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#REDIRECT [[L-PI-15-030, Application to Revise Technical Specifications to Adopt TSTF-523, Generic Letter 2008-01, Managing Gas Accumulation, Using the Consolidated Line Item Improvement Process]]
| number = ML15187A259
| issue date = 06/29/2015
| title = Prairie Island, Units 1 and 2 - Application to Revise Technical Specifications to Adopt TSTF-523, Generic Letter 2008-01, Managing Gas Accumulation, Using the Consolidated Line Item Improvement Process
| author name = Sharp S
| author affiliation = Northern States Power Co, Xcel Energy
| addressee name =
| addressee affiliation = NRC/Document Control Desk, NRC/NRR
| docket = 05000282, 05000306
| license number = DPR-042, DPR-060
| contact person =
| case reference number = GL-08-001, L-PI-15-030
| document type = Letter, License-Application for Facility Operating License (Amend/Renewal) DKT 50, Technical Specifications
| page count = 64
| project =
| stage = RAI
}}
 
=Text=
{{#Wiki_filter:XceIEnergy° JIUN 29 92015 L-PI-1 5-03010 CFR 50.90U S Nuclear Regulatory Commission ATTN: Document Control DeskWashington, DC 20555-0001 Prairie Island Nuclear Generating Plant Units 1 and 2Dockets 50-282 and 50-306Renewed License Nos. DPR-42 and DPR-60Application to Revise Technical Specifications to Adopt TSTF-523, "Generic Letter2008-01.
Managiing Gas Accumulation",
Using the Consolidated Line Item Improvement ProcessPursuant to 10 CFR 50.90, Northern States Power Company, a Minnesota corporation, doing business as Xcel Energy (hereafter "NSPM"),
hereby submits a request for anamendment to revise the Technical Specifications (TS) for Prairie Island NuclearGenerating Plant (PINGP),
Units 1 and 2.Attachment 1 provides a description and assessment of the proposed change.Attachment 2 provides the existing TS pages marked up to show the proposed change.Attachment 3 provides revised (clean) TS pages. Attachment 4 provides existing TSBases pages marked to show the proposed change. Changes to the existing TS Bases,consistent with the technical and regulatory
: analyses, will be implemented under theTechnical Specification Bases Control Program.
They are provided in Attachment 4 forinformation only.By letter dated January 15, 2015 (ML15015A404),
NSPM committed to evaluate theimpact of adopting Technical Specification Task Force (TSTF) Traveler 523 by June 30,2015 and submit an LAR for its adoption if necessary.
This submittal satisfies thecommitment.
Approval of the proposed amendment is requested by June 30, 2016. Once approved, the amendment shall be implemented within 90 days.In accordance with 10 CFR 50.91, a copy of this application, with attachments, is beingprovided to the designated State of Minnesota Official.
1717 Wakonade Drive East a Welch, Minnesota 55089-9642 Telephone:
651.388.1121 Document Control DeskPage 2If there are any questions or if additional information is needed, please contact Mr.Bryan Willard at 651--267-6829.
Summary of Commitments This letter contains no new commitments and no revisions to existing commitments.
I declare under penalty of perjury that the foregoing is true and correct.Executed on 2"e , oI'-TScott SharpDirector Site Operations, Prairie Island Nuclear Generating PlantNorthern States Power Company -Minnesota Attachments (4)cc: Administrator, Region Ill, USNRCProject Manager, PINGP, USNRCResident Inspector, PINGP, USNRCState of Minnesota ATTACHMENT 1Description and Assessment Application to Revise Technical Specifications to Adopt TSTF-523, "Generic Letter2008-01, Managing Gas Accumulation,"
Using the Consolidated Line Item Improvement Process1.0 DESCRIPTION The proposed change revises or adds Surveillance Requirements to verify that thesystem locations susceptible to gas accumulation are sufficiently filled with water and toprovide allowances which permit performance of the verification.
The changes arebeing made to address the concerns discussed in Generic Letter 2008-01, "Managing Gas Accumulation in Emergency Core Cooling, Decay Heat Removal, and Containment Spray Systems."
The proposed amendment is consistent with TSTF-523, Revision 2, "Generic Letter2008-01, Managing Gas Accumulation."
 
==2.0 ASSESSMENT==
2.1 Applicability of Published Safety Evaluation Northern States Power Company, a Minnesota corporation, doing business as XcelEnergy (hereafter "NSPM"),
has reviewed the model safety evaluation dated January15, 2014 as part of the Federal Register Notice of Availability.
This review included areview of the NRC staff's evaluation, as well as the information provided in TSTF-523, Revision
: 2. As described in the subsequent paragraphs,'
NSPM concluded that thejustifications presented in the TSTF-523, Revision 2, proposal and the model safetyevaluation prepared by the NRC staff are applicable to Prairie Island NuclearGenerating Plant (PINGP),
Units 1 and 2, and justify this amendment for theincorporation of the changes to the PINOP TS.TSTF-523, Revision 2, and the model safety evaluation discuss the applicable regulatory requirements and guidance, including the 10 CFR 50, Appendix A, GeneralDesign Criteria (GDC). PINGP Units 1 and 2 were not licensed to the 10 CFR 50,Appendix A, GDC. The PINGP equivalent of the referenced GDC are discussed in theUpdated Safety Evaluation Report (USAR) Section 1.2, Principal Design Criteria.
ThePINGP design criterion that equates to 10 CFR 50 Appendix A, GDC 1 s addressed inUSAR Section 1.2.1, Overall Plant Requirements (GDC 1 -GDC 5) and the designcriteria that equate to 10 CFR 50 Appendix A, GDC 34 through GDC 40 are addressed in USAR Section 1.2.6, Reactor Coolant Pressure Boundary (GDC 33 -GDC 36), andUSAR Section 1.2.7, Engineered Safety Features (GDC 37 -GDC 65). This difference Page 1 of Attachment 1 NSPMAdopt TSTF-523does not alter the conclusion that the proposed change is applicable to PINGP, Units 1and 2.2.2 Optional Changes and Variations NSPM proposes the following variations from the TS changes described in the TSTF-523, Revision 2, or~the applicable parts of the NRC staff's model safety evaluation dated January 15, 2014.The PINGP TS utilize different numbering than the NUREG-1431, Standard Technical Specifications (STS), on which TSTF-523, Revision 2, was based. PINGP TS do nothave the existing TS 3.5.2, EGGS -Operating, Surveillance Requirements revised byTSTF-523, Revision
: 2. This difference does not affect the applicability of TSTF-523, Revision 2, to the PINGP TS. Specifically, numbering and content differences areprovided in the following table.NUREG-1431, STS TSTF-523 Change PINGP TS Change Differences 3.5.2, EGCS -Operating Revise SR 3.5.2.3 and Add new SR 3.5.2.4, SRassociated Bases. 3.5.2.5, and new associated Bases. Renumber subsequent SRs.3.5.3, EGOS -Shutdown Revise LCO Bases Revise SR 3.5.3.1 to includeonly. two additional SRs.3.6.6A, Containment Spray Add new SR 3.6.6A.4 Add new SR 3.6.5.3 andand Cooling Systems and associated Bases. associated Bases.With the exception of the SR 3.5.2.5 addition, these differences are administrative innature. None of the proposed variations affect the applicability of TSTF-523 to thePINGP TS.NSPM is proposing the addition of new SR 3.5.2.5, with an associated Frequency of"Prior to entering Mode 3 after exiting shutdown cooling" in lieu of the specified 31 dayFrequency.
The justification for the additional SR and extended Frequency is providedbelow:*Safety injection system inaccessible location configuration The four inaccessible locations (two locations per unit) are designated 1SI-44,1SI-45 for Unit 1 and 2S1-14A, 2S1-14B for Unit 2. The inaccessible locations arelocated on corresponding line numbers 2-SI-35A, 2-SI-35B, 2-2SI-35A and 2-2SI-35B.
These locations are adjacent to the RCS first-off pressure isolation check valves and are inaccessible during normal operations due to dose andtemperature concerns.'
Page 2 of 6 Attachment 1 NSPMAdopt TSTF-523The Safety Injection system piping injects into each of the RCS cold legs througha single common pipe that branches into two separate 2" lines. On each of the 2"branches, there are two check valves installed that are the pressure boundaryvalves for the RCS. The first-off check valves (SI1-9-1, SI-9-2, 2SI-9-I, and 2SI-9-2) are 6" swing disc check valves. The second-off check valves (S1-I16-4, SI-i16-5, 2S1-16-4, and 2S1-16-6) are 2" spring loaded piston type check valves.The geometry of the four inaccessible locations consists of a vertically oriented6" check valve that connects to the RCS loop piping with RCS pressure on thedownstream side of the disc. These locations are all high points that would allowgas to accumulate inside the check valve on the upstream side of the disc.The locations are inaccessible due to high dose rates during power operation and close proximity to the RCS loop piping. These areas are examined at thepiping adjacent to the check valve due to the valve configuration andexamination limitations.
* Gas intrusion sourceThe Safety Injection piping connects directly to a pressurized Reactor CoolantSystem. Dissolved gases in the reactor coolant are controlled by the Chemicaland Volume Control System (VC) that maintains the concentration of hydrogenor nitrogen gas present through the Volume Control Tank (VCT). The currentGas Accumulation Management Program (GAMP) indicates if back-leakage
\were to occur, the lower pressure on the upstream side of the check valve wouldresult in hydrogen gas coming out of solution and a void formation.
Thus, theselocations meet the definition of susceptible locations per the programdocuments.
Site engineering personnel have determined that a very specific leakagecondition must exist for a void to form at the inaccessible locations.
For voidformation to occur, both the first-off and second-off pressure boundary checkvalves need to be leaking.
If only a single check valve is leaking, a void cannotform due to pressurization between the check valves. If the first-off check valveis leaking at a rate that is greater than the second-off check valve, then the areabetween the check valves will pressurize and a void cannot form. A void will onlyform if the second-off check valve is leaking at a greater rate than the first-off check valve since that is the only condition that will simultaneously allow leakagefrom the RCS and also prevent pressure buildup between the check valves.Per USAR Section 6, the design leakage limit for these valves is stated as 3cc/hr per inch of nominal pipe size. This means that the 6" first-off check valveswould have a design leakage rate of 18 cc/hr and the 2" second-off check valveswould have a design leakage rate of 6 cc/hr. This design leakage rate isimportant to consider since it is impossible to design a zero leakage check valvewith hard seats. Since the first-off check valves have a higher design leakagePage 3 of 6 Attachment 1 NSPMAdopt TSTF-523rate than the second-off check valves, it supports the position that void formation is unlikely.
This is because a higher leakage through the first-off check valves,when compared to the second-off check valves, would tend to pressurize thepiping between the check valves, which would effectively prevent void formation.
* Alternative monitoring PINGP will monitor the locations prior to entering Mode 3 after exiting shutdowncooling during startup in lieu of the specified 31 day frequency.
In addition to the proposed TS 3.2.5.2 Surveillance Frequency, the inaccessible locations are checked for voids at the earliest possible shutdown condition.
Thisas-found testing occurs in accordance with the PINGP GAMP, under conditions that ensure the check valves at the inaccessible locations are properly seated.During refueling
: outages, PINGP will verify the relative leakage rates of thecheck valves are maintained such that void formation during the cycle ismitigated.
The check valve leakage rates will be validated to ensure no leakageis present, or the leakage rate of the first-off check valves (SI-9-I, SI-9-2, 2SI-9-1, and 2SI-9-2) is greater than the corresponding second-off check valves (SI-16-4, SI-I16-5, 2S1-16-4, and 2S1-16-6).
By verifying the conditions necessary for void formation are not present,maintaining the as left condition during the cycle, and monitoring of the locations when accessible, reasonable assurance of safety is maintained for the system.3.0 REGULATORY ANALYSIS3.1 No Significant Hazards Consideration Northern States Power Company, a Minnesota corporation, doing business as XcelEnergy (hereafter "NSPM"),
requests adoption of TSTF-523, Revision 2, "GenericLetter 2008-01, Managing Gas Accumulation,"
which is an approved change to thestandard technical specifications (STS), into the Prairie Island Nuclear Generating Plant, Units I and 2, technical specifications (TS). The proposed change addsSurveillance Requirements to verify that the system locations susceptible gasaccumulation are sufficiently filled with water and to provide allowances which permitperformance of the verification.
Northern States Power Company, a Minnesota corporation (NSPM), evaluated whetheror not a significant hazards consideration is involved with the proposed amendment byfocusing on the three standards set forth in 10 CFR 50.92, "Issuance of amendment,"
as discussed below:Page 4 of 6 Attachment 1 NSPMAdopt TSTF-5231. Does the proposed amendment involve a significant increase in theprobability or consequences of an accident previously evaluated?
Response:
NoThe proposed change adds Surveillance Requirements (SRs) that requireverification that the Emergency Core Cooling System (ECCS), the Residual HeatRemoval (RHR) System, and the Containment Spray (CS) System are notrendered inoperable due to accumulated gas and to provide allowances whichpermit performance of the revised verification.
Gas accumulation in the subjectsystems is not an initiator of any accident previously evaluated.
As a result, theprobability of any accident previously evaluated is not significantly increased.
The proposed SIRs ensure that the subject systems continue to be capable toperform their assumed safety function and are not rendered inoperable due togas accumulation.
Thus, the consequences of any accident previously evaluated are not significantly increased.
Therefore, the proposed licensing basis change does not involve a significant increase in the probability or consequences of an accident previously evaluated.
: 2. Does the proposed amendment create the possibility of a new or different kind of accident from any accident previously evaluated?
Response:
NoThe proposed change adds SRs that require verification that the ECCS, the RHRSystem, and the CS System are not rendered inoperable due to accumulated gas and to provide allowances which permit performance of the revisedverification.
The proposed change does not involve a physical alteration of theplant (i.e., no new or different type of equipment will be installed) or a change inthe methods governing normal plant operation.
In addition, the proposed changedoes not impose any new or different requirements that could initiate anaccident.
The proposed change does not alter assumptions made in the safetyanalysis and is consistent with the safety analysis assumptions.
Therefore, the proposed licensing basis change does not create the possibility ofa new or different kind of accident from any previously evaluated.
: 3. Does the proposed amendment involve a significant reduction in a marginof safety?Response:
NoThe proposed change adds SRs that require verification that the ECCS, the RHRSystem, and the CS System are not rendered inoperable due to accumulated gas and to provide allowances which permit performance of the revisedPage 5 of 6 Attachment I NSPMAdopt TSTF-523verification.
The proposed change adds new requirements to manage gasaccumulation in order to ensure the subject systems are capable of performing their assumed safety functions.
The proposed SRs will ensure that theassumptions of the safety analysis are protected.
The proposed change does notadversely affect any current plant safety margins or the reliability of theequipment assumed in the safety analysis.
Therefore, there are no changesbeing made to any safety analysis assumptions, safety limits or limiting safetysystem settings that would adversely affect plant safety as a result of theproposed change.Therefore, the proposed licensing basis change does not involve a significant reduction in a margin of safety.Based on the above, Northern States Power Company, a Minnesota corporation (NSPM), concludes that the proposed amendment does not involve a significant hazards consideration under the standards set forth in 10 CFR 50.92(c) and,accordingly, a finding of "no significant hazards consideration" is justified.
4.0 ENVIRONMENTAL EVALUATION The proposed change would change a requirement with respect to installation or use ofa facility component located within the restricted area, as defined in 10 CFR 20, orwould change an inspection or surveillance requirement.
: However, the proposedamendment does not involve (i) a significant hazards consideration, (ii) a significant change in the types or significant increase in the amounts of any effluent that may bereleased
: offsite, or (iii) a significant increase in individual or cumulative occupational radiation exposure.
Accordingly, the proposed amendment meets the eligibility criterion for categorical exclusion set forth in 10 CER 51 .22(c)(9).
Therefore, pursuant to 10 CFR51.22(b),
no environmental impact statement or environmental assessment need beprepared in connection with the proposed amendment.
Page 6 of 6 ATTACHMENT 2Technical Specification Pages (Markup)3.4.6-33.4.7-43.4.8-33.5.2-23.5.2-33.5.2-43.5.3-23.6.5-33.6.5-43.9.5-33.9.6-311 pages follow RCS Loops -MODE 43.4.6SURVEILLANCEREQUIREMENTS______
SURVEILLANCE FREQUENCY SR 3.4.6.1 Verify required RHR or RCS loop is in 12 hoursoperation.
SR 3.4.6.2 Verify required SG capable of removing decay 12 hoursheat.SR 3.4.6.3----------NOTE--------
Not required to be performed until 24 hours aftera required pump is not in operation.
Verify correct breaker alignment and indicated 7 dayspower are available to each required pump.SR 3.4.6,4 NOTE---------------..
NOTNot reauired to be performed until 12 hours afterentering MODE 4.Verify required RHR looo locations susceptible to 31dygas accumulation are sufficiently filled with water.Prairie IslandUnits 1 and 2Unit 1 -Amendment No. 58Unit 2 -Amendment No. 93.4.6-3 RCS Loops -MODE 5, Loops Filled3.4.7SURVEILLANCEREQUIREMENTS______
SURVEILLANCE FREQUENCY SR 3.4.7.1 Verify required RHR loop is in operation.
12 hoursSR 3.4.7.2 Verify required SG capable of removing decay 12 hoursheat.SR 3.4.7.3-----------NOTE--------
Not required to be performed until 24 hours aftera required pump is not in operation.
Verify correct breaker alignment and indicated 7 dayspower are available to each required RHR pump.SR 3.4.7,4 Verify required RHR loop, locations susceptible to 31dyaccumulation are sufficiently filled withPrairie IslandUnits 1 and 2Unit 1 -Amendment No. 58Unit 2 -Amendment No. 41493.4.7-4 RCS Loops -MODE 5, Loops Not Filled3.4.8SURVEILLANCEREQUIREMENTS______
SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify required RHIR loop is in operation.
12 hoursSR 3.4.8.2----------NOTE---------
Not required to be performed until 24 hours aftera required pump is not in operation.
Verify correct breaker alignment and indicated 7 dayspower are available to each required RHR pump.SR 3.4.8.3 Verify RHR looD locations susceptible to gas 1dyaccumulation are sufficiently filled with water.Prairie IslandUnits 1 and 23483Unit 1 -Amendment No. 4-58Unit 2 -Amendment No. 4493.4.8-3 ECCS -Operating 3.5.2SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify the following valves are in the listed position.
12 hoursUnit 1ValveNumber3207032068320733220632207Unit 2ValveNumber3217332171321763220832209Westing-houseValveNumber8801A8801B8806A881 6A881 6BWesting-houseValveNumber8801A8801B8806A881 6A881 6BPositionOPENOPENOPENCLOSEDCLOSEDPositionOPENOPENOPENCLOSEDCLOSEDFunctionSI Injection to RCS Cold Leg ASI Injection to RCS Cold Leg BSI Cold Leg Injection LineSI Pump Suction from RIIRSI Pump Suction from RHIRFunctionSI Injection to RCS Cold Leg ASI Injection to RCS Cold Leg BSI Cold Leg Injection LineSI Pump Suction from RHRSI Pump Suction from RHTRSR 3.5.2.2-~~~NOTE--------
Not required to be met for system vent flow oathsopened under administrative control.31 daysVerify each ECCS manual, power operated, andautomatic valve in the flow path that is not locked,sealed, or otherwise secured in position, is in thecorrect position.
Prairie IslandUnits 1 and 2Unit 1 -Amendment No. 4-58 4-823.5.2-2 Unit 2 -Amendment No. 49 4-7-2 ECCS -Operating 3.5.2SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.5.2.3 Verify power to the valve operator has been removed 31 daysfor each valve listed in SR 3.5.2.1.SR 3.5,2.4 Verify ECCS accessible locations susceptible to 31dyaccumulation are sufficiently filled with water.SR 3.5,2.5 Verify ECCS inaccessible locations sulsceptible to accumulation are sufficiently filled with water. MD feextig sutowcooingSR 3.5.2.(!4 Verify each ECCS pump's developed head at the test In accordance flow point is greater than or equal to the required with the Inservice developed head. Testing ProgramSR 3.5.2.7$
Verify each ECCS automatic valve in the flow path 24 monthsthat is not locked, sealed, or otherwise secured inposition, actuates to the correct position on an actualor simulated actuation signal.Prairie IslandUnits 1 and 2Unit 13.5.2-3 Unit 2Amendment No. -8 4-82-Amendment No. -149 47 ECCS -Operating 3.5.2SURVEILLANCE REQUIREMENTS (continued)_______
SURVEILLANCE FREQUENCY SR 3.5.2.86 Verify each ECCS pump starts automatically on an 24 monthsactual or simulated actuation signal.SR 3.5.2.9-7 Verify each ECCS throttle valve listed below is in the 24 monthscorrect position.
Unit 1 Valve Number Unit 2 Valve NumberSI-15-6 2SI-15-6SI-15-7 2SI-15-7SI-15-8 2SI-15-8SI-15-9 2SI-15-9SR 3.5.2.1Q8 Verify, by visual inspection, each ECCS train 24 monthscontainment sump suction inlet is not restricted bydebris and the suction inlet strainers show no evidenceof structural distress or abnormal corrosion.
Prairie IslandUnits 1 and 2Unit 1 -Amendment No. 4-58s 4-823.5.2-4 Unit 2 -Amendment No. 449 4-7-2 ECCS -Shutdown3.5.3ACTIONS (continued)
________CONDITION REQUIRED ACTION COMPLETION TIMEC. Required Action and C.l1 Be in MODE 5. 24 hoursassociated Completion Time of Condition B notmet.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 The following SRs are applicable for all equipment In accordance required to be OPERABLE:
with applicable SRsSR 3.5.2.1 SR SR 3.5.2.3 SR 3.5.2.98, SR 3.5.2.4Prairie IslandUnits 1 and 2Unit 1 -Amendment No. 4--58 6-7-Unit 2 -Amendment No. 49 4473.5.3-2 Containment Spray and Cooling Systems3.6.5SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1----------...-
NOTE---------
Not required to be met for system vent flow oathsonened under administrative control.Verify each containment spray manual, poweroperated, and automatic valve in the flow path that isnot locked, sealed, or otherwise secured in position isin the correct position.
31 daysSR 3.6.5.2 Operate each containment fan coil unit on low motor 31 daysspeed for > 15 minutes.SR 3.6.5.3 Verify containment snrav locations susceptible to 31dyaccumulation are sufficiently filled with water.SR 3.6.5._____
Verify cooling water flow rate to each containment 24 monthsfan coil unit is >900 gpm.SR 3.6.5.54 Verify each containment spray pump's developed In accordance head at the flow test point is greater than or equal to with thethe required developed head. Inservice TestingProgramPrairie IslandUnits 1 and 2Unit 1 -Amendment No. -5l-t7-3.6.5-3 Unit 2 -Amendment No. 49 4-6-Reiocd by, lett--,r datd,. Augu,- 2,,, 2006)FIA Containment Spray and Cooling Systems3.6.5SURVEILLANCE REQUIREMENTS (continued)
______SURVEILLANCE FREQUENCY SR 3.6.5._fa-Verify each automatic containment spray valve in the 24 monthsflow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position onan actual or simulated actuation signal.SR 3.6.5.76 Verify each containment spray pump starts 24 monthsautomatically on an actual or simulated actuation signal.SR 3.6.5.8g7 Verify each containment cooling train starts 24 monthsautomatically on an actual or simulated actuation signal.SR 3.6.5._9g Verify each spray nozzle is unobstructed.
Following maintenance which couldresult in nozzleblockagePrairie IslandUnits 1 and 2Unit 1 -Amendment No. 58 41903.6.5-4 Unit 2 -Amendment No. -149 4-79 RHR and Coolant Circulation-High Water Level3.9.5SURVEILLANCE REQUIREMENTS______
SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify one RHR loop is in operation.
12 hoursSR 3.9.5.2 Verify required RLHR loon locations susceptible to 31dygas accumulation are sufficiently filled with water.Prairie IslandUnits 1 and 2Unit 1 -Amendment No. 41-58Unit 2 -Amendment No. 4493.9.5-3 RLIR and Coolant Circulation-Low Water Level3.9.6ACTIONS ______CONDITION REQUIRED ACTION COMPLETION TIMEB. (continued)
B.5.1 Close each penetration 4 hoursproviding direct accessfrom the containment atmosphere to the outsideatmosphere with a manualor automatic isolation valve, or blind flange.ORB.5.2 Verify each penetration is 4 hourscapable of being closed byan OPERABLEContainment Ventilation Isolation System.SURVEILLANCE REQUIREMENTS S URVEILLANCE FREQUENCY SR 3.9.6.1 Verify one RHLR loop is in operation.
12 hoursSR 3.9.6.2 Verify correct breaker alignment and indicated power 7 daysavailable to the required RIIR pump that is not inoperation.
SR 3.9.6.3 Verify. RHR looD locations susceptible to accumulation are sufficiently filled with water.Prairie IslandUnits 1 and 2Unit 1 -Amendment No. 4-58Unit 2 -Amendment No. 4-493.9.6-3 ATTACHMENT 3Technical Specification Pages (Retyped) 3.4.6-33.4.7-43.4.8-33.5.2-23.5.2-33.5.2-43.5.3-23.6.5-33.6.5-43.9.5-33.9.6-311 pages follow RCS Loops -MODE 43.4.6SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 Verify required RHR or RCS loop is in 12 hoursoperation.
SR 3.4.6.2 Verify required SG capable of removing decay 12 hoursheat.SR 3.4.6.3-----------NOTE--------
Not required to be performed until 24 hours aftera required pump is not in operation.
Verify correct breaker alignment and indicated 7 dayspower are available to each required pump.SR 3.4.6.4-----------NOTE--------
Not required to be performed until 12 hours afterentering MODE 4.Verify required RUR loop locations susceptible to 31 daysgas accumulation are sufficiently filled with water.Prairie IslandUnits 1 and 23463Unit 1 -Amendment No. 58Unit 2 -Amendment No. 4-493.4.6-3 RCS Loops -MODE 5, Loops Filled3.4.7SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 Verify required RHIR loop is in operation.
12 hoursSR 3.4.7.2 Verify required SG capable of removing decay 12 hoursheat.SR 3.4.7.3-----------NOTE--------
Not required to be performed until 24 hours aftera required pump is not in operation.
Verify correct breaker alignment and indicated 7 dayspower are available to each required RHR pump.SR 3.4.7.4 Verify required RHR loop locations susceptible to 31 daysgas accumulation are sufficiently filled withwater.Prairie IslandUnits 1 and 2Unit 1 -Amendment No. 5-sUnit 2 -Amendment No. 4-493.4.7-4 RCS Loops -MODE 5, Loops Not Filled3.4.8SURVEILLANCE REQUIREMENTS
______SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify required RIIR loop is in operation.
12 hoursSR 3.4.8.2----------NOTE---------
Not required to be performed until 24 hours aftera required pump is not in operation.
Verify correct breaker alignment and indicated 7 dayspower are available to each required RHR pump.SR 3.4.8.3 Verify RHIR loop locations susceptible to gas 31 daysaccumulation are sufficiently filled with water.Prairie IslandUnits 1 and 2Unit 1 -Amendment No. 4-58Unit 2 -Amendment No. 4-493.4.8-3 ECCS -Operating 3.5.2SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify the following valves are in the listed position.
12 hoursUnit 1ValveNumber3207032068320733220632207Unit 2ValveNumber3217332171321763220832209Westing-houseValveNumber8801A8801B8806A881 6A881 6BWesting-houseValveNumber8801A8801B8806A881 6A881 6BPositionOPENOPENOPENCLOSEDCLOSEDFunctionSI Injection to RCS Cold Leg ASI Injection to RCS Cold Leg BSI Cold Leg Injection LineSI Pump Suction from RIIRSI Pump Suction from RHRPositionOPENOPENOPENCLOSEDCLOSEDFunctionSI Injection to RCS Cold Leg ASI Injection to RCS Cold Leg BSI Cold Leg Injection LineSI Pump Suction from RIIRSI Pump Suction from RHRSR 3.5.2.2-~~~NOTE--------
Not required to be met for system vent flow pathsopened under administrative control.Verify each ECCS manual, power operated, andautomatic valve in the flow path that is not locked,sealed, or otherwise secured in position, is in thecorrect position.
31 daysPrairie IslandUnits 1 and 2Unit 1 -Amendment No. 4-58 41-823.5.2-2 Unit 2 -Amendment No. -149 1-72 ECCS -Operating 3.5.2SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.5.2.3 Verify power to the valve operator has been removed 31 daysfor each valve listed in SR 3.5.2.1.SR 3.5.2.4 Verify ECCS accessible locations susceptible to gas 31 daysaccumulation are sufficiently filled with water.SR 3.5.2.5 Verify ECCS inaccessible locations susceptible to gas Prior to enteringaccumulation are sufficiently filled with water. MODE 3 afterexiting shutdowncoolingSR 3.5.2.6 Verify each ECCS pump's developed head at the test In accordance flow point is greater than or equal to the required with the Inservice developed head. Testing ProgramSR 3.5.2.7 Verify~each ECCS automatic valve in the flow path 24 monthsthat is not locked, sealed, or otherwise secured inposition, actuates to the correct position on an actualor simulated actuation signal.Prairie IslandUnits 1 and 2Unit 1 -Amendment No. 4-5% 4-1-S3.5.2-3 Unit 2 -Amendment No. 4-49 4-72 ECCS -Operating 3.5.2SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.5.2.8 Verify each ECCS pump starts automatically on an 24 monthsactual or simulated actuation signal.SR 3.5.2.9 Verify each ECCS throttle valve listed below is in the 24 monthscorrect position.
Unit 1 Valve Number Unit 2 Valve NumberSI-15-6 2SI-15-6SI-15-7 2SI-15-7SI- 15-8 2SI- 15-8SI-15-9 2SI-15-9SR 3.5.2.1i0 Verify, by visual inspection, each ECCS train 24 monthscontainment sump suction inlet is not restricted bydebris and the suction inlet strainers show no evidenceof structural distress or abnormal corrosion.
IPrairie IslandUnits 1 and 2Unit 1 -Amendment No. 5-s 4-823.5.2-4 Unit 2 -Amendment No. 4-4-9 1-72 ECCS -Shutdown3.5.3ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIMEC. Required Action and C. 1 Be in MODE 5. 24 hoursassociated Completion Time of Condition B notmet.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 The following SRs are applicable for all equipment In accordance required to be OPERABLE:
with applicable SRsSR 3.5.2.1 SR 3.5.2.6SR 3.5.2.3 SR 3.5.2.9SR 3.5.2.4 SR 3.5.2.10SR 3.5.2.5Prairie IslandUnits 1 and 2Unit 1 -Amendment No. -4~1--847 3.5.3-2 Unit 2 -Amendment No.1-4914 Containment Spray and Cooling Systems3.6.5SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1---------
NOTE--------
Not required to be met for system vent flow pathsopened under administrative control.Verify each containment spray manual, poweroperated, and automatic valve in the flow path that isnot locked, sealed, or otherwise secured in position isin the correct position.
31 daysSR 3.6.5.2 Operate each containment fan coil unit on low motor 31 daysspeed for > 15 minutes.SR 3.6.5.3 Verify containment spray locations susceptible to gas 31 daysaccumulation are sufficiently filled with water.SR 3.6.5.4 Verify cooling water flow rate to each containment 24 monthsfan coil unit is>900 gpm.SR 3.6.5.5 Verify each containment spray pump's developed In accordance head at the flow test point is greater than or equal to with thethe required developed head. Inservice TestingProgramPrairie IslandUnits 1 and 2Unit 1 -Amendment No. 4-5 -t-7-33.6.5-3 Unit 2 -Amendment No. 4149 6 Containment Spray and Cooling Systems3.6.5SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.6.5.6 Verify each automatic containment spray valve in the 24 monthsflow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position onan actual or simulated actuation signal.SR 3.6.5.7 Verify each containment spray pump starts 24 monthsautomatically on an actual or simulated actuation signal.SR 3.6.5.8 Verify each containment cooling train starts 24 monthsautomatically on an actual or simulated actuation signal.SR 3.6.5.9 Verify each spray nozzle is unobstructed.
Following maintenance which couldresult in nozzleblockagePrairie IslandUnits 1 and 2Unit 1 -Amendment No. 4-5-s 4-93.6.5-4 Unit 2 -Amendment No.4-494--7-9 RHIR and Coolant Circulation-High Water Level3.9.5SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify one RHTR loop is in operation.
12 hoursSR 3.9.5.2 Verify required RJIR loop locations susceptible to 31 daysgas accumulation are sufficiently filled with water.Prairie IslandUnits 1 and 2Unit 1 -Amendment No. 58Unit 2 -Amendment No. 4-493.9.5-3 RHR and Coolant Circulation-Low Water Level3.9.6ACTIONSCO~NDITION REQUIRED ACTION COMPLETION TIMEB. (continued)
B.5.1 Close each penetration 4 hoursproviding direct accessfrom the containment atmosphere to the outsideatmosphere with a manualor automatic isolation valve, or blind flange.ORB.5.2 Verify each penetration is 4 hourscapable of being closed byan OPERABLEContainment Ventilation Isolation System.SURVEILLANCE REQUIREMENTS______
SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify one RHR toop is in operation.
12 hoursSR 3.9.6.2 Verify correct breaker alignment and indicated power 7 daysavailable to the required RIHR pump that is not inoperation.
SR 3.9.6.3 Verify RHR loop locations susceptible to gas 31 daysaccumulation are sufficiently filled with water.Prairie IslandUnits 1 and 2Unit 1 -Amendment No. 45-gUnit 2 -Amendment No. 41493.9.6-3 ATTACHMENT 4Technical Specification Bases (Markup)B 3.4.6-3B 3.4.6-6B 3.4.6-7B 3.4.6-8B 3.4.7-4B 3.4.7-7B 3.4.7-8B 3.4.8-2B 3.4.8-4B 3.4.8-5B 3.4.8-6B 3.5.2-6B 3.5.2-10B 3.5.2-11B 3.5.2-12B 3.5.2-13B 3.5.2-14B 3.5.3-2B 3.6.5-6B 3.6.5-11B 3.6.5-12B 3.6.5-13B 3.6.5-14B 3.6.5-15B 3.9.5-2B 3.9.5-5B 3.9.5-6B 3.9.5-7B 3.9.6-2B 3.9.6-6B 3.9.6-731 pages follow RCS Loops -MODE 4B 3.4.6BASESLCO(continued)
: b. Core outlet temperature is maintained at least 10°F belowsaturation temperature, so that no vapor bubble may form andpossibly cause a natural circulation flow obstruction.
Note 2 requires a steam or gas bubble in the pressurizer or that thesecondary side water temperature of each SG be _< 50F above eachof the RCS cold leg temperatures before the start of an RCP with anyRCS cold leg temperature
< the OPPS enable temperature specified in the PTLR. A steam or gas bubble ensures that the pressurizer willaccommodate the swell resulting from an RCP start. Either of theserestraints prevents a low temperature overpressure event due to athermal transient when an RCP is started.An OPERABLE RCS loop comprises an OPERABLE RCP and anOPERABLE SG which is capable of removing decay heat asspecified in SR 3.4.6.2.Similarly for the RHJR System, an OPERABLE RHR loop comprises an OPERABLE RHR pump capable of providing forced flow to anOPERABLE RHIR heat exchanger.
RCPs and RHR pumps areOPERABLE if they are capable of being powered and are able toprovide forced flow if required.
Management of voids isimtoortant to RHR System OPERABIIATY.
APPLICABILITY In MODE 4, this LCO ensures forced circulation of the reactorcoolant to remove decay heat from the core and to provide properboron mixing.Operation in other MODES is covered by:LCO 3.4.4, "RCS Loops -MODES 1 and 2";LCO 3.4.5, "RCS Loops -MODE 3";LCO 3.4.7, "RCS Loops -MODE 5, Loops Filled";LCO 3.4.8, "RCS Loops -MODE 5, Loops Not Filled";LCO 3.9.5, "Residual Heat Removal (RHR) and CoolantCirculation
-High Water Level" (MODE 6); andPrairie IslandUnits 1 and 2Unt1- Revyision`
....................
B 3.4.6-3 Unit2 -Revision,...endm.ent No. 49 RCS Loops -MODE 4B 3.4.6BASESSURVEILLANCE REQUIREMENTS (continued)
SR 3.4.6.2SR 3.4.6.2 requires verification that the required SG has thecapability to remove decay heat. The ability to remove decay heatrequires the ability to pressurize and control pressure in the RCS,sufficient secondary side water level in the SG relied on for decayheat removal, and an available supply of feedwater (Ref. 2). Theability of the SG to provide an adequate heat sink for decay heatremoval further ensures that the SG tubes remain covered.
The12 hour Frequency is considered adequate in view of the otherindications available in the control room to alert the operator to aloss of capability of the SG to remove decay heat.SR 3.4.6.3Verification that each required pump is OPERABLE ensures that anadditional RCS or RHTR pump can be placed in operation, if needed,to maintain decay heat removal and reactor coolant circulation.
Verification is performed by verifying proper breaker alignment andpower available to each required pump. Alternatively, verification that a pump is in operation also verifies proper breaker alignment and power availability.
The Frequency of 7 days is considered reasonable in view of other administrative controls available and hasbeen shown to be acceptable by operating experience.
This SR is modified by a Note that states the SR is not required to beperformed until 24 hours after a pump is not in operation.
SRi34.6.RHR System pitting and components have the potential to developvoids and pockets of entrained gases. Preventing and managing, aasintrusion and accumulation is necessary for proper operation of thePrairie IslandUnits 1 and 2Unitl1- *
* A endmn.-N I1-B 3.4.6-6 Unit dine.it-,,
e-449 l RCS Loops -MODE 4B 3.4.6BASESqT T BASESQTTD. JL IIT AMC LP.J &#xa5; V .LL..U 1 ..11 "T 1,%ALI J trequired RHR loon(s) and may also orevent water hammer. Dumpcavitation, and pumping of noncondensible into the reactorSelection of RHR System locations susceptible to accumulation is based onl a review of system design information, including, pi~ing,and instrumentation
: drawings, isometric drawings.
olan andelevation
: drawings, and calculations.
The design review issu~olemented by system waLk downs to validate the system highpoints and to confirm the location and orientation of imtortant comoonents that can become sources of or could otherwise causegas to be traooed or difficult to remove during system maintenance or restoration.
Susceptible locations denend on olant and systemconfiguration, such as stand-by versus ooerating conditions.
The RHR System is OPERABLE when it is sufficiently filled withwater. Acceotance criteria are established for the volume ofaccumulated gas at susceptible locations.
If accumulated isdiscovered that exceeds the acceotance criteria for the susceptible location (or the volume of accumulated at one or moresusceptible locations exceeds an acceotance criteria for gas volumeat the suction or discharge of a oump). the Surveillance is not met.If it is determined by subsecuent evaluation that the RHIR System isnot rendered inoperable by the accumulated gas (i.e.. the system issufficiently filled with water). the Surveillance may be declared met.Accumulated gas should be eliminated or brought within theacceptance criteria limits.RHR System locations susceptible to gas accumulation aremonitored and. if is found. the volume is comoared to theacceptance criteria for the location.
Susceptible locations in thesame system flow path which are subject to the same gas intrusion mechanisms may be verified by monitoring a representative sub-setPrairie IslandUnits 1 and 2Unit 1 -
No. 158oB 3.4.6-7 t.!t RCS Loops -MODE 4B 3.4.6BASESqT T
BASES~t TO ~ A~C .J.,Jk%.
V _3.LALL4..--1 " L JI. .J .-.'.) % .- U'..1%JiIL~t11L4.'..
Iof susceptible locations.
Monitoring may not be practical forlocations that are inaccessible due to radiological or environmental conditions.
the plant config~uration.
or nersonnel safety. For theselocations alternative methods (e.g.. operating parameters.
remotemonitoring) may be used to monitor the suscetntible location.
Monitoring is not required for suscetptible locations where themaximum notential accumulated gas void volume has beenevaluated and determined to not challenge system OPERABILITY.
The accuracy of the method used for monitoring the susceptible locations and trending of the results should be sufficient to assuresystem OPERABILITY during the Surveillance interval.
The SR can be met by virtue of having an RHR subsystem inservice in accordance with operating procedures.
This SR is modified by a Note that states the SR is not required to benerformed until 12 hours after entering MODE 4. In a rapidshutdown, there may be insufficient time to verify all susceptible locations nrior to entering MODE 4.The 31 day Frequencv takes into consideration the gradual nature ofgas accumulation in the RHR System piping and the procedural controls governing' system operation, REFERENCES
: 1. License Amendment Request Dated November 19, 1999.(Approved by License Amendment 152/143, July 14, 2000.)2. NRC Information Notice 95-35, "Degraded Ability of SteamGenerator to Remove Decay Heat by Natural Circulation."
Prairie IslandUnits 1 and 2Unit 1 -r.1dB3.4.6-8 Unit2- *
* i~ Amendment.+Ne-
,,9 RCS Loops -MODE 5, Loops FilledB 3.4.7BASESLCO(continued)
Note 4 provides for an orderly transition from MODE 5 to MODE 4during a planned heatup by permitting removal of RHiR loops fromoperation when at least one RCS loop is in operation.
This Noteprovides for the transition to MODE 4 where an RCS loop ispermitted to be in operation and replaces the RCS circulation function provided by the RHR loops.RHR pumps are OPERABLE if they are capable of being poweredand are able to provide flow if required.
A SG is capable ofremoving decay heat via natural circulation when: 1) there is theability to pressurize and control pressure in the RCS; 2) there issufficient secondary side water level in the SG relied on for decayheat removal; and 3) there is an available supply of feedwater (Ref.1). An OPERABLE SG can perform as a heat sink via naturalcirculation when it has the capability to remove decay heat asspecified in SR 3.4.7.2.
Management of voids is important toRHR System OPERABILITY.
APPLICABILITY In MODE 5 with RCS loops filled, this LCO requires forcedcirculation of the reactor coolant to remove decay heat from the coreand to provide proper boron mixing. One loop of RHR providessufficient circulation for these purposes.
: However, one additional RHIR loop is required to be OPERABLE, or a SG is capable ofremoving decay heat.Operation in other MODES is covered by:LCO 3.4.4, "RCS Loops-MODES 1 and 2";LCO 3.4.5, "RCS Loops-MODE 3";LCO 3.4.6, "RCS Loops-MODE 4";LCO 3.4.8, "RCS Loops-MODE 5, Loops Not Filled";LCO 3.9.5, "Residual Heat Removal (RHR) and CoolantCirculation-High Water Level" (MODE 6); andLCO 3.9.6, "Residual Heat Removal (RHR) and CoolantCirculation-Low Water Level" (MODE 6).Prairie IslandUnits 1 and 23474Unit 12-
* B ..74Unt2Revlsgmlo n dm.........
No. 119.
RCS Loops -MODE 5, Loops FilledB 3.4.7BASESSURVEILLANCE SR 3.4.7.3 (continued)
REQUIREMENTS controls available and has been shown to be acceptable by operating experience.
This SR is modified by a Note that states the SR is not required to beperformed until 24 hours after a pump is not in operation.
SR .47.RHR System piping and comoonents have the potential to developvoids and nockets of entrained gases. Preventing and managing intrusion and accumulation is necessary, for oroner operation of therequired RHR looo(s) and may also Prevent water hammer. oumpcavitation.
and pumping of noncondensible into the reactorvessel.Selection of RHR System locations susceptible to accumulation is based on a review of system design information, including pipingand instrumentation
: drawings, isometric drawings.
olan andelevation
: drawings, and calculations.
The design review issuoplemented by system walk downs to validate the system highPoints and to confirm the location and orientation of important comoonents that can become sources of gas or could otherwise causegas to be tranoed or difficult to remove during system maintenance or restoration.
Susceptible locations depend on slant and systemconfiguration, such as stand-by versus operating conditions.
The RHR System is OPERABLE when it is sufficiently filled withwater. Acceptance Criteria are established for the volume ofaccumulated gas at susceptible locations.
If accumulated gas isdiscovered that exceeds the acceptance criteria for the susceptible location (or the volume of accumulated gas at one or moresusceptible locations exceeds an acceotance criteria for volumeat the suction or discharge of a pump), the Surveillance is not met.If it is determined by subseauent evaluation that the RHR System isPrairie Island Unit 1 -
^ me.ndment Nc. 158:Units 1 and 2 B 3.4.7-7 Unit 2 * * ^mendment N.
RCS Loops -MODE 5, Loops FilledB 3.4.7SURVEILLANCE SR 3.4.7.4 (continued) not rendered inoperable by the accumulated (i.e.. the system issufficiently filled with water), the Surveillance may be declared met.Accumulated should be eliminated or brou.ght within theacceptance criteria limits.RHIR System locations susceptible to accumulation aremonitored and. if gas is found, the volume is compared to theacceotance criteria for the location.
Susceotible locations in thesame system flow oath which are subject to the same intrusion mechanisms may be verified by monitoring a representative sub-setof susceptible locations.
Monitoring may not be practical forlocations that are inaccessible due to radiological or environmental conditions.
the plant configuration, or personnel safety. For theselocations alternative methods (e.g.. operating parameters, remotemonitoring) may be used to monitor the suscentible location.
Monitoring is not required for susceptible locations where themaximum notential accumulated void volume has beenevaluated and determined to not challenge system OPERABILITY.
The accuracy of the method used for monitoring the Susceptible locations and trending, of the results should be sufficient to assureSystem OPERABILITY during the Surveillance interval.
The SR can be met by virtue of having an RHR subsystem inservice in accordance with operating nrocedures.
The 31 day Freauency takes into consideration the gradual nature ofgas accumulation in the RHR System tpiping and theporocedural controls system operation.
REFERENCES
: 1. NRC Information Notice 95-3 5, "Degraded Ability of SteamGenerators to Remove Decay Heat by Natural Circulation".
: 2. License Amendment Request Dated November 19, 1999.(Approved by License Amendment 152/143, July 14, 2000.)Prairie Island Unit 1- *
* e..,
48Units 1 and 2 B 3.4.7-8 Unit 2 -R__evsi nL.edmen't No. 11!9 RCS Loops -MODE 5, Loops Not FilledB 3.4.8BASESLCO(continued)
Note 1 permits all RHR pumps to be de-energized
< 1 hour per 8hour period. The circumstances for stopping both RHR pumps areto be limited to situations when the outage time is short and coreoutlet temperature is maintained
> 1 0&deg;F below saturation temperature.
The Note prohibits boron dilution with coolant atboron concentrations less than required to assure SDM is maintained or draining operations when RHR forced flow is stopped.Note 2 allows one RHR loop to be inoperable for a period of_< 2 hours, provided that the other loop is OPERABLE and inoperation.
This permits periodic surveillance tests to be performed on the inoperable loop during the only time when these tests are safeand possible.
An OPERABLE RHR loop is comprised of an OPERABLE RHRpump capable of providing forced flow to an OPERABLE RHR heatexchanger.
RHR pumps are OPERABLE if they are capable ofbeing powered and are able to provide flow if required.
Management of voids is imoortant to RI-R SystemOPERABILITY.
APPLICABILITY In MODE 5 with loops not filled, this LCO requires core heatremoval and coolant circulation by the RHR System.Operation in other MODES is covered by:LCO 3.4.4, "RCS Loops-MODES 1 and 2";LCO 3.4.5, "RCS Loops-MODE 3";LCO 3.4.6, "RCS Loops-MODE 4";LCO 3.4.7, "RCS Loops-MODE 5, Loops Filled";LCO 3.9.5, "Residual Heat Removal (RHR) and CoolantCirculation-High Water Level" (MODE 6); andLCO 3.9.6, "Residual Heat Removal (RHR) and CoolantCirculation-Low Water Level" (MODE 6).Prairie IslandUnits 1 and 2Unit 1 * * ,,, .TB 3.4.8-2 Unit 2 -Revlsl~nme.............-...
RCS Loops -MODE 5, Loops Not FilledB 3.4.8BASES (continued)
SURVEIlLANCE SR 3.4.8.1REQUIREMENTS This SR requires verification every 12 hours that the required loop isin operation.
Verification may include flow rate, temperature, orpump status monitoring, which helps ensure that forced flow isproviding heat removal.
The Frequency of 12 hours is sufficient considering other indications and alarms available to the operator inthe control room to monitor RHR loop performance.
SR 3.4.8.2Verification that each required pump is OPERABLE ensures that anadditional pump can be placed in operation, if needed, to maintaindecay heat removal and reactor coolant circulation.
Verification isperformed by verifying proper breaker alignment and poweravailable to each required pump. Alternatively, verification that apump is in operation also verifies proper breaker alignment andpower availability.
The Frequency of 7 days is considered reasonable in view of other administrative controls available and hasbeen shown to be acceptable by operating experience.
This SR is modified by a Note that states the SR is not required to beperformed until 24 hours after a pump is not in operation.
RUR System piping and comnonents have the potential to developvoids and nockets of entrained gases. Preventing and managing gasintrusion and accumulation is necessary, for proper operation of theRHIR loops and may also prevent water hammer. oumn cavitation.
and pumnping, of noncondensible gas into the reactor vessel.Selection of RHR System locations susceptible to accumulation is based on a review of system design information, including tpitingand instrumentation
: drawings, isometric drawings.
tnlan andelevation
: drawings, and calculations.
The design review isPrairie Island Unit 1 -B,,;yi,-k^
..mend..i eT..1-5Units 1 and 2 B 3.4.8-4 Unit 2- *
* i.,,n,,,,,me,,-NT-1,4.9 RCS Loops -MODE 5, Loops Not FilledB 3.4.8BASBSSI JR!V~ .1 .ANCP7:_4 Ri (continiie~d' supplemented by System walk downs to validate the system highpoints and to confirm the location and orientation of imoortant comnonents that can become sources of gas or could otherwise causegas to be tratwed or difficult to remove during system maintenance or restoration.
Susceptible locations depend on nlant and systemconfiguration, such as stand-by versus operating conditions.
The RHR System is OPERABLE when it is sufficiently filled withwater. Accertance criteria are established for the volume ofaccumulated gas at susceptible locations.
If accumulated gas isdiscovered that exceeds the acceotance criteria for the susceptible location (or the volume of accumulated at one or moresusceptible locations exceeds an accentance criteria for gas volumeat the suction or discharge ofas numnVb the Suirveillance is not met.If it is determined by subseauent evaluation that the RHR System isnot rendered inoperable by the accumulated gas (i.e.. the System issufficiently filled with water). the Surveillance may be declared met.Accumulated gas should be eliminated or brought within theacceptance criteria limits.HRHR System locations susceptible to gas accumulation aremonitored and. if gas is found. the volume is compared to theaccentance criteria for the location.
Susceptible locations in thesame system flow nath which are subiect to the same gas intrusion mechanisms may be verified by monitoring, a representative sub-setof susceptible locations.
Monitoring may not be practical forlocations that are inaccessible due to radiological or envirotnmental conditions.
the tnlant configuration, or personnel safety. For theselocations alternative methods (e.g.. operating parameters.
remotemonitoring) may he used to monitor the suscentible locationPrairie IslandUnits 1 and 2Unit 1 -Reviiok~
nn ie........Neo.1 58B 3.4.8-5 Unit 2-
^e-"n"dmcn 119t RCS Loops -MODE 5, Loops Not FilledB 3.4.8BASESSURVEILLANCE RFO.UIRIZVlENTS SR 3.4.8.3 (continued)
Monitoring is not required for susceptible locations where themaximum notential accumulated gas void volume has beenevaluated and determined to not challenge system OPERABILITy.
The accuracy of the method used for monitoring the suscentible locations and trending of the results should be sufficient to assuresystem OPERABILITY during the Surveillance interval.
This SR can be met by virtue of having an RHR subsystem inservice in accordance with operating procedures.
The 31 day Freauency takes into consideration the gradual nature ofgas accumulation in the RHIR System piping and the orocedural controls governing system operation.
REFERENCES None.Prairie IslandUnits 1 and 2B 3.4.8-6 Unit 2 -ReviiorAmendmer' Nc. 119 ECCS-Operating B 3.5.2BASESLCO In MODES 1, 2, and 3, an ECCS train consists of an SI subsystem (continued) and an RHR subsystem.
Each train includes the piping, instruments, and controls to ensure an OPERABLE flow path capable of takingsuction from the RWST upon an SI signal and RHIR capable of beingtransferred to take suction from containment Sump B.During an event requiring ECCS actuation, a flow path is required toprovide an abundant supply of water from the RWST to the RCS viathe ECCS pumps and their respective supply headers to each of thetwo cold leg injection nozzles and the reactor vessel upper plenum.In the long term, this flow path may be switched to take its supplyfrom the containment sump and to supply its flow to the RCS coldlegs or directly into the reactor vessel upper plenum. Management of as voids is imorattECSO RALTYThe flow path for each train must maintain its designedindependence to ensure that no single failure can disable both ECCStrains.Manual valves that could, if improperly positioned, reduce injection flow below that assumed for accident
: analyses, are blocked andtagged or locked in the proper position for injection.
Changes invalve position must be under direct administrative control.A block is a device that can be unclipped or unsnapped to allow astatus change of the component to which it is applied.
A lock is adevice that must be unlocked, destroyed or mechanically removed(such as a cap or blank) to allow a status change of the component towhich it is applied.As indicated in the LCO Note, the SI flow paths may be isolated for2 hours in MODE 3, under controlled conditions, to performpressure isolation valve testing per SR 3.4.15.1.
The flow path isreadily restorable from the control room.Prairie Island Unit 1 -Revisioi m ...d.......
Nov. 158Units 1 and 2 B 3.5.2-6 Unit 2 " "isi 'Acnden N. 119 ECCS-Operating B 3.5.2BASESSURVEII1ANCE REQUIREMENTS (continued)
SR 3.5.2.2Verifying the correct alignment for manual, power operated, andautomatic valves in the ECCS flow paths provides assurance that theproper flow paths will exist for ECCS operation.
This SR does notapply to valves that are locked, sealed, or otherwise secured inposition, since these were verified to be in the correct position priorto locking,
: sealing, or securing (A seal is a device that must bedestroyed to allow a status change of the component to which it isapplied).
A valve that receives an actuation signal is allowed to bein a nonaccident position provided the valve will automatically reposition within the proper stroke time. This Surveillance does notrequire any testing or valve manipulation.
Rather, it involvesverification that those valves capable of being mispositioned are inthe correct position.
The 31 day Frequency is appropriate becausethe valves are operated under administrative
: control, and animproper valve position would only affect a single train. ThisFrequency has been shown to be acceptable through operating experience.
The Surveillance is modified by a Note which exempts system venltflow paths opened under administrative control.
The administrative control should be oroceduralized and include stationing, a dedicated individual at the system vent flow oath who is in continuous communication with the onerators in the control room. Thisindividual will have a method to rapidly close the system vent flowSR 3.5.2.3Verification every 31 days that the motor control center supplybreakers are physically locked in the off position for each valvespecified in SR 3.5.2.1 ensures that an active failure could not resultin an undetected misposition of a valve. Since power is removedunder administrative control and valve position is verified every 12hours, the 31 day Frequency will provide adequate assurance thatpower is removed.Prairie IslandUnits 1 and 2Unit 1 -Revisioru
............
No. 158,,B 3.5.2-10 Unit 2 -Re,,sio-,'
^m..dme.n-No.
ECCS-Operating B 3.5.2BASESSURVEILLANCE SR 3.5.2.4 and SRJ35.2.5 REQUIREMENTS (continued)
ECCS opinng and comoonents have the potential to develop voidsand nockets of entrained gases. Preventing and inruio adaccumulation is necessary for uroner ooeration of the [ECCS and may also orevent water hammer. tnumo cavitation, andPumpin2 of noncondensible into the reactor vessel.Selection of ECCS locations susceotible to accumulation isbased on a review of system design information, including oining,and instrumentation
: drawings, isometric drawings.
nlan andelevation
: drawings, and calculations.
The design review issunolemented by system walk downs to validate the system highpoints and to confirm the location and orientation of important comoonents that can become sources of or could otherwise causegas to be traoped or difficult to remove during system maintenance or restoration.
Susceptible locations denend on olant and systemconfiguration, such as stand-by versus operating, conditions.
The ECCS is OPERABLE when it is sufficiently filled with water.Acceptance criteria are established for the volume of accumulatedat susceptible locations.
If accumulated is discovered thatexceeds the accentance criteria for the susceptible location (or thevolume of accumulated gas at one or more susceptible locations exceeds an accentance criteria for gas volume at the suction ordischarge of a oumon, the Surveillance is not met. If it is determined by subseauent evaluation that the ECCS is not rendered inoperable by the accumulated gas (i.e.. the system is sufficiently filled withwater). the Surveillance may be declared met. Accumulated gasshould be eliminated or brought within the accentance criteria limits.ECCS locations susceptible to gas accumulation are monitored and.if is found. the gas volume is comnared to the accentance criteriafor the location.
Susceptible locations in the same system flow nathwhich are subject to the same gas intrusion mechanisms may beverified by monitoring a repgresentative sub-set of susceptible locations.
Monitoring may not be practical for locations that arePrairie Island Unit 1 -
x-Ne Units 1 and 2 B 3.5.2-11 Unit 2-_Bi,;j;,nA.m.nd
..,.i.-Ne AA..
ECCS-Operating B 3.5.2BASESSURVElACE SR 3.5.2.4 and SR 3.5.2.5 (continued) inaccessible due tO radiological or environmental conditions, theplant configuration, or nersonnel safety. For these locatfions alternative methods (e.g.. operating narameters.
remote monitoring,)
may be used to monitor the susceptible location.
Monitoring is notrequired for susceptible locations where the maximum potential accumulated void volume has been evaluated and determined tonot challenge system OPERABILITY.
The accuracy of the methodused for monitoring the susceptible locations and trending of theresults should be sufficient to assure system OPERABILITy duringthe Surveillance interval.
Both the 31 day Freauencv for accessible locations and event-based Freauencv for inaccessible locations take into consideration thegradual nature of gas accumulation in the ECCS piping, and theorocedural controls governing, system operation.
Additionally, theFreauencv for inaccessible locations allows this Surveillance to beperformed under olant conditions that enable direct monitoring,.
The as-found conditions of the inaccessible locations are monitored at the earliest possible shutdown condition according to the GasAccumulation Management program.
In a rapid shutdown, theremay be insufficient time to verify the as-found condition of theinaccessible locations orior to RCS deoressurization.
SR3.52.6Periodic surveillance testing of ECCS pumps to detect grossdegradation caused by impeller structural damage or other hydraulic component problems is required by the ASME Code. This type oftesting may be accomplished by measuring the pump developed head at a single point of the pump characteristic curve. This verifiesboth that the measured performance is within an acceptable tolerance of the original pump baseline performance and that the performance at the test flow is within the performance assumed in the plant safetyanalysis.
SRs are specified in the Inservice Testing Program of thePrairie Island Unit 1 -RevisionAm-cndment No. 158,Units 1 and 2 B 3.5.2-12 Unit 2 -Revisiormendment-Ne.!A49 ECCS-Operating B 3.5.2BASESSURVEILLANCE SR 3.5.2.6 (continued)
REQUIREMENTS ASME Code. The ASME Code provides the activities andFrequencies necessary to satisfy the requirements.
SR and SR 3.5.2.86These Surveillances demonstrate that each automatic ECCS valveactuates to the required position on an actual or simulated SI signaland that each ECCS pump starts on receipt of an actual or simulated SI signal. This test is met when control board indications and visualobservations indicate that all components have received the safetyinjection signal in the proper sequence and timing, the appropriate pump breakers have opened and closed, and all automatic valveshave been placed in the proper position required to establish a safetyinjection flow path to the reactor coolant system.This Surveillance is not required for valves that are locked, sealed,or otherwise secured in the required position under administrative controls.
The 24 month Frequency is based on the need to performthese Surveillances under the conditions that apply during a plantoutage and the potential for unplanned plant transients if theSurveillances were performed with the reactor at power. The24 month Frequency is also acceptable based on consideration of thedesign reliability (and confirming operating experience) of theequipment.
The actuation logic is tested as part of Engineered Safety Feature (ESF) Actuation System testing, and equipment performance is monitored as part of the Inservice Testing Program.SR 3.5.2.9=7 Surveillance Requirements on ECCS throttle valves provideassurance that proper ECCS flows are maintained in the event of aLOCA. Proper flow resistance and pressure drop in the pipingsystem to each injection point in the SI System is necessary to: 1) prevent total pump flow from exceeding runout conditions when the system is in its minimum resistance configuration; Prairie Island Unit 1 -
^ .
r.1 4Units 1 and 2 B 3.5.2-13 Unit 2 -R " " ^
ECCS-Operating B 3.5.2BASESSURVEILLANCE REQUIREMENTS SR 3.5.2. 9i7 (continued)
: 2) provide the proper flow split between injection points inaccordance with the assumptions used in the ECCS LOCA analyses; and 3) provide an acceptable level of total ECCS flow to all injection points equal to or above that assumed in the ECCS LOCA analyses.
The 24 month Frequency is based on the same reasons as thosestated in SR 3.5.2.75 and SR 3...@SR 3.5.2.R0Periodic inspections of the containment sump suction inlet to theRHR System ensure that it is unrestricted and stays in properoperating condition.
The 24 month Frequency allows thisSurveillance to be performed under the conditions that apply duringa plant outage. This Frequency has been found to be sufficient todetect abnormal degradation and is confirmed by operating experience.
BASESREFERENCES
: 1. AEC "General Design Criteria for Nuclear Power PlantConstruction Permits,"
Criterion 44, issued for comment July10, 1967, as referenced in USAR Section 1.2.2. USAR, Section 6.2.3. USAR, Section 14.4. NRC Memorandum to V. Stello, Jr., from R.L. Baer,"Recommended Interim Revisions to LCOs for ECCSComponents,"
December 1, 1975.5. IE Information Notice No. 87-01.Prairie IslandUnits 1 and 2Unit 1 -^.me...d-ie
,e-1-5oB3.5.2-14 Unt** +x-1t ECCS -ShutdownB 3.5.3BASES (continued)
LCO In MODE 4, one of the two independent (and redundant)
ECCStrains is required to be OPERABLE to ensure that sufficient ECCSflow is available to the core following a DBA.In MODE 4, an ECCS train consists of an SI subsystem and an RHRsubsystem.
Each train includes the piping, instruments, and controlsto ensure an OPERABLE flow path capable of taking suction fromthe RWST and transferring suction to the containment sump.During an event requiring ECCS actuation, a flow path is required toprovide an abundant supply of water from the RWST to the RCS viathe SI subsystem capable (through manual actions) of injecting intoeach of the cold leg inj ection nozzles and reactor vessel upperplenum nozzles.
In the long term, a flow path is required to providerecirculation flow via the RHR subsystem from the containment sump into each of the reactor vessel upper plenum nozzles.
of voids is imtnortant to ECCS OPERABILITY.
This LCO is modified by two Notes. Note 1 allows an RHR train tobe considered OPERABLE during alignment and operation fordecay heat removal, if capable of being manually realigned (remoteor local) to the ECCS mode of operation and not otherwise inoperable.
This allows operation in the RHIR mode duringMODE 4.Note 2 allows an SI train to be considered OPERABLE when thepump is capable of being manually started for ECCS injection fromthe control room.APPLICABILITY In MODES 1, 2, and 3, the OPERABILITY requirements for ECCSare covered by LCO 3.5.2.In MODE 4 with RCS temperature below 3500F and both RCS coldleg temperatures above the SI pump disable temperature specified inthe PTLR, one OPERABLE ECCS train is acceptable without singlefailure consideration, on the basis of the stable reactivity of thereactor and the limited core cooling requirements Prairie Island Unit 1 -Revision 4-Units 1 and 2 B 3.5.3-2 Unit 2 -Revision 40-93 Containment Spray and Cooling SystemsB 3.6.5BASESAPPLICABLE Containment Cooling System air and safety grade cooling waterSAFElY flow. The Containment Cooling System total response timeANALYSES incorporates delays to account for load restoration and motor(continued) windup (Ref. 3).The Containment Spray System and the Containment CoolingSystem satisfy Criterion 3 of 10 CFR 50.36(c)(2)(ii).
LCO During a LOCA or SLB, a minimum of one containment coolingtrain and one containment spray train are required to maintain thecontainment peak pressure and temperature below the design limits(Ref. 4). Additionally, one containment spray train is also requiredto supply sufficient sodium hydroxide to containment to ensure thatthe pH of the sump liquid is alkaline.
To ensure that theserequirements are met, two containment spray trains and twocontainment cooling trains must be OPERABLE.
Therefore, in theevent of an accident, at least one train in each system operates, assuming the worst case single active failure occurs.Each Containment Spray System includes a spray pump, sprayheaders,
: nozzles, valves, piping, instruments, and controls to ensurean OPERABLE flow path capable of taking suction from the RWSTupon a containment spray actuation signal. Manual valves in thissystem that could, if improperly positioned, reduce the spray flowbelow that assumed for accident
: analysis, are blocked and tagged inthe proper position and maintained under administrative control.Containment Spray System motor operated valves, MV-32096 andMV-32097 (Unit 1), and MV-32108 and MV-32109 (Unit 2) areclosed with the motor control center supply breakers in the offposition.
of voids is important to Containment Sorav System OPERABILITY.
Each Containment Cooling System typically includes cooling coils,dampers, fans, and controls to ensure an OPERABLE flow path.With one CL strainer
: isolated, the containment cooling train on theassociated CL header is OPERABLE at CL supply temperatures Prairie Island Unit 1 -Revision 2-20Units 1 and 2 B 3.6.5-6 Unit 2 -Revision 2-2-0 Containment Spray and Cooling SystemsB 3.6.5BASESSURVELACE SR 3.6.5.12 (cotiue)REQUIREMENTS (c..nt.nue.)
The Surveillance is modified by a Note which exemots system ventflow oaths ooened under administrative control.
The administrative control should be oroceduralized and include stationing, a dedicated individual at the system vent flow oath who is in continuous communication with the onerators in the control room. Thisindividual will have a method to raoidlv close the system vent flowOperating each containment fan coil unit on low motor speed for> 15 minutes ensures that all trains are OPERABLE and that allassociated controls are functioning properly.
Motor current is measured and compared to the nominal currentexpected for the test condition.
It also ensures that blockage, fan ormotor failure, or excessive vibration can be detected for corrective action. The 31 day Frequency was developed considering the knownreliability of the fan coil unaits and controls, the two train redundancy available, and the low probability of significant degradation of thecontainment cooling train occurring between Surveillances.
It hasalso been shown to be acceptable through operating experience.
SR 3.6.5.3Containment Sorav System oioing and com oonents have thepotential to develon voids and nockets of entrained gases.Preventing and managing gas intrusion and accumulation isnecessary, for oroper ooeration of the containment soray trains andmay also orevent water hammer and oumo cavitation.
Seeto of Containmen oavSstem loain sucoil to1 aaccumulation is based on a review of system design information.
Prairie Island Unit 1 -Revision 4-9-5Units 1 and 2 B 3.6.5-11 Unit 2 -Revision 4-9-5 Containment Spray and Cooling SystemsB 3.6.5BASESSURVEILLANCE SR 3.6.5.3 (continued) including, piping, and instrumentation
: drawings, isometric drawings.
elan and elevation
: drawings, and calculations.
The design review issun~lemented by system walk downs to validate the system highpoints and to confirm the location and orientation of important comnonents that can become sources of or could otherwise causeaas to be tranoed or difficult to remove during, system maintenance or restoration, Susceptible locations depend on nlant and systemconfiguration, such as stand-by versus otperating conditions.
The Containment Snrav System is OPERABLE when it issufficiently filled with water. Accentance criteria are established forthe volume of accumulated at susceptible locations.
Ifaccumulated is discovered that exceeds the accentance criteriafor the susceptible location (or the volume of accumulated at oneor more susceptible locations exceeds an accentance criteria for gasvolume at the suction or discharge of a pump), the Surveillance isnot met. If it is determined by subseauent evaluation that theContainment Sorav System is not rendered inoperable by theaccumulated gas (i.e.. the system is sufficiently filled with water).the Surveillance may be declared met. Accumulated should beeliminated or brought within the accentance criteria limits.Containment Snray System locations susceptible to gasaccumulation are monitored and. if gas is found, the volume iscompared to the acceptance criteria for the location.
Susceptible locations in the same system flow path which are subject to the samegas intrusion mechanisms may be verified by monitoring arepresentative sub-set of susceptible locations.
Monitoring may notbe practical for locations that are inaccessible due to radiological orenvironmental conditions, the nlant configuration, or nersonnel safety. For these locations alternative methods (e.g,.. operatin&#xa2; narameters, remote monitoring) may be used to monitor thesusceptible location.
Monitoring is not required for susceptible Prairie Island Unit 1 -Revision 4-9-5Units 1 and 2 B 3.6.5-12 Unit 2 -Revision 4-9-5 Containment Spray and Cooling SystemsB 3.6.5SURVEILACE SR 3.6.5.3 (continued) locations where the maximum potential accumulated voidvolume has been evaluated and determined to not challenge systemrOPERABILITY.
The accuracy of the method used for monitoring the susceptible locations and trending, of the results should besufficient to assure system OPERABILITY during, the Surveillance The 31 day Freauencv takes into consideration the gradual nature ofgas accumulation in the Containment Spray System pining and theprocedural controls governing system operation.
Verifying that cooling water flow rate to each containment fan coilunit is > 900 gpm provides assurance that the design flow rateassumed in the safety analyses will be achieved (Ref. 4).Terminal temperatures of each fan coil unit are also observed.
Thistest includes verifying operation of all essential features including low motor speed, cooling water valves and normal ventilation system dampers.
The 24 month Frequency is based on; the need toperform these Surveillances under the conditions that apply during aplant outage; the known reliability of the Cooling Water System;the two train redundancy available; and, the low probability of asignificant degradation of flow occurring between Surveillances.
SR 3.6.5.54Verifying each containment spray pump's developed head at theflow test point is greater than or equal to the required developed head ensures that spray pump performance has not degraded.
Flowand differential pressure are normal tests of centrifugal pumpperformance required by the ASMiE Code (Ref. 6). Since thePrairie Island Unit 1 -Revision  9-5Units 1 and 2 B 3.6.5-13 Unit 2 -Revision
---
Containment Spray and Cooling SystemsB 3.6.5BASESSURVEILLANCE SR 3.6.5.54 (continued)
REQULREMENT containment spray pumps cannot be tested with flow through thespray headers, they are tested on recirculation flow. This testconfirms one point on the pump design curve and is indicative ofoverall performance.
Such inservice tests confirm component OPERABILITY, trend performance, and detect incipient failures byabnormal performance.
The Frequency of the SR is in accordance with the Inservice Testing Program.SR 3.6.5.65~
and SR 3.6.5.76_
These SRs require verification that each automatic containment spray valve actuates to its correct position and that each containment spray pump starts upon receipt of an actual or simulated actuation ofa containment High-High pressure signal. This Surveillance is notrequired for valves that are locked, sealed, or otherwise secured inthe required position under administrative controls.
To preventinadvertent spray in containment, containment spray pump testingwith a simulated actuation signal will be performed with theisolation valves in the spray supply lines at the containment and thespray additive tank isolation valves blocked closed. These tests willbe considered satisfactory if visual observations indicate allcomponents have operated satisfactorily.
The 24 month Frequency is based on the need to perform these Surveillances under theconditions that apply during a plant outage and the potential for anunplanned transient if the Surveillances were performed with thereactor at power. Operating experience has shown that thesecomponents usually pass the Surveillances when performed.
Therefore, the Frequency was concluded to be acceptable from areliability standpoint.
Prairie Island Unit 1 -Revision 4184Units 1 and 2 B 3.6.5-14 Unit 2 -Revision  84 Containment Spray and Cooling SystemsB 3.6.5BASESSURVEILLANCE SR 3.6.5.8:7 REQUIREMENrS (continued)
This SR requires verification that each containment cooling trainactuates upon receipt of an actual or simulated safety injection signal. The 24 month Frequency is based on engineering judgment.
See SR and SR 3.6.5.76, above, for further discussion of thebasis for the 24 month Frequency.
SR 3.6.5.98g With the spray header drained, low pressure air or smoke can beblown through test connections.
This SR ensures that each spraynozzle is unobstructed and provides assurance that spray coverage ofthe containment during an accident is not degraded.
Due to thepassive design of the nozzle, confirmation of operability following maintenance activities that can result in obstruction of spray isconsidered adequate to detect obstruction of the nozzles.Confirmation that the spray nozzles are unobstructed may beobtained by such means as foreign materials exclusion (FME)controls during maintenance, a visual inspection of the affectedportions of the system, or by an air or smoke test following maintenance involving opening portions of the system downstream of the containment isolation valves, or by draining and flushing thefilled portions of the system inside containment, as appropriate.
Maintenance that could result in nozzle blockage is generally a resultof a loss of FME control or a flow of borated water through a nozzle.Should either of these events occur, an engineering evaluation willbe performed to determine whether nozzle blockage is a possibleresult of the event.If loss of FME control occurs, an inspection or flush of the affectedportions of the system should be adequate to confirm that the spraynozzles are unobstructed since water flow would be required totransport any debris to the spray nozzles.
An air flow or smoke testmay be appropriate when borated water has inadvertently flowedthrough a nozzle.Prairie Island Unit 1 -Revision  99Units 1 and 2 B 3.6.5-15 Unit 2 -Revision 4-99 RHR and Coolant Circulation-High Water LevelB 3.9.5BASES (continued)
LCO Only one RHR loop is required for decay heat removal in MODE 6,with the water level > 20 ft above the top of the reactor vesselflange. Only one RHR loop is required to be OPERABLE, becausethe volume of water above the reactor vessel flange provides backupdecay heat removal capability.
At least one RHR loop must be OPERABLE and in operation toprovide:a. Removal of decay heat;b. Mixing of borated coolant to minimize the possibility ofcriticality; andc. Indication of reactor coolant temperature.
An OPERABLE RHR loop includes a RHR pump, a heat exchanger, valves, piping, instruments, and controls to ensure an OPERABLEflow path and to determine the low end temperature.
The flow pathstarts in one of the RCS hot legs and is returned to a RCS cold leg.Management of voids is imoortant to RI-R SystemOPEABILITY.
The LCO is modified by a Note that allows the required operating RHR loop to be removed from service for up to 1 hour per 8 hourperiod, provided no operations are permitted that would dilute theRCS boron concentration with coolant at boron concentrations lessthan required to meet the minimum boron concentration of LCO3.9.1. Boron concentration reduction, with coolant at boronconcentrations less than required to assure the RCS boronconcentration is maintained, is prohibited because uniformconcentration distribution cannot be ensured without forcedcirculation.
This permits operations such as core mapping oralterations in the vicinity of the reactor vessel hot leg nozzles andRCS to RHR isolation valve testing.
During this 1 hour period,decay heat is removed by natural convection to the large mass ofwater in the refueling cavity.Prairie Island Unit 1 -
.f.ie.A..mei..
eA4 Units 1 and 2 B 3.9.5-2 Unit 2 -RevisiorAmeiqdmezit-N.e.--49 RI-R and Coolant Circulation-High Water LevelB 3.9.5BASESACTIONSA.4. A.5, A.6.1, and A.6.2 (continued)
: b. One door in each air lock must be closed; andc. Each penetration providing direct access from the containment atmosphere to the outside atmosphere must be either closed bya manual or automatic isolation valve, blind flange, orequivalent, or verified to be capable of being closed by anOPERABLE Containment Ventilation Isolation System.With the RHR loop requirements not met, the potential exists for thecoolant to boil, clad to fail, and release radioactive gas to thecontainment atmosphere.
Performing the actions described aboveensures that all containment penetrations are either closed or can beclosed so that the dose limits are not exceeded.
The Completion Time of 4 hours allows adequate time to fulfill theRequired Actions and not exceed dose limits.SURVEILLANCE REQtUIEMENIS SR 3.9.5.1This Surveillance demonstrates that the RHR loop is in operation inorder to provide sufficient decay heat removal capability and toprevent thermal and boron stratification in the core. The Frequency of 12 hours is sufficient, considering the flow, temperature, pumpcontrol, and alarm indications available to the operator in the controlroom for monitoring the RHJR System.RHR System and comoonents have the notential to develonvoids and nockets of entrained gases. Preventing, and managing gasintrusion and accumulation is necessary for proner operation of thePrairie IslandUnits 1 and 2Unit 1 -
j...n.A.,,,dn.e iTe45 8B 3.9.5-5 Unit 2- Revisi~r^n.eiidnienit-Ne,.419 RH{R and Coolant Circulation-High Water LevelB 3.9.5BASESSURVEILLANCE SR 3.9.5.2 (continued)
RHR IOODS and may also prevent water hammer. pump cavitation.
and pumping, of noncondensible gas into the reactor vessel.Selection of RHR System locations susceotible to accumulation is based on a review of system design information, including pipingand instrumentation
: drawings, isometric drawings.
olan andelevation
: drawings, and calculations.
The design review issuoolemented by system walk downs to validate the system highpoints and to confirm the location and orientation of imoortant components that can become sources of or could otherwise causegas to be tranoed or difficult to remove during, system maintenance or restoration.
Susceptible locations depend on olant and systemconfiguration, such as stand-by versus operating conditions.
The RHR System is OPERAB3LE when it is sufficiently filled withwater. Acceotance criteria are established for the volume ofaccumulated gas at susceptible locations.
If accumulated gas isdiscovered that exceeds the acceotance criteria for the Susceptible location
(.or the volume of accumulated gas at one or moreSusceptible locations exceeds an acceotance criteria for gas volumeat the suction or discharge of a pumo). the Surveillance is not met.If it is determined by subseouent evaluation that the RHR System isnot rendered inoperable by the accumulated gas (i.e.. the system issufficiently filled with water). the Surveillance may be declaredl met.Accumulated should be eliminated or brought within theacceptance criteria limits.RHIR System locations susceptible to gas accumulation aremonitored and. if is found. the gas volume is comnared to theacceptance criteria for the location.
Susceptible locations in thesame system flow oath which are subjiect to the same gas intrusion mechanisms may be verified by monitoring, a representative sub-setof suscentible locations.
Monitoring, may not be practical forPrairie Island Unit 1 -ReviskonA................
15Units 1 and 2 B 3.9.5-6 Unit 2 -RevsioAmecdmcne~t NoT. 11t9 RH-R and Coolant Circulation-High Water LevelB 3.9.5BASESSURVEILLANCE SR 3.9.5.2 (continued) locations that are inaccessible due to radiological or environmental conditions, the nlant confi~uration.
or personnel safety. For theselocations alternative methods (e.g.. operating, narameters.
remotemonitorinQ) may be used to monitor the suscep~tible location.
Monitorin2 is not reauired for susceotible locations where themaximum potential accumulated gas void volume has beenevaluated and determined to not challenge system OPERABILITY.
The accuracy of the method used for monitorin2 the suscentible locations and trendin2 of the results should be sufficient to assuresystem OPERABLITY during, the Surveillance interval.
This SR can be met by virtue of having an RH subsystemn inservice in accordance with operating nrocedures.
The 31 day Freauencv takes into consideration the gradual nature ofaccumulation in the RIIR System and the procedural controls governing system oneration.
REFERENCES None.Prairie IslandUnits 1 and 2Unit 1 -Revyslr ............
No ....5~B 3.9.5-7 Unit2-9 _ '
N. 119n RHIR and Coolant Circulation-Low Water LevelB 3.9.6BASESLCO a. Removal of decay heat;(continued)
: b. Mixing of borated coolant to minimize the possibility ofcriticality; andc. Indication of reactor coolant temperature.
An OPERABLE RHR loop consists of an RHR pump, a heatexchanger, valves, piping, instruments and controls to ensure anOPERABLE flow path and to determine the low end temperature.
The flow path starts in one of the RCS hot legs and is returned to theRCS cold leg. Management of gas voids is imoortant to RHRSystem OPERABILITY.
Either RHR pump may be aligned to the Refueling Water StorageTank (RWST) to support filling or draining the refueling cavity orfor performance of required testing.The LCO contains two Notes which provide clarification of theLCO.Note 1 permits the RHR pumps to be de-energized for up to 1 hourper 8 hour period. The circumstances for stopping both RHR pumpsare to be limited to situations when the outage time is short and thecore outlet temperature is maintained
> 10 degrees F belowsaturation temperature.
The Note prohibits boron dilution ordraining operations when RHR forced flow is stopped.Note 2 allows one RHR loop to be inoperable for a period of 2 hoursprovided the other loop is OPERABLE and in operation.
Prior todeclaring the loop inoperable, consideration should be given to theexisting plant configuration.
This consideration should include thatthe core time to boil is short, there is no draining operation to furtherreduce RCS water level and that the capability exists to injectborated water into the reactor vessel. This permits surveillance teststo be performed on the inoperable loop during a time when thesetests are safe and possible.
Prairie Island Unit 1 --RevisionAmentdnentNe.-l-5.
Units 1 and 2 B 3.9.6-2 Unit 2 -RevisionAmend.menit-Ne,.-!
49 RHIR and Coolant Circulation-Low Water LevelB 3.9.6St VE.JANaREOtflREMENI E SR 3.9.6.3(continued)
RIHR System niping and comoonents have the potential to develonvoids and rockets of entrained gases. Preventing and managing intrusion and accumulation is necessary for proper otneration of theRHR loons and may also nrevent water hammer. tnumio cavitation.
and pumping, of noncondensible into the reactor vessel.Selection of RHR System locations suscentible to accumulation is based on a review of System design information, including pipingand instrumentation
: drawings, isometric drawings.
tolan andelevation
: drawings, and calculations.
The design review isSuo~lemented by system walk downs to validate the system highpoints and to confrm the location and orientation of imtportant components that can become sources of or could otherwise causeto be tratn~ed or difficult to remove during, system maintenance or restoration.
Susceptible locations detnend on nlant and systemconfiguration, such as stand-by versus operating conditions.
The RHIR System is OPERABLE when it is sufficiently filled withwater. Acceptance criteria are established for the volume ofaccumulated at susceptible locations.
If accumulated gas isdiscovered that exceeds the acceptance criteria for the susceotible location (or the volume of accumulated gas at one or moresusceptible locations exceeds an accetntance criteria for gas volumeat the suction or discharge of a pumtp), the Surveillance is not met.If it is determined by subseauent evaluation that the RHR System isnot rendered inop~erable by the accumulated gas (i.e.. the system issufficiently filled with water), the Surveillance may be declared met.Accumulated gas should be eliminated or brought within theaccentance criteria limits.RHR System locations susceptible to gas accumulation aremonitored and. if is found. the gas volume is comtoared to theaccet~tance criteria for the location.
Susceptible locations in thePrairie IslandUnits 1 and 2Unit 1 -R~yiis; edmi B 3.9.6-6 Unit 2 -RevisioAmendm:ent Nor. 1/19 RHTR and Coolant Circulation-Low Water LevelB 3.9.6BASESSURVEI1,1ANCE REOUIREMENrS SR 9_6_ 3 (cnntinuied'I same system flow oath which are subject to the same intrusion mechanisms may be verified by monitoring, a representative sub-setof suscentible locations.
Monitoring may not be practical forlocations that are inaccessible due to radiological or environmental conditions.
the nlant configuration, or nersonnel safety. For theselocations alternative methods (e.g.. onerating parameters.
remotemonitoring) may be used to monitor the susceptible location.
Monitoring is not required for susceptible locations where themaximum potential accumulated gas void volume has beenevaluated and determined to not challenge system OPERABILITY.
The accuracy of the method used for monitoring the susceptible locations and trending of the results should be sufficient to assuresystem OPERABILITY during the Surveillance interval.
This SR can be met by virtue of having an RHR subsystema nservicein accordance with operating procedures.
The 31! day Freauency takes into consideration the..gradual nature ofgas accumulation in the RHR System piping and the procedural controls governing system operation.
REFERENCES None.Prairie IslandUnits 1 and 2Unit 1 -* T. B 3.9.6-7 Unit
............
Ne. 49}}

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