ML19209B769
| ML19209B769 | |
| Person / Time | |
|---|---|
| Site: | Calvert Cliffs  |
| Issue date: | 10/08/1979 |
| From: | Lundvall A BALTIMORE GAS & ELECTRIC CO. |
| To: | Eisenhut D Office of Nuclear Reactor Regulation |
| References | |
| NUDOCS 7910100425 | |
| Download: ML19209B769 (40) | |
Text
cT BALTIMORE GAS AN D ELECTRIC COMPANY GAS AN D ELECTRIC OUILDING BALTIMORE, MARYLAN D 21203 ARTHUR s. LUNOVALL,JR. October 8, 1979 m...,.o.,
s e ..o Division of Operating Reactors Office of Nuclear Reactor Regulation U. S. Nuclear Regulatory Cor=tission Washington, D. C. 20555 Attn: Mr. Darrell G. Eisenhut Acting Director Sub.j ect : Calvert Cliffs Nuclear Power Plant Units Nos. 1 and 2 Adequacy of Station Electric Distribution Systems Voltares Gentlemen:
In your letter of August 8, 1979, you requested information on adequacy of station electric distribution system- voltages. The resnonses to your questions are provided in the attachment and apply to Units 1 and 2.
Very truly urs,
>> n & JJ Q
Enclosure ec: J. A. Biddison, Esquire G. F. Trowbridge, Esquire Mr. E. L. Conner, Jr. - ISC Mr. P. W. Kruse - CE 6
h 1139 '71 7910100 W
ATTAC10 TENT Rcsponse to NRC Regarding Adeuacy of Station Electric Distribution System Voltages The offsite and the onsite distribution system was reviewed per your request.
The voltage distribution of the onsite distribution system was calculated by use of the General Electric "N Bus Load Flow" program.
This was supplemented by additionel calculations in order to analytically determine voltage conditons down to the terminals of each safety relsted load. The following plant operating conditions were evaluated:
1.) Full Auxiliary Plant load 2.) Full Auxiliary Plant load with one (1) Reactor Coolant Pump (RCP) start 3.) Full Auxiliary Plant load with one (1) Circulating Water Pump (CWP) start 4.) Full Auxiliary Plant load with one (1) Condensate Booster Pump (CBP) start 5.) Full Auxiliary Plant load with Engineered Safety Features (ESF) start 6.) Full Auxiliary Plant load with Engineered Safety Features running 7.), Shutdown load The switchyard minimum voltage of 97% being the worst case for under voltage conditions was used for cases 1 through 6. Case 7 was evaluated for the maximum as well as the minimum switchyard voltages.
The " Guidelines for Voltage Drop Calculations" were applied during the reviews for Units 1 and 2 as indicated below.
- 1. Separate analyses should be performed assuming the power source to safety buses is (a) the unit auxiliary transformer; (b) the startup transformer; and (c) other available connections to the offsite network one by one assuming the need for electric power is initiated by (1) an anticipated transient (e.g., unit trip) or (2) an accident, whichever presents the largest load demand situation.
Item (a) is not applicable since there is no unit auxiliary transfo rmer. Grid connected 500 kV/14 kV station service transforme-s provide power for all plant loads including safety related buses. The largest load demand situation was plant auxiliaries at full load during Engineered Safety Features (ESF) actuation.
2.
For multi-unit stations a separate analysis should be performed for each unit assuming (1) an accident in the unit being analyzed and simultaneous shutdown of all other units at that station; or (2) an anticipated transient in the unit being anaylzed(e.g. ,
unit trip) and simultaneous shutdown of all other units at that station, whichever presents the largest load denand situation.
These were guidelines for the calculations.
jj}g ',7,
- 3. All actions the electric power system is designed to automatically initiate should be assumed to occur as designed (e.g., automatic bulk or sequential loading or automatic transfers of bulk loads from one transformer to another). Included should be consideration of starting of large non-safety loads (e.g., condensate pumps).
Automatic bulk loading of offsite transmission lines with ESF loads was evaluated. There are no automatic transfers of loads from one transformer to another. Consideration was given to starting large non-safety related loads.
See individual cases.
- 4. Manual load shedding should not be assumed.
Manual load shedding was not considered.
- 5. For each event analyzed, the maximum load necessitated by the event and the mode of operation of the plant at the time of the event should be assumed in addition to all loads caused by expected automatic actions and manual actions permitted by administrative procedures.
The full auxiliary plant load was derived from actual full load measurements and was utilized in all of the cases with the exception of case 7.
- 6. The voltage at the terminals of each safety load should be cal-culated based on the above listed considerations and assumptions and based on the assu=ption that the grid voltage is at the
" minimum expected value". The "minimur expected value" should be selected based on the least of the following:
- a. The minimum steady-state voltage experienced at the connection to the offsite circuit.
- b. The minimum voltage expected at the connection to the offsite circuit due to contingency plans which may result in reduced voltage from this grid.
- c. The minimum predicted grid voltage from grid stability analysis, (e.g., load flow studies).
The minimum predicted voltage at the connection to the offsite circuit is 485 kV (97%) during normal operation.
All design studies such as load flows use this value as a basis. To prevent the voltage from dropping below this point, system operators change taps on the Waugh Chapel Transformers located at the other end of the offsite transmission line.
- 7. The voltage analysis should include documentation for each condition analyzed, of the voltage at the input and output of each transformer 1139 '73
and at each intermediate bus between the connection to the offsite circuit and the terminals of each safety load.
Voltage analysis of the onsite distribution system evaluated the voltage at each subsequent level of transformation down to the terminals of the safety-related load.
- 8. The analysis should document the voltage setpoint and any inherent or adjustable (with nominal setting) time delay for relays which (1) initiate or execute automatic transfer of loads from one source to another; (2) initiate or execute automatic load shedding; or (3) initiate or execute automatic load sequencing.
See response to Item 12
- 10. For each case evaluated the calculated voltages on each safety bus should be compared with the voltage-time settings for the under-voltage relays on these safety buses. Any identified inadequacies in undervoltage relay settings require immediate remedial action and notification of NRC.
See response to Item 12
- 12. Voltage-time settings for undervoltage relays shall be selected so as to avoid spurious separation of safety buses from offsite power during plant startup, normal operation and shutdown due to startup and/or operation of electric loads.
a) Each of the two redundant 4 kV emergency buses is equipped with two sets of four redundant and independent undervoltage relays. The first set of four relays are set to provide a two out of four undervoltage signal upon loss of bus voltage.
(Relays are set to operate at 59% of 4160 V after time delay of 2 seconds.) The second set of four relays are set to provide a two out of four under-voltage signal on a sustained bus undervoltage.
(Relays are set to operate at 87% of 4160 V after time delay of 8 seconds.) Upon coincidence of two out of four of either set of four relays, the preferred supply circuit breakers of the bus with which the undervoltage relays are associated are tripped. The signal from the undervoltage relays of a particular load group acts on circuit breakers of the same load group only.
b) The coincidence of two out of four undervoltage signals from either set of four relays also initiates starting of the diesel generator which is connected to the bus with which the undervoltage relays are associated.
Note: The selection of the relays and their respective set-tings was determined after a detailed investigation in .
response to NRC's generic letter of June 3, 1977.
1139 '74
- 9. The calculated voltages at the terminals of each safety load should be compared with the required voltage range for normal operation and starting of that load. Any identified inadequacies of calculated voltage require immediate remedial action and notification of NRC.
See response to Item 11
- 11. To provide assurance that actions taken te assure adequate voltage levels for safety loads do not result in excessive voltage, assumming the maximum expected value of voltage at the connection to the offsite circuit, a determination should be made of the maximum voltage expected at the termi.als a
of each safety load and its starting circuit. If this voltage exceeds the maximum voltage rating of any item of safety equipment im=ediate remedial action is required and NRC shall be notified.
Below is the calculated voltage distribution on the safety related buses for each of the conditions indicated. The figures shown are the calculated bus voltages using the nominal bus voltage as a basis.
Starting Running Shutdown Bus Bus +RCP +CWP +CBP +ESF Aux Load A+ESF Case 7 Bus Volts No. Case 2 Case 3 Case 4 Case 5 Case 1 Case 6 97% 103%__
3 4.16 kV 11 .8951 .9261 .8638 .8531 .9418 .9238 .9913 1.0544 7 480 V llA .8969 .9295 .8639 .8166 .9460 .9172 1.0027 1.0683 8 480 V llB .9015 .9339 .8686 .8156 .9503 .9134 1.0082 1.0735 The calculated voltages at the terminals of each safety load is shown in the enclosed printout.
Tabulated below are the allowable operating ranges for continuous
, operation of safety related equipment.
Continuous % of 480 V Minimum Voltage or Starting % of 480 V Equipment Range 4160 V Voltage or 4160 V 460 V Motors 414 V - 506 V 86.3 - 105.4% 345V 72%
460 V 1 10%
4000 V Motors 3600 V - 4400 V 86.5 - 105.8% 3000V 72%
4000 V +- 10%
480 V Switchgear 508 V Maximum 105.8% N/A N/A 4160 V Switchgear 4760 Maximum 114.4% N/A N/A 480 V Motor Con- 528 V Maximum 110.0% 398 V 85%
trol Center i139 '75
~
Three problems are evident
- 1) At shutdown and offsite transmission line voltage at 103%,
the calculated bus voltages are 1.0% to 1.5% higher than allowable equipment voltages. The allowable offsite transmission line voltage range is 500 kV + 3% with both units running. With only one unit operating, the allowable voltage range is 500 kV + 1%, -3%. Limiting the upper transmission line voltage at 500 kV + 1%, lowers the calculated voltages for case 7 to within allowable equipment ratings.
- 2) At full auxiliary load and ESF start, the 480 V bus voltages during the starting transient are about 3.5%
below minimum pickup voltage for motor control center starters. This starting transient would have possibly caused fuses to blow in starter control circuits; however, in 1978 fuses were changed out as required to insure that a degraded voltage condition would not prevent motor starters from operating once the voltage recovered to 91.3%
immediately after the starting transient. (Required as a result of NRC generic letter of June 3,1977.)
- 3. At Full Auxiliary load and ESF start, the 4 kV bus voltages during the starting transient are about 1.5%
below the undervoltage relay setting of 87%. In order to prevent the relay from operating during load starting transients a time delay setting of 8 seconds is utilized.
TESTS Listed below are a number of tests that have been completed that verify the results of the calculations:
- 1) Reactor Coolant Pump Start Test. Three pumps were running and the fourth pump was started. The 500 kV Switchyard voltage was adjusted to 97% for the test. The 4 kV starting bus dropped to 95% of the initial steady state voltage. Comparing Case 2 with Case 1wealsosee95% drop {.8951-95%f 9416
- 2) Condensate Booster Pump Start Test. The 4 kV bus voltage was monitored while the Condensate Booster Pu=p was started. The 500 kV Switchyard voltage was adjusted to 974 for the test.
The 4 kV bus starting voltage dropped to 92.3% of initial steady state voltage. Comparing Case 4 with case 1 we also see 92% drop.
{.8638=92%1 w re
- 3) The pick up characteristics of contactors in safety related motor control centers was tested. Some control transformers have been replaced as a result of the testing, in order to bring contactor coil voltage within acceptable pick up value.
To further verify the accuracy of the submitted calculations, we plan to run voltage profile tests during full ESF starting by December 31, 1979.
1139 176
GDC - 17 Electrical power from the power grid system to the switchyard is supplied by two physically independent transmission lines designed and located so as to minimize the likelihood of their simulataneous failure under operating and postulated accident and environmental conditions. Two physically independent circuits from the switchyard to the onsite electrical dis-tribution system are also provided. The switchyard is designed with duplicate and redundant systems - e._,, two battery systems, two air supply systems, two trip coils per breake; , two protective relay schemes, and two cuxiliary AC supplies from plant emergency buses.
Enclosures:
Voltage Study Plant Single Line Safety Related Load Listir.d 1139 '77 6
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.~ BUS. ARE A VOLT AGE Af4GLE HW HVAR NW MVAR HW MVAR HVAR CKT TO BUS NW MVAR 3
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. VERT CLIFFS HUCLEAR POWER PLANT.
() TERMINAL VOLTAGE AT SAFETY RELATED EQUIPMENT-CASE 5 CMPHT H0 *
, VOLT AT EQPT EGPT HOM VOLT AT S T A R T'1 H G 1MA107 88.6748 4000.0000
() 1MA108 88.6224 4000.0000 1MA110 88.6176 4000.0000 IMA104
() 1MA105 88.6463 88.4227 4000.0000 4000.0000 t 1MA412 1MA109 88.2427 4000.0000 j ) j]3 ]
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g 88.6355 4000.0000
() 1MA411 88.6441 4000.0000 h 11 i 1MA407 83.6595 4o00.0000 1MA408 88.5629
) 1MA110 88.6176 4000.0000 4000.000o INA404 88.5986 4000.00C0
() IMA405 88.4666 4000.0000 1MA412 88.2427 4000.0000 1MA409 88.6430 4000.0000 1MA411 88.6441 4000.0000
( IMOV509 85.0447 460.0000 1MOV508 85.0389 460.0000 IM1406 83.3456
() 1McV6579 84.9015 460.0000 460.0000 1M074144 84.1190 460 0000 IM0Y659 84.6714
() 1MOV617 84.7812 460.0000 460.0000 1MOV627 84.7812 460.0000 IM0Y637
) 1MOV647 84.8595 84.9485 460.0000 460.0000 1MOV2080 85.0402 460.0000 INCY615 84.3156
() 1MCV625 84.3156 460.0000 460.0000 1MOV656 84.6585 460.0000 g 1M1402 84.6727 460.0000 IMOV4516 84.4858 460.0000 1MOV614 84.9946 '60.0000
(; iMOV624 84.7874 460.0000 IM1404 83.?344 460.0000 1MOV5250 84 9675 460.0000
{ IMOV501 85 0309 460.0000 1ME102 84.2151 460.0000 1ME105 84.3728 460.0000 1MB106 82.2617 460.0000
{ IMB108 84.9573 460.0000 1MD110 80.9548 460.0000
{ 1ME404 80.3057 460.0000 15E114 83.5594 460.0000 1MB121 84.4509 460 0000 IMB116 82.5774 460.0000
{ 1M5115 79.6610 460.0000 1M0231 82.4627 460.0000
( IMCV514 85.1515 460.0000 iMC406 83.5266 460.0006 1MOV5463 55 0551 460.0000 r 140'#4145 84 4811 460.0000 ll ' (j f 1.10 Y 6 6 0 85.0843 460.0000 1MCV635 84.8206 460.0000
O g 1MCv645 1McV616 84.6658 460.0000 84.9633 460.0000 IMcvG26 84.9633 460.0000 r IMCV636 85.0525 460.0000
- 1MCY646 85.6525 460.0000
!MC402 84 7667 460.0000 1M0Y4517 84.7431 460.0000 C. 1Mcv634 84.9193 460.0000 1MOV644 84.9193 460.0000 g 1M0404 84 1985 460.0000 1Mcv5251 35.0854 460.0000 1MOV5462 84.9512 460.0000 g th5402 84.4071 460.0000 IME405 83.478? 460.0030 1ME40 82.6787 460.0000 g, IME411 81.0940 460.0000 IME4to 82.2722 460.0000 1MB404 8o.4098 460.0000 1ME414 83.6938 460.0000 1MB121 84.5787 460.0000 1ME116 82.6787 460.0000 ****** 7' "*'****
0 - O O O O 1139 '05 O C C C C C C C r
W COMP 0 KENT NUM3ER DESCRIPTION
! M02 31 C H T N H T - F U'R C E AIR SUP FAH 11
, 1M03'1 CNTMNT PURCE AIR EXH FAN 11 1M0402 PEHEiRATIDH RM EXH FAH 12 1Mo404 ? 'a AIR COMPRESSOR 12 i
1M0406 DORIC ACID PUMP 12 1M1402 PEHEIRATION RN EXH FAN 11 1M1404 SU AIR COMPRF.SSOR 11
.s ~
1M1406 BORIC ACID PUMP 11 1MA104 LPSI PUMP 11 1MA105 SALT WATER PUNP 11 IMA107 CHTNHT SPRAY PUMP 11
) 1MA108 HPSI FUMP 11 IMA109 SERVICE WATER PUMP 11 1MA110 HPSI PUMP 13*
.I iMA110 HPSI PUMP 13 1MA404 LPSI PUMP 12
~
1MA405 SALT WATER PUMP 12 1MA407 CNTMNT SPRAY PUMP 12 1MA40% HPSI PUMP 12 1M6409 SERVICE WATER PUMP 12 1MA41! SERVICE WATER PUMP 13 1MA411 SERVICE WATER PUMP 13 1MA412 SALT WATER PUMP 13 1MA412 SALT WATER PUMP 13 1MB101 CAVITY COOLING FAN 11 i s 1MB102 CHTMNT COOLING FAN 11
'MBlo5 CHTNHT FILTER 11 MB106 COMP 0HEHT COOLING PUMP 11
..- MB108 CCHTROL RM A/C COMPRESSOR 11
', ... IMB110 SUGR RM A/C COMPRESSOR 11 iMB114 CNTMNT C00LlHG FAH 12 -
,x
!MB115 CHARGING PUMP 11
. / 1MB116 COMP 0HEHT COOLING PUMP 13 R 1MB116 9MPCHENT COOLING PUMP 13
' 'MBil? :IH PLANT EXHAUST FAH 11 1RB118 av7RUMENT AIR COMPRESSOR 11 IMB121 t.4TMNT FILTER 13
*/ 1MB121 CNTMNT FILTER 13 1MB401 CAVITY C00LINC FAH 12 11 IMB402
, CHTMNT COOLING FAH 13 thB403 PLANT AIR COMPRESSOR 11
*(.II
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IMB404 CHARCIHC PUMP 13
^1 M B 4 0 4 CHARCING PUMP 13
- g. (g IMB405 CHTMNT FILTER 12 9* IMB406 00MP0HEHT C00LINC PUMP 12
'f5
' iMB410 SUGR RM A/C CONPRESSOR 12
'. W IMB411 gg FUEL POOL CCOLING PUMP 11 30 1MB414 CNTMNT COOLING FAH 14 iME415 CHARCIHC PUMP 12 1MB417 MRIN PLANT EXHAUST FAN 12
'I 1MB418 INSTRUMENT AIR COMPRESSOR 12
, tt 1139 '06 e
II . gg- COMPONENT NUMBER DESCRIPTION 1MOV2000 INSTR AIR CHTMNT ISOL 1MOV4144 CHTMNT SUMP DISCH GI IMOV4145 CHTMNT SUMP DISCH IM3V4516 SC 11 FEEDWATER ISOL 1MOV4516 1MOV4517 SG 12 FEEDWaTER ISOL 1MOV4517 gg IMOV501 VOL CONT TK DISCH MOV 1MOV500 BA TK 12 TO CHARG PUMP S'E n 1MOV503 BA TK 11 TO CHARG PUMP !. *g t l gg INOV514 BA PUMPS TO CHARC PUMP SUl r IMOV5250 SW TO CIRC WTR PUMP RM COOLERS IM0Y5251 SW TO CIRC WTR PUMP RM COOLERS IMOV5462 CNTMNT HORM SUMP MWRT 1M6V5463 CNTMNT HORM SUMP MWRT 1MOV614 St TAHK 11A ISOL 1MOV614 1M0Y615 LPSI TO LOOP 114 CONT 1M0Y615 1MOV616 MAN HPSI TO LOOP 11A 1MOV616 1MOV617 HPSI TO LOOP 11A CONT 1MOV617' IMOV624 SI TANK 118 ISOL 1MOV624 1MOV625 LPSI TO LOOP 11B CONT 1MOV625 IMOY626 MAH HPSI TO LOOP 118 1MOV626 1MOV627 HPS! TO LOOP 118 COMT 1MOV627 1MoV634 SI TANK 12A ISOL 1Mov634 1MOV635 LPSI TO LOOP 12A CONT 1MOV635 1MOV636 MAN HPSI TO LOOP 12A 1MOV636 , IMOV637 HPSI TO LOOP 12A CONT 1MOV637 1MOV644 SI TANK 128 ISOL 1MOV644 1MOV645 LPS! TO LOOP 12B CONT 1MOV645 1MOV646 NAH HPSI TO LOOP 129 1MOV646 1M0Y647 HPSI TO LOOP 12B CONT 1MOV647 1MOV656 MAHUHL HPSI HDR ISOL 1MOV656 1MOV6579 CNTMNT ISOL IM0Y659 CS & SI PUMPS RECIRC iMOV660 CS & SI PUMPS RECIRC 1139 107}}