ML093340051

R. E. Ginna, Reply to Request for Additional Information Revisions to Loss-of-Power Diesel Generator Start Instrumentation Limiting Safety System Settings and Diesel Generator Load Test Value

ML093340051
Person / Time
Site:	Ginna
Issue date:	11/23/2009
From:	John Carlin Constellation Energy Group, Ginna
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
TAC ME0291
Download: ML093340051 (38)

Text

John Carlin Site Vice President CENG a joint venture of Consteulation 6nI el)DF Energy, R.E. Ginna Nuclear Power Plant, LLC 1503 Lake Road Ontario, New York 14519-9364 585.771.5200 585.771.3943 Fax November 23, 2009 U. S. Nuclear Regulatory Commission Washington, DC 20555 -0001 ATTENTION:

SUBJECT:

Document Control Desk R.E. Ginna Nuclear Power Plant Docket No. 50-244 Reply to Request for Additional Information RE: Revisions to Loss-of-Power Diesel- Generator Start Instrumentation-Limiting-Safety-System Settings-and-Diesel Generator Load Test Value (a) Letter from Mr. J. T. Carlin (Ginna LLC) to Document Control Desk (NRC)dated December 19, 2008, Application to Revise Technical Specification Limiting Conditions of Operation (LCOs) 3.3.2, 3.3.4, and 3.

8.1 REFERENCES

(b) Letter from Mr. J. T. Carlin (Ginna LLC) to Document Control Desk (NRC)dated January 22, 2009, Amendment to Application to Revise Technical Specification Limiting Conditions of Operation 3.3.2, 3.3.4, and 3.8.1 (c) Letter from Mr. E. A. Larson (Ginna LLC) to Document Control Desk (NRC)dated July 24, 2009, Reply to Request for Additional Information Associated with the Proposed License Amendment Request Regarding Revision of Technical Specification Limiting Conditions of Operation 3.3.2, 3.3.4, and 3.8.1 (d) Letter from Mr. D. V. Pickett (NRC) to Mr. J. T. Carlin (Ginna LLC) dated November 10, 2009, Request for Additional Information RE: Revisions to Loss-of-Power Diesel Generator Start Instrumentation Limiting Safety System Settings and Diesel Generator Load Test Value (TAC NO. ME029 1)On December 19, 2008, R.E. Ginna Nuclear Power Plant, LLC (Ginna LLC) submitted a License Amendment Request (LAR) seeking to revise Technical Specification (TS) Limiting Conditions of Operation (LCOs) 3.3.2, 3.3.4, and 3.8.1 (References (a) and (b)). As the result of an NRC Request for Additional Information, Ginna LLC subsequently submitted further information on July 24, 2009 (Reference (c)).WPRLA-R/O0Oc--"cZ(,

Document Control Desk November 23, 2009 Page 2 Subsequent to the most recent submittal, the NRC issued a second Request for Additional Information (Reference (d)). Attachment (1) contains our response to this request. Attachments (2) and (3) contain supporting information.

No new commitments are being made in this submittal.

Should you have questions regarding the information in this submittal, please contact Mr. Thomas Harding at (585) 771-5219 or via email at Thomas.HardingJr@cengllc.com.

Ve ors, STATE OF NEW YORK ours TO WIT: COUNTY OF WAYNE 1, John Carlin, being duly sworn, state that I am Vice President, R.E. Ginna Nuclear Power Plant, LLC (Ginna LLC), and that I am duly authorized to execute and file this request on behalf of Ginna LLC. To the best of my knowledge and belief, the statements contained in this document are true and correct. To the extent that these statements are not based on my personal knowledge, they are based upon information provided-by'other GinnaL-LCLemployees-and/or-consultants.--Such infoo ation has-been.reviewed in,.accordance with company practice and I believe it to be reliable.Subscribed and sworn before me, a Notary Public in and ýor the State of New York and County of]]/Y]L~L" , ,this day of .) IelLm6r 2009.WITNESS my Hand and Notarial Seal: Ah" ko7 V ) A' &,"i Notary Public.SHARONL. MILLER:-.-;

!Notary Public, State'o6 New York (My Commission Expires: Registration No.

Date Attachment 1: Response to Request for Additional Information Regarding Revisions to Loss-of-Power Diesel Generator Start Instrumentation Limiting Safety System Settings and Diesel Generator Load Test Value Attachment 2: Pages from DA-EE-92-1 1-01, Diesel Generator A Dynamic Loading Analysis Attachment 3: Pages from DA-EE-92-112-01, Diesel Generator B Dynamic Loading Analysis cc: S. J. Collins, NRC D. V. Pickett, NRC Ginna Resident Inspector, NRC P. D. Eddy, NYSDPS A. L. Peterson, NYSERDA ATTACHMENT 1 Response to Request for Additional Information Regarding-Revisions to Loss-of-Power ,Diesel Generator Start Instrumentation Limiting Safety System Settings and DieselGenerator Load Test Value R.E. Ginna Nuclear Power Plant, LLC November 23, 2009 Attachment I Response to Request for Additional Information Regarding Revisions to Loss-of-Power Diesel Generator Start Instrumentation Limiting Safety System Settings and Diesel Generator Load Test Value Request for Additional Information Question #1a: In response to Question #1 Ic in the licensee's letter dated July 24,2009, it was stated that"Attachment 6 contains individual Diesel Loading Simulation results for A and B Diesel Generator in three different scenarios.

For each diesel, a baseline (where the containment spray pump does not come on), a "most likely" and a "worst case scenario" are provided." The NRC staff could not find the requisite response (voltage and frequency simulation) in Attachment 6 of the licensee's submittal.

Please provide analysis for the worst case voltage and frequency transients of the diesel generator, if a containment spray pump is started coincident with another large load, and compare the voltage and frequency variation limits to those recommended in Regulatory Guide 1.9.The attached pages from Diesel Generator A Dynamic Loading Analysis, DA-EE-92-111-01, revision 2, (Attachment

2) show the requested information for the A diesel generator.

• Section 7.4.6 provides the acceptance criteria, with section 7.4.6.2 containing Regulatory Guide 1.9 requirements." Case DGA FU1 -DIG loading without containment spray. Table 6 defines the design criteria reference lines in the diesel generator transient response plots.The analysis figures must be in color in order to differentiate the lines." Case DGA FU2 -containment spray loaded with MCC C with transient plots" Case DGA FU3 -containment spray loaded with service water pump, WORST CASE, with transient plots The attached pages from Diesel Generator B Dynamic Loading Analysis, DA-EE-92-112-01, revision 1, (Attachment

3) show the requested information for the B diesel generator.

This analysis is currently being revised to include the level of detail shown in the A diesel generator analysis, it is not in color. The present revision does not have the criteria reference lines shown on the transient plots.Section 7.4.6.2 contains the Regulatory Guide 1.9 acceptance criteria.-Cases FU1, FU2 and FU3 with voltage and frequency plots are provided.Request for Additional Information Question #1b: Also, explain how the UV (undervoltage) relays provide the same level of UV protection when the loads are fed from onsite emergency diesel generator source.The 480 volt safeguards bus undervoltage (UV) protection contain degraded and loss of voltage relays that are active at all times. Each safeguards bus has its own set of UV protection relays.When being fed from offsite power, actuation of the bus UV system strips all bus loads, except containment spray, MCC C and D and required downstream MCCs, and component cooling water breakers on buses 14 and 16. The normal bus supply breaker from the offsite power source is tripped. A start signal to the respective diesel generator R.E. Ginna Nuclear Power Plant, LLC November 23, 2009 Page I ATTACHMENT 2 Pages from DA-EE-92-111-01, Diesel Generator A Dynamic Loading Analysis R.E. Ginna Nuclear Power Plant, LLC November 23, 2009 CALCULATION COVER SHEET A. INITIATION:

Site [3 CCNPP LI NMP [3 REG Calculation No.: DA-EE-92-1 11-01 Revision No.: 2 Vendor Calculation (Check one): [; Yes [ No Responsible Group: NEE.Responsible:

Engineer:

Bill Roettger B; CALCULATION ENGINEERING DISCIPLINE:.

[ Civil [I lnstr & Controls .. Nuclear U] Electrical E] Mechanical

[3 Other Title: DiEsEL GENERAToR.A DYNAMIC LOADING ANALYSIS Unit; 1 [32 El COMMON Proprietary'or Safeguards Calculation YES [ NO Comments:

PERIODIC REVISION Vendor CalcNo.: REVISION No.'Vendor Name: Safety Class (Check one): [Z SR [3 AUGMENTEDQUALU1Y L NSR There are assump~tions that require:Verification during walkdown:

TRACKING ID: N/A This calculation SUPERSEDES:

OA-EE-92r111-01., REVISION: C. REVIEW AND APPROVAL: Responsible Engineer:

a i ,,&4/,Ps Printed Name and Signature.

Is Design Verification Required?

F] Yes [3 No If yes, Design Verification Form is Li Attached LI Filed with: Date Independent Reviewer: Approval: r' Printed.Namre~ehd Signature VPrinled Name and Signature Date/0 ICi f/D e 7.4.6 Simulation Acceptance Criteria 7.4.6.1 The ETAP computer program was run for each of the cases outlined in section 2.1.The acceptance criteria were in accordance with IEEE-387 which specifies that the diesel generator should be capable of starting, accelerating, and being loaded with the design load within the time required by the equipment specification.

7.4.6.2 Regulatory Guide 1.9 specifies during motor starting the minimum frequency should not be less than 0.95 per unit (57 Hz) and should be restored to within 2% of nominal (58.8 Hz) within 60% of each load sequence interval.

The minimum voltage should not be less than 0.75 per unit and should be restored to within 10% of nominal within 60% of each load sequence interval.

Nominal voltage at Ginna is 480 volts RMS.The regulatory guide indicates that a greater percentage of the time interval may be used if it can be justified by analysis.

However, the load sequence time interval should include sufficient margin to account for the accuracy and repeatability of the load sequence timer.7.4.6.2.1 The above mentioned limits with regards to voltage and frequency will be interpreted as good "rule of thumb" design objectives however slight violations of those specific limits may be considered acceptable if justified by detailed dynamic analysis.

Such analysis must demonstrate that the "intent" of the Regulatory Guide is met; namely all of the required loads do come up to rated voltage and speed within the time required to successfully mitigate an accident.

Similarly, if the detailed dynamic analysis demonstrates that the intent of the Regulatory Guide is not met, even though the voltage and frequency criteria are not violated, the results would be considered unacceptable.

7.4.6.3 NRC Branch Technical Position PSB-I (Reference 3.2.2) indicates that if the load shed feature is retained during sequencing of emergency loads to the bus, the setpoint value in the Technical Specifications for the loss of voltage relay must specify a value having maximum and minimum limits and the basis for those limits must be documented.

Ginna does not bypass the automatic load shedding scheme during the sequencing of the emergency loads. It must therefore be demonstrated that the load shedding scheme will not inadvertently operate during a sequencing event (Reference 4.4.27).7.4.6.3.1 Reference 4.3.7 (Section 11.1.2) indicates that the loss of voltage relays at Ginna have a maximum analytical limit of 381.2 volts (79.42% of 480V). This is the maximum voltage at which the loss of voltage relay is expected to begin timing during an undervoltage condition.

Section 11.3.1 indicates that difference between dropout and pickup on the loss of voltage relays is 1%. The same section indicates that the minimum analytical time delay limit is 2.0 seconds. The voltage profiles on both Bus 14 and 18, during the sequencing event, should be such that the loss of voltage relays will not operate during this event.7.4.6.4 Regulatory Guide 1.9 also indicates that the potential for temporary over-frequency conditions that may be associated with the successful acceleration of a motor load and/or a tripping of the single largest load must not exceed the nominal speed plus 75% of the differences between nominal speed and the overspeed trip setpoint or 115% of nominal whichever is lower. The Ginna diesel engine is equipped with an overspeed trip device that shuts off the fuel supply and requires a manual reset before DA-EE-92-111-01 Page 31 of 6408 Revision 2 the diesel can be restarted (Reference 4.4.27 and Data sheet in Attachment II). The EDG Data sheet indicates that the overspeed trip setpoint is adjustable between 990 and 1035 RPM. Reference 4.1.5 indicates that the acceptance criterion for the overspeed trip setpoint is 1000 to 1050 RPM. Assuming that the trip setpoint could drift down to 990 RPM (66 Hz) then the maximum allowable frequency after successful motor acceleration and/or trip of the single largest motor would be 64.5 Hz.7.4.6.5 Regulatory Guide 1.9 also indicates that the transient following a complete loss of load should not cause the diesel generator speed to reach the overspeed trip setpoint.Again assuming that the trip setpoint could drift down to 990 RPM, the maximum allowable frequency associated with a complete loss of load would be 66 Hz.DA-EE-92-1 11-01 Page 32 of 6408 Revision 2 7.5.1 Case DGA FU1 7.5.1.1 Simulation Description This case quantifies the "A" diesel generator loading sequence during the "Injection phase" for the case where the Containment Spray pump does not come on. The timing sequence will be set up to simulate a LOOP after a LOCA. The purpose of this simulation is to identify a baseline case that will be used as the basis for establishing worst case simulations.

Upon SI all of the safeguard loads would be sequenced onto the buses (offsite power available) and start the EDG. A LOOP after LOCA event would result in all loads being tripped with the exception of the MCC=s. Then after approximately a 1.3 second time delay the EDG breakers would close and the loads would be resequenced on. A key point associated with this simulation is that the EDG has achieved a steady state condition (ie. V= 1.0 pu) prior to the first load being applied. A simultaneous LOOP LOCA simulation would typically have a less severe initial voltage dip since the first loads are applied prior to the EDG settling out to 1.0 per unit. Field results for a simultaneous LOOP LOCA indicate the EDG initially overshoots and is above 1.1 per unit when the EDG breaker is closed (ie MCC load connected).

The simultaneous LOOP LOCA simulation is covered later in this report (case DGAFU6).7.5.1.2 Simulation Timer Settings At time = 0.1 second corresponds to the point in time when the Diesel Generator Breaker closes and is therefore connected to MCC C. The MCC breaker is not tripped by the undervoltage relays (LOOP condition).

The breaker associated with SI 1A closes at time = 0.35 seconds. This 0.25 second delay after the closing of the diesel generator breaker is due to the time delays associated with the resetting of the undervoltage relays and breaker closing and was measured during testing. All of the Agastat timers were assumed to be at their nominal setting. The complete load sequencing for this simulation is as follows: DA-EE-92-111-01 Page 33 of 6408 Revision 2 Action Summary Time (See.) Dedee Týpe Deuce ID Action 0.100 Tie Protective DIeVice .CCIC 22C, Clae (I.35C hIditceon Machine SIIA Motor Accelerate 3.35P hiduc-ion Machine SIIC M1o0: Accelerate S.850 hiduction Machine RHRiA Mwoto Accelerate 13 .850 Induc.ion Machtne SWt IA Motor Accelerate 18.350 bIdu.c.ion Machine CF1.A Motor Accelerate 23.850 Induc.ion Machine CFID Motor Accelerate 28.850 hiducition Machkne AFWIA Motcr Accelerate 30.100 Tie Protective Device MCCC,_Eq1pii;Mtr Open 53.5. SPST Switch ClwoDvnFanN Clote The computer simulation is not an exact representation of the stated scenario because the transients associated with MOV actuation have been included in the simulation even though many of these valves would have already operated to their required state before power was lost and the EDG is sequenced on. Including this effect is not considered overly conservative because the voltage dip associated with the MCC loads is not that significant in either magnitude or duration when compared to the motor loads. In addition, the SI1A may still be spinning at about 45% (See attachment III) of rated speed when it is resequenced.

While this won't change the magnitude of the initial voltage dip, it should shorten the duration of the dip.The SIIA motor may have a small amount of residual voltage left when it is reconnected.

This residual voltage could cause the voltage dip to be slightly better or worse depending on the exact instant of closure. This effect is considered small since the SI 1 A motor has an open circuit time constant of about 1.4 second, ref. 4.4.15, and the "dead time" is expected to approach 1.7 seconds (1.3 second timer delay, .25 second delay indicated above and. 15 second delay for D/G breaker closing and associated relay operation).

Also the motors residual voltage may have been somewhat and/or nearly completely depleted by whatever event resulted in the loss of offsite power condition.

7.5.1.3 Simulation Results The results of this simulation are summarized graphically below. These results were generated by running the ETAP results through the post processing program EZFG.The EZFG program read the DGAFU 1.TS 1 ETAP output file. A complete listing of the ETAP input data and results are also attached.

The horizontal blue and red lines are added as an aid in order to compare the results against various design criteria.The associated design criteria are summarized in the following table: DA-EE-92-111-01 Page 34 of 6408 Revision 2 Table 6, EZFG Horizontal Line Markers Design Criteria Referene Lines (EZFG)EZFG Horizontal Line Value Description Reg Guide 1.9 recovery limit -must recover above this limit within 60% of Frequency Blue Line 58.8 Hz each load sequence interval Frequency Red Line 57 Hz Reg Guide 1.9, Minimum Freg limit (% of 480), Reg Guide 1.9 recovery limit -must recover above this limit within 60%Voltage Blue Line 90% of each load sequence interval (% of 480 V), Max Analytical Drop out limil for LOV relay (min operate time = 2.0 seconds), Reg Guide 1.9 limit for Voltage Red Line 79.42% minimum voltage is 75% of 480 Power Blue Line 1.95 MW Continuous rating of EDG Power Red Line 2.275 MW Maximum output of EDGA 12-13-2007 DGA FU1 Loop 1 min after LOCA. No Cont Spray Volts %Mag (EDGA) Max = 111.49 at time =6.31 Min= 81.76 at time =0,41 125.00 100.00 75.00 0.00 30.00 Time (sec) 60.00 Figure 12, DGAFU1, DG voltage (% 480V) profile DA-EE-92-111-01 Page 35 of 6408 Revision 2 12-13-2007 DGA FU1 Loop 1 min after LOCA. No Cont Spray Volts ZMag (Bus 14)Max = 110-69 at time =6.31 Min = 79.64 at time =0-41 125.00 100.00 75.00 I -~0.00 30-00 Time (see)60.00 0.00 30.00 Time (sod 60.00 Figure 13, DGAFUl Bus 14 voltage (% 480V) profile 12-13-2007 DGAFU1 Loop 1 min after LOCA. No Cont Spray Volts WMag (Bus 18) Max = 111.49 at time =6.31 Min 81.76 at time =0.41 125.00 100.00 t i~ -f-_____75.00 0.00 30.00 Time (sec) 60.00 Figure 14, DGAFUI, Bus 18 voltage (% 480V) profile DA-EE-92-111-01 Page 36 of 6408 Revision 2 12-13-2007 DGAFUl Loop 1 min after LOCA. No Cont Spray Elec (MWI (EDGA GEN) Max = 1.97 at time =28.95 Min = 0.02 at time =0-02 2.00 1.00 0.00 0.00 30.00 Time (sec) 60.00 Figure 15, DGAFUl, DG Power Profile Figure 16, DGAFUI, DG Frequency Profile The above figures demonstrate that there are no Regulatory Guide violations associated with this simulation.

They also demonstrate that the loss of voltage relays will not inadvertently operate and that all of the motors successfully accelerate.

DA-EE-92-111-01 Page 37 of 6408 Revision 2 The results of this simulation can be used to help determine the worst point in time for the Containment Spray to come on. This "worst case time" scenario will then be incorporated into the DGA_FU3 simulation.

The effect of the most recent revisions to this calculation are illustrated in the following three figures which compare the DGAFU 1 results for the 2007 and 1997 ETAP simulations.

The EZFG program reads the 1997 ETAP output file (DGAFU1.OUT, Red Line) and compares it to the 2007 ETAP output file (DGAFU1 .TS1, Blue Line). All of the EZFG target multipliers are set to 1.0 for this comparison.

12-2Z-2007 DGA_FU1 Loop 1 rmin alter LO CA. No Cont Spray Engineer:

Bill Roettgei loop 1 min after Ioca No CSpray pumps Study Case If 900 Target File Extrema >>>Volts ZMag (EDGAI Max = 110.68 at time =2.65 Max = 111-49 at time =6.31 Min = 83.97 at time =14.05 Min = 81.76 at time =0-41 125.00 100.00 75.00 0.O 30.00 Time (see)60.00 Figure 17, DGAFUl, DG voltage (% 480V) profile (1997 Vs 2007)DA-EE-92-111-01 Page 38 of 6408 Revision 2 12-22-2007 DGAFU1 Loop 1 min aften LOCA. No Cont Spiay Engineer:

Bill Roettges loop 1 mrin afte Ioca No CSpoay pumps Study Case I1 900 Target File Exhema >>>Elec (MW) (EDGA GEN)2.00 1.00 el 0.00 Max = 202 at time =29.05 Max = 1-97 at time =28,95 Min = 0.02 at time =0.10 Min = 0.02 at time =0.02 0.00 30.00 Time (sec)60.00 Figure 18, DGAFUl DG power profile (1997 Vs 2007)12-22-2007 DGAFU1 Loop 1 min altet LOCA. No Cont Spway Enginee,:

Bill Roettger loop 1 min altet Ioca No CSpraV pumps Study Case I 900 Target File Extiema >>>Freq (Hz) (EDGA GEN)Max = 60.57 at time =23.15 Max = G0.79 at time =23.07 Min = 58.98 at time =14.75 Min = 59.03 at time =0.67 65.00 60.000 55.00 0.00 30.00 Time (sec)60.00 Figure 19, DGAFUl Frequency Profile (1997 Vs 2007)DA-EE-92-111-01 Page 39 of 6408 Revision 2 The most significant effect of the recent revisions is associated with the first dip of the voltage profile. The additional 5% voltage dip at this point is related to differences in the modeling of the EDG's initial condition, differences in the MCC loads as well as changes to the SI and EDG cable models along with changes to the SI motor model. These effects are more clearly illustrated in the following figure.12-22-2001 DGAFU1 Loop 1 min after LOCA. No Cont Spray Engineer:

Bill Roettgez loop 1 min after loca No CSpcay pumps Study Case # 900 Target File Extiema >>>Volts %Mag (EDGA)Max = 110.68 at time =2-65 Max = 11149 at time =6.31 Min = 86.55 at time =0.45 Min = 81.76 at time =041 125.00 100.00 75-00 0.00 5.00 Time (sec)10.00 Figure 20, DGA FUl, DG voltage (% 480V) profile (1997 Vs 2007) -Zoomed DA-EE-92-111-01 Page 40 of 6408 Revision 2 7.5.2 Case DGA FU2 7.5.2.1 Simulation Description This case is a repeat of DGAFU I with the single exception that the Containment Spray pump comes on with MCC C. This is the most likely time for Spray to come on since the scenario assumes the accident has been in progress for over 1 minute.The Containment Spray breaker will not be tripped by a LOOP condition and therefore the MCC and Spray will come on simultaneously once the EDG breaker closes.7.5.2.2 Simulation Timer Settings At time = 0.1 second corresponds to the point in time when the Diesel Generator Breaker closes and is therefore connected to MCC C and CSPIA. All of the Agastat timers were assumed to be at their nominal setting. The complete load sequencing for this simulation is as follows: Ac (ion Summa [Iv Trne (See.) Dedvie Type De-ice ID 0'.100 lnduvticailMachue c(."?!ANMO-Cr Accelerate

('.100 Tie Pwtecnxe Deiice M1CC:.C -22C ' Clo-e U.50 Induaeiom Mkiue -1A llotor Acceletate 3.850 bidum ce Machine SH1C24tc Accelerate S.850 h d-niom .Machne PRl"IYA Motcr Accekerate 13.850 bid-anio Machiue SDP.A 11 ot, Accelerate 1.850 Indu-tio Machine (C'A Accelerate 23.850 Ind' ica 1Machue (TID N.oce: Accelerate 2S.850 AFWPI.A Moto. Accelerate 30.100 Tie P'oteete De.'ice MC'C: Open 53.350 SPST Sintcbi Clo:e 7.5.2.3 Simulation Results The results of this simulation are summarized graphically below. These results were generated by running the ETAP results through the post processing program EZFG.The EZFG program read the DGAFU2.TSI ETAP output file. A complete listing of the ETAP input data and results are also attached.DA-EE-92-111-01 Page 41 of 6408 Revision 2 12-26-2007 DGA_FU2 Loop 1 min after LOCA. Cont Spray with MCC Volts WMag (EDGA) Max = 113-23 at time =2.99 Min = 74-73 at time =0.35 125.00 100.00 LT. -75.00 0.00 30.00 Time (sec) 60.00 Figure 21, DGAFU2, DG voltage (% 480V) profile 12-26-2007 DGA._FU2 Loop 1 min after LOCA. Cont Spiay with MCC Volts %Mag (Bus 14) Max = 112.56 at time =2.99 Min = 71.78 at time =0.35 125.00 100.00 75.00 0.00 30.00 Time (see) 60.00 Figure 22, DGA-FU2, Bus 14 voltage (% 480V) profile DA-EE-92-1 11-01 Page 42 of 6408 Revision 2 12-26-2007 DGAFU2 Loop 1 min altet LOCA. Cont Spway with MCC Volts ZMag (Bus 18) Max = 11323 at time =2-99 Min = 74.73 at lime =0-35 125.00 100.00 "-p.---75.00 0.00 30.00 Time (sec) 60.00 Figure 23, DGAFu2, Bus 18 voltage (% 480V) profile 12-26-2007 DGAFU2 Loop 1 min altei LOCA. Cont Spway with MCC Elec (MW) (EDGA GEN) Max = 2.18 at time =28.95 Min = 0.02 at time =0.02 2.00__ _ __ _ _ _ _ _1.00 0.000.00 0.00 30-00 Time (sec) 60-00 Figure 24, DGAFU2, DG Power Profile DA-EE-92-1 11-01 Page 43 of 6408 Revision 2 12-26-2007 DGA_FU2 Loop 1 min altei LOCA. Cont Spiay with MCC Fieq [Hz) (EDGA GEN) Max = 60.79 at time =23-11 Min = 58.64 at time =0.61 65.00 60.00 1-V~55.00 0.00 30.00 Time (sec) 60.00 Figure 25, DGA-FU2, DG Frequency Profile Figure 21 demonstrate that there is a slight Regulatory Guide violation (Vmin at EDG terminals

= 74.73% and limit = 75%) however the loss of voltage relays will not inadvertently operate and all of the motors successfully accelerate.

The loss of voltage relays on Bus 14 are picked up for 0.78 seconds (minimum operate time = 2.0 seconds) as is more clearly illustrated in the following figure.12-26-2007 OGAFtJ2 Loop 1 min altei LOCA. Cant Spiay with MCC Volts (Bus 14)Max= 112.56 at time =2.99 Min = 71.78 at time A-35 125.00 100.00 Li) ~.I'I----1---*-~ /1~-KY 75.00 [/0.00 10.00 Time (secl 20.00 0.00 20.00 Figure 26, DGAFU2, Bus 14 Voltage (% 480V) Zoomed DA-EE-92-111-01 Page 44 of 6408 Revision 2 It should be noted that the amount of time "picked up" associated with the LOV relay is calculated by recognizing that the relay can begin timing when the voltage drops to 79.42% of 480V however it may not stop timing until the voltage recovers 1% above this value or 80.2 1% of 480V.Figure 24 indicates a final steady state load on EDGA is 1.94 MW which is consistent with the 1938.62 kW value listed in Table 8 of Reference 4.3.2. The final steady state load for this particular case in the previous revision of this calculation was 2.0 MW.DA-EE-92-111-01 Page 45 of 6408 Revision 2 7.5.3 Case DGA FU3 7.5.3.1 Simulation Description This case is a repeat of DGA FU1 with the Containment Spray pump coming on with SWIA. This was determined to be the worst possible time for this random load to come on since this is when the voltage is at a minimum value at a point in time later on in the sequence.

It can be noted in DGAFU 1 that the voltage is at its absolute minimum at time = 0.41 seconds (SI1A) however the voltage is nearly as low when the service water is sequenced on and more of the capability of the excitation system has been "used up" as the diesel generator is supporting the previously sequenced loads.7.5.3.2 Simulation Timer Settings At time = 0.1 second corresponds to the point in time when the Diesel Generator Breaker closes and is therefore connected to MCC C. All of the Agastat timers were assumed to be at their nominal setting. The complete load sequencing for this simulation is as follows: Action Summai Timae (See.) Dekve T)pe Dewiee ID 0.100 Tie ,MCCIC_22C C o:.e 0.350 Indur2-ion Machiue SI1A Motor Accelerate 3.S50 id'a.cwcoi Machine SIIC Motor Accelerate S.S50 Machine RHRI.A Motou Accelerate 13.S50 bichndm: Machine CSP',A Moor Accelei:ute 13.S50 hid:.-:ion Machine SW?,10 I A Motoi Accelerate 18.$50 Ind=c:ion Machine CFriA Motor Accelerate 23.S50 hid'-tcion Machine CFiD M.oor Accelerate 28.850 Ind-,-lionu Machbine AFWP1A Motor Accerate 30.100 Tie ?wtective MCCCEq1UiMtr Open 53.350 SPST Siritch ff, C ]o:.e, 7.5.3.3 Simulation Results The results of this simulation are summarized graphically below. These results were generated by running the ETAP results through the post processing program EZFG.The EZFG program read the DGAFU3.TS 1 ETAP output file. A complete listing of the ETAP input data and results are also attached.DA-EE-92-1 11-01 Page 46 of 6408 Revision 2 12-26-2007 DGAFU3 Loop 1 min after LOCA. Cont Spray with SW Volts ZMag (EDGA) Max 111.49 at time =6.31 Min 74.55 at time =14-13 125.00 100.00 1-- -75.00 0.00 30.00 Time (sec) 60.00 Figure 27, DGAFU3, DG Voltage (% 480V) profile 12-26-2007 DGA_FU3 Loop 1 min after LOCA, Cont Spway with SW Volts %Mag (Bus 14) Max 110.69 at time =6.31 Min= 72-38 at time =14.15 125.00 100.00 75.00 0.00 30.00 Time Isece GO.00 Figure 28, DGAFU3, Bus 14 voltage (% 480V)profile DA-EE-92-111-01 Page 47 of 6408 Revision 2 12-26-2001 DGAFU3 Loop 1 min alter LOCA. Cont Spway with SW Volts ZMag (Bus 181 Max = 111.49 at time =6.31 Min = 73.59 at time =14-13 125.00 100.00 0. .... .-75.00 0.00 30.00 Time (sec) 60.00 Figure 29, DGAFU3, Bus 18 voltage (% 480v) profile 12-26-2007 DGA_FU3 Loop 1 min after LOCA. Cont Spray with SW Elec (MW) (EDGA GEN) Max = 2,18 at time =28.95 Min = 0-02 at time =0.02 2.00 __ __1.00 0.00 0.00 30.00 Time (sec) 60.00 Figure 30, DGAFU3, DG Power Profile DA-EE-92-111-01 Page 48 of 6408 Revision 2 12-26-2007 DGAFU3 Loop 1 min alter LOCA. Cont Spray with SW Freq (Hz) (EDGA GEN) Max = 60.80 at time =23-09 Min= 58.88 at time =14-39 65.00 60-00 -55.00 0.00 30.00 Time (see) 60.00 Figure 31, DGAFU3, DG Frequency Profile Figure 27 demonstrate that there is a slight Regulatory Guide violation (Vmin at EDG terminals

= 74.55% and limit = 75%) however the loss of voltage relays will not inadvertently operate and all of the motors successfully accelerate.

The loss of voltage relays on Bus 14 are picked up for 0.88 seconds (minimum operate time = 2.0 seconds) as is more clearly illustrated in the following figure.12-26-2007 DGA_FU3 Loop 1 min after LOCA. Cont Spray with SW Volts %Mag (Bus 14) Max= 110.69 at time =6.31 Min 72-38 at time =1415 125-00 100.00 10-" 75.00 0.00 10.00 Time (see) 20.00 Figure 32, DGAFU3, Bus 14 voltage (% 480V) profile, Zoomed DA-EE-92-111-01 Page 49 of 6408 Revision 2 ATTACHMENT 3 Pages from DA-EE-92-112-01, Diesel Generator B Dynamic Loading Analysis R.E. Ginna Nuclear Power Plant, LLC November 23, 2009 Design Analysis Diesel Generator B Dynamic Loading Analysis Rochester Gas & Electric Corporation 89 EAst Avenue Rohehter, New York 14649 DA-EE-92-112-1 Revision I Effective Date aj 'S, )ýý, Prepared By: Reviewed By:/sign Engineer Date bate/"-Reviewer 7.4.4.4 The fbllowing load profile resulted In a reasonable match of the EDO response and corresponded with the expected MCC loading during the RSSP.TABLE 7410 MCC Lading Valuta Utilized In ETAp Modul To Match IMAP.2.2 Test Rults Loading When EDO Brekae Closes 200 375 (T1- 0.0 Sewonds to T-0.25 Seaom)Centnus Loadi Followin StW 100 25 (Tinis .25 Seoodu).iii 7.4.5 Cable Impedance 7.4.5.1 The cable lengths and type were obtained from circuit schedules while the cable impedances are based on the ETAP library values. These values were reviewed and found to be reasonable.

7.4.6 Simulation Acceptance Criteria 7.4.6.1 The ETAP computer program was run for each of the cases outlined in section 2.1.The acceptance criteria was in accordance with IEEE-387 which specifies the diesel generator must be able to start and accelerate the required loads.7.4.6.2 Regulatory Guide 1.9 specifies during motor starting the minimum frequency should not be less than 0.95 per unit (57 Hz) and should be restored to within 2% of nominal (58.8 Hz) within 60% of each load sequence interval.

The minimum voltage should not be less than 0.75 per unit and should be restored to within 10% of nominal within 60% of each load sequence interval.DA-BE-92-112-01 Page 21 of 34 ReVision 1 7 .5.1 ase 0911L=7.5.1.1 SimultIon Description This cas quantifies the "B9 diesel generator loading sequence during the "Injection phase' fbr the case where the Containment Spray pump does not come on. The timing sequence will be set up to simulate a LOOP after a LOCA. The purpose ofthls simulation Is to ldentif, a baseline case that will be used as the basis fbr establishing wors case simulations.

Upon Sl all ofthe sufbguard loads would be sequenced onto the bum (offsite power available) and start the EDO, A LOOP after LOCA event would result in all loads being tripped with the exception of the MCC's. Then after approximately a 1.3 seoond time delay the EDO breakers would close and the loads would be resequenced on. A key point associated with this simulation is that the EDO has achieved a steady state condition (ie. V- 1.0 pu) prior to the first load being applied. A simultaneous LOOP LOCA simulation would typically have a less severe initial voltage dip since the first loads are applied prior to the EDO stling out to 1.0 per unit, Field results for a simultaneous LOOP LOCA indicate the EDO Initially overshoots and is above 1. 1 per unit when the EDO breaker is closed (ie MCC load connected).

The simultaneous LOOP LOCA simulation is covered later in this report (case DOBFU6).7.5.1.2 Simulation Timer Setttlp At time -0.1 second corresponds to the point In time when the Diesel Generator Breaker closes and is therefore connected to MCC D. The MCC breaker is not tripped by the under voltage relays (LOOP condition).

The breaker associated with SI 1B closes at time = 0.35 seconds. This 0.25 second delay after the closing of the diesel generator breaker is due to the time delays associated with the resetting of the under voltage relays and breaker closing and was measured during testing. All of the agastat timers were assumed to be at their nominal setting. The complete load sequencing for this simulation is as follows: 0,100 Diesel Generator (both Bus 16 and 17)0.350 SI 1B 5.850 Sl IC 10.850 RHR 1B 15.850 SW ID 20.850 CF lB 25.850 CF IC 30.850 AFWP IB DA-ZE-92-112-01 Page 22 of 34 RevisionI The computer simulation is not an exact representation of the stated scenario because the transients and effects associated with the loads being first sequenced on to the offste source have been ignored. Ignoring these transients is conservative because many of the valves would have operated to their required state and therefore the MCC load would be less than what was modeled. Ignoring this effect is not considered overly conservative because the voltage dip associated with the MCC loads Is not that significant in either magnitude or duration when compared to the motor loads. In addition, the SIIB may still be spinning at about 45% (See attachment A) of rated speed when it is resequenced.

While this wont change the magnitude of the Initial voltage dip, it should shorten the duration of the dip.The StIB motor may have a small amount of residual voltage left when it is reconnected.

This residual voltage could cause the voltage dip to be slightly better ,r worse depending on the exact instant of closure. This effect is considered small since the St1IB motor has an open circuit time constant of about 1.4 second, ref 4.4.15, and the "dead time" is expected to approach 1.7 seconds (1.3 second timer delay, .25 second delay indicated above and .15 second delay for DIO breaker dosing and associated relay operation).

7.5.1.3 Simulation Results The complete set of input data for this simulation is contained in Attachment JI along with the initial (time ) load flow solution.

The dynamics of the system as it goes from the initial load flow solution to the final load flow solution is summarized in Figures I -3 of Attachment J 1. The minimum voltage was 81.12% and the minimum frequency was 58.80 Hz, Both of these are well above the 75% and 57 Hz criteria.Figure 2 is a plot of the generator power (internal losses Included) as a function of time. The peak power capability (2.3 MW) of the engine is above the peak value (2.06 MW) obtained in this simulation.

It is evident from each of the figures that all motors successfully accelerate.

The results of this simulation can be used to help determine the worst point in time for the Containment Spray to come on. This "worst case time" scenario will then be incorporated into the DGBFU3 simulation.

DA-ZE-92 -112-01 Page 23 of 34 itevision I

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A.ZI.21 3 '14 :.i, 6 11 4 7.5.2 Cs WgauD 2 e -TT,(+C H M4 AIT J 2- c V Ct S 7.5.2.1 SImulation Description This case is a repeat of DOB-FUI with the uingle exception that the Containment Spray pump omes on with MCC D. This is the most likely time for Spray to ome on since the senurio mes the accident has beon In progress tbr over I minute. The Containment Spray breaker will not be tripped by a LOOP condition and therefbre the MCC and Spray will come on simultaneously once the EDO breaker doses.7.5.2.2 Siumlation Timer Settingp AmW BuM 0.100 Diesel Generator and Containment Spray 0.350 S lIB 5.850 SI IC 10.850 RI III 15.850 SW ID 20.850 CF 1B 25.850 CF IC 30.850 AFVP IB 7.5.2.3 Simubtadn Results The complete set of input data for this simulation is contained in Attachment J2 along with the initial (time- 0 .) load flow solution.

The dynamics of the system as it goes forom the initial load flow solution to the final load flow solution is summarized in Figures I -3 of Attachment J2. The minimum voltage was 76.2% and the minimum f"equency was 58.75 Hz. Both of these are above the 75% and 57 Hz criteria.

Figure 2 is a plot of the generator power (internal losses included) as a function of time. The peak power capability (2.3 MW) of the engine is above the peak value (2.25 MW)obtained in this simulation.

The final steady state load out of the EDO for this simulation is about 2.0 MW which is in close agreement with the steady state analysis (Reference 4.3.2). It is evident from each of the above figures that all motors successfilly accelerate.

DA-3-952-112-01 Page 24 of 34 Revision I Enginwec Bill Roettge Sld Cs t 901 a-m.-Loop I mn ghe loca. cONT SPRAY ON WITH c i ft 12 .0 -- ---- -------- OII JI If -- -- i -- -- i -- -- -- -- 0 OOIO.L al -w-1 -J -.. .L -- -J HI Z-, C4 I I $II S- -.-a a a a a --.... ...... -a ----- -IL ----- -------- ---I I I I I I l I I l a aI I I t I I o I. I I I II I I I S I 750 I I I I a NJIIl ' t' U It IU ' I....blI i .. II4i I I S I S I l IIS.II ...9 OJ ...Ii ..l I I I l I I I ..I I I 3 3 I I I I 0.00 20.00 Tim (see) 40.00 aa I-.Enginee. Bi Roetiger Cue £ 01 Loop I win afte koca. cONT SPRAY ON WITH wce 0 c a S~*~cl 4 C4 Fireq (Hz) (dglb I Maw = 6.72 at ime -275 Min 5IL75 a die =1.25-- ---- ----- ----------f a a--a-a-a-

-- --a*"I ' I " " " ---L-I I ._- -------I. -, ..... -----r ------------r -- --¶-4----- ----L ------I. I I I I nn I--I aI 4 a 4 a I 4 IIl 4 a I a I I I -U I I I I ,I I I I " aa-a --- -------raaa- -T ----a~ aa a -,---a a Ia I I I I U U I I I I I I I I I I I n I -I- -aa' ......I a a a a a a a S9 I I IIO I I I Iti glm, I 4 iI UlI I Al II 1 2D.W It IlI&0 0.00 Tm. (nel 7.5.3 Mu.RUN..EU3-See 1 4 TT6ACII14MA'-j 13 C- UJA/EC-7.5.3.1 Simulation Ducription This case is a repeat ofDOBJU! with the Containment Spray pump coming on with SIIC. This was determined to be the worst possible time for this random load to come on since this is when the voltage is at a minimum (See Figure I of Attachment 7.5.3.2 Simulation Timer Settlapi ,.j I -?c.,e_ t 0.100 0.350 5.850 10.850 15.850 20.850 25.850 30.850 Diesel Generator (both Bus 16 and 17)S[ IB St IC and Containment Spray RHRIB SW ID CF IB CF IC AFWP IB 7.5.3.3 Simulation Results The complete set of input data for this simulation is contained in Attachment J3 along with the initial (time ) load flow solution.

The dynamics of the system as it goes from the initial load flow solution to the final load flow solution is summarized in Figures 1 -3 of Attachment J3.The minimum voltage was 72.52% and the minimum frequency was 58.61 Hz. The slight violation of the 75% voltage criteria is considered acceptable since the voltage recovers above 90% within 1. 1 second. Figure 2 is a plot of the generator power (internal losses included) as a function of time. The peak power capability (2.3 MW)of the engine is above the peak value (2.25 MW) obtained in this simulation.

The final steady state load out of the EDG for this simulation is about 2.0 MW which is in close agreement with the steady state analysis (Reference 4.3.2). It is evident from each of the above figures that all motors successfully accelerate.

DA-3B-92-112-01 Page 2S of 34 ReViSion I 0e..En~nw.e BEl Roelge Sbudy cms t Ni tn Loop I min aftm ba C nt Spray with ale VoalMag.(Bus16 3 Max= 115.Mt a -1i=5 ft 72-52 att =&5 aI I 1 I I I I I II I I I I I I I II" ----- " .125.00- ------- I --- -4 0 I , I I , i I I I*- -- -- -- -- ---------------

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