ML19209C226
| ML19209C226 | |
| Person / Time | |
|---|---|
| Site: | Davis Besse  |
| Issue date: | 10/09/1979 |
| From: | Roe L TOLEDO EDISON CO. |
| To: | Gammill W Office of Nuclear Reactor Regulation |
| References | |
| NUDOCS 7910120223 | |
| Download: ML19209C226 (62) | |
Text
{{#Wiki_filter:, TOLEDO EDISON Docket No. 50-346 LOWELL E. ROE
. .c. pr... .
License No. NPF-3 [[,*h.*l,*L"'"' Gere.' No. 543 occober 9, 1979 Mr. William Gammill Acting Assistant Director for Operating Reactors Projects Division of Operating Reactors United States Nuclear Regulatory Commission Washington, D.C. 20555
Dear Mr. Gammill:
Attached with this letter is our response to your inquiry dated 8/8/79 on adequacy of station electric distribution systems voltages for Davis-Besse Nuclear Power Station Unit No. 1. The analyses cover many operating modes, and we draw to your attention that our present power operation mode is with one startup transformer and two 'ous tie transformers. The case analyses for this mode are prefixed by the number "12", and Appendix B explains completely the case numbering system. We operate in this manner, because our preferred mode of power operation with the auxiliary transformer and two bus tie trans-formers does not presently meet a strict interpretation of the design requirement for two off-site sources of power available. The preferred mode cases are prefixed by "32", and we are currently pursuing modification to the Station via a facility change request to allow this mode. Please note that we will issue to you a schedule of tests by December 7, 1979, and after these tests are run, we will submit a final report. Yours very truly, W "7 Q 11^4 lb9 LER/TWM
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Attachment 5 mj b/2 7910120A M THE TCLECO EDISCN COMPANY EDISCN PLAZA 300 MADISCN AVENUE TOLEDO, CHIO 43652
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ANALYSES OF THE ADEQUACY OF THE DAVIS-BESSE NUCLEAR POWER STATION ONSITE ELECTRICAL AU"ILIARY DISTRIBUTION POWER SYSTEM VOLTAGES Prepared in
Response
to the Nuclear Regulatory Co=nission Request . of August 8, 1979 October 8, 1979 9 1i44 160
*L:-a TABLE OF CONTENTS
[
! I. Introduction i
II. Analyses s A. Introduction ,
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B. 3i5 kV Crid System ,
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C. Load Analyses
- 9. Equipeent Ratings E. System Operation ,
- 1. Main Generation Systes
- 2. 13.8 kV System
- 3. 4.16 kV System
- 4. 480 V Bus
- 5. Safety Related Syste=s F. Operating Procedures
- 1. Grid System
- 2. Plant Procedures 3.- Technical Specifications G. Modes of Operation and Analyses
- 1. Unit Auxiliary Transfor=er ,
s
- 2. Startup Transforcer
- 3. Overvoltage
, s H. Assumptions
- I. Testing III. Conclusion Appendices A. Cross Reference to Enclosure 2 of the Nuclear Regulatory Commission letter of August 8, 1979 , ,
B. Case Numbering System 7 i
)
TABLE OF CONTENTS ( CONT.) Figure 1 Davis-Besse Nuclear ?over Station 1-Line Figure 2 Davis-Besse Nuclear Power Station 1-Line Figure 3 Davis-Besse Nuclear Power Station 1-Line Figure 4 Davis-Besse Nuclear Power Station 1-Line Figure 5 (Sh. 1,2) Davis-Besse Nuclear Power Station Graph of Bus Voltages Versus Case Nu=bers Figure 6 (Sh. 1,2) Davis-Besse Nuclear Power Station Graph of Bus Voltages Versus Case Nu=bers Figure 7 Davis-Besse Nuclear Power Station Graph of Generator Bus Load Versus Bus Voltages
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Cases 32021, 32121, 32221, 32321A, 323213, 31021, 31121, 31221, 31321A, 31321B, 22021, 22121, 22221, 22321, 21021, 21121, 21221, 21321, 12021, 12121, 12221, 12321, 11021, 11121, 11221, 11321, 22020, 12020 k 8
E -. i i g f I
; Introduction 6
l The Davis-Besse Nuclear Power Station is a single unit station with the electrical I auxilf ary system and safety related systems supplied f rom the of f site network as _ i depicted in Figure No. 1. During startup and shutdown the electrical auxiliary 1 t systems are supplied from either or both startup transformers 01 and 02. For normal power operation the electrical auxiliary systems are supplied f rom the unit auxiliary transformer 11 with the startup transformers as immediately available reserve sources of offsite power. t Analyses A. Introduction Separate analyses were performed assuming the power sources from the offsite network to the safety related buses as derived from (1) unit auxiliary transformer and (2) the startup transformer (s). For each case it was assu=ed that the need for electric power was initiated by an anticipated transient such as a unit trip or an accident, whichever presented the largest load demand. Manual load shedding was not assumed. The computer model developed to perform the analyses incorporated preliminary load data collected at the plant with the unit operating at 100 percent of the electrical output power. In addition, the computer model used actual test data for the installed equipment. The plant's existing electrical auxiliary system
. configuration (e.g. breaker status, transforcer taps, etc.) was included in the computer model.
f ! 11^4 16,3
i i B. 345 kV Crid Svstem The Davis-Besse 345 kV switchyard is served by three 345 kV transmission lines. All three lines are constructed such that a structural collapse -
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of one line will not cause outage of the other lines. The range of voltage -[ for the 345 kV system at the Davis-Besse unit is indicated in Table No.1. Table No.,_1 Made of Full Load Voltage No Load Volta 2e Operation Maximum Minimum Maximum Minimum 1 102.1% 101.7% *N.A. for Mode (From Unit of Operation Auxiliary No. 1 Transfor=er) - 2 102.2% 98.3% 102.2% 98.3% (From Startup Transformer)
*The auxiliary sfstem is only operating-in the full load condition when supplied from the unit auxiliary transformer.
(Ref: TECo letter to the NRC, March 1, 1977 Serial No. 230) Free Table No.1, the worst case range of the 345 kV system grid voltage is 98.3% to 102.2% on a base of 345 kV. With the Davis-Besse unit not in service, the three-phase short circuit level is 10830 MVA at the 345 kV bus. With the Davis-Besse unit and the Davis-Besse to Bayshore 345 kV line not in service the three-phase short
' circuit level is 6589 MVA at an angle of 85.55 degrees. The Davis-Besse to Bayshore 345 kV line has the largest contribution of short circuit MVA. For the analyses relating to equipment starting, the value of 6589 MVA is used to simulate the worst case conditions.
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C. Load Analvses The maximum loading of the unit's electrical auxiliary syste= is whenever an accident occurs simultaneously with nor=al power operation (mode 1), startup (= ode 2) and hot standby (mode 3). These three modes of operation - represent the cases whereby the plant's auxiliary system is at full load. - Table No. 2 indicates the total maximum loading of the unit's auxiliary syste=. Table No. 2
- Mode 1, 2 and 3 Accident Total lead Load load 52231 kVA 2651 kVA 54882 kVA
*From preliminary plant load data collected with the unit ac 100 percent output power.
Table No. 3 indicates the maximum transformer loadings assumin2 the worst case single contingency. Table No. 3 Maxi =us Percent of Transfo rmer Rating Loading Rating Unit Auxiliary 11 52/69 MVA 54.882 MVA 79.5% Startup 01, 02 39/52/69 MVA 54.882 MVA 79.5% Bus Tie AC, BD 12/16 MVA 9.286 MVA 58.0% D. Ecuir:ent Rating s The following Table No. 4 indicates the voltage range over which safety related equipment (1. e. valves, fans, pumps, etc.) can Operate continuously in the performance of their design function (Ref: TECo letter to NRC, July 18, 1977; Serial No. 293).
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. Table No. 4 Equipcent Rance Base Value Sourc e Safety related motors
- 90%-110 120V,240v,460V, 4kV NEMA MG-1 Safety related 4.16 switchgear Maximum of 114 4.16kV ANSI C37.0g*
, 2 Safety related 480V switchgear Maximum af 132 480V ANSI C37.13 120V Contactors** 85 -110: 120V NEMA ICS 2-110 120V Relays ** 85%-110 120V NEMA ICS 2-212
- Safety related motors (valves, fans and pumps) are designed and type-tested to start at 70: voltage and to provide full load torque during a momentary dip to 65% of rated motor nameplate voltage at the motor terminals for 15 seconds. The'only exceptions to this requirement are the following electrical equipment which have a starting capability of 80: rated motor nameplate voltage.
- 1. Containment recirculation fans 1 and 2
- 2. Battery room vent fans 1-1 and 1-2 The loss of these far.s for 7.5 seconds is inconsequential to the safe shutdown of the plant. The 7.5 seconds is derived from the time delay associated with the 4.16 kV safety related bus undervoltage protection described in Section II.E.3.
** Tests performed by the Toledo Edison Compacy at the Davis-Besse plant demonstrated that the conta; tors will pickup and hold with 80% voltage on the primary of the control power transformer. These tests si=ulated the worst case configuration at Davio-Besse with respect to heavy loading on the control poner transformer dua to auxiliary coils, lights and heaters, low voltage at the contactor coil due to voltage drop on long runs of external control cable, greatert pickup voltage due to largest contactor size used with a given size control power transformer. No failures of control power fuses were experienced, 80 primary voltage was maintained for a minimum of 10 seconds after contactor pickup and all auxiliary relays performed as required (Ref: TECo letter to NRC, July 18,1977; Serial No. 293)
E. System Operation
- 1. Main Generation System The protection for the main turbine generator consists of generator protection and turbine protection. During normal operation with the unit's electrical auxiliary system supplied through the unit auxiliary transformer, the operation of these protection systems results in three
!ifferent plant operating conditions.
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i . . i 5-l* The generator protection system has the following two divisions which result in two of the three afore=entioned operating conditions: 1
- 1. abnormal conditions originating in the grid system .
Q. abnor=al conditions originating in the main generation system. Abnormal conditions originating in the grid system are identified on the generator as:
- l. out of step
. 2. underfrequency
- 3. negative phase sequence
- 4. overcurrent (voltage restraint)
Under these conditions, the unit is isolated from the 345 kV grid system by opening bre ?.ers 34560 and 34561 (Ref: Figure No. 2). The unit's output power is reduced to the unit's electrical auxiliary system requirements. A transfer of the electrical auxiliary system :3 the startup transformer is not performed because the protection system has identified the abnormal condition (s) to be originating in the 345 kV grid system which also provides power to the startup transformers. Abnor=al conditions originating in the main generation system are identified as:
- 1. generator low field and loss of field
- 2. unit auxilisry transformer 11
- a. sudden pressure
- b. primary phase overcurrent
- c. secondary ground
- d. differential
- 3. main transiurmer 1 e
- a. sudden pressure
- b. differential
- 4. generator differential
- 5. dual volts / hertz (overexcitation)
- 6. generator reverse power 11^4 167
( . [ With these conditions, the unit is isolated from the 345 kV grid system i by opening breakers 34560 and 34561 (Ref: Figure No. 2). The 13.8 kV buses A and B are im=ediately fast transferred (6 cycles) from the {
' unit auxiliary transformer 11 to the startup transfor=er(s) 01 and/or i
- 02. 4 The specific startup transformer (s) is determined by preselection y using the reserve source selector switches. These switches can align eitber startup transformer to each 13.8 kV bus. The .amediate fast transfer of the electrical auxiliary system to the startup transformer (s) is performed because the protection system has identified the abnormal f condition (s) to be originating in the main generation system and not the 345 kV erid system.
The turbine protection system, which results in the third plant operating condition, detects abnormal conditions relating to the turbine and are identified as:
- 1. shaft pump low discharge pressure
- 2. high vibration
- 3. loss of condenser vacuum
- 4. o.ve rspeed
- 5. thrust bearing wear detector and bearing oil pressure
- 6. high exhaust hood temperature (hood coil)
- 7. loss of stator coolant runback or trip
- 8. no EHC 125V DC input power
- 9. loss of both primary and secondary speed signals
- 10. loss of both + 30V DC power supplies
- 11. loss of both - 22V DC power supplies
- 12. reactor trip (trip of CRDM breakers A&B or C&D)
- 13. loss of all four reactor coolant pumps 141 loss of hydraulic pressure
- 15. generator trip
- 16. master trip pushbutton
- 17. mechanical trip Any of these abnor=al conditions or trips results in a turbine trip which closes the main steam stop valves and the combined intercept valves.
With the closure of these valves and any of the breakers 34560, 34561 HX11A or HX11B closed (Ref: Figure No. 2) the generator anti-motoring
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circuit is functional. This circuit has a 30 second time delay which trips breakers 34560, 34561 HIllA and RX11B 30 seconds after a turbine trip. Under nor=al operation with breakers 34560 and/or 34561 closed and breakers EX11A and EX11B closed, a turbine trip results in a 30 second = delayed transfer of the 13.8 kV buses A and B from the unit auxiliary source to the preselected startup transformer (s). The actual transfer occurs in 6 cycles but the transfer initiation is delayed for 30 seconds. In addition to protecting the main turbine generator, the generator protection and the turbine protection will initiate the anticipatory reactor trip system (ARTS) which trips the reactor. This system is also actuated bf anual tripping of the turbine or tripping of both main feedwater pump turbines. Operation of the ARTS will occur coincidentally with either the 6 cycle fast bus transfer or the 30 second delayed bus transfer of the 13.8 kV buses A and B from the unit auxiliary transfor=er 11 to the preselected startup transfor=er(s) 01 and 02 as previously described.
- 2. 13.8 kV System Power to the 13.8 kV buses A and B can be supplied from either the unit auxiliary transformer 11 or startup transformers 01 or 02. (Ref: Figure No. 2). As indicated in section II.E.1. the reserve source selector switches are provided to preselect the alignment of startup transformers for buses A and B. This preselection of the alignment is for the bus ,
6 cycle fast transfers. When paver is being supp) 4 3 G tes A and B from the unit auxiliary transfccmer 11, the reserv sourec (slector switches can be used to pre-i;^4 169
I 4 I
, elect an alignment of either startup transformer 01 or 02 to bus A and . Likewise for bus B. The reserve source selector switches can be set so that l , only one startup transformer is aligned to both 13.8 kV buses A and B. -
6
~ ; When hower is being supplied to a 13.8 kV bus by a sta.rtup tranformer, _
the reserve source selector switch for that bus can preselect the alternate startup transformer source. This permits a fast bus transfer to the
, alternate startup transformer source should the original source fail.
The fast bus transfer scheme from the unit aux liary transformer 11 to the startup transformers 01 and/or 02 is further enhanced by fast acting synchrocheck relays. Opening of the 345 kV breakers 34560 and 34561 during normal power operation with the electrical auxiliary systems being supplied power from the unit auxiiiary transfor=er Ill will result in these relays monitoring the phase angle difference between the secondary voltage of the unit auxiliary transformer 11 and the startup transformer (s) secondary voltage during the 6 cycle bus transfer. Should the angle exceed 35 degrees the transfer will be blocked to prevent out of phase reenergization and the associated overvoltage stresses on the plant's electrical auxiliary system. These fast acting synchrocheck relays are also functional during the 30 second delayed transfer scheme described in Section II.E.1.
- 3. 4.16 kV System
. During normal operation and accident conditions without a loss of offsite power, the safety related 4.16 kV buses C1 and D1 are supplied power from the bus tie transformers AC and BD (Ref. Figure No. 3). Each safety related 4.16 kV bus is provided with a fast transfer (6 cycles) scheme which will transfer the bus from its normal source to an alternate source of power. As an example, the normal supply of power to the 4.16 kV 4
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f
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i g Bus Cl is f rom bus tie transformer AC through 4.16 kV bus C2. Thould a fault occur in the bus tie transformer AC, breaker AACC2 opens and ABDCI closes. Should a fault occur on the 4.16 kV bus C2, breaker AC110 opens and ABDCl closes. - 5 Each 4.16 kV safety related bus is provided with two levels of voltage protection (90% and 59% of 4.16 kV). Four relays at each level function in a coincidental logic to preclude spurious trips of the offsite power source. De time delays (i.e. 7.5 and .5 seconds, respect-tively) associated with the relays are chosen so as to minimize the effect of short duration disturbances from reducing the availability of the offsite power source, to assure that the allowable time duration of a degraded voltage condition does not result in failure of safety systems or components and to assure the starting times of equi; cent assumed in the accident analysis are not exceeded. De 90% undervoltage relays set at 7.5 seconds automatically initiate disconnection of the offsite power source whenever the voltage setpoint of 90% (4.16 kV base) and time delay of 7.5 seconds have been exceeded. De 59% (4.16 kV base) undervoltage relays set at .5 seconds automatically initiate the disconnection of the offsite power source, load shed the bus and start the diesel generator whenever the voltage setpoint of 59% (4.16 kV base) and time delay of .5 seconds have been exceeded. Momentary undervoltage pushbutton bypass of the 90% relays is provided. nese bypass pushbuttons are used during starting of a reactor coolant
, pump or circulating water pump. De bypassing of the relays under these conditions is required because (1) the 4.16 kV safety related bus voltage dips below 90% and (2) the accelerating time of the pump is greater than 7.5 seconds. Actual testing at the Davis-Besse plant has indicated the 11^4 171
i
; !I !! accelerating time of the reactor coolant pumps is approximately 9.5 6 ;, seconds. The 4.16 kV safety related bus voltage will also drop below 'I 90% for a condensate pump start. However, the accelerating time of the pe=p is less than 7.5 seconds. . .=
- 4. 480 V. System Power to the safety related 480 V systems is supplied from the 480 V safety 6 related buses El and F1 (Ref: Figure No. 4). The power to all of the safety related motor control centers is supplied from these buses.
- 5. Safety Related Systems Whenever an accident condition occurs with offsite power available, all of the safety related loads are started immediately. The loads are not sequenced on the offsite network. Whenever an accident condition occurs coincidental with or following a loss of offsite power, all of the safety related loads are sequenced on the diesel generator.
F. Operating Procedures
- 1. Crid System The 345 kV grid system is operated under guidelines established by the East Central Area Reliability Agreement (ECAR) of which the TECo system is a member.
- 2. Plant Procedures The plant operators are provided with plant system procedures which specifically identify action to be taken by an operator when operating an individual piece of equipment or a system.
The control room operator is provided with the following voltage monitors to determine the status of the unit's electrical auxiliary system voltages: (Ref: TECo letter to NRC, March 1,1977; Serial No. 230) 1i^4 172
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. Voltmeter Ecuircent Type [ 4.16 kV Safety related Switchgear CE-185 480 V Safety related Unit Substation GE-185 345 kV .: Grid System GE-185 5 13.8 kV Switchgear GE-185 13.8 kV Feeders fro: the Start-up Transformers and GE-185 Unit Auxiliary Transformer 25 kV Generator Bus GE-A340 The following voltage alarms are also provided in the control room: (Ref : TECo letter to NRC, July 18, 1977; Serial No. 293) Alarm Setpoint 4.16 kV Safety related Bus Voltage Low 95% 4.16 kV Safety related Bus Voltage High 103.3% & 102% 480 V Safety related Bus Voltage Low 92% 13.8 kV Bus Voltage Low 95% 4.16 kV Bus Voltage Low 95% 480 V Bus Voltage Low 92% These alar =s are to initiate operator action, if required, in accordance with the plant alarm procedures.
- 3. Technical Specifications The technical specifications concerning limiting condition for operation of the Davis-Besse unit electrical cuxiliary system are identified in section 3/4.8 of Appendix A to License No. NPF-3.
G. Modes of Operation and Analyses For the analyses, various operating conditions were postulated to demonstrate the capabilities of the unit's electrical auxiliary system and to assure that the safety i 1'4 173
E. s I t i related buses would have adequate voltage to perform their safety functions. Cases were developed to simulate normal operating conditions as well as contingency conditions. Analyses were performed for starting of the largest 13.2 kV motor (reactor coolant , pump), the largest 4.0 kV motor (condensate pump) and the safety features actuation] system (SFAS) equipment. The following is the result of the analyses: It should be noted that the various curves included in the analyses are a function of bus voltage and not motor base voltage. Also, the curves are of the worst case bus voltage for the individual analysis. A case numbering system was developed for the analyses which is described in Appendix B.
- 1. Unit Auxiliary Transfor=er The nor=al configuration of the unit's electrical auxiliary system during power operation is the unit auxiliary transformer 11 supplying power from the 25 kV generator bus. The bus tie transformers AC and BD and the unit substation transformers are in their normal alignment as indicated in Figure Nos. 3 and 4, respectively. The following Table No. 5 indicates the case nu=bers for the normal case and the various contingency cases which were analyzed.
Table No. 5 Transformers Reactor Condensate in Normal Coolant Pump SFAS Se rvice Operation Pumo Start Start Start Unit Auxiliary and 32021 32121 32221 32321A Two Bus Tie 32321B e Unit Auxiliary and 31021* 31121* 31221* 31321A* One Bus Tie 31321B*
- Unit Operating under Technical Specification 3/4.8 11d4 174
Case No. 32021 is the normal operating case for the plant during power operation. The 25 kV generator bus voltage is dependent upon the VAR flow from the main turbine generator. This VAR flow is dependent upon the operating conditions ,
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of the 343 k" grid. With the Davis-Besse Unit operating, . Table No. 7 indicatea the 25 kV generator bus and the 345 kV bus voltages for different VAR flow conditions. Table No. 7 Generator output 25 kV 345 kV Bus Bus W MVAR Voltage Voltage 906 189 98.7% 102.1% 906 418* 101.3% 101.7%
- At maximum hydrogen pressure From Table No. 7, as the generator VAR requirements decrease, the 25 kV bus voltage will decrease and the 345 kV bus voltage increases indicating an excess of VAR's in the grid system. Whenever the generator VAR require-ments increase, the 25 kV bus voltage will increase and the 345 kV bus voltage decreases indicating a demand for VAR's by the grid system. As indicated in Table No. 1, the 345 kV bus voltage range is 101.7% to 102.1%.
Therefore, the corresponding 25 kV generator bus voltage range is 98.7% to 101.3%. For Case Nos. 32021 and 31021, Figure Nos. 5 and 6 indicate the range of bus voltage for the 4.16 kV and 480 V safety related buses corresponding to the normal operating range of the 345 kV grid system. From Figures No. 5 and 6, the normal operating safety related equipment is operating within it's continuous operating capability as indicated in Section .I.D. 11^4 175
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I [ , t k Case No. 32121 indicates the effects on the safety related buses from a reactor I
- coolant pump start. As described in Section II.E.3., the momentary undervoltage I
j pushbutton bypass will be used to prevent tripping of the feeder breakers
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I to the 4.l_6 kV safety related bus during these starting conditions. This _ s s 2
'1 case neglected the effects of the turbine generator including the excitation ,
i system so that the results are conservative. Case No. 32221 indicates the ei.- s on the safety related buses from a con-densate pump start. As indicated in Section II.E.3., the momentary undervoltage pushbutton bypass is not used. Likewise, this case neglected the effects of the turbine generator. Case Nos. 32321 A and B indicate the effects on the safety re".ated buses from a SFAS start. Whenever an SFAS start is initiated during power operation with the unit's electric.1 auxiliary system supplied from the unit auxiliary transformer 11, a reactor trip results in a turbine trip which energizes the generator anti-notoring circuit and it's associated 30 second delayed transfer scheme described in Section II.E.1. The safety related systems are started ir:=ediately and loaded on the unit auxiliary transformer 11. Since the turbine is tripped, the generator output will continue initially until the trapped steam in the turbine has been expended. Once the trapped steam has been exhausted, the generator will act as a motor load on the 25 kV generator bus. The exact size of this motor load is dependent upon many factors such as condenser back pressure, windage losses, bearing wear, etc. Depending on the turbine hood back pressure, the turbine generator manufacturer has indicated that a load as large as 18700 KW could be experienced. The exact timing of the generator changing from a source of power to a motor load is difficult to predict. A typical range may be 1.6 - 2.2 seconds. However, based on ther- conditions, case no. 32321A is an SFAS start assuming no contri-
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. bution fro = the main turbine generator. Case No. 32321B is an SFAS start I assuming the main turbine generator as a 25000 KW load. These results are conservative since the effect of the generator excitation system has not been . included.i From Figure No. 7 the effect of increasing the load on the 25 kV j bus has minimal impact on the safety related bus voltages. Case Nos. 31021, 31121, 31221, 31321A and B are the corresponding analyses ! which assu=e the worst case single contingency (loss of a bus tie transformer). As indicated, the unit would be operating under a technical specification limit. Figure Nos. 5 and 6 are a comparison of the equipment capabilities to the anticipated bus voltage for the normal operating range of the 345 kV grid system. The figures also include the alarm setpoints described in Section II.F.2. which will initiate operator action. The trip setpoints of the undervoltage protection scheme described in Section II.E.3., are included in Figure No. 5. It should be noted for Figures No. 5 and 6 that whenever the equipment capability is compared to the various cases, the correct individual capability be used. For example, Case Nos. 32021 and 31021 are for normal operation. Therefore, only the equipment capabilities for normal operation need be r asidered. For cases such as 32121 or 32221 only the equipment capability to withstand the voltage fluctuations should be compared. Finally, for cases such a 32321A or 31321A the equipment capability to actuate should be compared with the calculated results. The following are two specific examples in using Figures No. 5 and 6:
- 1. Figure No. 6 Assuming an accident occurs coincidental with offsite power available, Case No. 32021 indicates that the contactors and relays will be energized with a 480V safety related bus volt-age ran'ge of 100.6 to 103.7 percent which is within their 80 11^4 177
!I f , fr percene actuation capability. All the contactors and relays 6 [ required to operate will energize before the voltage on the [ 480V safety related bus dips in the range of 87.5 to 77.7 I percent from Case Nos. 32321A or 32321B due to motors start- - 1
; 'ing. The motors have 67.1 percent starting capability.
},
- 2. Figure No. 5 Assuming a reactor coolant pu=p motor start, Case No. 32121 indicates that the 4.16 kV safety related bus voltage will dip in the range of 85.2 to 88.8 percent. This is within motor capability to withstand voltage dips to 62.5 percent for 15 seconds.
- 2. Startup Transformer With the unit's electrical auxiliary system being supplied from the startup transformer (s), the following Table No. 6 indicates the case numbers for the normal case and the various contingency cases which were analyzed. As indicated in Section II.B the analyses associated with equipment starting assume the Davis-Besse Unit and the Davis-Besse to Bayshore 345 kV line are not in service.
Table No. 6 Transformers Reactor condensate in Normal Coolant Pump SFAS Se rvice Operation Pu=p Start Start Start TVo Startup and 22021 22121 22221 22321 Two Bus Tie TV9 Startup and 21021* 21121* 21221* 21321* One Bus Tie One Startup and 12021 12121 12221 12321 Two Bus Tie one Startup and 11021* 11121* 11221* 11321* One Bus Tie .
- Unit Operating under Technical Specification 3/4.8 i1'4 178
- g. .
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5 Case Nos. 22021, 22121, 22221 and 22321 are the normal configuration of the plant's electrical auxiliary system when being supplied from the startup transformers.
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Case Nos. 21021, 21121, 21221 and 21321 are single contingency cases which assc=e that a bus tie transformer is outaged. As indicated, the unit would be operating under a technical specification limit which would permit plant operation for a maximum of 72 hours before being required to shutdown if the outaged bus tie transformer was not restored to service. Case Nos. 12021,12121,12221 and 12321 are single contingency cases which have assumed that a startup t: .aformer is either in a standby condition as described in Section II.E.2. or the transformer is out of service in which case the plant would be operating under a technical specification limit. Case Nos. 11021,11121,11221 and 11321 are double contingency cases which have assumed the worst case conditions of the plant's electrical auxiliary system configur:ation. Again, the plant would be operating under a technical specifica-tion limit. Case Nos. 11121, 11221 and 11321 have assu=ed thu Davis-Besse to Bayshore 345 kV line is out of service. Figure Nos. 5 and 6 are a comparison of the equipment capabilities to the anticipated bus voltage for the normal operating range of the 345 kV grid
, system. The anticipated bus voltage range corresponds to the maximum and minimum grid voltage fluctuat*,n of 102.2% to 98.3%.
- 3. dVervoltage Overvoltage conditions on the plant's electrical auxiliary system occurs when the unit is shutdown with the electrical auxiliary system lightly i1^4 179
tL .
- ig -
i loaded and high grid system voltage. Table No. 8 indicates the case
. numbers which were analyzed.
Table No. 8 Transformers Bus Tie Transformer Taps in One Tap Se rvice Normal Above Nominal Two Startup and 22020A 22020B Two Bus Tie One Startup and 12020A 1207.0B Two Bus Tie Case Nos. 22020 and 12020 indicate that the safety related bus voltages may be above the continuous operating capability of the equipment. However, two things must be noted. First, under these conditions, very little safety related equipment is operating. Secondly, the operator is provided two overvoltage alarms on the 4.16 kV safety related buses (102% and 103.3%) which will initiate operator action in accordance with the p. ant alarm procedures identified in Section II.F.2. By resetting the caps on the bus tie transformers to one tap above nominal, cases 22020 and 12020 indicate that the bus voltage will again be within the equipment capability under these ceaditions. H. Assumptions Since the computer analyses used actual plant data, there were no major assumptions which have an influence on the results. I. Testing , To verify the result of these analyses, tests will be performed on the Davis-Besse 21ectrical auxiliary system simulating those conditions which are feasible. The s -ific test procedures, test outlines, etc. will be included in another report. Ii'4 180
C, . i
- I i
- A schedule of the tests to be performed will be submitted to the Nuclear Regulatory Com=ission by December 7,1979. The results of the test program and these computer analyses will ebe compared and a final report submitted to the Nuclear Regulatory -
Com=ission. III. CONCLUSION The analyses have demonstrated that adequate voltage will exist on the safety related buses so that the safety systems can perform their functions. The analyses - have included contingency cases which further support the capabilities of the plant's electrical auxiliary system. The analyses have included comparison of the safety related equipment capabilities to continuous operating conditic,s, transient conditions and actuation conditions. To further verify the plant's electrical auxiliary system capabilities, testing will be performed at the Davis-Besse plant and the results of that testing will be compared to these analyses. i1'4 181
s I i APPENDIX A e CROSS REFERENCE TO ENCLOSURE 2 [ OF THE NUCLEAR REGULATORY COMMISSION LETTER OF AUGUST 8, 1979 ~
-: =.
Section No. of ~, October 8,1979 Item No. Analyses
- 1. II.G.1, II.G.2
- 2. N/A
- 3. II.E.1., II.E.2., II.E.3., II.G.
- 4. II.A.
- 5. II.C., II.G.I.
- 6. II.B.
- 7. II.G.
- 8. II.E.1., II.E.2., II.E.3., Fig. No. 5
- 9. II.D. , II.G. Fig. Nos. 5 and 6
- 10. II.E.3., II.G.I. Fig. No. 5
- 11. II.G.3.
- 12. II.E.3.
- 13. II.H.
11'4 182
AI'PENDIX B CASE NUMBERING SYSTEM vg 3 _X, 3 3 X 3 Startup/ Unit Aux. Special Cases Transformer ., A 1 - One Startup XFMR > As Required Bus Tie loading B 2 - Both Startup XFMRS Transformer - 0 - No I.oad 3 - Unit Aux. XFMl 1 - One Bus 1 - Full Load Tie XFMR 2 - Both Bus Tie XFMRS Equipment Tap Status Setting 0 - Nothing Starting 2 - Unit Aux. - 2 Taps Down 1 - RCP Motor Start Startup/ Bus Tie - 1 Tap Down 2 - Cond. Pump Start Unit Substation - Nominal 3 - SFAS Start
~
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.M rn 11 Unit Auxiliary Transfomer 25 - 13. 8 kV 32/69 MVA I) 13.8 kV Bus 3 l)) !) !) })) !) l').8 kV Bus A BD AC t.L A> LL JJ n former us or=er 13.8 - 4.16 kV 13.8 - 4.16 kV 12/16 MVA 12/16 MVA
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4.16 kV Bus D2 4.16 kV Bus C2 I Emergency ~7 I~ Emergency ~ ~ 'g Diesel l g Diesel i Generator 2 Generator 1 I L J I , p _ , _ l)_ q )_ ') ') 1 4.16 kV Bus D1 1) I) I I I ' 4.14 kV Bus C1 I
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- - - STARTING CONDITIONS .-'.
UNIT AUI. [ .. _ -
- 7. -
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- TRANSPORMER ELECTRICAL AU1TLIARY -
TAPS LOAD CONDITIONS O FULL IDAD
, EQi. 1 TAP 2 TAPS .- O
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DOWN NO L.OAD r .., 2 DOWN . STARTING CONDITIONS . - ~_ .I. L~'. . ~1 UNIT ADI. . . e'.N/A. : x Nag . .
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O REAN COOIANT PUMP - 01 X
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TAPS CHANGED BD 13.8 kv/480v X 4 .16 k V / 48 r.'T X}}