLY CHECK1-MU-V-107B 1 C 2.5 CK SA A C O/C 302-661 G-2 CCD CMCOD CMCOF CMValve Name CONTAINMENT ISOLATION -HPI TO RC "B" SUPPLY CHECK1-MU-V-107C 1 C 2.5 CK SA A C O/C 302-661 D-2 CCD CMCOD CMCOF CMValve Name CONTAINMENT ISOLATION -HPI TO RC "C" SUPPLY CHECK1-MU-V-107D 1 C 2.5 CK SA A C O/C 302-661 D-2 CCD CMCOD CMCOF CMValve Name CONTAINMENT ISOLATION -HPI TO RC "D" SUPPLY CHECK1-MU-V-112 2 A/C 4 CK SA A 0 C 302-661 B-5 CC RRCO M3LT Y2Valve Name MAKEUP TANK OUTLET CHECK VALVE1-MU-V-116 1 A/C 1.5 CK SA A 0 C 302-661 F-3 BDO CMCCL CMLTJ AJValve Name CONTAINMENT ISOLATION -SEAL INJ SPRY/RC CHK1-MU-V-14A 2 A/C 6 SCK MO A C O/C 302-661 B-4 CC RRCO RRLT Y2PI Y2STO M3Valve Name MU PUMP SUCTION FROM BWST STOP CHECK VALVE1-MU-V-14B 2 A/C 6 SCK MO A C O/C 302-661 B-2 CC RRCO RRLT Y2PI Y2STO M3Valve Name MU PUMP SUCTION FROM BWST STOP CHECK VALVERJ-12RJ-13RJ-13RJ-13RJ-13Revision 0October 25, 2013A15 -33  5"Inservice Testing Valve TableMAKEUP & PURIFICATION (Page 2)Valve EPN Safety. Category Size Valve Act. Active / Normal Safety P&&ID P&&IDClass Type Type Passive Position Position Coor.1-MU-V-16A 2 B 2.5 GL MO A C .O/C 302-661 H-4Test TestType Freq.PI Y2STC M3STO. M3Relief Deferred Tech.Request Just. Pos.1-MU-V-16BValve Name CONTAINMENT ISOLATION -HPI "A" CONTROL VALVE2 B 2.5 .GL MO A C O/C 302-661 G-4 PISTCSTOValve Name CONTAINMENT ISOLATION -HPI "B" CONTROL VALVE1-MU-V-16C 2 B 2.5 GL MO A C O/C 302-661Valve Name CONTAINMENT ISOLATION -HPI "C" CONTROL VALVE1-MU-V-16D 2 B 2.5 GL MO A C O/C 302-661Valve Name CONTAINMENT ISOLATION -HPI "D" CONTROL VALVE1-MU-V-18* 2 A 2.5 GA AO A 0 C 302-661D-2 PISTCSTOD-2 PISTCSTOG-4 FCLTJPISPSTCY2M3M3Y2M3M3Y2M3M3CSAJY2M3CSRRRR.M3RRRRM3RRRRM3CSAJY2CSCSJ-03 IST-013Valve Name CONTAINMENT ISOLATION -CHARGE LINE ISOL VALVE1-MU-V-193A 2 C 2 SCK SA A SYS O/C 302-661 D-5Valve Name MU-P1A RECIRC.STOP CHECK VALVE1-MU-V-193B 2 C 2 SCK SA. A SYSValve Name MU-P1B RECIRC STOP CHECK VALVE1-MU-V-193C 2 C 2 SCK SA A SYSValve Name MU-PlC RECIRC STOP CHECK VALVE1-MU-V-20 2 A 4 GA AO A 0O/C 302-661 D-4O/C 302-661 D-3C 302-661 F-3CCCOCPCCCOCPCCCOCPFCLTJPISTCCSJ-03RJ-27RJ-27RJ-27RJ-27RJ-27RJ-27CSJ-04 IST-013CSJ-04Valve Name CONTAINMENT ISOLATION -RCP SEAL WATER ISOL VLV1 A/C 2.5
* CK SA A 0 C 302-661 H-21-MU-V-219BDO CMCCL CMLTJ AJValve Name NORMAL MAKEUP LINE TO HPI LINE B CHECK'Revision 0October 25, 2013A15 -34  5Inservice Testing Valve TableMAKEUP & PURIFICATION (Page 3)Valve EPN SafetyClass1-MU-V-220 1Category Size Valve Act. Active / Normal Safety P&&ID P&&ID Test TestType Type Passive Position Position Coor. Type Freq.C 2.5 CK SA. A C 0 302-661 G-2 BDC CMCOD CMRelief Deferred Tech.Request Just. Pos.Valve Name HPI LOOP "B" BACK FLOW FROM MAKEUP -CHECK VALVE1-MU-V-238 2 C 0.25 RV SA A C O/C 302-660 F-5 LTJ AJRT Y101-MU-V-251-MU-V-261-MU-V-2A1-MU-V-2B1_MU-V-31-MU-V-36Valve Name RCS LETDOWN CONTAINMENT PENETRATION RELIEF2 A 4 GL MO A 0 C 302-660 C-3 LTJ AJPI Y2SP M3STC CSValve Name CONTAINMENT ISOLATION RCP SEAL RETURN ISOL VALVE2 A 4 GA AO A 0 C 302-660 C-4 FC CSFO CSLTJ AJPI Y2SP M3STC CSValve Name CONTAINMENT ISOLATION RCP SEAL RETURN LETDOWN ISOLA 2.5 GL MO A 0 C 302-660 GA LTJ AJPI Y2SP M3STC CSValve Name CONTAINMENT ISOLATION -LETDOWN CLR "A" OUTLET VLV1 2.5 GL MO A 0 C 302-660 F4 LTJ AJPI Y2SP M3STC CSValve Name CONTAINMENT ISOLATION -LETDOWN CLR "B" OUTLET VLV2 A .2.5 GA AO A 0 C 302-660 G-5 FC CS*LTJ AJPI Y2SP M3STC CSValve Name CONTAINMENT ISOLATION -LETDOWN COOLER ISOL VALVE2 A 2 GA MO A 0 O/C 302-661 D-6 LT Y2PI Y2STC M3STO M3Valve Name MU PUMPS RECIRC ISOLATION VALVECSJ-05CSJ-05CSJ-05CSJ-05IST-013CSJ-05CSJ-05CSJ-06CSJ-06CSJ-06CSJ-06CSJ-06 IST-013CSJ-06CSJ-06Revision 0October 25, 2013A15-35  5Inservice Testing Valve TableMAKEUP & PURIFICATION (Page 4)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.1-MU-V-37 3 A 2 GA MO A 0 O/C 302-661 D-7 LT Y2PI Y2STC M3STO .M3Valve Name MU PUMPS RECIRC ISOL VALVE1-MU-V-51 3 B 1 DIA AO A C 0 302-660 C-10 PI Y2STO M3Valve Name EMERGENCY BORIC ACID ADD VALVE TO MAKEUP TANK1-MU-V-54A 3 C 0.75 CK SA A C c .302-660 D-10 CCP CMCO CMValve Name LITHIUM HYDROXIDE PUMP TO MU SYSTEM CHECK1-MU-V-54B. 3 C 0.75 CK .SA A C C 302-660 D-10 CCP CMCO CMValve Name HYDRAZINE PUMP TO MU SYSTEM CHECK1-MU-V-73A 2 C 3 CK SA A SYS O/C 302-661 C-5 CC RR RJ-15CO RR RJ-15Valve Name MU-P1A DISCHARGE CHECK VALVE1-MU-V-73B 2 C 3 CK SA A SYS O/C .302-661 C-4 CC RR RJ-15CO RR RJ-15Valve Name MU-P1B DISCHARGE CHECK VALVE1-MU-V-73C 2. C 3 CK SA A SYS O/C 302-661 C-3 CC RR RJ-15CO RR RJ-15Valve Name MU-PlC DISCHARGE CHECK VALVE1-MU-V-86A 1 C 2.5 CK SA. A .C 0 302-661 D-1 BDC CMCOD CMValve Name LOOP"D" RCS HPI INLET CHECK VALVE1-MU-V-86B 1. C 2.5 CK SA A C 0 302-661 D-1 BDC CMCOD CMValve Name LOOP "C' RCS HPI INLET CHECK VALVE1-MU-V-94 1 C 2.5 CK SA A SYS 0. 302-661. G-1 BDC CMCOD CM.Valve Name LOOP "B" RCS HPI INLET CHECK VALVE1-MU-V-95 1 C. 2.5 CK SA A C o 302-661 H-1 BDC CMCOD CMValve Name LOOP "A" RCS HPI INLET CHECK VALVERevision 0October 25, 2013 A15 -36 Valve EPN1-NI-V-261-NI-V-27Attachment 15Inservice Testing Valve TableNUCLEAR PLANT NITROGEN SUPPLY (Page 1)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.2 A 1 GL M P LC .C 302-720 D-9 LTJ AJValve Name CONTAINMENT ISOLATION -650# N2 SUPPLY TO RB2 A 1 GL M P LC C 302-720 D-9 LTJ AJValve Name CONTAINMENT ISOLATION -650# N2 SUPPLY TO RBRevision 0October 25, 2013A15 -37  5Inservice Testing Valve TableNUCLEAR SERVICES RIVER WATER (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.1-NR-V-16B 3. B 12 BTF MO P O/C/T Al 302-202 G-9 PI Y2Valve Name NUCLEAR SERVICES HX NS-C-1B OUTLET ISOLATION1-NR-V-16C 3 B 12 BTF MO P O/CIT Al 302-202 F-9 PI Y2Valve Name NUCLEAR SERVICES HX NS-C-1C OUTLET ISOLATION1-NR-V-16D 3 B 12 BTF MO P O/CIT Al 302-202 F-9 PI Y2Valve Name NUCLEAR SERVICES HX NS-C-1D OUTLET ISOLATION1-NR-V-19 3 B 24 BTF MO A C 0 302-202 E-5 EO Y2PI Y2Valve Name NR SYSTEM OUTLET TO SCREEN WASH HEADER1-NR-V-IA 3 B 16 BTF MO A O/C 0 302-202 C-10 PI Y2STO M3Valve Name NUC RIVER PUMP "A" DISCH VALVE1-NR-V-tB 3 B 16 BTF MO A O/C 0 302-202 C-9 PI Y2STO M3Valve Name NUC RIVER PUMP "8" DISCH VALVE1-NR-V-IC 3 B 16 BTF MO A O/C 0 302-202 C-9 PI Y2STO M3Valve Name NR-PlC DISCH VALVE1-NR-V-2 3 A 30 BTF MO P C C 302-202 C-9 LT Y2PI Y2Valve Name NR TO SR HEADER ISOLATION VALVE1-NR-V-20A 3 C 16 CK SA A SYS O/C 302-202 B-10 CC M3CO M3Valve Name NR-P1A DISCHARGE CHECK VALVE1-NR-V-20B 3. C 16 CK SA A SYS O/C 302-202 B-9 CC M3CO M3Valve Name NR-P1B DISCHARGE CHECK VALVE1-NR-V-20C 3 C 16 CK SA A SYS O/C 302-202 B-9 CC M3CO M3Valve Name NR-P1C DISCHARGE CHECK VALVE1-NR-V-21A 3 C 0.5 RV SA A C O/C 302-202 G-8 RT Y10Valve Name INTERMEDIATE SERVICE COOLER IC-C-lA RELIEF1-NR-V-21B 3 C 0.5 RV SA A C O/C 302-202 F-8 RT Y10Valve Name INTERMEDIATE SERVICE COOLER IC-C-lB RELIEFRevision 0October 25, 2013. A15 -38  5Inservice Testing Valve TableNUCLEAR SERVICES RIVER WATER (Page 2)Valve EPN Safety. Category Size Valve Act... Active/ Normal Safety .p&&ID P&&IDClass Type Type Passive Position Position : Coor.Test Test Relief. Deferred Tech.Type Freq. Request Just. Pos.1-NR-V-22A 3 C 2 CK SA A C O/C 302-202 B-10Valve Name NR-P1A VACUUM BREAKER (Check Valve)I-NR-V-22B 3 C 2 CK :SA A C O/C 302-202 B-10Valve Name NR-P1 B VACUUM BREAKER (Check Valve)1-NR-V-22C 3 C 2 CK SA A C O/C 302-202 B-9Valve Name NR-P1C VACUUM BREAKER (Check Valve)1-NR-V-25A 3 C 1.5 RV SA A C O/C 302-202 H-10Valve Name NUCLEAR SERVICES HX NS-C-1A TUBE SIDE RELIEF.1-NR-V-25B 3 C 1.5 RV SA.. A C O/C 302-202 G-10Valve Name NUCLEAR SERVICES HX NS-C-1B TUBE SIDE RELIEF1-NR-V-25C 3 C
* 1.5 RV SA A C O. OC 302-202 .G-10Valve Name NUCLEAR SERVICES HX NS-C-1C TUBE SIDE RELIEF!-NR-V-25D 3 C 1.5 RV SA A C O/C 302-202 F-10Valve Name NUCLEAR SERVICES HX NS-C-1D TUBE SIDE RELIEF.1-NR-V-4A 3 A 30 BTF MO A C C 302-202 E-10Valve Name DEICING MAKEUP VALVE "A"1-NR-V-4B 3 A .30 BTF MO A C C 302-202 E-10CCCOCCCOCCCORTRTRTRTLTPISTCLTPISTCPIPI*PILTPIP1PIPI.M3.M3M3M3M3M3Y10Y10Y10Y10Y2Y2M3Y2Y2.M3Y2Y2Y2Y2Y2Y2Y2Y21-NR-V-53A1-NR-V-53B1-NR-V-53C1-NR-V-61-NR-V-8B1-NR-V-8C1-NR-V-8DBBBABBBValve Name DEICING MAKEOP VALVE "B"2 BALL MO .P 0 0 302-203 A-5Valve Name NR-S-1A BACKWASH VALVE*2 BALL MO P 0 0 302-203 A-5Valve Name NR-S&1B BACKWASH VALVE2. BALL MO P 0 0 .302-203 A-5Valve Name NR-S-1C BACKWASH VALVE30 BTF MO
* P C C 302-202 E-8Valve Name HX VAULT CROSS CONNECT BETWEEN NR & SR12 BTF MO P 0 0 302-202 G-10Valve Name NUCLEAR SERVICES HX NS-C-11B INLET ISOLATION12 BTF " MO P 0 0 302-202 F-10Valve Name NUCLEAR SERVICES HX NS-C-lC INLET ISOLATION12 .BTF MO P 0 0 302-202 F-10Valve Name NUCLEAR SERVICES HX NS-C-ID INLET ISOLATIONRevision 0October 25, 2013A15 -39  5Inservice Testing Valve TableNUCLEAR SERVICES CLOSED COOLING WATER (Page 1)Valve EPN Safety Category Size Valve Act. Active / Normal Safety P&&ID P&&IDClass Type Type Passive Position Position Coor.1-NS-V-10A 3 C 12 CK SA A SYS O/C 302-610 G-3Valve Name NUC SVCS PUMP "A" DISCHARGE CHECK VALVE1-NS-V-10B 3 C 12 .CK SA A .SYS O/C 302-610 G-3Valve Name N.S-P1B DISCHARGE CHECK VALVE1-NS-V-10C 3 C 12 CK SA A SYS O/C 302-610 G-2Valve Name NS-P1C DISCHARGE CHECK VALVE1-NS-V-11 2 A/C 8 CK SA A 0 C 302-610 D-9Valve Name RCP MOTOR COOLER SUPPLY VALVE1-NS-V-135 3 C 0.5 XFC SA A 0 C 302-610 E-9Valve Name NS/RR CROSS-CONN EXCESS FLOW VALVE1-NS-V-15 2 A 8 GA MO A 0 C 302-610 D-8Test TestType Freq.CCF CMCOD CMCPF CMCCF CMCOD CMCPF CMCCF CMCOD CMCPF CMBDO CMCCL CMLTJ AJBDO M3CC M3LTJ AJPI Y2SP M3STC CSPI Y2STO M3PI Y2STO M3BDO M3CC M3LTJ AJRT Y10Relief Deferred Tech.Request Just. Pos.IST-014CSJ-07CSJ-071-NS-V-16A.1-NS-V-16B1-NS-V-2051-NS-V-21 13332BBCA/CValve Name RC MOTOR COOLER RETURN VALVE8 GA MO A O/C 0 302-610 D-3Valve Name SPENT FUEL POOL COOLER SF-C-1A COOLING WATER INLET8 GA MO A 0/c 0 302-610 D-2Valve Name SPENT FUEL POOL COOLER SF-C-1B COOLING WATER INLET2 CK SA *A SYS C 302-610 H-6Valve Name NSCCW SURGE TANK DEMIN WATER SUPPLY CHECK VALVE0.25 RV SA A C O/C 302-610 A-8Valve Name RB RETURN HEADER PENETRATION RELIEFIST-014Revision 0October 25, 2013A15-40  5Inservice Testing Valve TableNUCLEAR SERVICES CLOSED COOLING WATER (Page 2)Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&&ID P&&ID Test TestClass Type Type Passive Position Position Coor. Type Freq.1-NS-V-35 2 A 8 GA MO A 0 C 302-610 A-9 LTJ AJPI Y2SP M3STC CSValve Name RC MOTOR COOLER RETURN VALVE1-NS-V-36A 2 C 0.5 RV SA A C O/C 302-610 F-8 .RT Y10Valve Name RB FAN MOTOR COOLER 1A RELIEF1-NS-V-36B 2 C 0.5 RV SA A C O/C 302-610 F-7 RT Y10Valve Name RB FAN MOTOR COOLER 1B RELIEF1-NS-V-36C 2 C 0.5 RV SA A C O/C 302-610 F-7 RT Y10Valve Name RB FAN MOTOR COOLER 1C RELIEF1-NS-V-37A 3 C 0.5 RV -SA A C O/C 302-610 F-5 RT Y10* Valve Name STEAM GENERATOR SAMPLE COOLER CA-C-2A RELIEF1-NS-V-37B 3 C 0.5 RV SA A C O/C 302-610 F-5 RT Y10Valve Name STEAM GENERATOR SAMPLE COOLER CA-C-2B RELIEF1-NS-V-3. 3 C 0.5 RV SA " A C O/C .302-610 F-5 RT Y10Valve Name PRESSURIZER SAMPLE COOLER CA-C-1 RELIEF1-NS-V-39A 3 C 0.5 RV SA A C O/C :302-610 C-2 RT Y10Valve Name SPENT FUEL POOL COOLER SF-C-IA TUBE SIDE RELIEF1-NS-V-39B 3 C 0.5 RV SA A *. C O/C 302-610 C-1 RT Y10Valve Name SPENT FUEL POOL COOLER SF-C-lB TUBE SIDE RELIEF1-NS-V-4 2 A 8 GA MO A 0 C 302-610. A-8 LTJ AJ.PI Y2SP M3STC CSValve Name RCP MOTOR COOLER RETURN VALVE1-NS-V40A 3 C 0.5. RV SA A C O/C" 302-610 B-8 RT Y10Valve Name RC WASTE EVAP DISTILLATE COOLER WDL-C-3A RELIEF1-NS-V-40B 3 C 0.5 RV SA A .. C O/C 3027610 B-7 RT Y10Valve Name RC WASTE EVAP. DISTILLATE COOLER WDL-C-3B RELIEF1-NS-V-41A 3 C 0.5 RV SA A
* C
* O/C 302-610 *C-8 RT Y10Valve Name RC WASTE EVAPORATOR CONDENSERWDL-C-2A RELIEF1-NSV-41B 3 C 0.5 RV SA
* A. C O/C 302-610 B-8 RT Y10Valve Name RC WASTE EVAPORATOR CONDENSER WDL-C-2B RELIEF1-NS-V-42A 3 C .5. 0.5 RV. .SA .A C O/C 302-610 B-6 RT Y10Valve Name WASTE GAS COMPRESSOR COOLER WDG-P-1A RELIEFRevision 0October 25, 2013 A5 -.41Relief Deferred Tech.Request Just. Pos.CSJ-08CSJ-08CSJ-08CSJ-08. 5Inservice Testing Valve TableNUCLEAR SERVICES CLOSED COOLING WATER (Page 3)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.1-NS-V-42B 3 C 0.5 RV SA A C O/C 302-610 B-6 RT Y10.Valve Name WASTE GAS COMPRESSOR COOLER WDG-P-1B RELIEF1-NS-V-43A. 3 C 0.5. RV SA A C 0/C 302-610 B-6 RT Y10Valve Name RC PUMP SEAL RETURN COOLER MU-C-2A RELIEF1-NS-V-43B 3 C 0.5 RV SA A C O/C 302-610 B-5 RT Y10Valve Name RC PUMP SEAL RETURN COOLER MU-C-2B RELIEF1-NS-V-44A 3 C 0.5 RV SA .A C. O/C 302-645 B-6 RT Y10Valve Name MU-P-1A MOTOR AND BEARING COOLING WATER RELIEF1-NS-V-44B 3 C 0.5 RV SA A C .0/C 302-610 D-4 RT Y10Valve Name MU-P-1B MOTOR AND BEARING COOLING WATER RELIEF1-NS-V-44C "3 C 0.5 RV SA A C O/C 302-645 B-7 RT Y10Valve Name MU-P-iC MOTOR AND BEARING COOLING WATER RELIEF1-NS-V-45A 3 C 0.5 RV SA A C O/C 302-610 D-10 RT Y10Valve Name RC-P-1A MOTOR COOLER RELIEF1-NS-V-45B 3 C 0.5 RV SA A C O/C 302-610 D-10 RT Y10Valve Name RC-P-1B MOTOR COOLER RELIEF1-NS-V-45C 3 C 0.5 RV SA A C o/C 302-610 C-10 RT Y10Valve Name RC-P-lC MOTOR COOLER RELIEF1-NS-V-45D 3 C 0.5 RV SA A C O/C 302-610 B-10 RT Y10Valve Name RC-P-1D MOTOR COOLER RELIEF1-NS-V-46A 3 C 0.5 RV SA " .A C. O/C 302-610 F-6 RT Y10Valve Name CONTROL BLDG AC HEAT EXCHANGER AH-C-4A RELIEF1-NS-V-46B 3 C 0.5 RV SA *A C O/C 302-610 F-6 RT Y10Valve Name CONTROL BLDG AC HEAT EXCHANGER AH-C-4B RELIEF.1-NS-V-47 3 C 2 .RV SA A C o/C 302-610 H-7 RT Y4Valve Name NS SURGE TANK NS-T-1 RELIEF1-NS-V-48A 3 C 0.5 RV SA *A C 0/C 302-610 G-2 RT Y10Valve Name NS & DC PUMP AREA COOLER AH-E-15A RELIEF1-NS-V-48B 3 C 0.5 RV SA .. A. C O/C 302-610 G-1 RT Y10Valve Name NS & DC PUMP AREA COOLER AH-E-15B RELIEF1-NS-V-49A 3 C 1 .RV SA ' A .C O/C. 302-610 F-9 RT Y10Valve Name EFW PUMP AND IA COMPR ROOM COOLER AH-E-24A RELIEF1-NS-V-49B 3 C 0.5 RV SA A C O/C 302-610 F-8 RT Y10Valve Name EFW PUMP AND IA COMPR ROOM COOLER AH-E-24B RELIEFRevision 0October 25, 2013 A15 -42  5Inservice Testing Valve TableNUCLEAR SERVICES CLOSED COOLING WATER (Page 4)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.1-NS-V-51A 3 C 0.5 RV SA A C O/C 302-610 C-3 RT Y10Valve Name SPENT FUEL PUMP ROOM COOLER AH-E-8A RELIEF1-NS-V-51B 3 C 1 RV SA A C O/C 302-610 C-3 RT Y10Valve Name SPENT FUEL PUMP ROOM COOLER AH-E-8B RELIEF1-NS-V-52A 2 B 1 GA AO P 0 0 302-610 E-8 PI Y2Valve Name CONTAINMENT ISOLATION -AH-E1A MOTOR COOLER SUPPLY1-NS-V-52B 2 B 1 GA AO P 0 0 302-610 E-7 PI Y2Valve Name CONTAINMENT ISOLATION -AH-E1B MTR COOLER SUPPLY1-NS-V-52C 2 B 1 GA AO P 0 0 302-610 E-7 PI Y2Valve Name CONTAINMENT ISOLATION -AH-E1C MTR COOLER SUPPLY1-NS-V-53A 2 B 1 GA AO P 0 0 302-610 F-8 PI Y2Valve Name CONTAINMENT ISOLATION -AH-E1A MTR COOLER RETURN1-NS-V-53B 2 B 1 GA AO P 0 0 302-610 F-7 PI Y2Valve Name CONTAINMENT ISOLATION -AH-E1B MTR COOLER RETURN1-NS-V-53C 2 B 1 GA AO P 0 0 302-610 F-7 PI Y2Valve Name CONTAINMENT ISOLATION -AH-EIC MTR COOLER RETURN1-NS-V-54A 3 B 1.5 GL AO A T 0 302-610 C-4 FO M3 IST-013STO M3Valve Name SPENT FUEL PUMP ROOM COOLING COIL FLOW CONTROL1-NS-V-54B 3 B 1.5 GL AO A T 0 302-610 C-3 FO M3 IST-013STO M3Valve Name SPENT FUEL PUMP ROOM COOLING COIL FLOW CONTROL VLV1-NS-V-85 3 A 0.5 GL M A 0 C 302-610 E-9 EC Y2Valve Name NS-FI-76 ROTOMETER OUTLET ISOL VALVE1-NS-V-96A 3 C 0.75 RV SA A C O/C 302-610 G-10 RT Y10Valve Name NUCLEAR SERVICES HX NS-C-1A SHELL SIDE RELIEF1-NS-V-96B 3. C 0.75 RV .SA A C O/C 302-610 G-9 RT Y10Valve Name NUCLEAR SERVICES HX NS-C-1B SHELL SIDE RELIEF1-NS-V-96C 3 C 0.75 RV SA A C O/C 302-610 G-9 RT Y10Valve Name NUCLEAR SERVICES HX NS-C-1C SHELL SIDE RELIEF1-NS-V-96D 3 C 0.75. RV SA A C O/C 302-610 G-8 RT Y10Valve Name NUCLEAR SERVICES HX NS-C-1 D SHELL SIDE RELIEFRevision 0October 25, 2013 A15 -43  5Inservice Testing Valve TablePENETRATION PRESSURIZATION SYSTEM (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.1-PP-V-210 2 A 1 GL M P C *C 302-706 E-8 LTJ AJValve Name CONTAINMENT INTEGRITY BACKUP SUPPLY AHV1NB "1-PP-V-211 2 A 1 GL M P C C 302-706 G-10 LTJ AJValve Name CONTAINMENT INTEGRITY -BACKUP SUPPLY TO AH-V1C/D1-PP-V-212 2 A 2 GL M P C C 302-706 F-7 LTJ AJValve Name CONTAINMENT INTEGRITY -PP-T1B SUPPLY TO.AH-V1ANB1-PP-V-213 .2 A 2 GL M P C C 302-706 G-9 LTJ AJValve Name CONTAINMENT INTEGRITY -PP-T1A SUPPLY TO AH-V1C/DRevision 0October 25, 2013 A15 -44 Valve EPN1-RB-V-1A1-RB-V-lB1-RB-V-lC1-RB-V-iD1-RB-V-iE1-RB-V-2A1-RB-V-7SafetyClassNANANANANA2Attachment 15Inservice Testing Valve TableREACTOR BUILDING EMERGENCY COOLING WATER (Page.1)category Size Valve Act. Active / Normal Safety* P&&ID P&&IDType Type Passive* Position Position Coor.C 0.5 RV SA A C O/C 302-611 G-6Valve Name RB NORMAL COOLING COIL 1A RELIEF VLVC 0.5 RV SA A C O/C 302-611 G-6Valve Name RB NORMAL COOLING COIL 1B RELIEF VLVC 0.5 RV SA A C O/C 302-611 G-6Valve Name RB NORMAL COOLING COIL 1C.RELIEF VLVC 0.5 RV SA
* A C O/C 302-611 G-6Valve Name RX COMPARTMENT COOLING COIL AH-C-3A RELIEF VLVC 0.5
* RV SA A C O/C 302-611 G-6Valve Name RX COMPARTMENT COOLING COIL AH-C-3B RELIEF VLVA 8 GA MO A 0 C 302-611 F-8Test Test Relief Deferred Tech.Type Freq. Request Just. Pos.RT Y10RT Y10RT Y10RT Y10RT Y10LTJ AJPI Y2SP M3 CSJ-09STC CS CSJ-09LTJ AJPI Y2SP M3 CSJ-09STC CS CSJ-09Valve Name CONTAINMENT ISOLATION -RB NORMAL AIR COOL SUP VLV2 A 8 GA MO A 0 C 302-611 F-8Valve Name CONTAINMENT ISOLATION -RB NORMAL COOL RETURN ISOLRevision 0October 25, 2013A15-45
.Valve EPN1-RC-RD-11-RC-RD-21-RC-RV-1A1-RC-RV-1B1-RC-RV-2SafetyClass221 "1*Attachment 15Inservice Testing ValveREACTOR COOLANT (Page 1)Category Size Valve Act. Active I Normal SafetyType Type Passive Position PositionD 2 RPD SA A C 0.Valve Name RCS HOT LEG VENT LINE RUPTURE DISK RD-1D 2 RPD SA A C 0Valve Name RCS HOT LEG VENT LINE RUPTURE DISK RD-2C'" 2.5 RV SA A
* C O/CValve Name PRESSURIZER.CODE SAFETY VALVEC 2.5 RV SA A C O/CValve Name PRESSURIZER CODE SAFETY VALVEB/C 4 RV SO A C O/CValve Name PZR PILOT OPERATED RELIEF VALVE (PORV)1-RC-V-144A 1 C 14 CK SA A ' C 0Valve Name REACTOR VESSEL INTERNAL VENT VALVE1-RC-V-144B -1 C 14 C.K SA A C 0Valve Name REACTOR VESSEL INTERNAL VENT VALVE*1-RC-V-144C 1 C .14 CK SA A C -0Valve Name REACTOR VESSEL INTERNAL VENT VALVE1-RC-V-1440 1 C 14 CK SA A C 0Valve Name REACTOR VESSEL INTERNAL VENT VALVE1-RC-V-144E 1 C 14 CK SA A C 0Valve Name REACTOR VESSEL INTERNAL VENT VALVE1-RC-V-144F 1 C 14 CK SA A C 0Valve Name REACTOR VESSEL INTERNAL VENT VALVE1-RC-V-144G 1 C 14 CK SA A C 0Valve Name REACTOR VESSEL INTERNAL VENT VALVE1-RC-V-144H 1 C 14 CK SA A .C 0Valve Name REACTOR VESSEL INTERNAL VENT VALVE1-RC-V-2 1 CB 4 3 *GA MO A 0 O/CValve Name PORV (RC-RV2) ISOLATION VALVETableP&&ID P&&ID Test Test Relief Deferred Tech.Coor. Type Freq. Request Just. Pos.302-650 D-8 DT Y5302-650 D-2 DT Y5302-650 G-6 RT Y5302-650. G-6 RT Y5302-650 G-6 FC RR VR-01 IST-013RT Y5 VR-01STC RR VR-01STO RR VR-01CC RR RJ-28CO !RR RJ-28CC RR RJ-28CO RR RJ-28CC RR RJ-28CO RR RJ-28CC RR .RJ-28CO RR RJ-28CC RR RJ-28CO RR .RJ-28CC RR RJ-28CO RR RJ-28CC RR RJ-28CO RR RJ-28CC RR -RJ-28CO RR R RJ-28302-650 G-6 PI Y2STC M3STO M3Revision 0October 25, 2013A15-46  5Inservice Testing Valve TableREACTOR COOLANT (Page 2)Valve EPN Safety Category Size Valve Act. Active / Normal Safety P&&ID P&&IDClass Type Type Passive Position Position Coor.1-RC-V-23 .1 A/C 1.5 CK SA A. C. O/C 302-650 G-6* Valve Name DH PRESSURIZER SPRAY LINE CHECK VALVE.1 GL MO A C O/C 302-650 G-81-RC-V-281-RC-V-31-RC-V-41-RC-V-40A1 8Valve Name PZR VENT TO RCDT ISOLATION VALVE1 B 2.5 GL MO A 0C 302-650 E-6Valve Name PRESSURIZER SPRAY LINE ISOLATION VALVE1 A 1.5 GL MO'. A C 0(/C 302-650 G-6Valve Name DECAY HEAT PRESSURIZER SPRAY LINE ISOLATION VALVE1 B 0.5 GL SO A C O/C 302-650 E-8Test TestType Freq.CC RR.COF RRLTH Y2P1 Y2STC CSSTO CSPI *Y2STC CSLTH Y2PI Y2STc CSSTO CSFC CSPI Y2STC CS*STO CSFC CSPI Y2STC CSSTO CSFC CSPI .Y2STC CSSTO CSFC CSPI Y2STC CSSTO CSFC CSP1 Y2STC CSSTO CSRelief Deferred Tech.Request Just. Pos.RJ-23RJ-23CSJ-11.CSJm 1CSJ-17CSJ-18CSJ-18CSJ-12 IST-013CSJ-12CSJ-12CSJ-12 IST-013.C SJ-12CSJ-12CSJ-12 IST-013CSJ-12CSJ-12CSJ-12 IST-013CSJ-12CSJ-12CSJ-13 IST-013CSJ-13CSJ-13Valve Name "A" HOT LEG HIGH POINT VENT TO RCDT AND ATMOSPHERE1-RC-V-40B. 1 B 0.5 GL SO A C O/C 302-650 E-2Valve Name "B" HOT LEG VENT TO RCDT AND ATMOSPHERE1-RC-V-41A 1 B 0.5 GL SO A C C 302-650 E-8Valve Name "A" HOT LEG VENT TO RCDT AND ATMOSPHERE1-RC-V-41B 1 B 0.5 GL SO A C C 302-650 E-2Valve Name "B" HOT LEG VENT TO RCDT AND ATMOSPHERE1-RC-V-42 1 B 0.5 GL .SO. A. C O/C 302-650 G-4Valve Name REACTOR VESSEL VENT TO REACTOR BLDG ATMOSPHERERevision 0October 25, 2013A15-47  5Inservice Testing Valve TableREACTOR COOLANT (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.1-RC-V-431 B 0.5 GL SO A C C 302-650 G-4 FC CSPI Y2STC CSSTO CSValve Name REACTOR VESSEL VENT TO REACTOR BLDG ATMOSPHERE1 B 1 GL SO A C O/C 302-650 G-7 FC CSPI Y2STC CSSTO CSValve Name PRESSURIZER HIGH POINT VENT ISOLATION VALVECSJ-13 IST-013CSJ-13CSJ-131-RC-V-44CSJ-11 IST-013CSJ-11CSJ-11Revision 0October 25, 2013A15-48  5Inservice Testing Valve TableREACTOR BUILDING EMERGENCY COOLING 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.I-RR-V-1oA 3 B 2 GL AO A C o/c 302-611 E-3 FC M3 IST-013P1 Y2STC M3STO M3Valve Name RR-P1A RECIRCULATION MINIMUM FLOW BYPASS VALVE1-RR-V-10B .3 .B 2 GL AO A C 0/C 302-611 E-2 FC M3 IST-013PI Y2STC M3STO M3Valve Name RR-P1B RECIRCULATION MINIMUM FLOW BYPASS VALVE1-RR-V-11A 2 C 0.5
* RV SA A C O/C 302-611 F-4 RT Y10Valve Name RBEC COIL "A" RELIEF1-RR-V-11B 2 C 0.5 RV SA A C O/C 302-611 E-4 RT Y10Valve Name RBEC COIL "B" RELIEF1-RR-V-11C 2 C 0.5 RV SA A C O/C 302-611 D-4 RT Y10Valve Name RBEC COIL "C" RELIEF1-RR-V-12A 3 C 2 CK SA A C O/C 302-611 D-3 CC *M3CO M3Valve Name RIVER WATER PUMP "A" VACUUM BREAKER (Check Valve)1-RR-V-12B 3 C 2 CK SA A C. O/C 302-611 D-2 CC M3CO M3Valve Name RIVER WATER PUMP "B" VACUUM BREAKER (Check Valve)1-RR-V-1A 3 B 16 BTF MO A C 0 302-611 E-2 PI Y2STO M3Valve Name RR-P1A DISCHARGE VALVE1-RR-V-1B 3 B 16 BTF MO A C 0 302-611 E-2 P1 Y2STO M3.Valve Name RR-P1B DISCHARGE VALVE1-RR-V-33A 3 B 2 BALL MO P 0 0 302-203 A-6 P1 Y2Valve Name RRwS-1A BLOWDOWN VALVE1-RR-V-33B 3 B 2 BALL MO P 0 0 302-203 A-8 PI Y2Valve Name RR-S-1B BLOWDOWN VALVE1-RR-V-3A 2 B 12 GA MO A 0 O/C 302-611 H-4 PI Y2STC M3STO M3Valve Name CONTAINMENT ISOLATION -RBEC COIL "A" INLET VALVE1-RR4V-3B 2 B 12 GA MO A 0 o/C 302-611 G-4 P1 Y2STC M3STO M3Valve Name CONTAINMENT ISOLATION -RBEC COIL "B" INLET VALVE1-RR-V-3C 2 B 12 GA MO A 0 O/C 302-611 F-4 PI Y2STC M3STO M3Valve Name CONTAINMENT ISOLATION -RBEC COIL "C" INLET VALVERevision 0October 25, 2013 A15 -49 Valve EPN1-RR-V-4A1-RR-V-4B1-RR-V.4C1-RR-V-4D1-RR-V-51-RR-V-61-RR-V-7A1-RR-V-7B1-RR-V-8A1-RR-V-8B1-RR-V-9A1-RR-V-9B1-RR-V-9CAttachment 15Inservice Testing Valve TableREACTOR BUILDING EMERGENCY COOLING WATER (Page 2)Safety Category Size Valve Act. Active / Normal Safety P&&ID P&&IDClass Type Type Passive position Position Coor.2 B .12 GA MO A C O/C 302-611 E-3Valve Name CONTAINMENT ISOLATION -RBEC COIL "IA" OUTLET VLV2 B 12 GA MO *A C O/C 302-611 E-3Valve Name CONTAINMENT ISOLATION -RBEC COIL "IB" OUTLET VLV2 B 12 GA MO A C O/C 302-611 D-3Valve Name CONTAINMENT ISOLATION -RBEC COIL "IC" OUTLET VLV2 B 12 GA MO A C O/C 302-611 D-3Valve Name CONTAINMENT ISOLATION -RBEC COIL "1C" OUTLET VLV3 B 10 BTF MO A C 0 302-611 B-3Valve Name RR-V6 RB COOLING COIL DISCHARGE BYPASS VALVE3 B 10 *BTF DIA A T 0 302-611 B-3Valve Name RB EMERG COOLING COIL BACK PRESSURE REGULATOR3 C 16 CK. SA A C 0. 302-611 D-2Valve Name RB EMERG COOL PUMP "A" DISCHARGE CHECK VALVE3 C .16 CK SA A C 0 .302-611 D-2Valve Name RB EMERG COOL PUMP "B" DISCHARGE CHECK VALVE3 C 20 CK SA A C O/C 302-611 F-2Valve Name RIVER WATER TO RB COOL UNITS CHECK VALVE3 C 20 CK SA A C O/C 302-611 F-2Valve Name RIVER WATER TO RB COOL UNITS CHECK VALVE3 C 12 CK SA A C 0 302-611 E-4Valve Name CONTAINMENT ISOLATION -AH-E1A EMERG COOL OUTLET3 C 12 CK SA
* A C 0 302-611 E-4Valve Name CONTAINMENT ISOLATION -AH-E1B EMERG COOL OUTLET3 C 12 CK SA
* A C 0 302-611 D-4Valve Name CONTAINMENT ISOLATION -AH-ElC EMERG COOL OUTLETTest TestType Freq.PI Y2STC M3STO M3PI Y2STC M3STO M3PI Y2STC M3STO M3PI Y2STC M3STO M3PI Y2STO M3FO M3STO M3*BDC RRCOF RRBDC RRCOF RRCC M3COF RRCC M3COF RRBDC RRCOF RRBDC RRCOF RRBDC RRCOF RRRelief Deferred Tech.Request Just. Pos.IST-013RJ-18, IST-014RJ-18RJ-18 IST-014RJ-18RJ-14RJ-14RJ-11 IST-014RJ-11RJ-11 IST-014RJ-11RJ-11 IST-014RJ-1 1Revision 0October 25, 2013A15 -50  5Inservice Testing Valve TableSTATION SERVICE AIR (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.1-SA-V-2 2 A 2 GL M P LC C 302-271 E-1 LTJ AJValve Name CONTAINMENT ISOLATION -SERVICE AIR TURB BLDG1-SA-V-3 2 A 2 GL M P LC C 302-271 E-1 LTJ AJValve Name CONTAINMENT ISOLATION -RB 1ST FL SVC AIR ISOLRevision 0October 25, 2013 Al5 -.51 Three Mile Island Unit #1Inservice Testing Program PlanAttachment 15Inservice Testing Valve TableSPENT FUEL COOLING (Page 1)Valve EPN Safety Category Size Valve Act. Active/ Normal Safety P&&ID P&&ID Test Test Relief DeferredClass Type Type Passive Position Position Coor. Type Freq. Request Just.1I-SF-V-1 B 8 DIA AO A O/C 0 302-630 F-6 PI :Y2FO M3STO M3Tech.Pos.IST-01 31-SF-V-111-SF-V-121-SF-V-141-SF-V-151-SF-V-2Valve Name SF-P-1A SUCTION FROM SF POOL "B"3 B 8 DIA AO A O/CValve Name COOLER sF-ClA RETURN TO SF POOL "B"3 B 8 DIA AO A O/CValve Name COOLER SF-CiA RETURN TO SF POOL "A"3 B 8 DIA AO A O/CValve Name COOLER SF-C1B RETURN TO SF POOL "B"3 B 8 DIA AO A O/CValve Name COOLER SF-C1B RETURN TO SF POOL "A"3 B 8 DIA A0 A O/C0. 302-630 E-4 PIFOSTOO 302-630 E-4 PIFOSTOO 302-630 D-4. PIFOSTOO 302-630 D-4 PIFOSTOY2M3M3Y2M3M3Y2M3M3Y2M3M3Y2M3M3.IST-013IST-013IST-013IST-013IST-0130 302-630 F-6PEFOSTOValve Name SF-P-1A SUCTION FROM SF POOL "A"A .8 GA M .P LC C 302-630 E-7 LTJ AJ1-SF-V-221-SF-V-231-SF-V-41-SF-V-51-SF-V-501-SF-V-512Valve Name FUEL TRANSFER CANALFILL & DRAIN LINE VALVE2 A 8 GA M P LC C 302-630Valve Name FUEL TRANSFER CANAL FILL & DRAIN LINE VALVE3 B 8 DIA AO. A O/C 0 302-630E-7 LTJ AJD-6 PIFOSTOY2.M3M3Valve Name SF-P-1B SUCTION FROM SF POOL "B"8 DIA AO *A 0O/CIST-013.IST-0133'0 302-630 D-6 PI Y2FO M3STO M30/C 302-630 H-4 CCR CMCOF CMValve Name SF-P-1B SUCTION FROM SF POOL "A"3 C 8 CK SA A 0.3 CValve Name SF POOL "A" COOLING RETURN CHECK VALVE8 CK SA A 0 O/C 302-630Valve Name SF POOL "B" COOLING RETURN CHECK VALVEH-1 CCR CMCOF CMRevision 0October 25, 2013A15 -52  5Inservice Testing Valve TableSPENT FUEL COOLING (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.1-SF-V-7 3. C 8 CK SA A
* SYS O/C 302-630 F-5 CC M3CO M3Valve Name SF-P1A DISCHARGE CHECK VALVE1-SF-V-8 3 C 8 CK SA A SYS O/C 302-630 D-5 CC M3CO M3Valve Name SF-P1B DISCHARGE CHECK VALVERevision 0October 25, 2013A15 -53  5Inservice Testing Valve TableGASEOUS WASTE DISPOSAL (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.1-WDG-V-32 A 2 GL MO A 0 C 302-694 -G-6 LTJ AJPI Y2STC M3Valve Name CONTAINMENT ISOLATION -RB VENT HEADER VALVE1-WDG-V-4 2 A2 GA SO A 0 C 302-694 G-5 FCý M3LTJ AJPI Y2STC M3Valve Name CONTAINMENT ISOLATION -RB VENT HEADER VALVEIST-013Revision 0October 25, 2013A15 -54  5Inservice Testing Valve TableLIQUID RADWASTE DISPOSAL (Page 1)Valve EPN Safety Category Size Valve Act. Active I Normal Safety P&&ID P&&IDClass Type Type Passive Position Position Coor.1-WDL-V-303 2 A 3 GA MO A C C 302-690 F-8Valve Name CONTAINMENT ISOLATION -RC DRAIN PUMP DISCH VALVE1-WDL-V-304 2 A 3 GL AO A C C 302-690 E-8Valve Name CONTAINMENT ISOLATION -RC DRAIN PUMP DISCH ISOL1-WDL-V-534 2 A 6 GA AO A C C 302-719 B-6Valve Name CONTAINMENT ISOLATION -RB SUMP DRAIN TO AUX BLDG1-WDL-V-535 2 A 6 GA AO A C C 302-719 B-6Valve Name CONTAINMENT ISOLATION -RB SUMP DRAIN TO AUX BLDG1-WDL-V-727 2 A/C 0.25 RV SA A C O/C 302-690 F-8Test Test Relief Deferred Tech.Type Freq. Request Just. Pos.LTJ AJPI Y2STC M3FC M3LTJ AJPI Y2STC M3FC M3LTJ AJPI Y2STC M3FC M3LTJ AJPI Y2STC M3LTJ AJRT Y10IST-013IST-013IST-013Valve Name CONTAINMENT PENETRATION NO. 331 RELIEFRevision 0October 25, 2013A15 -55 Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 16CHECK VALVE CONDITION MONITORING PLAN INDEXRevision 0October 25, 2013A16- 1
.Three Mile Island Unit #1Inservice Testing Program PlanATTACHMENT 16Valves in Check Valve Condition.Monitoring ProgramValves shown in this table are monitored in the Check Valve Condition Monitoring (CVCM)Program. The details for each valve, including individual. valve testing information, can be found inAttachment 15 of this Program Plan.. The Test Plan and Test Analysis review for the valves aremaintained in the individual Check Valve Condition Monitoring Plans.Item CVCM Plan Valve EPNs DescriptionContainment Isolation -RB Spray Header Check1 CMP-BS-01 1-BS-V-30A/B ValvesContainment Isolation -Reclaimed Feed To RB2 CMP-CA-01 1-CA-V-192 Check3 CMP-CF-01 1-CF-V-12A/B Containment Isolation -CFT Makeup Check Valves4 CMP-CF-02 1-CF-V-4A/B Core Flood Tanks Outlet Check Valves5 CMP-CO-01 1-CO-V-16A/B Condensate Check Valve -Supply To EFW Pumps6 CMP-CO-02 1-CO-V-175A/B EFW Pump Bearing Cooling Return Check Valves7 CMP-DH-01 1-DH-V-69 Containment Isolation -DH To PZR Aux Spray Line8 CMP-FW-01 1-FW-V-122AJB Containment Isolation -OTSG Inlet Check Valves9 CMP-IC-01 1-IC-V-16 Containment Isol -CRD Cooling Inlet Check Valve10 CMP-IC-02 1-iC-V-18. Containment Isol -Inter CIg Inlet to RB Check Valve11 CMP-MS-01 1-MS-V-9A/B Main Steam Supply Check Valve To EF-Ul..1-MU-V-12 CMP-MU-01 107A/B/C/D Containment Isolation -HPI To RC Supply Checks13 'CMP-MU-02 1-MU-V-54A/B Lithium Hydroxide Pump To MU System Checks14 CMP-MU-03 1-MU-V-116 Containment Isolation -Seal Ini Spray/RC Check15 CMP-MU-04 1-MU-V-219 Normal Makeup Line To HPI Line B CheckHPI Loop "B" Back Flow From Makeup -Check16 CMP-MU-05 1-MU-V-220 Valve1-MU-V-86A/B,17 CMP-MU-06 MU-V-95 RCS HPI Inlet Check Valves18 CMP-MU-07 1-MU-V-94 Loop RCS HPI Inlet Check Valve19 CMP-NS-01 1-NS-V-11 RCP Motor Cooler Supply Valve1-NS-V-20 CMP-NS-02 1OA/B/C Nuc Svcs Pump Discharge Check Valves21 CMP-SF-01 1-SF-V-50/51. SF Pool Cooling Return Check ValveRevision 0October 25, 2013A16 -2}}

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