ML12114A002

Crystal River, Unit 3, Response to Request for Additional Information to Support NRC Electrical Systems Branch (Eeeb) Technical Review of the CR-3 Extended Power Uprate LAR (TAC No. ME6527)

ML12114A002
Person / Time
Site:	Crystal River
Issue date:	04/16/2012
From:	Franke J A Progress Energy Florida
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
3F0412-06, TAC ME6527
Download: ML12114A002 (34)

Text

kProgress EnergyCrystal River Nuclear PlantDocket No. 50-302Operating License No. DPR-72April 16, 20123F0412-06U.S. Nuclear Regulatory CommissionAttn: Document Control DeskWashington, DC 20555-0001Subject: Crystal River Unit 3 -Response to Request for Additional Information to SupportNRC Electrical Systems Branch (EEEB) Technical Review of the CR-3 ExtendedPower Uprate LAR (TAC No. ME6527)References: 1. CR-3 to NRC letter dated June 15, 2011, "Crystal River Unit 3 -LicenseAmendment Request #309, Revision 0, Extended Power Uprate" (AccessionNo. ML1 12070659)2. NRC to CR-3 letter dated March 2, 2012, "Crystal River Unit 3 NuclearGenerating Plant -Request For Additional Information For Extended PowerUprate License Amendment Request (TAC No. ME6527)" (Accession No.ML12052A130)Dear Sir:By letter dated June 15, 2011, Florida Power Corporation, doing business as Progress EnergyFlorida, Inc., requested a license amendment to increase the rated thermal power level of CrystalRiver Unit 3 (CR-3) from 2609 megawatts (MWt) to 3014 MWt (Reference 1). On March 2,2012, the NRC provided a request for additional information (RAI) required to support theEEEB technical review of the CR-3 Extended Power Uprate (EPU) License Amendment Request(LAR) (Reference 2).The attachment, "Response to Request for Additional Information to Support NRC ElectricalSystems Branch (EEEB) Technical Review of the CR-3 EPU LAR," provides the formalresponse to the RAI needed to support the EEEB technical review of the CR-3 EPU LAR.In support of the EPU technical review RAI responses, two enclosures are provided.Enclosure 1, "Station Blackout DC Loads," provides a listing of battery loads that demonstratesthe DC Electrical System capability to provide four hour coping during a Station Blackout event.Enclosure 2, "Battery Room Layout Drawing -Proposed FCS Battery Location," illustrates theproposed location and layout of the new Fast Cooldown System batteries with respect to theexisting safety-related station batteries.This correspondence contains no new regulatory commitments.Progress Energy Florida. Inc. I-woCrystal River Nuclear Plant15760 W. Powerline StreetCrystal River, FL 34428 U.S. Nuclear Regulatory Commission3F0412-06Page 2 of 3If you have any questions regarding this submittal, please contact Mr. Dan Westcott,Superintendent, Licensing and Regulatory Programs at (352) 563-4796.Sincerely,J A. Frankeice PresidentCrystal River Nuclear PlantJAF/parAttachment:Response to Request for Additional Information to Support NRC ElectricalSystems Branch (EEEB) Technical Review of the CR-3 EPU LAREnclosures:1. Station Blackout DC Loads2. Battery Room Layout Drawing -Proposed FCS Battery Locationxc: NRR Project ManagerRegional Administrator, Region IISenior Resident InspectorState Contact U.S. Nuclear Regulatory Commission3F0412-06Page 3 of 3STATE OF FLORIDACOUNTY OF CITRUSJon A. Franke states that he is the Vice President, Crystal River Nuclear Plant for FloridaPower Corporation, doing business as Progress Energy Florida, Inc.; that he is authorized on thepart of said company to sign and file with the Nuclear Regulatory Commission the informationattached hereto; and that all such statements made and matters set forth therein are true andcorrect to the best of his knowledge, information, and be/J A. FrankeVice PresidentCrystal River Nuclear PlantThe foregoing document was acknowledged before me this 6," day of, 2012, by Jon A. Franke.Signature of Notary PublicState of Florida ..... ,... -(Print, type, or stamp CommissionedName of Notary Public)PersonallyKnown -ProducedOR- Identification FLORIDA POWER CORPORATIONCRYSTAL RIVER UNIT 3DOCKET NUMBER 50-302 /LICENSE NUMBER DPR-72ATTACHMENTRESPONSE TO REQUEST FOR ADDITIONAL INFORMATIONTO SUPPORT NRC ELECTRICAL SYSTEMS BRANCH (EEEB)TECHNICAL REVIEW OF THE CR-3 EPU LAR U. S. Nuclear Regulatory Commission Attachment3F0412-06 Page 1 of 15RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION TOSUPPORT NRC ELECTRICAL SYSTEMS BRANCH (EEEB)TECHNICAL REVIEW OF THE CR-3 EPU LARBy letter dated June 15, 2011, Florida Power Corporation (FPC), doing business as ProgressEnergy Florida, Inc., (PEF) requested a license amendment to increase the rated thermal powerlevel of Crystal River Unit 3 (CR-3) from 2609 megawatts (MWt) to 3014 MWt. On March 2,2012, the NRC provided a request for additional information (RAI) required to support theEEEB technical review of the CR-3 Extended Power Uprate (EPU) License Amendment Request(LAR).For tracking purposes, each item related to this RAI is uniquely identified as EEEB X-Y, with Xindicating the RAI set and Y indicating the sequential item number.1. (EEEB 1-1)In your original LAR dated June 15, 2011 (ADAMS Accession No. ML 112070659),Attachment 5, Section 2.3.1.2, pages 2.3.1-4 and 2.3.1-5, "Detailed EPU Impacts by Zone," thelicensee provided an environmental qualification (EQ) reclassification of the plant area due toprojected post-EPU environmental conditions, which impacts Zone 17 in the IntermediateBuilding, and Zones 18, 23, 47, 60, 62, and 78 in the Auxiliary Building.Provide a list of the equipment/components that will be affected as a result of the new areasbeing designated as "harsh." Provide the post-EPU radiation levels in these reclassified zonesand the radiation levels to which these equipment/components are qualified.Response:The environmental impact to equipment and components in plant areas reclassified as HARSHEQ zones due to EPU conditions is limited to elevated radiation levels. Point specific dosecalculations were performed to more accurately reflect the calculated Total Integrated Dose(TID) to individual equipment/components following a design basis accident.Table 1, "Equipment/Component TIDs for Reclassified EQ Zones," lists the highest calculatedTID for each EQ zone reclassified as a result of operation at EPU conditions. As applicable,Table 1 also lists the equipment/components in each zone affected by the increased radiationlevels and includes the calculated point specific TID for each equipment/component.Table 1 -Equipment/Component TIDs for Reclassified EQ ZonesEQ Zone Equipment/Component Tag Number (rads)17 -Intermediate Building 1.10E+05Motor Starter -MFW Startup Block FW-33-MST 7.05E+02Valve to OTSG BMotor Operator -EFW Block Valve toOTSG A FWV-35-MOA 3.86E+02 U. S. Nuclear Regulatory Commission3F0412-06AttachmentPage 2 of 15EQ Zone Equipment/Component Tag Number TID(rads)Motor Starter -FWV-35 FWV-35-MST 3.66E+02Motor Starter -FWV-36 FWV-36-MST 7.35E+02Terminal Box -FWV-36 FW-41-TB 1.21E+03Terminal Box -MSV-411/412-SV4and Press Switches MS-21-TB 3.68E+02Terminal Box -MSV-55 MS-6-TB 6.95E+02480V Pressurizer Heater MCC-3B MTMC-9, IA 3.9 1E+02480V Pressurizer Heater MCC-3B MTMC-9, 1B 3.77E+02480V Pressurizer Heater MCC-3B MTMC-9, IC 3.78E+02480V Pressurizer Heater MCC-3B MTMC-9, ID 3.77E+02480V Pressurizer Heater MCC-3B MTMC-9, 2A 3.54E+02480V Pressurizer Heater MCC-3B MTMC-9, 2B 3.55E+02480V Pressurizer Heater MCC-3B MTMC-9, 2C 3.55E+02480V Pressurizer Heater MCC-3B MTMC-9, 3A 3.52E+02480V Pressurizer Heater MCC-3B MTMC-9, 3BL 3.52E+02480V Pressurizer Heater MCC-3B MTMC-9, 3BR 3.52E+02480V Pressurizer Heater MCC-3B MTMC-9, 3C 3.52E+02480V Pressurizer Heater MCC-3B MTMC-9, 4A 3.54E+02480V Pressurizer Heater MCC-3B MTMC-9, 4B 3.54E+02480V Pressurizer Heater MCC-3B MTMC-9, 4C 3.54E+02480V Pressurizer Heater MCC-3B MTMC-9, 5A 3.55E+0218 -Auxiliary Building No EX' components in this EQ 1.53E+05zone.23 -Auxiliary Building 1.22E+04DC Disconnect Switch -Spare DPDP-2A-10; DIS 1.28E+03DC Disconnect Switch -125V Control DPDP2A 19; DIS 1.28E+03Power to RCP-3A D_ DP-2A-19;_DIS _ 1.28E+03DC Disconnect Switch- 125V Control DPDP-2A-2; DIS 1.28E+03Power to RCP-3C DPDP-2A-2;_DIS _ 1.28E+03DC Disconnect Switch -DCV- I O-SV DPDP-2A-20; DIS 1.28E+03DC Disconnect Switch -250V Motor DPDP-2A-3; DIS 1.28E+03Power to RCP-3A D_ DP-2A-3;_DIS _ 1.28E+03PC Disconnect Switch -250V Motor DPDP-2A4; DIS 1.28E+03Power to RCP-3C DPDP-2A-4;_DIS _ 1.28E+0347 -Auxiliary Building No EX' components in this EQ 1.91 E+04zone.60 -Auxiliary Building No EX1 components in this EQ 9.38E+05zone.62 -Auxiliary Building 1.62E+05EDG-3B Emergency Load Shedding -HTCP-2 1.56E+04Peat Tracing F U. S. Nuclear Regulatory Commission Attachment3F0412-06 Page 3 of 15Equipment/Component Tag Number TID(rads)78 -Auxiliary Building 4.58E+04_HD- IC Positioner AH- 196-POS I 4.22E+03EX -CR-3 designation for electrical components important to safety which is relied upon to remainfunctional during and after design basis events.2. (EEEB 1-2)In the original LAR, Attachment 5, Section 2.3.1.2, page 2.3.1-5, "Summary of EPU Impact onComponent Basis," the licensee discussed the proposed plant changes as a result of EPU, asreferred to Appendix E, which add or modify equipment subject to EQ requirements. Thelicensee further stated, "These new components will be designed, procured, and installed incompliance with appropriate EQ requirements."Provide a detailed list (preferably in a table) of new EQ equipment, which are referenced in theabove paragraph. Provide a discussion of EQ (similar to the EQ discussion provided in Section2.4 of Appendix E, page E-38, for atmospheric dump valves and accessories) for the following:(i) new EQ motor operated valves (MOVs) and the new EQ transmitters for the lowpressure injection cross-tie and hot leg injection design change,(ii) new EQ MOV for the feedwater booster pump modification,(iii) new EQ differential pressure indicating switches, and(iv) EQ core exit thermocouple for the Inadequate Core Cooling Monitor System change.Response:The new EQ components listed in Section 2.3.1, "Environmental Qualification of ElectricalEquipment," of the EPU Technical Report (TR) (Reference 1, Attachments 5 and 7) are beingevaluated in the associated CR-3 Engineering Change (EC) packages. Once it is determined thata component is located in a designated HARSH EQ Zone, an EQ Vendor Qualification Package(VQP) is created for the new component or the component is added to an existing EQ VQP, asapplicable. Finalization of the EPU plant modifications is currently in progress and includes theassociated EQ evaluations which will be completed once the specific location and type ofcomponent is known.Analysis of the new components:(i) The new EQ motor operators associated with the new low pressure injection cross-tieand hot leg injection lines are Limitorque valve operators. The same model of motoroperators are currently qualified and included in the CR-3 EQ program. Also, new EQtransmitters have been identified as Rosemount transmitters. The same model oftransmitters are currently qualified and included in the CR-3 EQ program. Therefore, U. S. Nuclear Regulatory Commission Attachment3F0412-06 Page 4 of 15both the new motor operators and transmitters will be included in the applicable CR-3VQPs.(ii) Replacement EQ motor operators associated with the main feedwater suction valves areLimitorque valve operators. The same model of motor operators are currently qualifiedand included in the CR-3 EQ program. Therefore, the replacement EQ motor operatorswill be included in the applicable CR-3 VQP.(iii) New differential pressure switches associated with the Emergency Feedwater Systemrecirculation valves are to be included in the CR-3 EQ Program and as such, a VQP isbeing finalized for these new EQ components.(iv) Eight core exit thermocouples are being upgraded to safety-related in support of thenew Inadequate Core Cooling Mitigation System. The same model of thermocouplesare currently qualified and included in the CR-3 EQ program. Therefore, the upgradedthermocouples will be included in the applicable CR-3 VQP.3. (EEEB 1-3)In the original LAR. Attachment 5, Section 2.3.1.2, page 2.3.1-2, the licensee stated, "Theenvironmental parameters evaluated for EPU conditions include temperature, pressure,radiation dose, submergence, chemical spray effects, and humidity, for both normal operationand post-accident conditions."a) Confirm that the margins for the equipment qualified per guidance under Institute ofElectrical and Electronics Engineers (IEEE) Standard 323-1974, "Standard forQualifying Class 1E Equipment for Nuclear Power Generating Stations," aremaintained under EPU conditions.Response:For EQ equipment installed at CR-3 after February 23, 1983, including new equipmentrequiring environmental qualification in accordance with lOCFR50.49, FPC confirmsthat the associated margins specified in IEEE 323-1974 will be maintained duringoperation at EPU conditions.b) Original LAR Figure 2.3.1-1 (Post-EPU LOCA [loss-of-coolant accident] versus EQBounding Profile Comparison, Inside Containment Temperature), appears to show thatthe IEEE recommended temperature margin (15 'F) is not maintained at one point(1.OOE+04 time/280 7F). Please clarify the apparent deviation.Response:The EQ bounding profile curve indicated in Figure 2.3.1-1, "Post-EPU LOCA vs. EQBounding Profile Comparison (Inside Containment)," of the EPU TR (Reference 1,Attachments 5 and 7) represents a bounding temperature profile of loss of coolantaccidents (LOCAs) at EPU conditions. EQ equipment inside the containment isqualified to temperatures at least 15'F above the highest temperature on the EQbounding curve. Therefore, the EQ equipment inside containment continues to meetthe temperature margin recommended in IEEE 323-1974.

U. S. Nuclear Regulatory Commission3F0412-06AttachmentPage 5 of 15c) Provide the post-EPU pressure profile for conditions inside containment todemonstrate that the integrated pressure curve is bounded by the current EQbounding profile.Response:EQ components inside containment were evaluated to confirm that pressure margin iswithin the recommendations of IEEE 323-1974. Consistent with CR-3 TechnicalSpecification 5.6.2.20, a peak containment internal pressure was used to determine theEQ limiting pressure; 54.2 psig x 10% = 5.42 psig. The qualified pressure of each EQcomponent located in the containment was compared to the EQ limiting pressure todetermine the pressure margin. The results are provided in the following table; Table2,"EQ Pressure Margin by Component -Inside Containment." Table 2 shows thesmallest margin is 15.22 psig, which is within the recommendations of IEEE 323-1974.Table 2 -EQ Pressure Margin by Component -Inside ContainmentTested MarginVQP ID Description Pressure (psig)(psig)INST-B014-04 B&W (Framatome) Incore Detector System 66 17.22INST-C515-07 Conax RTDs 7H24-10000-01 70 21.22Conax RTDs 7Q22 & 7Q77INST-C515-08 Thermocouple/Resistance Temperature Device 87.6 38.82(RTD)INST-G030-11 Gamma Metrics Neutron Flux Monitors 70 21.22INST-G050-13 GEMS RB Building Flood Level Transmitters 66 17.22INST-G063-12 General Atomic RD-23 Hi Range Radiation 78 29.22MonitorsINST-R369-01 Rosemount 1153 Series B Transmitters 73 24.22INST-R369-03 Rosemount 1154 Transmitters 110 61.22INST-R369-04 Rosemount 1154, Series H Transmitters 85 36.22INST-R369-05 Rosemount 177HW RTDs (Cold Leg) 129.9 81.12INST-R369-09 Rosemount 1154 Transmitters / 1159 sensors 110 61.22INST-T068-06 TEC Valve Monitoring System 64 15.22INST-W108-15 Weed Instrument Co RTD (Hot Leg) 75.35 26.57MTR-W120-02 Westinghouse Fan Motors AHF-IA, B & C 80.8 32.02PEN-C515-03 Conax Electrical Penetration 2325-7870 74.5 25.72PEN-C515-06 Conax ECSA conduit seal assemblies 75 26.22TERM-E159-07 EGS Grayboots -GB-3, old style series 81 32.22TERM-E159-12 EGS Grayboots -GB-lA & 2A series 105 56.22TERM-K080- 10 Kerite 480V Tape termination 80 31.22TERM-R098-04 Raychem WSCF-N Standard Splices 66 17.22TERM-R098-09 Raychem WSCF-N(S) New Formula Splices 124 75.22VLV-L200-07 Limitorque Class RH, AC Reliance Motors 70 21.22VLV-T020-01 Target Rock Solenoid Valves 81VV-01, 02 & 03 69 20.22 U. S. Nuclear Regulatory Commission Attachment3F0412-06 Page 6 of 15d) Provide the post-EPU temperature profile for main steam line break environmentalconditions to demonstrate that the profile is less severe than LOCA as discussed onpage 2.3.1-3, under "Summary EPU Impact" in Reactor Building.Response:A specific post-EPU temperature profile of the environmental conditions during aMSLB accident to demonstrate that the profile is less severe than a LOCA was notdeveloped and; thus, is not provided. The LOCA environmental conditions areconsidered more severe than the MSLB accident environmental conditions asconcluded by the NRC staff in a letter to FPC dated June 5, 1981 (Reference 2). Thisletter states, in part, that, "...for plants designed and equipped with an automaticcontainment spray system which satisfies the single-failure criterion, the main-steam-line-break (MSLB) environmental conditions are enveloped by the large-break-LOCAenvironmental conditions." The CR-3 Reactor Building Spray System satisfies thesingle-failure criterion and; therefore, the CR-3 EQ program continues to be based onthe LOCA containment temperature results.4. (EEEB 1-4)In the original LAR, Attachment 5, Section 2.3.1.2, page 2.3.1-2, under "Description ofAnalyses and Evaluations," the licensee stated that "Even though the EPU design changepackages are not yet issued for construction, EPU impacts on parameters important to EQ areknown."Provide clarification of this statement. Also, the NRC staff finds that in Attachment 10 of theoriginal LAR, "List of Regulatory Commitments," the licensee states that CR-3 will implementall EPU modifications per Technical Report (TR) Attachment E. Confirm that the licenseeintended to refer to Appendix E, "Major Plant Modifications," of Attachment 5 of the originalLAR instead of TR Attachment E.Response:When referring to Attachment E in Attachment 10, "List of Regulatory Commitments," of theCR-3 EPU LAR (Reference 1), FPC is referring to the modifications described in Appendix E,"Major Plant Modifications," and associated enclosures of the EPU TR (Reference 1,Attachments 5 and 7).FPC has evaluated the impact to plant parameters important to EQ at EPU conditions andprovided the results of the evaluations in Section 2.3.1, "Environmental Qualification ofElectrical Equipment," of the EPU TR (Reference 1, Attachments 5 and 7). A revision to theEnvironmental Qualification Plant Profile Document has been prepared to reflect the plantconditions during EPU operation. Based on revised EPU environmental conditions, EQ VQPs,are being prepared to reflect EPU environmental conditions, which also include new EQcomponents. These documents will be finalized as part of completion of the EC packagesrequired prior to EPU implementation.

U. S. Nuclear Regulatory Commission Attachment3F0412-06 Page 7 of 155. (EEEB 1-5)In the original LAR, Attachment 5, Section 2.3.1.2, page 2.3.1-4, the licensee stated, "The RB[Reactor Building] postulated maximum flood level is not impacted by the proposed EPUconditions."Indicate the maximum postulated flood level versus the levels of the equipment to demonstratethat the associated equipment is not impacted by the EPU conditions in the RB. Similarly,address the postulated flood level conditions in the Intermediate Building.Response:The CR-3 RB maximum expected flood elevation at EPU conditions remains unchanged at lessthan 102 ft. With the exception of the RB sump transmitter capillary tubes, electrical equipmentimportant to safety is installed above this level and; therefore, is not impacted by floodingconditions during EPU operation. Additionally, new electrical equipment important to safetyrequired for operation at EPU conditions will be installed in the RB above the maximum floodelevation of 102 ft.The CR-3 Intermediate Building (IB) maximum flood level at the 95 ft. building elevation is2 in. and the maximum flood level at the 119 ft. building elevation is 2 ft.-2 in. FPC evaluatedthese internal flooding levels and determined that they were not impacted by EPU conditions.Electrical equipment important to safety is installed above these levels and; therefore, is notimpacted by flooding conditions during EPU operation. Additionally, new electrical equipmentimportant to safety required for operation at EPU conditions will be installed in the IB above themaximum expected flooding levels.6. (EEEB 1-6)In the original LAR, Attachment 5, Appendix E, "Major Plant Modifications," Section 1.4.1, thelicensee stated, "The power and control from the existing MOVs will be re-routed into the RBthrough two new electrical penetrations (converted mechanical penetrations 327 and 328 fromthe Triangle Room)."Confirm that the new electrical penetrations are environmentally qualified with margins for theinstalled life in accordance with the guidance provided in IEEE Standard-317, "Standard forElectric Penetration Assemblies in Containment Structures for Nuclear Power GeneratingStations."Response:The vendor qualification report for the new electrical penetration assemblies demonstrates thatthese penetration assemblies will perform their intended design function under normal andaccident environmental conditions without loss of mechanical or electrical integrity over a 40year installed life thereby assuring compliance with the requirements of IEEE 317-1983.

U. S. Nuclear Regulatory Commission Attachment3F0412-06 Page 8 of 157. (EEEB 1-7)In the original LAR, Attachment 5, Section 2.3.2.2 under Section 2.3.2, "Offsite Power System,"the licensee discussed the adequacy of the switchyard main generator output breaker capacity.Also in Appendix E, the licensee stated that no changes to either switchyard (230 kV and500 kV) are necessary to support EPU.Provide a discussion that demonstrates that other equipment such as breakers (other than thegenerator main breaker), disconnects, buses, current transformers, tie-lines, etc., have adequatecapacity so that the existing switchyard is capable of supporting EPU conditions (i.e., theequipment have adequate margins between the maximum worst case steady-state load and theequipment ratings).Response:As discussed in Section 2.3.2, "Offsite Power System," of the EPU TR (Reference 1,Attachments 5 and 7), the CR-3 generating unit shares the 500 kV switchyard with an adjacentlarge fossil generating unit and two 500 kV transmission lines. The PEF transmission divisionconducted a system impact study of the Crystal River Energy Complex transmission systemconsidering the additional 180 MWe net generation and concluded that the current systemconfiguration; including the 500 kV switchyard transmission lines, disconnects, buses, currenttransformers, and tie-lines; has sufficient margin between the maximum steady state loadconditions and the equipment ratings.In addition, as described in Appendix E of the EPU TR (Reference 1, Attachments 5 and 7) theCR-3 main generator step-up transformers have been replaced during a previous outage. Thisplant modification anticipated a generation increase of 200 MWe. Also, based on a review ofother supporting electrical systems, additional equipment was replaced during the main generatorstep-up transformer replacement; two high voltage bushing current transformers, two low voltagebushing current transformers, two low voltage external current transformers, and three lightningarrestors -one per main transformer.The 230 kV switchyard is the preferred offsite power source for the CR-3 Class 1E AC ElectricalSystem. Since the 500 kV and 230 kV electrical systems are not directly inter-connected at theCrystal River Energy Complex, the additional generation as a result of the CR-3 EPU does notimpact the capability of the 230 kV offsite power source to CR-3. FPC has concluded that the230 kV switchyard has the capacity to provide the additional load resulting from EPU operationand the current system configuration; including the 230 kV switchyard transmission lines,disconnects, buses, current transformers, and tie-lines; has sufficient margin between themaximum steady state load conditions and the equipment ratings.8. (EEEB 1-8)In the original LAR, Attachment 5, Section 2.3.3.2, page 2.3.3-3, the licensee mentionedupgrades to the isolated-phase bus duct and the pre-and post-EPU continuous current ratings.Provide a summary of the calculation used to determine that the calculated short-circuit currentavailable at the bus duct is within the bus short circuit capacity rating.

U. S. Nuclear Regulatory Commission Attachment3F0412-06 Page 9 of 15Response:The short circuit analyses of the CR-3 Class 1E and Balance of Plant AC Electrical DistributionSystems calculate short circuit currents for evaluating the adequacy of fault current interruptingratings and to ensure equipment momentary current ratings are not exceeded using ElectricalTransient Analyzer Program (ETAP) software. These analyses included major AC electricalcomponents added as a result of the CR-3 EPU. The short circuit analysis, based on thecurrently planned EPU configuration, indicates the maximum isolated-phase bus duct shortcircuit current is less than 250,000 amps which is less than the capacity rating of 345,000 amps.In addition, changes that impact electrical calculations not yet included in the formal calculationsare evaluated using the Electrical System Calculation Impact Assessment process to ensure thecomposite effect of the electrical system changes are acceptable. Electrical System CalculationImpact Assessment forms are included in individual EC packages. The composite effect of theEPU design changes is evaluated to ensure that the existing ratings are not exceeded. AdditionalCR-3 AC Electrical Distribution System configuration changes as a result of EPU operation arebeing evaluated using this process and are expected to be bounded by the equipment ratings dueto margin in the electrical calculations between calculated short circuit current and the ratedvalues.9. (EEEB 1-9)In the original LAR, Attachment 5, Section 2.3.3.2, page 2.3.3-3, the licensee stated that theproposed Class 1E modifications would not result in any configuration changes that wouldadversely impact the maximum emergency diesel generator (EDG) loading currently assumed.Provide a discussion and a summary of the calculation that demonstrates that the EDG loading inthe post-EPU state, after taking into account increased loads on the vital bus inverters andengineered safeguard bus (safety-related) instrument power systems, will remain within eachEDG's capacity.Response:Prior to issuance of revised EDG loading calculations, EDG loading logs are updated andmanaged using the Electrical System Calculation Impact Assessment process to ensure eachEDG remains within its design capacity. Conservative electrical loading values, as a result ofoperation at EPU conditions and currently planned EPU-related plant modifications, are includedin these EDG loading logs. The summation of the electrical loading changes identified in theEDG loading logs shows that each EDG will remain within its design capacity during post-EPUoperation.Additions and reductions in electrical loading to the Class 1E AC Electrical Distribution System,including increased loads on the vital bus inverters and the vital AC buses, have been evaluatedusing conservative loading values. The vital AC bus inverter loading changes as a result ofcurrent EPU design modifications are: (1) Inverter IA -296 watt increase; (2) Inverter lB -309.2 watt increase; (3) Inverter IC -no loading changes; and (4) Inverter 1D -6.2 wattreduction. These changes do not exceed the conservative inverter loading values included in theEDG loading calculations and; as a result, do not adversely impact the EDG loading.

U. S. Nuclear Regulatory Commission Attachment3F0412-06 Page 10 of 15In accordance with the CR-3 EC process, the EDG loading calculations will be revised toincorporate the actual electrical loading impacts from EPU operation and EPU-relatedmodifications following finalization of the modifications to confirm each EDG remains within itsdesign capacity.10. (EEEB 1-10)In the original LAR, Attachment 5, Section 2.3.3.2, page 2.3.3-4, the licensee stated, "All lowervoltage buses, switchgear, and motor control centers were demonstrated to have sufficientvoltages at the lowest operating voltage on the grid to assure operability of the connectedequipment."Provide a discussion and a summary of the calculation that demonstrates that the degradedvoltage relay and under voltage relay settings at the 480 volt load center buses are not adverselyaffected by operation under EPU conditions.Response:The CR-3 480 V load center buses do not have a degraded voltage relaying scheme; only loss ofvoltage relays. The 480 V fixed loss of voltage relays ensure selected 480 V loads are removedfrom the associated bus to prevent bus overload on re-energization and are not being altered as aresult of operation at EPU conditions. The First Level Undervoltage Relays (FLURs) andSecond Level Undervoltage Relays (SLURs) associated with the 4160 V ES buses provideundervoltage and degraded voltage protection for the downstream 480 V electrical distributioncomponents.The FLURs and SLURs dropout, pickup and time delay setpoints, and tolerances have beenevaluated considering proposed changes to the Class IE AC Electrical Distribution System.Conservative bus loading values were used to ensure the undervoltage and degraded voltageschemes are acceptable for operation at EPU conditions. A qualitative assessment of the safety-related ETAP analyses have concluded that the FLURs and SLURs settings are not adverselyimpacted and continue to be acceptable for operation at EPU conditions. In accordance with theCR-3 EC process, the electrical loading calculations will be revised to incorporate the actualelectrical loading impacts from EPU operation and EPU-related modifications followingfinalization of the modifications to confirm the undervoltage and degraded voltage schemes areacceptable for operation at EPU conditions.11. (EEEB 1-11)In the original LAR, Attachment 5, Section 2.3.3.2, page 2.3.3-2, the licensee stated, "Theimpact of the electrical load increase was evaluated using load flow, short circuit, and protection-coordination studies."Provide a summary of the evaluation/study that demonstrates that the short-circuit rating due tothe increase in loads (Class 1E and Non-Class 1E switchgear buses) are not adversely impactedby the load increase.

U. S. Nuclear Regulatory Commission Attachment3F0412-06 Page 11 of 15Response:The short circuit analyses of the CR-3 Class I E and Balance of Plant AC Electrical DistributionSystems calculate short circuit currents for evaluating the adequacy of fault current interruptingratings and to ensure equipment momentary current ratings are not exceeded using ETAPsoftware. These analyses include major AC electrical components added as a result of the CR-3EPU.An initial non safety-related ETAP analysis was performed considering EPU conditions and theresults were provided in Section 2.3.3, "AC Onsite Power System," of the EPU TR (Reference 1,Attachments 5 and 7). Subsequent to submittal of the CR-3 EPU LAR, FPC has discovered anincorrect design input in this ETAP analysis. This condition was identified in the CR-3Corrective Action Program and the short circuit analysis has been re-performed. The revisednon safety-related ETAP analysis indicates that the short circuit ratings are exceeded at EPUconditions on several non-segregated bus duct sections from the unit auxiliary transformer to the4160 V buses. As a result, a plant modification has been added to the EPU scope of work toreplace the sections of bus duct that were determined to require upgrading with higher shortcircuit ratings. This modification will replace five 4160 V non-segregated bus duct sections andwill be completed prior to EPU operation. The short circuit analysis, based on the currentplanned EPU configuration, indicates the maximum short circuit current associated with the non-Class lE switchgear buses does not exceed equipment interrupting duty and momentary dutyvalues and continues to be acceptable for operation at EPU conditions.EPU modifications to the Class 1E AC Electrical Distribution System do not increase theavailable short circuit current on the Class 1E switchgear. Conservative vital bus loading valuesare included in the safety-related ETAP analyses; therefore, additional inverter electrical loadingas a result of safety-related EPU modifications do not impact the short circuit ratings of theClass 1E switchgear. In addition, changes related to the 480V electrical loads (e.g., replacingMOVs) do not adversely impact the safety-related short circuit analyses since the changesconsist of the same or reduced equipment short circuit contribution. As such, the maximumshort circuit current associated with the Class lE switchgear buses does not exceed equipmentinterrupting duty and momentary duty current values and continues to be acceptable foroperation at EPU conditions.12. (EEEB 1-12)In the original LAR, Attachment 5, Section 2.3.4.1, page 2.3.4-2, the licensee discussed the loadimpacts on the direct current (DC) power system due to the proposed EPU and stated thatemergency feedwater flow increase/flow control modification has an impact on DC power butremains within the loading capabilities of the station batteries.Provide a comparison of the existing loads and the loads added to the DC power system as aresult of the EPU. Also, provide the design rating for each safety-related and nonsafety-relatedbattery at CR-3 to show that adequate capacity exists to support EPU conditions.

U. S. Nuclear Regulatory Commission Attachment3F0412-06 Page 12 of 15Response:The CR-3 Class lE 250/125 V station batteries are rated at 1708 amp-hours (A-H) for eighthours to 1.81 volts per cell (vpc). In addition, the Emergency Feedwater System (EFW) dieseldriven pump (EFP-3) battery is rated at 231 A-H for eight hours to 1.81 vpc.An evaluation was performed considering EPU operating conditions to determine the impact onthe CR-3 Class 1E DC Electrical Distribution and non-Class 1E DC Electrical DistributionSystems, including the impact of design modifications as a result of the CR-3 EPU. The totalchanges on vital bus inverter loading, changed as a result of EPU design modifications, do notexceed the conservative inverter loading values included in the DC electrical calculations and donot adversely impact the Class 1 E battery loading.The EFW System pump recirculation line modification adds less than 2 amps to the 'B-positive'125 V Class lE battery and less than 2 amps to the diesel driven EFW pump (EFP-3) battery.No specific loading changes are planned for the 'B-negative' 125 V Class lE battery or the 'A'250/125 V Class lE battery. Table 3, "Pre-EPU B-positive Class lE Battery and EFP-3 BatteryLoading Data," provides the current pre-EPU battery peak zero to one minute and diesel startloading profiles for the 'B-positive' 125 V Class 1E battery and the EFP-3 battery.Table 3 -Pre-EPU B-positive Class 1 E Battery and EFP-3 Battery Loading DataDiesel Start2-hour Profile 4-hour Profile ProfileBattery (amps) (amps) (amps)B-positive Class 1E 125 V 335.7 286.1 356.4EFP-3 NA NA 144.4The non-Class 1E 250/125 V battery is rated at 2200 A-H for eight hours to 1.81 vpc. Anelectrical engineering assessment considering EPU operating conditions concluded that the non-Class 1E DC Electrical Distribution System is not adversely affected as a result of EPUoperation and the non-Class 1E 250/125 V battery will continue to perform as designed.In accordance with the CR-3 EC process, the electrical loading calculations will be revised toincorporate the actual DC electrical loading impacts from EPU operation and EPU-relatedmodifications following finalization of the modifications to confirm the battery loading isacceptable for operation at EPU conditions.13. (EEEB 1-13)In the original LAR, Attachment 5, Section 2.3.5.2, the licensee addressed the systems andcomponents necessary to cope with a station blackout (SBO).a) Provide a summary of SBO loads for both pre-and post-EPU conditions.

U. S. Nuclear Regulatory Commission Attachment3F0412-06 Page 13 of 15Response:Enclosure 1, "Station Blackout DC Loads;" contains the pre-EPU loads associated withthe Class 1E station batteries and the EFP-3 battery. An evaluation was performedconsidering the current EPU modifications to determine the impact on the SBO loadingand concluded that the SBO loading impact is limited to the EFW pump recirculation linemodification. Modifications associated with inverter loading are bounded by the loadingvalues assumed in the applicable calculations; as such, these modifications do not alterSBO coping.The EFW pump recirculation line modification adds less than two amps to the 'B-positive' 125 V Class 1E battery and to the EFP-3 battery. There are no other changes tothe Class 1E DC loads associated to EPU design changes that impact the ability to copewith an SBO at CR-3. Qualitative assessments have determined there is sufficient marginavailable on these battery systems to support the minor loading increase.b) Section 14.1.2.9.5.2 of the CR-3 Final Safety Analysis Report provides an analysis(based on NUMARC 87-00) that supports a coping duration of 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> for an SBO eventat CR-3. This section indicates that the analyses were performed based on a core powerlevel of 2772 megawatts thermal (MWt) and that no analyses are required to support apower uprate of 2609 MWt.Explain whether the analyses provided in the original LAR Section 2.3.5.2 wereperformed to support a power upgrade to an increased core power of 3014 MWt due toEPU conditions.Response:As stated in Section 2.3.5, "Station Blackout," of the EPU TR (Reference 1, Attachments5 and 7), the core decay heat value in the SBO analyses performed for EPU operation isbased on an initial core power of 3014 MWt plus 0.4% heat balance calculationuncertainty and 16.4 MWt from reactor coolant pump heat.14. (EEEB 1-14)On January 31, 2012 (ADAMS Accession No. ML120330114), the licensee submittedsupplemental information in Attachment C, "Clarification Information to the CR-3 EPUTechnical Report Section 2.7.3.1 Regarding the [Fast Cooldown System] FCS Batteries." Basedon its review of the supplemental information, the NRC staff requests the following:a) Discuss the impact of the EPU on battery room temperature during normaloperation, design basis events, and beyond design basis events (such as an SBO).Response:The Class 1E station battery room temperatures are maintained by the Control ComplexVentilation (AH-XK) System. As discussed in Section 2.7.3.1, "Control Room AreaVentilation System," of the EPU TR (Reference 1, Attachments 5 and 7); the normal U. S. Nuclear Regulatory Commission Attachment3F0412-06 Page 14 of 15operational flow paths and flow rates associated with the AH-XK System do not changeas a result of EPU operation; the heat load increases due to EPU operation and associatedplant modifications are small; and the equipment operational thermal loads do not changefollowing a LOCA at EPU conditions. A qualitative assessment of the EPU impact onthe Control Complex heat load calculations, which include the Class 1E battery rooms,was performed and the assessment determined that the room temperatures will remainbelow the maximum allowable normal and post-LOCA Control Complex temperatures.Also, the additional BTUs were compared to the existing margins in the SBO analysesand the additional heat loads as a result of EPU operation and associated modificationswere qualitatively determined to have a small impact on these margins.b) Discuss the impact of placing the FCS batteries in the battery rooms has on battery roomtemperature during normal operation, design basis events and beyond the design basisevents (such as an SBO).Response:The FCS batteries are much smaller than the station safety-related batteries. TheClass 1E station batteries are rated for 1708 A-H for eight hours to 1.81 vpc while theproposed FCS batteries are rated for 50 A-H for eight hours to 1.75 vpc. The currentSBO temperature rise calculations associated with the Class 1E station battery roomsindicate a maximum calculated temperature of approximately 107TF. A qualitativeassessment of the FCS battery impact on the battery room temperature rise calculationswas performed. The additional heat load from the FCS batteries was conservativelycalculated using two times the full amperage from each battery bank during worst caseconditions (i.e., maximum loads and minimum voltage). This conservative heat loadassumption represents a very small percentage of heat, approximately 0.06%, of thatproduced by the Class lE station batteries and does not increase the evaluatedtemperatures of the battery rooms during normal operation, design basis events, orbeyond design basis events including an SBO event.c) Discuss the installation details of the FCS batteries in the battery rooms.Response:The new FCS battery banks are to be mounted in new battery racks on the plant stationbattery room floors on a horizontal plane with the existing station batteries to meet plantseparation criteria. Enclosure 2, "Battery Room Layout Drawing -Proposed FCSBattery Location," illustrates the proposed location and layout of the FCS batteries withrespect to the existing safety-related station batteries.The positive and negative terminal battery cables for the FCS will be installed in flexconduit and routed to disconnect switches mounted on the west wall (left wall asillustrated in Enclosure 2) of the battery rooms. The FCS batteries and racks will beinstalled greater than four feet horizontally from the station batteries to ensure CR-3electrical circuit physical separation criteria are met.

U. S. Nuclear Regulatory Commission Attachment3F0412-06 Page 15 of 15The seismically qualified racks provided by C&D Technologies will be installed andanchored in the concrete in accordance with CR-3 anchor bolt procedures and the batterymanufacturer installation instructions.d) Discuss the seismic design considerations for the FCS battery installation and thepotential seismic impact on the other safety-related equipment/components in the batteryrooms.Response:The FCS batteries and associated supporting equipment have been seismically tested inaccordance with IEEE 344, "IEEE Recommended Practice for Seismic Qualification ofClass 1E Equipment for Nuclear Power Generating Stations." Associated conduit andcable routing will be installed in accordance with applicable CR-3 installation practices toassure this equipment is seismically qualified. The FCS batteries and racks will beinstalled greater than four feet horizontally from the station batteries to ensure CR-3electrical circuit physical separation criteria are met.References1. FPC to NRC letter dated June 15, 2011, "Crystal River Unit 3 -License AmendmentRequest #309, Revision 0, Extended Power Uprate." (Accession No. ML 112070659)2. NRC to FPC letter dated June 5, 1981, "Environmental Qualification of Safety-RelatedElectrical Equipment." (Accession No. 8107060035)

FLORIDA POWER CORPORATIONCRYSTAL RIVER UNIT 3DOCKET NUMBER 50-302 /LICENSE NUMBER DPR-72ENCLOSURE 1STATION BLACKOUT DC LOADS Progress EnergyCrystal River Unit 3Battery and Charger Sizing CalculationBattery A -Positive, 4 HourDesign Load DataE90-0099, Rev. 4Attachment 7.2Page 2 of 6Source Paneland Switch DescriptionSteady RatedOp State or Current Start TimeQty Inrush (Amps) (minL (sec)Ending TimemminL. (sec)Tag NumberDPDPIA 04 DUAL INPUT INVERTER 3A VBIT-1ADPDP1A 06 BATTERY CHARGER 3A DPBC-1ADPDP1A 10 BATTERY CHARGER 3E DPBC-IE(1A10DPDP1A 18 250/125-DC BATTERY 3A DPGD-1AGROUND DETECTORDPDP5A 01 RC VENT VALVE & CONTROL 1030(5A01)DPDP5A 03 RELAYS & IND LIGHTS FOR EX 1060(5A03)ACT A -HPI1.00 SS1.00 SS1.00 SS1.00 SS168.0000.1010.1010.0010 00 00 00 023924024024059000DPDP5A 04 MUP-3A CONTROLDPDP5A 09 480V ES SW MTSW-3F BKRCONTROLMUP-3A(5A04)MTSW-3F(5A09DPDP5A 15 SW VALVES & CONTROL 1038(5A15)DPDP5A 17 SW VALVES & CONTROL 1038(5A17)DPDP5A 21 SW & AH VALVES & CONTROL 1041 (5A21)DPDP5A 22 WS VALVES/AH CONTROL 1038(5A22)DPDP5A 23 MAKEUP AND PURIFICATION MUP-3A(5A23)PUMP MUP-1A BACKUP LOPDPDP5A 24 MAKEUP & PURIF PUMP MUP- MUP-5A(5A24)1A BACKUP GEAR OIL PUMPDPDP5A 26 EFV58 CONTROLLER EFV58DPDP5A 28 MAN TRANSFER SWITCH FOR DPXS-1 (5A28)POWER SELECT TO MUP-3B/5BDPDP5A 29 EFV57 CONTROLLER EFV57DPDP6A 01 DFP-3A CONTROL/EGDG-1A DFP-3A(6A01)TACHDPDP6A 03 EGM-2A CONTROL EGM-2A(6A03)DPDP6A 07 EDG DC FUEL OIL TRANSFER DFP-lC(6A07)PUMP DFP-1CDPDP6A 08 EMERG DIESEL GEN DC FUEL DFP-3A(6A08)OIL AUX. PUMP DFP-3A1.00 SS6.72 SS1.00 SS186.90 IN15.72 SS15.72 SS3.50 SS1.50 SS7.01 SS1.00 SS1.00 IN1.00 SS1.00 IN1.00 SS1.00 SS123.92 IN31.36 SS2.50 SS1.00 SS0.32 SS0.6720.10018.6901.5721.5720.3500.1500.7010.68011.5700 030 00 00 31 00 00 00 00 00 030240012402402402402400300302400302402402403.240 0 0 240 02.314 0 318.750 0 33.750 0 63.000 0 012.392 0 03.136 0 30.250 30 03.000 0 00.032 0 0Printed: 4/1612009 Case Code: AP4HPrinted: 4/1612009Case Code: AP4H Progress EnergyCrystal River Unit 3Battery and Charger Sizing Calculation EBattery A -Positive, 4 HourDesign Load DataSteady RatedOp State or Current Start TimeTaa Number Qty Inrush (Amps) (mini (sec)90-0099, Rev. 4Attachment 7.2Page 3 of 6Ending TimeminL_ (sec)Source Paneland SwitchDPDP6A 09DPDP6A 12DPDP6A 14DescriptionEDG AIR COMPRESSORMOTOR EGM-2AEMERG DIESEL GEN EGDG-1ACONTROL RELAYSEDG 3A DIFF LOCKOUT & AUX.RELAY CONTROLEGDG-1A SYNCH CHECKRELAYING500 KV SUBST & OPT TRIPMASTER LOCKOUT RELAYB.E.S.T. DIFFERENTIAL &LOCKOUT RELAYPRIMARY UNIT TRIP LOCKOUTRELAYDPDP7ADPDP7ADPDP7ADPDP7ADPDP8ADPDP8ADPDP8ADPDP8ADPDP8ADPDP8ADPDP8ADPDP8A020406070107080911141617EGM-2A(6A09)EGCP-1A(6A12EGCP-2A(6A14EGDG-1A(7A021004(7A04)SSAA-1 (7A06)1004(7A07)EFV-2 MOTORFWV-36(8A07)FVV-36(8A08)FWV-35(8A09)1035(8A11)(8A14)1041(8A16)ASV-20467.94170.066.666.66170.061.001.001.001.001.001.00SSINSSSSINSSINSSSSINSS6.79417.0060.6660.66617.0060.1225.5530.1180.2185.4690.034001239239000000000050001001240123923924024002402400240000500010010HOTWELL ISO TO MTR DRIVENEFP -EFV-2SUBV -FWV-36CONTROL POWER FOR FWV-36FEEDWATER BLOCK TO STMGEN RCSG-1A -FWV-35MS VALVES & CONTROLWS SOLENOID VALVES &CONTROLMS VALVES & CONTROLTURBINE DRIVEN EFP INLETISO VALVE -ASV-2041.00 SS 0.050 0 0 240 01.00 IN 5.237 0 0 1 01.00 SS 0.881 1 0 240 02.00 SS 0.278 0 0 240 0Printed: 411612009 Case Code: AP4HPrinted: 4/16/2009Case Code: AP4H-SProgress Energy Battery and Charger Sizing CalculationCrystal River Unit 3 Battery A -Negative, 4 HourE90-0099, Rev. 4Attachment 7.4Page 2 of 7Design Load DataSource Paneland Switch DescriptionSteady RatedOp State or Current Start TimeTag Number Qty Inrush (Amps) (min) (sec)Ending Time(mm)j (sec)DPDP1A 05 INVERTER 3CDPDP1A 11 BATTERY CHARGER 3EDPDP1A 12 BATTERY CHARGER 3CDPDP1A 18 250/125-DC BATTERY 3AGROUND DETECTORDPDP5A 02 WS VALVES & CONTROLDPDP5A 06 ES A 480V UV LOCKOUTRELAYSVBIT-1CDPBC-IE(1A1 1DPBC-1CDPGD-1A(5A02)1169(5A06)DPDP5A 08 CRD PRIMARY TRIP BREAKER 1072(5A08)UNIT 10DPDP5A 10 4160V SWGR ES BUS 3A BKR MTSW-2C/DCONTROLDPDP5A 14 SW VALVES & CONTROL 1038(5A14)DPDP5A 16 SW & Cl VALVES & CONTROL 1038(5A16)DPDP5A 18 MTXS-1 & CA VALVE CONTROL 1041(5A18)DPDP5A 23 MAKEUP AND PURIFICATION MUP-3A(5A23)PUMP MUP-1A BACKUP LOPDPDP5A 24 MAKEUP & PURIF PUMP MUP- MUP-5A(5A24)1A BACKUP GEAR OIL PUMP1.00 SS 180.000 0 0 239 591.00 SS 0.101 0 0 240 01.00 SS 0.101 0 0 240 01.00 SS 0.001 0 0 240 01.00 IN 12.842 0 0 0 11.00 SS 0.203 0 1 240 01.00 IN 2.212 0 0 1 01.00 SS 0.212 1 0 240 0312.54 IN 31.254 0 0 0 333.65 SS 3.365 0 3 1 033.65 SS 3.365 1 0 239 033.65 SS 3.365 239 0 239 50100.65 IN 10.065 239 50 240 03.50 SS 0.350 0 0 240 03.00 SS 0.300 0 0 240 01.00 SS 0.227 0 0 240 01.00 IN 11.570 0 0 0 31.00 SS 2.314 0 3 30 01.00 IN 18.750 0 3 0 61.00 SS 3.750 0 6 30 01.00 SS 0.672 0 0 30 00.15 SS 0.101 30 0 240 0DPDP5A 25 MUP-5A CONTROLMUP-5A(5A25)DPDP5A 27 CA VALVES & CONTROL 1041(5A27)DPDP5A 28 MAN TRANSFER SWITCH FOR DPXS-1 (5A28)POWER SELECT TO MUP-3B/5BDPDP5A 31 CRD DC TRIP BKR UNITS 3 & 4 1076(5A31)DPDP6A 04 EDG 3A FUEL OIL TANK LEVEL EGCP-1A(6A04INSTRUMENTSDPDP6A 06 DFP-1C CONTROL DFP-lC(6A06)123.92 IN31.36 SS2.50 SS1.00 IN1.00 SS2.00 SS12.3923.1360.2504.2120.2120.1240 00 330 00 01 00 00302401240240300000Printed: 4/16/2009 Case Code: AN4HPrinted: 4116/2009Case Code: AN4H-Progress EnergyCrystal River Unit 3Battery and Charger Sizing Calculation E90-0099, Rev. 4Attachment 7.4Battery A -Negative, 4 Hour Page 3 of 7Design Load DataSteady RatedOp State or Current Start Time Ending TimeU,Source Paneland SwitchDPDP6A 07DPDP6A 08DPDP6A 09DPDP6A 10DescriptionEDG DC FUEL OIL TRANSFERPUMP DFP-lCEMERG DIESEL GEN DC FUELOIL AUX. PUMP DFP-3AEDG AIR COMPRESSORMOTOR EGM-2AEMERG DIESEL GEN EGDG-1ACONT PNL ANNUN.IDPDP7A 01 ES BUS DEGRADED VOLT.ALARM RELAYDPDP7A 03 GENERATOR BKR PRIMARYTRIPDPDP7A 05 SU TRANS DIFFERENTIAL &LOCKOUT RELAYSDPDP7A 10 230 KV BKR 4900 AND 4902CONTROLDPDP7A 12 PLANT LINE 4 230 KVDIFFERENTIALDPDP8A 01 HOTWELL ISO TO MTR DRIVENEFP -EFV-2DPDP8A 02 CONTROL FOR HOTWELL ISOTO MTR DRIVEN EFP -EFV-2DPDP8A 04 HPI RECIRC TO RB SUMP SVVALVES & CONTROLDPDP8A 07 SUBV -FWV-36DPDP8A 09 FEEDWATER BLOCK TO STMGEN RCSG-1A -FWV-35DPDP8A 10 CONTROL POWER FOR FWV-36DPDP8A 13 RCV VENT VALVES &CONTROLDPDP8A 15 CONTROL POWER FOR ASV-204DPDP8A 17 TURBINE DRIVEN EFP INLETISO VALVE -ASV-204DPDP8C 01 EFP-2 ISOLATION (DC) VALVE -EFV-11DPDP8C 02 CONTROL POWER FOR EFV-1 1DPDP8C 03 EFP-2 ISOLATION (DC) VALVE -EFV-32Printed: 41/16/2009Tag NumberDFP-IC(6A07)DFP-3A(6A08)EGM-2A(6A09)EGCP-1A(6A101014(7A01)1004(7A03)1169(7A05)SSAA-61169(7A12)EFV-2 MOTOREFV-2 CNTRLMUV-543/544-SVFWV-36(8A07)FWV-35(8A09)FWV-35(8A10)1030(8A1 3)ASV-204(8A1 5ASV-204EFV-1 1(8C01)EFV-11 (8C02)EFV-32(8C03)1.001.001.008.001.001.001.00INSSSSSSSSSSSS2.2080.6670.0500.4000.1341.0000.218010000000000001240240240240240240Qty Inrush (Amps) (mini (sec) (mini (sec)00000003.00 SS0.150 0 0 240 02.00 SS 0.100 0 0 240 01.00 SS 0.200 0 0 240 01.00 SS0.150 0 0 240 0Case Code: AN4H-Progress EnergyCrystal River Unit 3Battery and Charger Sizing CalculationBattery A -Negative, 4 HourE90-0099, Rev. 4Attachment 7.4Page 4 of 7Design Load DataSource Paneland SwitchDPDP8C 04Description Taa NumberCONTROL POWER FOR EFV-32 EFV-32(8C04)Steady RatedOp State or CurrentQty Inrush (Amps)1.00 SS 0.150Start Time(mLm. (sec)0 0Ending Time(mini (sec)240 0DPDP8C 05 CROSSTIE ISOLATION VALVE -EFV-12(8C05)EFV-12DPDP8C 06 CONTROL POWER FOR EFV-12 EFV-12(8C06)Printed: 4/1612009 Case Code: AN4HPrinted: 4/16/2009Case Code: AN4H-j Progress EnergyCrystal River Unit 3Battery and Charger Sizing CalculationBattery B -Positive, 4 HourDesign Load DataE90-0099, Rev. 4Attachment 7.6Page 2 of 7Source Paneland Switch Description Taq NumberDPDP1B 01 250/125-DC BATTERY 3B DPGD-1BGROUND DETECTORDPDP1B 06 MISC. SW SOLENOID VALVES (1B06)DPDP1B 09 BATTERY CHARGER 3F DPBC-1 F(1 B09DPDP1B 11 BATTERY CHARGER 3D DPBC-1DDPDP1B 15 DUAL INPUT INVERTER 3B VBIT-1BDPDP5B 02 MTSX-1 CONTROL & CA 1042(5B02)VALVES & CONTROLDPDP5B 03 RELAYS & IND LIGHTS FOR ES 10611(5B03)ACT. B -HPIDPDP5B 04 MUP-3C CONTROL MUP-3C(5B04)DPDP5B 06 480V ES SW B UV & LOCKOUT 1169(5B06)RELAYSDPDP5B 09 480V ES SW B BRK CONTROL MTSW-3GDPDP5B 14 SW & CA VALVES & CONTROL 1039(5B14)DPDP5B 15 SWVALVES & CONTROL 1039(5B15)DPDP5B 16 SW & CI VALVES & CONTROL 1039(5B16)DPDP5B 17 SW & MU VALVES & CONTROL 1039(5B17)DPDP5B 18 SW VALVES & AH CONTROL 1039(5B18)DPDP5B 22 AH & CA VALVES & CONTROL 1039(5B22)Steady RatedOp State or Current Start TimeQty Inrush (Amps) (min) (sec)Ending Time(mm) (sec)1.00 SS7.14 SS1.00 SS1.00 SS1.00 SS8.75 SS1.00 SS6.72 SS1.00 SS1.00 IN1.00 SS185.93 IN14.72 SS14.72 SS11.91 SS9.18 SS9.68 SS4.50 SS7.57 SS1.00 SS9.80 SS7.07 SS1.00 IN1.00 SS1.00 IN1.00 SS1.00 SS123.92 IN31.36 SS2.50 SS1.00 SS0.001 0 0 240 00.7140.1010.101148.0000.87500000000002402402402392400005902.564 0 0 240 00.6720.1007.4700.26518.5931.4721.4721.1910.9180.9680.4500.7570.6120.9800.70711.5702.31418.7503.7503.00012.3923.1360.2503.000030000010300000030000000030030 0240 00 1240 00 31 0240 030 0240 0240 0240 0240 0240 030 0240 00 330 00 630 0240 00 330 0240 0240 0Case Code: BP4HDPDP5B 23 MAKE-UP & PURIFICATIONPUMP MUP-1C BACKUP LOPMUP-3C(5B23)DPDP5B 24 MAKEUP & PURIF PUMP MUP- MUP-5C(5B24)1C BACKUP GEAR OIL PUMPDPDP5B 26 EFV56 CONTROLLER EFV56DPDP5B 28 MAN TRANSF SW FOR MUP- DPXS-1(5B28)3B/5B CONTROL POWERDPDP5B 29 EFV55 CONTROLLERPrinted: 4/1612009EFV55

.2Progress EnergyCrystal River Unit 3Battery and Charger Sizing Calculation EBattery B -Positive, 4 HourDesign Load DataSteady RatedOp State or Current Start Time90-0099, Rev. 4Attachment 7.6Page 3 of 7Ending Time1mm) (sec)240 0Source Paneland SwitchDPDP6B 01DPDP6B 03DPDP6B 07DPDP6B 08DPDP6B 09DPDP6B 10DescriptionDFP-3B CONTROL/EGDC-11BTACHEGM-2B CONTROLEDG DC FUEL OIL TRANSFERPUMP DFP-1DEDG DC AUX. FUEL OIL PUMPDFP-3BEDG 3B AIR COMPRESSORMOTOR EGM-2BEMERG. DIESEL GEN. EGDG-1B CONT. PNL. ANNUN.EGDG-1B CONTROL & ALARMRELAYS.EGDG-1B DIFF. LOCKOUT &AUX. RELAYSDPDP6BDPDP6B1214Tag NumberDFP-3B(6B01)EGM-2B(6B03)DFP-1D(6B07)DFP-3B(6B08)EGM-2B(6B09)EGCP-1B(6B10EGCP-1B(6B12EGCP-2B(6B141004(7B03)1023(7B05)EGDG-1B(7B061169(7B08)1023(7B14)SSAA-2(7B1 5)EFV-1 MOTORASV-5(8B05)ASV-5(8B06)DPDP7B 03 500 KV & OPT ALT TRIP &RESET MASTER LOCKOUTRELAYDPDP7BDPDP7BDPDP7BDPDP7BDPDP7BDPDP8BDPDP8B05060814150105MOS CONTROL & BREAKERINDICATIONEGDG-1B SYNCH CHECKRELAYINGSU XFMR PROTECTIVERELAYSPLANT LINE 4 BACKUPPROTECTION230 KV BKR 4900 AND 4902CONTROLHOTWELL ISO TO TURBDRIVEN EFP-2 -EFV-1TURB DRIVEN EMERGFEEDPUMP INLET ISO VALVEASV-51.001.0067.94170.066.666.66170.061.001.001.001.001.001.001.001.001.001.001.00Qty Inrush (Amps) (min) (sec)0.32 SS 0.032 0 0INSSSSINSSSSININSSSSSSSSSSSSINSSINSS2.2080.6676.79417.0060.6660.66617.0065.5530.11816.7180.1220.2680.1341.00019.6003.4001.5300.441010012392390000000000100000050010000001001240240123923924002402402402402402400240DPDP8B 06 CONTROL POWER FOR ASV-5Printed: 4116/2009 Case Code: BP4HPrinted: 411612009Case Code: BP4H J Progress EnergyCrystal River Unit 3Battery and Charger Sizing CalculationBattery B -Positive, 4 HourDesign Load DataE90-0099, Rev. 4Attachment 7.6Page 4 of 7Source Paneland SwitchDPDP8B 09DPDP8B 11DPDP8B 12DPDP8B 13DPDP8B 14DPDP8B 15DPDP8B 17DPDP8B 20Steady RatedOp State or Current Start TimeQty Inrush (Amps) (min) (sec)Ending Time(mi) (sec)DescriptionFEEDWATER SU BLOCKVALVE -FWV-33FEEDWATER BLOCK TO STMGEN RCSG-1B; FWV-34CONTROL POWER FOR FWV-34SUPPLY BLOCK TO EFP-2VALVE MSV-55CONTROL POWER FOR MSV-55SUPPLY BLOCK TO EFP-2VALVE -MSV-56MS VALVES & CONTROLPOWERMUV-49 POWER & CONTROLTag NumberFWV-33(8B09)FWV-34(8B1 1)FWV-34(8B12)MSV-55(8B13)MSV-55(8B14)MSV-56(8B15)1035(8B17)1039(8B20)2.00 SS 0.100 0 0 240 00.15 SS 0.150 0 0 240 02.001.00SSSS0.2780.621000024024000Printed: 4/16/2009 Case Code: BP4HPrinted: 4/1612009Case Code: BP4H Progress EnergyCrystal River Unit 3Battery and Charger Sizing CalculationBattery B -Negative, 4 HourDesign Load DataE90-0099, Rev. 4Attachment 7.8Page 2 of 7Source Paneland Switch DescriptionDPDP1B 01 250/125-DC BATTERY 3BGROUND DETECTORDPDP1B 10 BATTERY CHARGER 3FDPDP1B 16 DUAL INPUT INVERTER 3DDPDP1B 17 BATTERY CHARGER 3BDPDP5B 01 RCV VENT VALVES &CONTROLDPDP5B 08 CA VALVES & CONTROLDPDP5B 10 4160 V SWGR ES BUS 3B BKRCONTROLDPDP5B 21 SW & AH VALVES & CONTROL,MU INDICATIONDPDP5B 23 MAKE-UP & PURIFICATIONPUMP MUP-lC BACKUP LOPDPDP5B 24 MAKEUP & PURIF PUMP MUP-lC BACKUP GEAR OIL PUMPDPDP5B 25 MUP-5C CONTROLDPDP5B 27 WS SOLENOID VALVES &CONTROLDPDP5B 28 MAN TRANSF SW FOR MUP-3B/5B CONTROL POWERDPDP5B 30 CRD PRI TRIP BREAKER UNIT11, SHUNT TRIP PWRDPDP5B 31 CRD PRI TRIP BKR CONTROLDPDP6B 04 EDG 3B FUEL OIL TANK LEVELRELAYSDPDP6B 06 DFP-1 D CONTROLDPDP6B 07 EDG DC FUEL OIL TRANSFERPUMP DFP-1DTao NumberDPGD-1BDPBC-1F(1B10VBIT-1DDPBC-1B1032(5B01)1042(51B08)MTSW-2E/F1042(5B21)MUP-3C(5B23)MUP-5C(5B24)MUP-5C(5B25)(5B27)DPXS-1(5B28)1073(5B30)1076(5B31)EGCP-1B(6B04DFP-1D(6B06)DFP-1D(6B07)SteadyOp State orQty Inrush1.00 SS1.001.001.00391.9934.1434.1434.14101.147.011.001.001.001.001.000.15SSSSSSINSSSSSSINSSINSSINSSSSSSRatedCurrent(Amps)0.0010.101124.0000.10139.1993.4143.4143.41410.1140.70111.5702.31418.7503.7500.6720.101Start Time0mm) (sec)0 0Ending Time(mmn) (sec)240 0000001239239000000302402392400123923924024003003030240123.9231.362.501.001.001.001.002.00INSSSSINSSINSSSS12.3923.1360.2502.2120.2124.2120.2120.268003001010030000000302401240124024030000000Printed: 4/16/2009 Case Code: BN4HPrinted: 4/1612009Case Code: BN4H Progress EnergyCrystal River Unit 3Batteiry and Charger Sizing Calculation EBattery B -Negative, 4 HourDesign Load DataSteady RatedOp State or Current Start TimeTag Number Qty Inrush (Amps) (mini (sec)90-0099, Rev. 4Attachment 7.8Page 3 of 7Ending TimeImini (sec)Source Paneland SwitchDPDP6B 08DPDP6B 09DPDP7B 01DPDP7B 04DPDP7B 07DPDP7B 09DPDP8B 01DPDP8B 02DPDP8B 04DPDP8B 05DescriptionEDG DC AUX. FUEL OIL PUMPDFP-3BEDG 3B AIR COMPRESSORMOTOR EGM-2BES B BUSSES DEGRADEDVOLTAGE ALARM RELAYGENERATOR BKR BACLUPTRIP & CLOSEALTERNATE UNIT TRIPLOCKOUTSBACK-UP ES XFMR PROTRELAYINGHOTWELL ISO TO TURBDRIVEN EFP-2 -EFV-1CONTROL POWER FOR EFV-1CONTROL ROOM EMERGENCYLIGHTINGTURB DRIVEN EMERGFEEDPUMP INLET ISO VALVEASV-5DFP-3B(6B08)EGM-2B(6B09)1014(7B01)1004(7B04)1004(7B07)BEST (7B09)EFV-1 MOTOREFV-1 CNTRLCR EMERG LTGASV-5(8B05)1.001.001.001.001.003.001.001.001.00SSSSINSSSSSSSSINSS0.0500.8845.4690.0340.3530.1507.28019.6003.400240240024024024024001DPDP8BDPDP8BDPDP8BDPDP8BDPDP8BDPDP8BDPDP8BDPDP8BDPDP8BDPDP8DHPI RECIRC TO RB SUMP SVVALVE POWER & CONTROLFEEDWATER SU BLOCKVALVE -FWV-33CONTROL POWER FOR FWV-33FEEDWATER BLOCK TO STMGEN RCSG-1B; FWV-34SUPPLY BLOCK TO EFP-2VALVE MSV-55SUPPLY BLOCK TO EFP-2VALVE -MSV-56CONTROL POWER FOR MSV-56MS VALVES & CONTROLPOWERWS SOLENOID VALVES &CONTROLEFP-1 ISOLATION VALVE -EFV-14MUV-545/546-SVFWV-33(8B09)FWV-33(8B1 0)FWV-34(8B1 1)MSV-55(8B13)MSV-56(8B1 5)MSV-56(8B16)1117(8B18)(8B21)EFV-14(8D01)1.00 SS4.00 SS1.00 SS0.050 0 0 240 00.2001.093000024024000Printed: 4/1612009 Case Code: BN4HPrinted: 4116/2009Case Code: BN4H Progress EnergyCrystal River Unit 3Battery and Charger Sizing CalculationBattery B -Negative, 4 HourE90-0099, Rev. 4Attachment 7.8Page 4 of 7Design Load DataSource Paneland Switch Description Tao NumberDPDP8D 02 CONTROL POWER FOR EFV-14 EFV-14(8D02)DPDP8D 03 MTR DRV EMERG FWP EFP-1 EFV-33(8D03)TO STM GEN VALVE -EFV-33DPDP8D 04 CONTROL POWER FOR EFV-33 EFV-33(8D04)Steady RatedOp State or CurrentQty Inrush (Amps)1.00 SS 0.150Start Time(mi) (sec)0 0Ending TimeImm) (sec)240 01.00 SS0.150 0 0 240 0Printed: 4/1612009 Case Code: BN4HPrinted: 4/16/2009Case Code: BN4H-Progress EnergyCrystal River Unit 3Battery and Charger Sizing CalculationBattery D -Positive, 4 HourDesign Load DataE90-0099, Rev. 4Attachment 7.9Page 2 of 5Source Paneland Switch DescriptionDPDP1D 00 DC POWER AVAILABLEREMOTE INDICATING LIGHTDPDP1D 03 DC TURBO SOAKBACK OILPUMP MOTOR AND CONTROLTan NumberPWR AVAILDLP-18Steady RatedOp State or Current Start TimeQty Inrush (Amps) (min) (sec)1.00 SS 0.050 0 0Ending TimejMm) (sec)240 0DPDP1D 04 GROUND DETECTOR DPGD-1DDPDP1D 05 DC FUEL PUMP MOTOR AND DFP-7CONTROLDPDP1D 06 EFCP-1 DC CONTROL POWER EFCP-1DPDP1D 07 DC CIRCULATING OIL PUMP DLP-17MOTOR AND CONTROLDPDP1D 10 BATTERY CHARGER DPBC-1J DPBC-1J1.00 IN369.80 SS1.00 SS1.00 SS1.00 SS1.00 IN279.80 SS279.80 SS193.40 SS1.00 IN609.80 SS1.00 SS1.00 SS1.00 SS46.0983.6980.0100.0100.06034.0982.7982.7981.93462.0986.0980.0100.0100.0500525000500052500001240240012402400012402405250005000525000Printed: 411612009 Case Code: EF4HPrinted: 4/1612009Case Code: EF4H-FLORIDA POWER CORPORATIONCRYSTAL RIVER UNIT 3DOCKET NUMBER 50-302 / LICENSE NUMBER DPR-72ENCLOSURE 2BATTERY ROOM LAYOUT DRAWING -PROPOSED FCSBATTERY LOCATION 28'-60ROL BUILDING AIR B01-FaGINEEREDFEGUARDLAY CAB-G-0--ICD_ , 1/--TCONTROL BUILDING IPanEAIR BOUNDARY (BELOW)AIRBOLF=(fLA6L cC/LtC-(-*1