ML093500094
| ML093500094 | |
| 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 | |
| Download: ML093500094 (40) | |
Text
John Carlin Site Vice President CENG a joint venture of 0
Constmellation Energyef R.E. Ginna Nuclear Power Plant, LLC 1503 Lake Road Ontario, New York 14519-9364 585.771.5200 585.771.3943 Fax iohn.carlintcenqlic.com 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
REFERENCES:
(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 (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. ME0291)
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)).
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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
- ours, STATE OF NEW YORK TO WIT:
COUNTY OF WAYNE I, 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 Ginna LLC employees and/or consultants. Such info 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 or the State of New York and County of car] £
,this _
day of /0.Og.*LfL,(
2009.
WITNESS my Hand and Notarial Seal:
/jiT)(L/&O7
Notary Public,,6
SHARON L. WILLER Notary Public, State 61 New York My Commission Expires:
Registration No. 01 M166017755 Monroe County, ýf Commission Expires Decombe,,21 20-/"
Dat
.e "1, : Response to Request for Additional Information Regarding Revisions to Loss-of-Power Diesel Generator Start Instrumentation Limiting Safety Sy'stem Settings and Diesel Generator Load Test Value : Pages from DA-EE-92-1 11-01, Diesel Generator A Dynamic Loading Analysis : 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 Diesel Generator Load Test Value R.E. Ginna Nuclear Power Plant, LLC November 23, 2009 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 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 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 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 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 is initiated with subsequent closing of the diesel generator supply breaker(s) to the bus(es) that experienced the UV. Component cooling water pumps are tripped if a safety injection signal is present and safeguards loads are sequenced on.
When being fed from the onsite diesel generators, actuation of the bus UV system strips all bus loads, except containment spray, MCC C and D and required downstream MCCs and component cooing water breakers on buses 14 and 16. The diesel generator supply breakers to its respective safeguards buses are not tripped. If a safety injection signal is present then safeguards loads will be re-sequenced onto their respective bus once voltage recovers above the UV relay reset values, component cooling water pumps will not be in-service. If a safety injection signal is not present then loads are started upon bus voltage recovery, as required.
R.E. Ginna Nuclear Power Plant, LLC November 23, 2009 Page 2
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 Li CCNPP Li NMP
]
REG Calculation No::
DA-EE-92-1 11-01 Revision No.:
2 VendoirCalculation (Check one):
0i Yes Z
No Responsible Group:
NEE.
Responsible Engineer:
Bill Roettger
- 8. CALCULATION ENGINEERINGDISCIPL.INE:.
EL Civil Li 1nstr &Controls Li. Nuclear 0
Electrical Li Mechanical Li Other Title.
DIESEL GENERATOQR A DYNAMIC LADiNG ANALYSIS Unit:
r1,2 Li COMmON Proprietary or Safeguards Calculation Li YEs NO Comments:
PERIODIC REVISION Vendor Calc No.:
REVISION No,'
Vendor Name:
Safety Claiss (Check one):
f" SR L. AUGMENTEo'QuALI*Ty L NSR There are assumptions that require Verification during walkdown:
TRACKING ID:
N/A This calculation SUPERSEDES:
DA-EE-92-11 1-01 REVISION..1 C.. REVIEW AND APPROVAL:
Responsible Engineer:
~
7t;E Printed Name and Signature Is Design Verification Required?
Lir Yes L 'No If yes, Design Verification Form is E] Attached LI Filed with:
Date Independent Reviewer:
Approval:
Printed Name_-,nd Signature
-frinled Name and Signature
" 0Date De "
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-1 (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-92-111-01 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 SI1A 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 Summar-v Tine (See.)
Deiice Type Deilce ID Action 0.100 Tie Protective DeVice MCCIC_22C Clwte 0.350 Induc.uon Machine SI1A Motor Accelerate 3.850 Inducton Machine SIIC Motor Accelerate 8.850 Induction Machine RHRIA h'lotor Accelerate 13.850 Induction Machine S\\T I A Motor Accelerate 1.850 Induction Machine CFA Motor Accelerate 2"3.850 Induc.-ion Machine CFID Motor Accelerate 28.850 Indutcion Machine AFWT1IA Mo.or Accelerate 30.100 Tie Protective Device MCCCEqnivuMtr Open J3350 SPST Switdhi sw_DynFanN.
Close 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 1A 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 Freq 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 limit 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.O00 75.00 0.00 30.00 Time (sec) 60.00 Figure 12,
- DGAFUl, DG voltage (% 480V) profile DA-EE-92-111-01 Page 35 of 6408 Revision 2
12-13-2007 DGAFU1 Loop 1 min after LOCA. No Cont Spray Volts WMag (Bus 14)
Max = 110.69 at time =6.31 Min = 79.64 at time =0.41 125.00 100.00 75.00 0.00 30.00 Time (sec) 60.00 Figure 13, DGAFUl Bus 14 voltage (% 480V) profile 12-13-2007 DGAFU1 Loop 1 min after LOCA. No Cont Spray Volts ZMag (Bus 18)
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 14,
- DGAFUl, Bus 18 voltage (% 480V) profile DA-EE-92-111-01 Page 36 of 6408 Revision 2
12-13-2007 DGA_FUl Loop 1 min aitef LOCA. No Cont Spray Elec (MW) (EDGA GEN)
Max = 1.97 at time =20.95 Min = 0.02 at time =0.02 2.00 1.00 0.00 0.00 30-00 Time (sec) 60.00 Figure 15,
- DGAFUI, DG Power Profile 12-13-2007 DGAFUl Loop 1 min after LOCA. No Cont Spray Freq (Hz) (EDGA GEN)
Max = 60.79 at time =23.07 Min = 59.03 at time =0.67 65.00 60.00 55.00 0.00 30.00 Time (sec) 60.00 Figure 16,
- DGAFUl, 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 (DGAFU 1.TS I, Blue Line). All of the EZFG target multipliers are set to 1.0 for this comparison.
12-22-2007 DGAFU1 Loop 1 min after L0CA. No Cont Spray Engineer: Bill Roettger loop 1 min after loca No CSpiay pumps Study Case I# 900 Target File E xtrema >>>
Volts ZMag (EDGA)
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 0.00 30.00 Time (sece 60.00 Figure 17,
- DGAFUI, DG voltage 2007)
(% 480V) profile (1997 Vs DA-EE-92-111-01 Page 38 of 6408 Revision 2
12-22-2007 DGA_FUI Loop 1 min after LOCA. No Cont Spray Engineer: Bill Roettger loop 1 min after loca No CSpray pumps Study Case # 900 Target File Extiema >>>
Elec (MW) (EDGA GEN)
Max = 2.02 at time =29.85 Max = 1.97 at time =28.95 Min = 0.02 at time =0.10 Min = 0.02 at time =0.02 2.00 1.00 0.00 0.00 30.00 Time (sec) 60.00 Figure 18, DGA FUl DG power profile (1997 Vs 2007) 1 2-22-20ZI DGA FU1 Loop 1 min after LOCA. No Cont Spray Engineer: Bill Roettger loop 1 min after loca No CSpray pumps Study Case # 900 Target File Extrema >>>
FFeq (Hz) (EDGA GEN)
Max = 60.57 at time =23.15 Max = 60.79 at time =23.07 Min = 58.98 at time =1 4.75 Min = 59.03 at time =0.67 65.00 60.00 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.
12-22-2007 DGAFU1 Loop 1 min after LOCA. No Cont Spray Engineer: Bill Roettget loop 1 min after loca No CSpray pumps Study Case #I 900 Target File Extrema >>>
Volts %Mag (EDGAI Max = 110.68 at time =2.65 Max = 111.49 at time =6.31 Min = 86.55 at time =0.45 Min = 01.76 at time =0.41 125.00 100.00 f I
75.00 0.00 5.00 Time (secl 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 DGAFUl 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 CSP1A. All of the Agastat timers were assumed to be at their nominal setting. The complete load sequencing for this simulation is as follows:
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.TS 1 ETAP output file. A complete listing of the ETAP input data and results are also attached.
DA-EE-92-11t1-01 Page 41 of 6408 Revision 2
12-26-2007 DGAFU2 Loop 1 min after LOCA. Cont Spray with MCC Volts ZMag (EDGA]
Max = 113.23 at time =2.99 Min = 74.73 at time =0.35 125.00 100.00 75.00 0.00 30-00 Time (sec) 60.00 Figure 21, DGAFU2, DG voltage (% 480V) profile 12-26-2007 DGAFU2 Loop 1 min after LOCA. Cont Spray 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 (sec) 60.00 Figure 22, DGA-FU2, Bus 14 voltage (% 480V) profile DA-EE-92-111-01 Page 42 of 6408 Revision 2
12-26-2007 DGA_FU2 Loop min altel LOCA. Cont Spway with MCC Volts %Mag (Bus 18)
Max = 113.23 at time =2.99 Min = 74.73 at time =0.35 125.00 100.00 75.00 0.00 30.00 Time (sec) 60.00 Figure 23, DGA Fu2, Bus 18 voltage (% 480V) profile 12-26-2007 DGAFU2 Loop 1 min after LOCA. Cont Spray with MCC Elec (MW) (EDGA GEN)
Max = 2.18 at time =28.95 Min = 0.02 at time =0.02 2.00 1.00 0.00 0.00 30.00 Time (sec) 60.00 Figure 24,
- DGAFU2, DG Power Profile DA-EE-92-111-01 Page 43 of 6408 Revision 2
12-26-2007 DGA_FU2 Loop 1 min after LOCA. Cont Spway with MCC Freq (Hz) (EDGA GEN)
Max = 60.79 at time =23.11 Min = 58.64 at time =0.61 65.00 W000 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 DGAFU2 Loop 1 min afte LOCA. Cont Spray with MCC Volts WMag (Bus 14)
Max = 112.56 at time =2.99 Min = 71.78 at time =0.35 125.00 1o0000 75.00 0.00 10.00 Time (see) 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-92-1 11-01 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 SWLA. 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 I that the voltage is at its absolute minimum at time = 0.41 seconds (SIIA) 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 Summary Time (See.)
Device Type Deiuce ID 0.100 Tie Protective Device MCCI C22C C]o;e 0.350 Inducton Machine SI 1A Motor Accelerate 3.850 Ind'tiion Machite SI1C Motor Accelerate 8.850 Indtimon Mlachiue RHRI A Motor Accelerate 13.850 Inducfon tMchine CSPIA Motor Accelerate 13.850 Indintion Machine SI"PI A Motor Accelerate 18.850 Induction Machine CF A Motor Accelerate 23.850 Induction Machine CF i D Momor Accelerate 28.850 Indixtion Machine AFW'P1A Motor Accelerate 30.100 Tie Protective Device MCCC EquivM"r Open
- 53. 350 SPST Switch SwDvnFanN C]oe 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 DGA FU3 Loop-1 min alter LOCA. Cont Spray with SW Volts XMag (EDGA)
Max = 111.49 at time =6.31 Min = 74.55 at time =14-13 125.00 100.00 0"_
75.00 0.00 30.00 Time (secl 60.00 Figure 27,
- DGAFU3, DG Voltage (% 480V) profile 12-2G-2007 DGA_FU3 Loop 1 min alter LOCA. Cont Spray 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 Isecl 60.00 0-00 30-00 Time (sec) 60.00 Figure 28, DGA FU3, Bus 14 voltage (% 480V) profile DA-EE-92-111-01 Page 47 of 6408 Revision 2
12-26-2007 DGAFU3 Loop 1 min alter LOCA,. Cont Spray with SW Volts %Mag (Bus 18)
Max = 111.49 at time =6.31 Min = 73.59 at time =14.13 125.00 100.00 75.00 0.00 30.00 Time (sec) 60.00 Figure 29,
- DGAFU3, Bus 18 voltage (% 480v) profile 12-26-2007 DGAFU3 Loop 1 min aftei LOCA. Cont Spray with SW Elec (MWJ (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, DGA FU3, DG Power Profile DA-EE-92-111-01 Page 48 of 6408 Revision 2
12-26-2007 DGAFU3 Loop 1 min after LOCA. Cont Spray with SW FReq (Hz) (EDGA GEN)
Max = 60.80 at time =23-09 Min = 58.08 at time =14.39 65.00 60.00 55.00 0.00 30.00 Time (sec) 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 DGAFU3 Loop 1 min after LOCA. Cont Spiay with SW Volts WMag (Bus 14)
Max = 110.69 at time =6.31 Min = 72.38 at time =14.15 125.00 100.00 75.00 0.00 10.00 Time (sec) 20.00 Figure 32,
- DGAFU3, Bus 14 voltage (% 480V) profile, Zoomed DA-EE-92-111-01 Page 49 of 6408 Revision 2
The minimum voltage on Bus 14 is slightly greater than shown in case DGAFU2, mostly because the containment spray and service water pumps are on different buses. The duration for voltage recovery is a little longer as compared to DGAFU2, mostly because MOVs are not part of the voltage dip for DGAFU3.
DA-EE-92-111-01 Page 50 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
Duelg Analysis Diesel Generator B Dynamic Loading Analysis Rochester Gas & Electric Corpoation 89 East Avenue Rochester, New York 14649 DA-Ei*92-112-01 Revisionl I Effective Date prepared By:
lgn Enzineer Date 11ý 2
.07 Reviewed By:
7.4.4.4 The following load profile resulted in a reasonable match of the EDO response and corresponded with the expected MCC loading during the RSSP.
TABLE 7-10 AdCC LoAsding Values Utilized In ETAP To Mateh RI
-P.2.2 Test Rsults Loading When EDO Breaker Claose (T - 0.0 Seconds to T-0.25 Saeods) 200 375 Condnuous Loa*dn Followin Start 100 25 (Tlime >.25 Scow&n)--
7.4.5 Cable Impedance 7.4.5.1 The cable lengths and type were obtained f'rom 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-ZE-92-112-02 ae2 f34Rvuo Page 21 of 34 ReVi~sion I
7.5.1.1 Simulation Description This cue quantifies the "B" 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 ldentif a baseline case that will be used as the basis for establishing worst case simulations.
Upon S1 all of the safbegu loads would be sequenced onto the buses (offiite 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 EDO breakers would dose 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 settling 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 (io MCC load connected). The simultaneous LOOP LOCA simulation is covered later in this report (case DOB FU6).
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 D. The MCC breaker is not tripped by the under voltage relays (LOOP condition). The breaker associated with S11B 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 coing 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:
Time(e1w BNMake.Close 0.100 Diesel Generator (both Bus 16 and 17) 0.350 SI IB 5.850 SI IC 10.850 RIHR IB 15.850 SW ID 20.850 CF IB 25.850 CF 1C 30.850 AFWP IB DA-N3-92-11a-02 Page 22 of 34 Revision I
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 offtIte 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 bemause the voltage dip ssoiated 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 won't change the magnitude of the initial voltage dip, it should shorten the duration of the dip.
The S1IB 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 SlIB 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.1 second delay for D/G breaker closing and associated relay operation).
7.5.1.3 Simulation Results The complete set of input data for this simulation is contained in Attachment J1 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 JI. 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 fuanction 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-BE-92 -112-01 Page 23 of 34 Revision I
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7.5.2.1 Simulation Description This cae is a repeat of DOBJUI with the single exception that the Containment Spray pump comes on with MCC D. This Is the most likely time for Spray to come on since the scenario suesthe accident has been In progress for over I minute. The Contalnmnt Spray breaker will not be tripped by a LOOP condition and therefore the MCC and Spray will come on simultaneously once the EDO breaker closes.
7.5.2.2 SImulation Timer Settings
'Afe nBt.8kWaChn 0.100 Diesel Generator and Containment Spray 0.350 SI IB 5.850 SI IC 10.850 RHR IB 15.850 SW ID 20.850 CF IB 25.850 CF IC 30.850 AFWP IB 7.5.2.3 Simulation 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 from 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 firequency 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 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-B3-92-112-O1 Paqe 24 of 34 Revision I
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Sl 1B SI IC and Containment Spray IUR IB SW ID CF IB CF lC AFWP IB 7.5,3.3 Simulation Results The complete set of input data for this simulation is contained in Attachment D3 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 J3.
The minimum voltage was 72.52% and the minimum frequency was 53.61 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-92-212-01 Page 2S of 34 Revision I.
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