ML20028B584
| ML20028B584 | |
| Person / Time | |
|---|---|
| Site: | Catawba  |
| Issue date: | 12/01/1982 |
| From: | Tucker H DUKE POWER CO. |
| To: | Adensam E, Harold Denton Office of Nuclear Reactor Regulation |
| References | |
| NUDOCS 8212030049 | |
| Download: ML20028B584 (82) | |
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Duxe POWER GOMPANY P.O. nox 33180 CHARLOTTE, N.C. 28242 HAL B. TUCKER TELEPHONE vsom emensnent (704) 373-4 &31
== = -< man December 1, 1982 Mr. Harold R. Denton, Director Office of Nuclear Reactor Regulation U. S. Nuclear Regulatory Commission Washington, D. C. 20555 Attention: Ms. E. G. Adensam, Chief Licensing Branch No. 4 Re: Catawba Nuclear Station Docket Nos. 50-413 and 50-414
Dear Mr. Denton:
In order to facilitate the completion of the review of the Catawba FSAR, Duke Power Company is transmitting herewith responses or revised responses to open items of the following technical review branches.
Attachment 1 - Hydrologic Engineering Attachment 2 - Quality Assurance .
Attachment 3 - Chemical Engineering Attachment 4 - Auxiliary Systems 'N Attachment 5 - Power Systems Attachment 6 - Containment Systems Attachment 7 - Procedures and Test Review These responses will be included in FSAR Revision 7.
Very truly yours, Hal B. Tucker i ROS/php t Attachment cc: Mr. James P. O'Reilly, Regional Administrator U. S. Nuclear Regulatory Commission Region II 101 Marietta Street, Suite 3100 Atlanta, Georgia 30303 Mr. P. K. Van Doorn NRC Resident Inspector Catawba Nuclear Station 8212030049[hh3 PDR PDR ADOCK A
e Mr. Harold R. Denton, Director December 1, 1982 -
Page 2 cc: Mr. Robert Guild, Esq.
Attorney-at-Law P. O. Box 12097 '
Charleston, South Carolina 29412 Palmetto Alliance 2135 Devine Street Columbia, South Carolina 29205 Mr. Jesse L. Riley Carolina Environmental Study Group 854 Henley Place Charlotte, North Carolina 28207 Mr. Henry A. Presler, Chairman Charlotte-Mecklenburg Environmental Coalition 943 Henley Place Charlotte, North Carolina 28207 l
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Attachment 1 Hydrologic Engineering Branch l
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3 g g approximately 560 ft (171 m) long extending'icross a small peninsula and dis , '
charging into Lake Wylie. Discharge capability of the pipe is calculated 't using methods descr;ibed in the Handbook of Hydraulics (Reference 11). I i -
A graphical routing of the flood results in a maximum raiervoir elevation of N 581.3 ft (177.2 m) during the sixth hour of reinfall. Jhis' excess inflow into t, thereservoiris620Acft(7.6x10s,3)witha:surchafgeonthepondof10'.3'ft;'
(3.1 m). g g N t .i !
The maximum wave height is calculated using farmulae developed by Saville, f McLendon and Cochran as oatlined in Water and Wastewater Engineerina (Reference .
12). The maximum wind ve!ocity for the area,' recorded at Charlotte, North Carolina, is 57 mph (92 kpu) for a one minute a'verage from the northeast.
I Translating the velocity into its component for the direction of maximum /
fetch (east), the maximum velocity is 40 mph (64 kph) and the fetch length '
is 0.42 mi (0.68 km). The significant wave height is calculated to be 1.3 ft (0.4 m). A ratio of wave height to runup (H p/H 3
), calculated by the methods previously described, is 0,3. The maximum height of the wave on the slope includingtherunupis1.{ft(0.3m).
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,,' j Thus, the maximum flood' de'vation incYudin'g wave ar.d runup becomes 58?. 3 ft t msl (177.5 m). The crest elevation is sett at 595.0 ft (18f.4' m) tc safely y
accommodate the highest flood surcherge downstream for Lake Wylie. Therefore, /
there is an 12.7 ft (3.9 m) fresboard on the upstream side to contain the -
PMF surcharge, wave height, and wade ernup. '
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The analysis of a PMF peak on Lak!e' Wylie occurring coincident with a LPNF Q240.17 peak on the SNSWP was not evaluated because it was not considerad cre'dibb that the two PMF peaks would cofncide. \
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i The SNSWP dam is protected from wave action by riprap as sh2w.n sin Figure 2.5.6-1.
The total loss of volume in the SNSW pcod due to sedimentation auring the 40
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year plant life is calculated by'Use of the universal soil 1os,s equation 1 l (Eq (1) Reference 19) to be 5.2 ac-ft. '
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! The resulting distribution of this sedimant witnin the pond is dependent on l
several characteristics of the expected sediment load indicatcs.that,about '
! two-thirds of the sediment will settle in delta type formations. Tb determinedbyemployingtherelationshipL=v/sxd(Reference [19)c,isw ' '
! s Where: L = length required for particle to settle '
4 d = depth of settling zone -
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The forward velocity in the pond is taken conservatively as 0.1 ft/sec, and the depth of settling zone is taken to be 20 ft. The fall velocity of the i
sediment is found from Stoke's Law v = g.g s
Where:
t D = diameter of particle j s a
( p = viscosity of water (2.359 x 10 5 lb.5/ft2) l\ ys= density of sediment (165 lb/ft3)
>($1 f y = density of water (62.4 lb/ft3)
'Using the grain size analysis for site soils, it is calculated that approxi-mated two-thirds of the sediment entering the pond would settle rapidly (L < 310 ft). This would lead logically to the formation of delta deposits in the head water areas of the pond. This conclusion is substantiated by data from existing resevoirs, presented in Reference 20. The one-third or approximately 1.7 ac-ft of sediment which does not deposit in the upper regions of the pond can be assumed to distribute uniformly in the form of bottom set deposits in the vicinity of the dam and SNSW intake structure.
This amount of deposition should have no adverse impact on the operation of the SNSW intake structure. Soundings will be taken around the SNSW in-take structure prior to fuel loading and at 5 year intervals thereafter to assure that sediment deposits will not adversely affect the operation of the NSW System.
Operation of the pond as the ultimate heat sink is described in Section 9.2.8.
2.4.9 CHANNEL DIVERSIONS The source of cooling water for Catawba Nuclear Station is Lake Wylie. There are seven reservoirs on the Catawba River upstream from Wylie Dam, all of which are owned and operated by Duke Power Company. Within limits set by the operat-
. ing licenses of these dams and dam leakage, the minimum discharge to Lake Wylie l is controlled by Duke Power. No present means exist to divert or reroute other than minor amounts of water used for municipal supply.
In the event of the loss of Lake Wylie, the Catawba Station could be safely shut down using the Standby Nuclear Service Water Pond.
2.4.10 FLOODING PROTECTION REQUIREMENTS The SNSWP dam top elevation of 595.0 ft (181.4 m) msl, is adequate for the maxi-mum flood level of 592.4 ft (180.6 m) ms1. It is designed to withstand wave wash
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l due to a coincidental wind wave runup by an overland wind of 40 mi (64 km) per hour.
The north end of the plant yard at the end of the water intake cove is protected l from wave action by a riprap cover. The rip rap is class IA, a 2 ft. (0.6 m) c 2.4-15a Rev. 7 l
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to provide a means for groundwater to flow from beneath the fill concrete into .!
the foundation underdrain. The three-foot penetration of these drilled holes insures that interception of rock joints is obtained. The 3 ft (0.91 m) depth is determined from the dip and spacings of the joints in the rock. The joint- .
ing in the powerhouse area is demonstrated in construction photographs shown in Figure 2.4.13-19. ,
Combined with the foundation underdrain is a continuous exterior wall drain.
This exterior wall drain consists of a 2 ft (0.61 m) minimum thickness zor.ed i
sand and stone f'lter placed vertically from the bottom of the excavation up to an elevation of 589+0 ft (179.5 m) asl (4.5 ft (1.37 m) below yard grade),
l and a 12 in (30.5 cm) diameter perforated corrugated metal pipe which is con-tinuous horizontally around the exterior wall near the bottom of the zoned fil-i ter. The zoned filter consists of an outer layer of fine material which sur-rounds an inner layer of coarse material. Both filter layers conduct seepage as well as surround the perforated drain pipe.
Figure 2.4.13-17 shows the gradation limits of the fine and coarse filter material derived from field gradation tests. Also shown on Figure 2.4.13-17
- is the backfill design gradation. Figure 2.4.13-18 shows the gradation l limits of the coarse filter material placed a minimum of l'-0" around the i perforated drain pipe. The gradations shown satisfy the following criteria
- 1) D15 (Base) < 5 085 (Filter) -
- 2) 015 (Base) ,
D1.5 (Filter) - 4
- 3) D85 (Filter)
Q241.7 Perforated Pipe Hole Diameter 11 The following values were used in computing the filter criteria:
- Maximum D15 (Coarse) = 8. 2m (Figure 2.4.13-17)
Minimum D15 (Coarse) = 1.4mm (Figure 2.4.13-17)
Minimum 085 (Coarse) = 9.5mm (Figure 2.4.13-18)
Average D15 (Fine) = 0.32mm (Figure 2.4.13-17)
Average D85 (Fine) = 1.7mm (Figure 2.4.13-17)
D85 (Backfill) = 0.63mm (Figure 2.4.13-17)
D15 (Backfill) = 0.013mm (Figure 2.4.13-17)
Perforated Pipe Hole Diameter = 3/8 in. = 9.5mm The following calculations verify that the filter criteria are satisfied:
Backfill and Fine Filter:
015 (Fine) = 0.32mm = 0.5 D85 (Backfill) .63mm 2.4-27 Rev. 7
CNS .
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system. In an assumed time of 15 minutes before the isolation valves are closed, 35,400 gallons of water is pumped into the system. After the valves are closed, an additional 86,000 gallons from the pipe will drain into the system, during an estimated 40-minute time period.
Water from the postulated pipe break flows through the zoned wall filter where it is intercepted by the flow channels and perforated pipe which carries the water to all three sumps. The total capacity of the six pumps is 1350 gallons per minute. This compares to the postulated induced flow rates of 2360 gal-lons per minute for the 15 minutes prior to shutting the isolation valves and the 2150 gallons per minute after the valves are closed. The net difference between the amount of water draining into the system and the amount of water pumped out of the sumps is approximately 47,150 gallons. The storage capacity of the three sumps (below pump level) is 48,000 gallons, thus the sumps alone could store the 47,150 gallons excess. The storage capacity of the flow chan-nels in the underdrain system is approximately another 16,000 gallons, giving an added margin of storage capacity.
A postulated break in the Condenser Circulating Water piping is also investi-gated. The Auxiliary / Reactor Building groundwater drainage system is isolated from the CCW piping by a nominal 17-foot (5.2 m) minimum thickness impermeable layer of compacted earth backfill as shown in Figure 2.4.13-22. If a break in ltheCCWpipinginducestheflowintotheTurbineBuildinggroundwaterdrainage system, no effect on the Auxiliary / Reactor Building system will be realized since the two systems are totally isolated.
A failure of the Condenser Circulating Water System inside the Turbine Building is considered highly unlikely. However, a rupture of two water boxes (one on each unit) in this system and the subsequent flooding is analyzed. Such a postu-Q410*28 lated rupture could induce 1,340,000 Ft3 of water into the Turbine Building.
The top of this water would be at elevation 375.4 ft. (175.4 m) ms1. A rein-forced concrete wall with a top elevation of 576.0 ft. (175.6 m) ms1 is de-signed to contain this water within the Turbine Building and prevents the water from flooding into the Auxiliary Building.
The groundwater environment in the immediate vicinity of the site will be sub-stantially changed by construction. The effects will be to decrease the slope of the water table and thus to increase the transit time of contaminants moving from the site to any discharge point. Since the bottom elevations of the str-uctures are below the natural water table, an underdrain system has been in-stalled to lower the water table. This will result in a minimum groundwater level of about elevation 540 feet ms1. in the Reactor / Auxiliary Building area and a depression of the water table with groundwater flow toward the Reactor /
Auxiliary Building area from all directions inside the radius of influence.
The groundwater level will approach the surface elevation of Lake Wylie near the lake shore. A groundwater level monitoring program has verified the ex-pected construction stage drawdown and will establish the stabilized elevation of groundwater outside the Reactor / Auxiliary Building walls.
Q241.7 Table 2.4.13-10 shows the latest results of the permanent groundwater mon-
- Q440.102 itoring. All wells are dry with the exception of Groundwater Monitor Well 4 2.4-32 Rev. 7
CNS v -
l which has groundwater at elevation 548.5 feet asl (1.5 feet below the top of the 4.0 feet thick foundation mat). A 4.0 fee + thick concrete mat will Q241,7 experience no resultant uplift load until submerged more than 9 feet. There-fore, the groundwater monitoring verifies the assumption that the groundwater drainage system eliminates uplift and hydrostatic forces on subsurface walls and foundation sats. ,
Twelve permanent groundwater wells are installed in the zoned wall filter around the perimeter of the Reactor / Auxiliary Building walls. Continuous l monitoring devices will be installed in six of the twelve wells to monitor the groundwater level in the zoned wall filter. In addition to the continuous monitoring devices, each of the six wells have three points of alarm to alert the plant operator to a rise in groundwater. The first alarm is set at the elevation of the top of the adjacent floor slab in the building. The second alarm point is set five feet and the third fifteen feet above the top of the adjacent floor slab. Any alarm will alert the plant operator to a groundwater rise. The remaining six wells without monitoring devices will be available to dewater the zoned wall filter in the unlikely event of a rise in groundwater.
Remedial action as described in the Technical Specifications would be initiated when groundwater rises above the elevation of the floor slab in the wall drain.
The location of the twelve groundwater wells is shown in Figure 2.4.13-14.
In addition to the twelve groundwater wells around the perimeter of the Reactor /
Auxiliary Building walls, sixteen temporary observation wells are located at strategic locations to monitor groundwater levels at the site. The locations of the observation wells are shown in Figure 2.5.1-12.
Q240.19 The latest results of the temporary observation well monitoring are provided in Table 2.4.13-11.
2.4.14 TECHNICAL SPECIFICATION AND EMERGENCY OPERATION REQUIREMENTS With the exception of the Technical Specifications describing remedial action required in the event of a rise in groundwater as described in Section 2.4.13.5, the hydrologic design bases developed in the preceding sections do not neces-sitate technical specifications or emergency procedures to ensure safety-related plant functions. In the event of an accidental radioactive release, indus-tries and municipalities that utilize Lake Wylie and the Catawba River down-stream as a water supply are notified of possible contamination.
I 2.4-33 Rev. 7
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- 17. Prickett, T.A. and Lonnquist, C. G., " Selected Digital Computer Techniques for Groundwater Resource Evaluation," Illinois State Water Survey, Urbana, Illinois, Bulletin 55, 1971.
- 18. Harr, M.E., Groundwater and Seepage, McGraw-Hill Book Company, New York, 1962, p. 43-44. ,
- 19. National Research Council, Transportation Research Board, NCHRP Report 70, Design of Sedimentation Basins, Washington, D. C., 1980.
- 20. Chow, V. T. Handbook cf Applied Hydrology, McGraw-Hill Book Company, New York, 1964, p. 17-23.
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Attachment 2 Quality Assurance Branch
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260.0 QUALITY ASSURANCE
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260.1 In Chapter 17.0 of the FSAR, Duke Power Company has referenced Duke (AR) Power Company Topical Report, Duke-1A entitled, " Quality Assurance Program." This report was recently revised (Amendment 5 letter to Haass from Wells dated March 30, 1981) and is currently under review by the Quality Assurance Branch. It is not clest in Section 17.0 of the FSAR which revision of the Duke Topical Report Duke Power Company intends to apply to the Catawba Nuclear Station. Therefore, clearly describe, by revision number and date, which issue of the Duke topical report will be applicable to the Catawba Nuclear Station.
Response
Topical Report DUKE-1A is intended to be a comprehensive, up-to-date description of Duke's Quality Assurance program for all Duke nuclear plants. Therefore, DUKE-1A, through and including Amend-ment 5, is applicable to the Catawba Nuclear Station.
260.2 Identify or reference in Chapter 17.0 of the Catawba FSAR, those (AR) safety-related structures, systems, and components under the control of the QA program.
Response
See revised Section 17.0.2.
260.3 Section 17.1.2.2 of the standard format (Regulatory Guide 1.70) re-i quires the identification of safety-related structures, systems, and components controlled by the QA program. You are requested to supplement and clarify the Catawba FSAR in accordance with the following:
a) The following items do not appear on FSAR Table 3.2.1-1, 3.2.1-2, 3.2.2-2, or 3.10-1. Add the appropriate items to the table and provide a commitment that the remaining items are subject to the pertinent requirements of the FSAR QA program or justify not doing so.
- 1. Station vents (stack) 2'. Chilled water system compression tank
- 3. Diesel generator engine fuel oil system engine driven pumps
- 4. Diesel generator engine fuel oil system strainers l
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,ge ser 8N io t c) meD de the 9 9gc to
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- 3. See revised Table 3.2.2-2 (Page 2).
- 4. See revised Table 3.2.2-2 (Page 2).
- 5. See revised Table 3.2.2-2 (Page 3).
- 6. See revised Table 3.2.2-2 (Page 3).
- 7. See revised Table 3.2.2-2 (Page 4).
- 8. See revised Table 3.2.2-2 (Page 4).
- 9. See revised Table 3.2.2-2 (Page 4).
- 10. No safety function, manufacturing standards applicable.
- 11. No safety function, manufacturing standards applicable.
- 12. Included in Reactor Vessel Internals, Table 3.2.2-2, Page 4a).
- 13. Part of Pressurizer (Table 3.2.2-2 (Page 4a)) and Reactor Coolant System piping.
- 14. The steam generator steam flow restrictors are integral with the steam generator steam outlet nozzle. The flow restrictors are qualified with and subject to the same QA program as the steam generators.
- 15. See revised Table 3.2.2-2 (Page 5).
- 16. See revised Table 3.2.2-2 (Page 5).
- 17. See revised Table 3.2.2-2 (Page 10).
- 18. See revised Table 3.2.2-2 (Page 10).
- 19. See revised Table 3.2.2-2 (Page 10).
- 20. See Section 17.0.2.1.1.
- 21. See Section 17.0.2.1.1.
- 22. See revised Table 3.2.2-2 (Page 9).
- 23. Penetrations are Class B. I
- 24. See Section 17.0.2.1.1 and revised Table 3.2.2-2 (Page 10).
l
- 25. See revised Table 3.2.2-2 (Page 8).
260-4 Rev. 7 New Page !
l
-- 1
,;= * #
- 26. See revised Table 3.2.1-1 (Page 2).
- 27. a) and b) See Tables 3.11-1 through 3.11-4. Cable trays are included in Table 3.10-1 (Page 21).
c) While fire stops are not safety-related and therefore not' covered by the Appendix B QA program, they are treated as fire protection-related and are subject to QA Category 3 requirements.
- 28. a) and b) See Tables 3.11-1 through 3.11-4. Cable trays are included in Table 3.10-1 (Page 21).
- 29. As discussed in Section 9.4.2.2, this radiation monitor performs no safety function during irradiated fuel handling operations and is therefore not subject to th6. requirements of the QA program.
Radiation monitors are discussed in Section 17.0.2.2.
- 30. See revised Table 3.2.1-1 (Note 6).
b) See revised Table 3.2.1-1 (Note 5).
c) The operational QA program includes provisions to assure that the design and implementation of modifications to the stations structures, systems and components is performed in a manner so as to assure that quality is maintained in a manner commen-surate with the remainder of the system which is being modified, or as directed by applicable regulation. In the specific case of modifications to the site and roof drainage systems, the modification process would insure that the flood vulnerability of safety-related structures, systems, and components would not be increased.
d) Safety related instrumentation and controls described in Sec-tions 7.1 through 7.6 plus safety-related instrumentation and controls for safety-related fluid systems are subject to the pertinent requirements of the QA program described in Chapter 17.
e) The fuel oil recirculation pump and the clean and used lube oil tanks transfer pumps provide supplementary, non-safety related services which are not essential for the operation of the diesel. Failure or loss of these components during a design basis earthquake would not hinder diesel operation. Under the guidelines set forth in Regulatory Guide 1.29, the fuel oil recirculation pump and the clean and used lube oil tank transfer pumps would not require seismic Category I design clas-sification. Since these components are not safety-related, they are not subject to the requirements of the QA program.
260-5 Rev. 7 New Page
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=
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', fertlee-Generater Founentles - III - I I - - = =
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- Sett and tester Presseres, Aseleg Eptement teams. Shipptag and becetulag , S Leeds Aroes
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- lit I I I * * * *
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- Ill - I - - = = *
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Tab 13 3.2.2-2 (Page 2) , l I {
- Summary of Criteria - Mechanical System Components .
( (7) (8) (9) ! (2) (3) (4) (5) (6) ' Selseic
- Tornado System Component or System Scope Safety Class Code QA Reqd. Location Rad. Source OBE DBE Wind Missile !
I FD Diesel Generator Engine Fuel Oil System a Tanks Day D 3 III-3 X DB X X X X Fuel Oil (16) D 3 III-3 X B - X X X X , Pumps . l Engine Driven Motor Driven Booster D D (18) 3 (18) III-3 X X D8 DB (18) X X X X X X Recirculation D NNS Manuf. - Standards - 0 - - - - - Filters - - 4 Recirculation D NNS Manuf. - Standards - 0 - Relief Valves D 3 III-3' X D8 - X X X X . Valves
- All Valves (Excluding IFD8, IFD9, D .3 III-3 X D8,B -
X,X X X IFD10, IFD11, IFD16, IFD17, IFD81, ' IFD82, IFD83, and 1FD84) '
- IFD8, IFD9, IFD10, IFD11, IFD16, D NNS B31.1 -
0 - IFD17, IFD81, IFD82, IFD83, and ' IFD84 Strainers d i Engine Driven D (18) (18) X DB - (18) X X l DB X X X X Motor Driven Booster D 3 III-3 X 1 FW Refuelina Water Systee i Refueling Water Storage Tar.k D 2 III-2 X 0 P X X X - l X X ; Refueling Water Pump . D NNS - - A8 P ' AB - - X X Refueling Water Recirculating Pump D NNS - - P A8 P - - X X Refueling Water Pump Strainer D - NNS - Valves D 2,NNS III-2, X,- AB P X,- X,- X X i B31.1.0 GH Hydrogen Systee
- - - - I Hydrogen Vessels , D NA VIII -
0 - Valves D NA- - - AB
! GN Nitrogen Systes . ,
)i Nitrogen Vessels D NA VIII,(17) - 0 -
Valves . D NA VIII - AB,TB - GS Hydrogen Bulk Storace. System Hydrogen Bulk Storage Cylinders D NA VIII,(17) - 0 - - - Valves D NA - - A8 KC Component Cooling System Component Cooling Surge Tank D 3 III-3 X A8 P X X X X Rev. 7
Tabla 3.2.2-2 (Page 3) - l
?
- l
{ Summary of Criteria - Mechanical Systes Components 3 (2) (3) (4) (5) (6) (7) (8) ('9)' Seismic Tornado Systee Component or System Scope Safety Class Code Q$Reqd. Location Rad. Source OBE DBE Wind Missile Component Cooling Pump D 3 III-3 X AB P X X X X* I' i Component Cooling Drain Sump Pump D NA - - AB P - -
'X X
' Component Cooling HX (tube) D 3 III-3 X AB -
X X X X (shell) D 3 III-3 X AB P X X X X l Valves D 2,3,NNS Ill-2, X X,- AB,C AB P X,X,- X,X,- X X - B31.1.0 KC Sump Pump Y. Strainer D NNS - - AB P - - X X , j
, KD Diesel Generator Coolina Water System r Cooling Water Heat Exchangers (tube) D 3 III-3 X DB -
X X X X (shell) D 3 III-3 X DB - X X X X i Pumps l Circulation D (18) (18) X DB - (18) X X Keep Ware D 3 III-3 X DB - X X X X Jacket Water Heater D 3 III-3 X DB - X X X X Standpipe D 3 III-3 X DB - X X X X 4 Temperature Regulating Valves D 3 III-3 X DB - X X X X ! Valves D 3 111 X DB - X X X X KF Spent Fuel Cooling System Pump . Fuel Pool Cooling D 3 III-3 X AB X X X X X 4 Fuel Pool Skimmer D NNS - - AB X - - X X ,
/ ! Fuel Transfer Canal Unwatering D NNS - -
AB X - - X X Fuel Pool Cooling Heat Exchanger p'-E ' (tube) D 3 ~ III-3 X AB X X X X X (shell) D 3 III-3 X AB P X X X X Fuel Pool Cooling Deelneralizer
. t D NNS VIII -
AB X - - X ,X i
~
F11ters :
'f Fuel Pool Cooling Pre-Filter D NNS VIII -
AB X - - X X f a Fuel Pool Cooling Post-Filter D NNS VIII - AB X - - X X L
,/: Fuel Pool Sklamer D NHS VIII -
AB X - - X X
? Fuel Pool Skimmer Strainer D NHS' VIII -
AB X - - X X j Fuel Pool Cooling Pump Strainer D 3 - X AB X X X X X i ls Valves D 3,NNS III-3, X,- AB X X,- X,- X X ly B31.1. 0 . . n *
.3 KR Recirculated Cooling Water System
, Valves (Note 22) D NNS B31.1.1 X AB,TB - - - - -
LD Diesel GNnerator Li$4 h System . ,
;q <
Clean Lube 011 Storage Tank NHS VIII - B - - - - - Used Lube Oil Storage Tank NHS VIII - B - - -
~
} Diesel Gen. Eng. Lube 011 Sump Tank 3 III-3 X . DB - X X X X l Diesel Gen. Eng. Lube Oil Transfer ( Pumps NNS Manuf. - Standards - DB - (18) X X + l Rev.{ i
._ _._ ~ . - -
l Tabis 3.2.2-2 (Page 4) Summary of Criteria - Mechanical System Components , (2) (4) (5) (6) (7) (8) (9) ! (3) Selselc - Tornado System Component or Systes Scope Safety Class Code QA Reqd. Location Rad. Source 08E CfE Wind Missile i l Engine Driven Lube 011 Pump (18) (18) X DB - (18) X X Clean Lube 011 Tank Transfer Pump NNS Manuf. - Standards - 0 - - - - - Used Lube Oil Tank Transfer Pump NNS Manuf. - Standards - 0 - - - - - Prelube 011 Pump 3 III-3 X D8 -
- X X 'X X Sump Tank Heaters 3 III-3 X DB -
X X X X i Full Flow Filters 3 III-3 X DB - X X X X i Lube Oil Coolers 3 III-3 X DB - X X X X , Prelube Oil F11ter 3 III-3 X DB - X X X X i
, l Strainers (18) (18) X DB -
(18) X X . 2 Relief Valves 3 III-3 X 08 - X X X X i Valves , (1) #1LD23, ILD28, ILD86, ILD89, NNS B31.1 - DB,0 - - - X,- X-s ILD67, ILD87, ILD88, ILD61,
.,'; ILD66, ILD68, ILD62, ILD63, '
{ ILD64, ILD65, ILD85, ILD53, and ILD58
^?" l (2) ILD19, ILD71, (18) (18) X DB -
(18) N X
#1LD17,ILD18,lD26,ILD4, ILD72, ILD2, l ILCt7, ILD47, ILD48, ILD32, * .-; ILD49, ILD78, ILD79, ILD56, ILD31, ILD57, ILD34, ILD101, ILD100, and ILD1 T- (3) A11 Other Valves 3 III-3 X DB -
X X X X j NB Boron Recycle Systes
; Pumps , 'A Evaporator Feed W NNS - -
A8 A - - X X
$ Reactor Makeup W NHS - -
A8 - - - X X y Tanks . ; Holdup (11) D 3 III-3 X A8 X X X X X
,' Reactor Makeup Water Storage (11) D NNS VIII -
0 - - - X - Reagent W NNS VIII - A8 - - - X X " hC Deelneralizers X X Evaporator Feed ', W 3 III-3 X AB 1 X X Evaporator Condensate W NNS - - AB P - - X X
. .l, Filters -
6 Evaporator Feed W 3 III-3 X AB X X X X ,X, Evaporator Condensate W NNS - - AB P - - X* X Evaporator Concentrates W NNS - - AB P - - X- X Evaporator - Gas Stripper Pkg. W NNS (23) VIII - AB X - - X
- X Evaporator Condensate Returo Unit D NA VIII -
AB - - - X X Valves . . , , D 2,3 III-2,3 X AB.C X X X X X Recycle fieldup Tank Air Ejector , X X Strainer D 3 III-3 X AB X X X Sample Vessels D NHS (10) X AB X - - X ' X NC Reactor Coolant Systee
/
Reactor Vessel W 1 111-1 X C X X X X X . Rev. 7 ) f
l Ttbis 3.2.2-2 (Page 5)
~
l Summary of Criteria - Mechanical System Components i; i-- (2) (3) (4) (5) (6) (7) . (B) (9) . ( Selsele Tornado 1 System Component or Systee Scope Safety Class Code QA Reqd. Location Rad. Source DBE DBE Wind Missile ND Residual Heat Removal Systee ' l RHR Pumps W 2 III-2 X AB X X X X X RHR Heat Exchangers (tube) W 2 III-2 X AB X X X X X ' '
'i .(shell) W 3 III-3 X AB P X X X X Valves D 1,2 III-1,2 X C,AB X X X X 'X .{
4 NF M Condenser Refrigeration System
. Ice Baskets W 2 (10) X C -
X X X X Ice Bed Doors W 2 (10) X C - X X X X NF Refrigeration Units W NA - - AB - - - X X . Ice Machine W NA - - AB - - - X X Air (4*111pg Units W NA (10) - C P - - X X Vahn D 2 171-2 X C.AB P X X X X j- Glycol Strainers W NA - AB - - - X X it, Ice Bin & Annex Cond. Units W NA - - AB - - - X X
- '.- Ice Bin W NA - -
AB - - - X X , Ice Annex . W NA - - AB - X X l
,,- Ice Bin & Annex Air Handlers . W NA - - -
'AB - - -
X X Ice Blower Package W NA - - AB - - - X X ! 4 Ice Cond. Cyclone Receiver W NA - - C - - - X X
,1 Rotary Valve Assembly W NA - -
AB - - - X X
+
NF Floor Cooling Defrost Heater W NA -
,- C - - - X X y NF Slab Cooling . W NA B31.1 -
C - X X X X NF Glycol Bypass Strainer W NA VIII - AB - - - X X t Pumps .
' t;b NF Glycol W NA - -
AB - - - X X i
; NF Glycol Mixing & Storage D NA VIII -
AB - - - X X }
/, Ice Making Solution Feed D NA VIII -
AB - - - X X ; l ', NF Floor Cooling W NNS - - C - - - X X i Tanks .
.-- Glycol Mixing & Storage - 0 NNS VIII -
AB - - - X X i Ice Making Solution Mixing D NNS VIII - AB - - - X X (7 NF Glycol Expansion W NHS VIII - C - - - X X
'[ NI Safety Infection System p
-;. Pumps Safety Injection X X
, W 2 P&V-II X AB P X X Boron Injection Recirculation W 3 P&V-III X AB -
X X X X { _ UHI Makeup and Testing D NNS - - AB P - - X X Tanks ..
.,' l . .
UHI Water Accum61alor W 2 III-2. X AB P X X X X UHI Mitrogen Accumulator W 2 III-2 X AB - X X X X UHI Surge W 2 III-2 X AB P X X X X Accumulator W 2 III-2 X C P X X X X Boron Injection W 2 III-2 X AB P X X X X BI Surge (13) W 3 III-3 X AB - X X X X Rev. 7 j fl
l' l Tabla 3.2.2-2 (Page 8) Summary of Criteria - Mechanical Systee Components . ( (2) (3) (4) (5) (6) (?) , (8) (9) Selsele - Tornado i System Component or Systee Scope Safety Class Code QA Reqd. Location Rad. Source 08E 08E Wind Missile j i RY Exterior Fire Protection , Fire Protection Pumps. D NA (15) X 0 - - - - - Valves D NA - X 0,5 - - - - - SA Main Steam to Aux 111ary Equipment f Valves (Note 22) D 2 III-2 X AB,DH - X X X X , SB Main Steam Bypass to condenser System Turbine Bypass Valves D NA - - TB - - - - ' - SM Main Steam Systee
- Main Steam Isolation Valves D 2 III-2 X C;l -
X* X X X
< SV Main Steam Vent g Atmosphere System Power Operated Relief Valves D 2 III X DH -
X X X X Safety / Relief Valves D 2 III-2 X DH - X X X X TE Feedwater M Turbine Exhaust Valves (Note 22) D 3 III-3 X AB,DH - X X X X 4 . VA Auxiliary Buildinc Ventilation Systen
} "
O Aux. Building Radlation Air Supply Air Handling Units D NNS - X AB P - - X X 1 Aux. Building General Air Supply Air Handling Units D NNS - X AB P - - X X i , Aux. Building Filtered Exhaust Filter ;
! Trains D 3 (12) X A8 P X X X X !~
i Aux. Building Filtered Exhaust Fans D 3 AMCA(14) X AB P X X X X :
.n Auxillary Building General Exhaust ! / Fans D NA - - -
A8 - - - X X Misc Aux. Bldg Air Handling Units ll l Q X, ,X,
~
By Cont. D NA - - A8 P - - Aux 111ary Building Filtered Exhaust Ducting D 3 X AB P X X X' X l VB Breathina Ap System Valves (N'te o 22)' '
- D 2,NNS NA III-2, X SB.A8,R8 - - - - -
831.1.1, VC Control Area $ Systee Control Room Air Handling Units D 3 III-3 X A8 P X X X X AMCA(18) i Control Room Area Pressurizing Filter Train D 3 (12) X A8 P X X
- X X Rev. 7
Tabla 3.2.2-2 (Page 9) ' l Summary of Criteria - Mechanical System Components ;; . I (2) (3) (4) (5) (6) (7) (8) (9) : Selselc - Tornado
. Systee Component or System Scope Safety Class Code QA Reqd. Location Rad. Source 08E DBE Wind Misslie i Battery Room Exhaust Fans D 3 AMCA(14) X AB -
X X X X- f Switchgear Room Air Handling Units D 3 (12) X A8 - X X X X I III-3 VD Diesel Building Ventilation Systee j Diesel Building Normal Ventilation , Fans D NNS - DB - - - X X . Diesel Building Normal Heating Colls .D NHS - DB - - - X X ;
, Diesel Building Ventilation Filters D NNS -
X DB - - - X X
. Diesel Building Generator Ventilation .
Fans .D 3 AMCA(14) X 08 - X X X X VE Annulus Vent System . Annulus Vent Fans D 3 AMCA(14) X A8 X X, X' X X A Annulus Vent Fliter Trans. D 3 AMCA(12) X A8 X X X X X h Motsture Separator D 3 AMCA(12) X A8 X X X X X Valves (Dampers) D 3 AMCA(12) X A8 X
- X X X X Ducting D 3 X A8 X X ,X X X
{ VF Fuel Pool Ventilation Systes , [ Fuel Handling Area Air Handling Unit D NNS - - AB ~P X X Fuel Handling Area Exhaust Filter 4 Train . D 3 (12) X A8 P X X X X Fuel Handling Area Exhaust Fans D 3 AMCA(14) X- A8 P X X X X { l E VG Diesel Generator Incine Starting Air Systee I f E l Air Compressors . D NNS 831.1 X 08 - (22) X X } Starting Air Tanks D 3 III-3 X DB - X X X iX
';' D/G Starting Air After Cooler (shell) D 3 III-3 X DB -
X X X X (tube) D 3 III-3 X DB - X X X X
-' Starting Air Dryers D NNS blII X DB -
(22) X X l Reifef Valves D 3 III-3 X DS - X X X X Valves 2 (1) #1VG1, 1YG2, IVG3, IVG4, D NNS 831.1 - D8 - X X X X IVG45, IVG46, IVG47, IVG48, . . z' IVG36, and 1YG80
~z l (2) Valves between starting air D NNS Manuf. - Standards - DB - - -
X' X ca aftercoolers and check valves 9 IVGs, IVG6, IVG49, and IVG50 R (3) (Yalves Supplied.Dn Engine D (18) (18) X DS - (18) X X
&l Skid) IVG25,.1VG26, IVG27, IVG28, IVG29, 1VG30, IVG31,
- IVG32, IVG69, IVG70, IYG71, IVG72, IVG73, IVG74, IVG75, and IVG76.
(4) All Other Valves D 3 III-3 X ' DB - X X X X Rev. 7
[ Tabla 3.2.2-2 (Page 10) [ h - Summary of Criteria - Hechanical System Components . ( >l .> (8) (9) 4 (2) (3) (4) (5) (6) (7) G Seisele . Tornado
,y Systee Component or System Scope Safety Class Code QA Reqd. Location Rad. Source D8E DBE Wind Missile 1 VN Diesel Generator Engine Air and Exhaust Systee i f
5
< m Intake Filter D (18) (18) X DB -
(18) X X l 9 Intake Sliencers - D (18) (IB) X DB - (18) X X l 2 Exhaust Silencers D (18) (18) X DB - (18) X X , Fr Valves D 3 III-3 X DB , - X X X X l VP Containment h and, Containment Venttiation Systee f [ Containment Purge Air Handling Units D Containment Purge Air Exhaust Fans .D NNS NNS AB AB P P X X X X Containment Purge Air Exhaust Filters D NNS - - AB P - - X X .
' Incore Instr. Room Purge Exhaust Air .
Handling Unit D NNS - - A8 P ,- X X
- Incore Instr. Purge Supply Air
-R Handling Uhlt D NNS - -
AB P - - X X p Valves D 2 III-2 X A8,C P X X X X VQ Containment Air Release and Addition Systee . Filters . D NNS - - AB P -
-) X X Valves D 2 III-2 X AB,C P X X X X
-f- Fans D NA - -
AB P X X
, VV Containment Ventilation Systee i ,. i
-.'-') Upper Containment Ventilation Units D NNS - -
C P X X Upper Containment Return Air Fans D NHS - - C P - - X X
- - - X X CRDM Vent Fans D NNS -
C P
- - X X Lower Containment'. Vent Units D NNS - -
C P [ Containment Aux. Charcoal Filter , ( ' Units Containment Aux. Charcoal Filter D NNS - - C P - - X X
~
Unit Fans D NNS - - C P X X
.f; - -
+ Incore Instr. Room Ventilation Units D NNS - -
C P X X
-h VX Containment Q Return and Hydrogen Skimmer Systes
, Air Return Fans D 2 AMCA(12) X C X X X X 'X '
. Hydrogen Skimmer Fans. D 2 AMCA(14) X C X X X X X
'? Valves D 2 III-2 X C X X X X X
! VY Containment Hydrogeri Sample & Purge Systes Containment Hydrogen Purge Inlet - - -
X X Blower D NNS (10) RB Containment Sample Blower X. - - X X l D NNS (10) AB Post Accident Elec. Hydrogen Re-combiner Pkg. W 2 (20) X C - X X X X l t ReV. 7 l .I
T Tabla 3.2.2-2 (Page 11) , Summary of Criteria - Nechanical System Components 1,
.; ' (2) (3) (4) (5) (6) (7) (B) (9)
Selsele Tore:lo
; Systee Component or Systen Scope Safety Class Code QA Reqd. Location Rad. Source OBE DBE Wind Missile !
Containment Sample Vessel D NNS (10) AB X -
, X X I Valves (Note 22) , , D 2,3,NNS III-2 AB,C X X X X X t III-3, j B31.1 l VZ Nuclear Service Water M Structure Ventilation System Ventilation Fans , D 3 ANCA X RN -
X~ X X X
, Dampers D 3 ANCA X RN -
X X X X
, r Normal Fans D NNS ANCA -
RN - X X X X i WC Conventional Waste Water Treatment Syst'es . Pumps WC Settling Fond Nixing D NA - - 0 - - -
\
)
WC Recirculation D NA - ' - 0 - - - - -
)
Q s, WC Caustic Feed . D NA - - 0 - - - - - V WC Cheetcal Addition Pit Sump D NA - - 0 - - - - - ] WC Settilng Pond Nixing Pump Pit f.g Susp . D NA - - 0 - - - - - WC Final Haldup Pond Inlet & Outlet Valve Pit Sump D NA - - 0 - - - - -
' WC Sulfuric Acid Storage Tank Contaireent Sump D NA - -
0 - - - - - Transformer Base Drainage Sump o D NA - - 0 - - - - - WC Caustic Storage Tank D NA D100 - - - - - - I4 Valves - D NA - - SB - - - - - d il. .' ( WE Equipment Decontamination Equipment Decontamination Pump and Accumulator D NA - - AB - - - X X Equipment Decontamination Tank D NNS D100 - AB - - - X X J Valves . D 2 (21) X C.AB X X X X I Fuel Cask Decon Pit. Sump Pump Strainer D NNS (10) - AB P - - X X l Fuel Cask Decon Pit. Sump Pump D NNS - - AB P - - X X
,/ WG. Gaseous Waste Disposal Systes Waste Gas Compressor Package W 3 III-3 X AB X X X X X Waste Gu Hydrogen Recombiner Pkg. W 3 (10) X AB X X X X X Waste Gas. Decay Tank., , D 3 III-3 X AB X X X X X Waste Gas' Sample Vessel: D NNS (10) -
AB X - - X X
..', Gas Decay Tank Drain Pump W NNS - ' -
AB X - - X X Waste Gas Decay Tank Gas Traps W NNS - - AB X - - X X
.Noisture Separators D 3 III-3 X AB X X X X .X Valves D 2,3 III-2,3 X C.AB X X X X X
! Rev. 7
Tab 12 3.2.2-2 (Page 14) , l - Summary of Criteria - Mechanical System Components ;; (2) (3) (4) (5) (6) (7) (8) (9) Selsele - Tornado ,
. System Component or Systee Scope Safety Class Code QA Reqd. Location Rad. Source CBE D8E Wind Missfie ,
4
< Radwaste Transfer Skid D NNS 831.1 -
AB X - - X X
' Dewatering Pump Skid, D NNS 831.1 -
A8 P - - X X WZ Groundwater Drainage Systee Aux. 81dg. Groundwater Drainage Sump Pumps D 3 III-3 X 0 - X X X X . Turbine B1dg. Groundwater Drainage Sump Pumps D NA (10) - 0 - - - X X X X
. .'. Valves 0 -
, D 3 III-3 X X X YA Conventional Cheetcal Addition System ' .
Valves D NNS 831.1 - A8,TB,St. -
- .;; YC Control Area Chilled Water Systee l Control Area Chl11ed Water Pumps' D 3 III-3 X A8 P X X X X l Control Area Chiller D 3 III-3 X AB P X X X X YD Drinking Water Systee .
fl'
+
Valves (Note 22). D NA 831.1.0 X AB - X X - -
!c, : YJ Computer Area Chilled Water System j
Computer Room Chillers D NNS - 58 - - - * - -
. . 't. -
c.p. Computer Room Ch111er Pumps D - 58 - - - - q b- YM Makeup Deelnera11 red Water System Valves (Note 22) D NA 831.1.0 X A8 - X X - Containment Isolation Valves D 2 III-2 X AB,C - X X X X
; ~.-:. '? ZD Diesel Generator Engine Crankcase Vacuum Systee Iff. Valves D 3 III-3 X DB -
X X X X s
. +-
a
. b .' '. .' , 1 j \'
s Rev. 7
TABLE 3.10-1 (Page 21) ELECTRICAL EQUIPMENT SEISMIC QUALIFICATION EQUIPMENT CATEGORY EQUIPMENT QUALIFICATION QUALIFICATION
& OESCRIPTION VENDOR METHOD REFERENCE VII. Other Equipment Radiation Monitors General Atomic Test G.A. Test Report E-254-960 l Safety Valve Position TEC Test / Analysis TEC Report 517-TR-01,
. Indication 02, and 03 Hydrogen Analyzers Consip Delphi, Inc. Test / Analysis Project No,~1035-1, Rev. 2 Control Room Area Chillers Carrier Test / Analysis Report No. A-133-77 Dated 9/19/77 (CNM-1211.00-0071) Electric Hydrogen Westinghouse (NSSS) Test / Analysis WCAP-7709 Sup. 1-4 Recombiner WCAP-7820 Sup. 1-4 i (MCM-1399.36-0004) ESF Filter Train Alison Later Later Fire Protection System Electric Heater and Control Indeeco Analysis Indeeco Report No. EDI-1365 Control Panel (CNM-1211.00-440) l Cable Tray Metal Products Test / Analysis CNC-1139.14-13-003 Rev. 7
', 4 . ,- s ,-
g. 1 A h
>t i O
,I
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).
t o ( 4 - p (
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1 h Attachment 3
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s ' s. Chemical lEngineeringBranch , Y t s t * [ T O
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}
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ad . . i.- TABLE 6.1.2-2 g- . . k .,. .
^
Organic Materials Inside Containment - Coatings and Paint Mass,1bsiPerUnit) J ^ Carbon Steel
.^
- Epoxy Topcoat 4,075 Concrete Epoxy Surfacer 17,560 Epoxy Topcoat 10,857 Electrical Cable Insulation l Chlorosulphonated Ethylene Propylene Rubber Polyethylene - 16,662 Flame Retardant Cross Linked Polyethylene Flame Retardant Ethylene Propylene Motors (Duke Scope Only) _
D439 Zinc Chromate Alkyd Enamel 22.6 lbs Nomex Insulation 27 lbs.
;* Ice Condenser Equipment Amount per Unit i
E P T Sponge Rubber Foam 100 lbs. s Scotch Grip 34, 3M Co. Adhesive 55 gal. R T V Sealant, G. E. 1200 400 lbs. Silicone Sealant Mylar 100 lbs. Oils Reactor Coolant Pump Motors 1260 gal.
, Electric Motor Operators (Valves) 70 gal.
/
- Steel surfaces are primed with 2 mils of a coating that is 83% zinc in a 4 silicate binder.
g' Rev. 7
~+*
m.-_.
f Attachment 4 Auxiliary Systems t I
+
1 l l l l l 1
--- - - ----m_,__ __ _ . _ _ _ , _ _ _ _ _ _ _ ,_ _, , _ _ ,
l
. CNS
' ~
., l
~ service water temperature, and the water separator removes any water condensed '
in the cooling process. The air receivers smooth out any pressure surges.
~
Downstream of the air receivers, the station air headers carry station air throughout the plant. 9.3.1.2.3 Breathing Air System Breathing air is supplied by two breathing air compressors. The compressors discharge to two water separators which remove water in the air before it flows to the two breathing air receivers which serve to smooth out the air flow. The receiver discharge lines join and supply breathing air to various locations in the Auxiliary Building and inside the Containment. 9.3.1.3 Safety Evaluation The compressed air systems are designed to provide dependable sources of compressed air for all station uses. Sufficient redundancy is provided to give a high degree of reliability to the air supply at all times. Sufficient air receiver capacity is provided to meet system high air demand transients. All the air compressors are normally supplied with electrical power from the station M.. ired bus which allows them to receive electrical power from either unit. Failure of the compressed air systems will not render any safety system equipment or its function inoperable. A loss of instrument air during an ac-cident or station blackout would cause all pneumatically operated valves in the station which are essential for safe shutdown to fail in the safe position. The instrument air compressors and air dryers can be manually loaded on the blackout bus. This provision is made to facilitate shutdown, especially dur-ing a Control Room evacuation coincident with a statior, blackout. The reliable power source for the compressors in this case is the blackout bus, and the re-liable cooling water source for the aftercoolers, intercoolers, and oil coolers is the Nuclear Service Water System.
'A listing of the valves that can be operated from the Auxiliary Shutdown Com-iplex is listed in Section 7.4.7.
9.3.1.4 Instrumentation Application Sufficient instrumentation is provided to monitor system performance and to control the system automatically or manually under all operating conditions. 9.3.1.5 Tests and Inspections 1 The instrument air system is fully tested and inspected in accordance with ap-propriate recommendations of Regulatory Guide 1.80 prior to initial operation as described in Chapter 14. The air at the discharge of the air dryers is Annually, the air at
',the checked and verifiedistotested filter discharge have an foracceptable dew pointdew andpoint.
particulate contamination. Air samples are taken at selected remote locations of the instrument air ' system and checked for oil and particulate matter as recommended in Regulatory Guide 1.80 and in accordance with MC11.1-1976 (ISA-S7.3). Adequate operating performance monitoring assures system integrity. 9.3-2 Rev. 7 m_ - - _ - . __ um_ ._ -_ --
)
1 - CNS 410.15 Provide a listing of all. light loads (those of weight'less than one (9.1.4) fuel assembly) carried over the open reactor vessel or the spent fuel
. ~_
p ool including their kinetic energy on impact with spent fuel and dis-cuss the consequences of dropping of these loads on stored fuel. It is our position that dropping of these loads not result in release of radioactivity in excess of that assumed in the design basis fuel han-dling accident.
Response
The consequences of the drop of loads lighter than a fuel element will be less than the drop of a single fuel element as reported in Chapter 15 of the FSAR. The design of the tools and the fuel build- , ing cranes prevents the tools from dropping onto the fuel from a great height. Fuel handling tools over 100 pounds are all over 30 feet in length. Because of the height of the fuel building crane these tools can only be carried a few feet above the fuel. With the short vertical drop distance and the low weight per foot of length involved, there is no real probability of damage to the fuel. The major fuel handling tools (listed below) all have weights under 18 pounds per foot and are not carried high above the fuel. All other potential loads will have weights under 100 pounds and pose no threat to the fuel assemblies. Therefore, the single fuel , assembly drop accident in Chapter 15 is the maximum credible accident involving dropped loads and spent fuel damage. FUEL ASSEMBLY HANDLING TOOLS Name Weight- Length RCC Thimble Plug Handling Tool 249 Lbs. 36'8" Spent Fuel Assembly Handling Tool 477 Lbs. 35'4" BPRA Handling Tool 661 Lbs. 38'2" Irradiation Sample Handling Tool 297 Lbs. 34'7" 410.16 Figure 9.5.4-10 indicates that the nuclear service water yard piping (9.2.1) crosses the non-safety-related condenser circulating water system piping. Gescribe the protective features provided for the nuclear service water piping at these crossover points against the effects resulting from failed condenser circulating water pipe in a SSE. It is our position that the integrity of the nuclear service water sys-tem be maintained in a SSE.
Response
See revised Section 9.2.1.2.1. 410-8 Rev. 7
Attachment 5 Power Systems Branch
. ~ . - . . - . _ _ _ _ _ _ _ _ _ _ _ _ _
CNS . ' ~ As shown in Figure 8.2.1-7, these two physically independent 230kV circuits . connect the switchyard to the~two half-size unit step-up transformers and
, through the plant distribution system to the onsite emergency power system
- buses. These two circuits maintain their physical independence from the -
switchyard to the onsite emergency power buses. The isolation of the two i circuits from the unit generator is accomplished by two generator circuit breakers. The design concept utilizing two generator circuit breakers and two half-size unit step-up transformers provides two immediate access circuits for supplying offsite power to the unit's safety systems. The offsite power system is designed to minimize the probability of losing electric power from any supplies as a result of or coincident with the loss of the unit generator, the transmission network, or the onsite electric power supplies. Compliance with General Design Criterion 18 The requirements of General Design Criterion 18 are implemented in the design of the offsite power system. The design permits periodic inspection and test-ing of important areas and features. The design includes the capability to 4 periodically test the operability and functional performance of the components of the systems as a whole and under conditions as close to design as practical. 8.2.1.5 Offsite Power System Operational Description Each nuclear generating unit at Catawba is pro,ided with two independent immediate access circuits of offsite power. Prior to and during start-up of the nuclear unit, the Unit Auxiliary Power System receives power from the 230kV transmission. system through these two independent circuits, the two independent unit step-up transformers, and the two independent sets of unit , auxiliary transformers. During this period, the generator circuit breakers l and their associated motor operated disconnect switches are open. After the unit generator has been brought to rated speed and its field applied, the three phase MOD switches located on each side of the two generator circuit breakers are closed. The unit generator is then connected to the system by closing the generator circuit breakers. Automatic and manual synchronization are provided and both are supervised by synchronizing relays. During normal operation, each unit is connected to the transmission system via the two gene-rator circuit breakers and the two power transport circuits resulting in high unit operational reliability and availability. 8.2.1.5.1 Generator Circuit Breakers The projected momentary (peak) fault current at Catawba with the addition of future lines and generating capacity exceeds the rating shown in the McGuire Safety Evaluation Report (NUREG-0422). Accordingly, the circuit breakers have been tested at 920 and 935 KA close and latch. The breaker contacts were inspected after completion of the test by both Duke Power Company and Delle-Alsthom representatives. No contact wear was observed since no arcing occurred during this test. However, slight pittings and shifting of the con-tacts inherent to the electromagnetic stresses were noticed. 8.2-4 Rev. 7
~
CNS
~The above test and inspection was conducted in accordance with' applicable portions of ANSI C37.09-1970 Standard.
- l The other ratings of the generator breaker as listed in McGuire FSAR envelope the requirements for McGuire and Catawba. _
8.2.1.5.2 Offsite Power System Protective Relaying The offsite power system for each unit is divided into three distinct relay protection zones encompassing (1) the unit generator, (2) preferred power
~
train A and associated transformers, and (3) preferred power train B and associated transformers. This protective relaying system is designed to ' remove from service with precision and accuracy any element of the offsite j power system subjected to an abnormal condition that may prove detrimental to the effective operation or integrity of the unit. I The primary protective relaying scheme for the offsite power system is zone-over-lapping relaying with backup relaying for protection against primary relaying failure. The offsite power system protective relaying zones are shown on Figure 8.2.1-8. Additionally, the types of relays used in each zone are also listed on this i figure. 8.2.1.6 Reliability Considerations The Duke transmission system is designed to conform to the reliability criteria established by the Southeastern Electric Reliability Council (SERC). The reliability criteria assures that each Of the SERC member systems is designed to avoid system cascading upon the occurrence of any one of the following:
- 1. l.oss of Generation
, A. Sudden loss of entire generating capability in any one plant.
- 2. Loss of Load 1
A. Sudden loss of large load or major load center
- 3. Loss of Transmission A. The outage of the most critical transmission line caused by a three-phase fault during the outage of any other critical transmission line, or B. Sudden loss of all lines on a common right-of-way, or C. Sudden loss of'a substation (limited to a single voltage level within the substation plus transformation from that voltage level),
including any generating capacity connected thereto, or D. Delayed clearing of a three phase fault at any point on the system due to failure of a breaker to open. 8.2-5 Rev. 7
... CNS .
a, . - The six station cooling towers and their associated motor control centers are
' divided into three groups such that a Unit 1 and a Unit 2 cooling tower are fed'from the 13.8kV system through a common feeder. Feeders are arranged so that two' cooling towers are fed from each unit's 13.8kV system and two may be fed from either unit. An interlock scheme is provided to preclude the possi-bility of connecting the two units together at the 13.8kV level through the cooling tower feeder breakeis.
The above design allows two cooling towers on each unit to operate with the loss of one 13.8kV source. 8.3.1.1.2 Class 1E AC Power Systems 8.3.1.1.2.1 4160VAC Essential Auxiliary Power System The 4160VAC Essential Auxiliary Power System supplies power to those Class 1E loads required to safely shutdown the unit following a design basis accident. This system is also available to supply power to the 4160VAC Blackout Auxiliary Power System as discussed in Section 8.3.1.1.1.4. The 4160VAC Essential Aux-iliary Power System is shown on Figure 8.3.1-3. The 4160 volt essential system is divided into two completely redundant and independent trains designated A and B, each consisting of one 4160 volt switch-gear assembly, three 4160/600 volt transformers, two 600 volt load centers, and associated loads. Normally each Class 1E 4160 volt switchgear is powered from its associated non-Class 1E train of the 6900VAC Normal Auxiliary Power System as discussed
- in Section 8.3.1.1.1.3. Additionally, an alternate source of power to each i
4160 volt essential switchgear is provided from the 6900 volt system via two separate and independent 6900/4160 volt transformers. These transformers are shared between units and provide the capability to supply an alternate source of preferred power to each unit's 4160 volt essential switchgear from either unit's 6900 volt system. A key interlock scheme is provided to preclude the possibility of connecting the two units together at either the 6900 volt level or the 4160 volt level. Each train of the 4160VAC Essential Auxiliary Power System is also provided with a separate and independent emergency diesel generator to supply the Class 1E loads required to safely shutdown the unit following a design basis accident. Additionally, each diesel generator is capable of supplying its associated 4160 volt blackout switchgear through a connection with the 4160 volt essential switchgear. Voltage studies have been performed to optimize the voltage levels at the safety-related buses and transformer tap settings selected accordingly. The results of these studies indicate the voltages are within acceptable limits Q430.9 for the worst case conditions as listed below. With maximum expected grid Q4300109 voltage and with minimum anticipated plant loading, the maximum voltage on the 4160V bus will be l'.056 times rated. With minimum expected grid voltage, one offsite power supply out of service, and an accident occurring during 8.3-5 Rev. 7 j
_. CNS .
. power operation, the minimum voltage will be 0.9287 times rated at the 4160V level and 0.9244 times the motor rating (575V) at the 600V level.- The worst case voltage dip under these same conditions with all loads running the nuc-lear service water pump being started is 11.16% at the 4160V level. Tests to verify these results are discussed in Table 14.2.7-1.
Each of the redundant 4160V~ essential buses is provided with two levels of undervoltage protection to monitor bus voltage. Each level is provided with a separate set of three instantaneous under voltage relays which are utilized in a two-out-of-three logic scheme. 'Q430.9 The first level undervoltage relays are set to drop out at 84.1% of normal
- Q430.109 bus voltage (4160V). This setpoint was selected such that relay operation will not be initiated during normal motor starting; however, these relays will detect loss of voltage and initiate action in a time frame consistent with the accident analysis.
The second level provides degraded voltage protection and is set to operate for voltage less than 90%. This second level employs two time delays: the first (40 seconds) establishes the existence of a sustained degraded voltage condition and provides an annunciator alarm in the control room; the second (10 minutes) permits corrective operator action prior to separat-ing the Class 1E and offsite power systems. The occurrence of a safety in-jection signal subsequent to the first time delay will immediately separate the Class 1E and offsite power systems. If the first level undervoltage scheme is initiated, the following automatic sequence takes place: Time (Sec) Event T=0 1. Bus undervoltage relays operate (two-out-of-three logic initiated)
- 2. Associated diesel generator starts
- 3. Timing relay initiated and begins to time out 8.5 seconds.
T = 8.5 Timing relay times out. If the undervoltage condition still exists, the Class 1E switchgear incoming breaker is tripped, thus isolating the bus from the offsite power sources, and the bus is load shed. However, if the undervoltage condition clears before 8.5 seconds, the undervoltage relays will automatically reset and the bus will continue to be supplied from its normal source. When this occurs, the diesel must be manually shut down. T = 11.0 Diesel generator breaker closes, thus aligning the diesel generator to the essential bus, and the necessary automatic load sequencing begins. This step assumes that the in-itiating undervoltage condition did not clear prior to T = 8.5 seconds. 8.3-6 Rev. 7
-. u -.
CNS
.;* ~
j As described above, this undervoltage protection scheme initiates separation
- of the Cla~ss 1E buses from the preferred power source 8.5 seconds after a complete loss of offsite power occurs.
- Q430.9
'Q430.109 The thermal capabilities of.various Class IE motors to withstand locked rotor current without damage have been reviewed. By comparison with thermal con-ditions that could occur when operating equipment at voltages much lower than its rating, there is no reason to expect any equipment damage for the
- 8.5 second period prior to load shed.
If a blackout condition is the single event to be considered, the diesel gen-erator load sequencer will sequence only those leads required to mitigate the consequences of the blackout. During this condition, the normal feeder breaker to the 4160 volt blackout switchgear is tripped, and the alternate incoming breaker from the associated 4160 volt essential switchgear is closed. An elec- ' ~ trical interlock scheme is provided such that the normal incoming breaker to the 4160 volt blackout switchgear must be tripped and the alternate incoming breaker from the 4160 volt essential switchgear must be closed before the 4160 volt essential switchgear feeder breaker can be closed. Loads required within the first 12 minutes following a blackout are automatically sequenced on the diesel generator. Those loads required after 12 minutes are manually loaded as nec-essary. If a blackout condition occurs simultaneously with a loss of coolant accident (LOCA), the same procedure, as. defined above for the blackout condition, is followed except only the Class IE loads required to mitigate the effectc of the accident are sequenced onto the diesel generator. The non-Class 1E 4160 volt blackout system is completely disconnected from the Class 1E 4160 volt essential system with interlocks provided to maintain the isolation. If blackout sequencing is in progress when a LOCA input signal is received, the non-Class IE 4160V system is separated and blocked as described. The load sequencer is then automatically reset and LOCA required loads that are not already energized from the blackout loading sequence are connected to the bus. l If LOCA load sequencing is in progress when a blackout occurs, the non-Class l 1E 4160V system will remain de-energized and blocked with the following auto-matic load sequencer actions occurring:
- 1. Load sequencer reset
- 2. Load shedding of the 4160V Class 1E bus
- 3. LOCA required load sequencing re-initiated The committed loading sequence for blackout and accident conditions is pro-vided in Table 8.3.1-1. An additional feature of the load sequencer is the
!Q430.9 accelerated sequence which is operational whenever sequencer controlled bus
- Q430.109 loading is in progress, whether the sequencer actuation is the result of a LOCA, blackout, or a LOCA concurrent with a blackout. The accelerated
! sequence will automatically apply the load groups with a minimum of two seconds between groups if the bus voltage and diesel engine speed have re-covered to 92.5% and 98%, respectively. The committed sequence times will 8.3-7 Rev. 7
- - ~ _ . - - . - - __-. - . . - . - - . . . . - - - . - -- - - - _ - . . -
CNS . be met or. bettered by the accelerated sequence, the committed sequence or 0430.9 a combination of the two. Both sequences employ a common loading relay Q430.109 for each group to assure that once a loading signal is applied by the ac-celerated sequence, it will not be reapplied by the committed sequence. All Class 1E equipment is supplied from the two redundant and independent trains of the Class 1E 4160 ' volt essential system. The 4160VAC Essential Aux-iliary Power System has sufficient capacity and capability to supply those systems required to safely shutdown the unit assuming a complete failure of one essential train. The redundant 4160 volt essential switchgear assemblies are located in separate rooms on different elevations within the Category I Aux-iliary Building. The independence between redundant trains of the Auxiliary Power System is
- shown on Figure 8.1.2-1. Additionally, a detailed description of the physical
. identification of Class 1E equipment is provided in Section 8.3.1.3.
The instrumentation and controls for each train of the 4160 volt essential system are supplied from the corresponding train of the Class 1E 125VDC Vital Instrumentation and Control Power System as shown in Table 8.3.1-2. Refer to Section 8.3.2.1.2.1 for further discussion of the 125VDC Vital System. The only Class 1E loads shared between units are two full-capacity redundant and independent air conditioning compressors in the Control Area Chilled Water System. Each compressor is assigned to one of the Class 1E trains of the 4160 volt essential system and has the capability of being supplied from either unit. A manual interlock scheme is provided to prevent both units from simul-taneously supplying the compressors. This interlock scheme meets the requirements of Regulatory Guide 1.6. The protection schemes provided for the 4160VAC Essential Auxiliary Power i System are designed to 1) minimize the effect of faulted equipment on the rest of the system and to maximize the availability of the remaining equipment, and
- 2) to limit damage and out-of-service time of the faulted equipment.
The incoming feeders for each Class 1E 4160 volt train are protected by time-delayed phase-overcurrent relays and ground sensors. Additionally, synchronism-check relay and breaker failure schemes are also provided. The phase-overcurrent 8.3-7a Rev. 7
CNS i ' i 8.3.1.1.2.2 600VAC Essintiel Auxilicry Power System { The 600VAC Essential Auxiliary Power System supplies power to the 600 volt essential motor control centers which are located in load concentration areas throughout the plant. Connected to the essential motor control centers are all of the 600 volt essential loads which require power during accident con-ditions and non-essential loads which are required to be disconnected during accident conditions. Two essential motor control centers (IEMXG and 2EMXH) are provided to supply power to loads which are shared between the two units, e.g. Control Area Chilled Water System. The Train A loads, fed from motor control center IEMXG, are identified in Table 8.3.1-1 in the remarks column. The corresponding Train B loads are fed from 2EMXH. This system is shown on Figure 8.3.1-3. The only non-Class 1E loads which can be powered from the Class 1E AC or DC systems during an accident are the AC emergency lighting transformers and the diesel generator engine lube oil transfer pump motors which are discon-nected on a LOCA. The lighting transformers are given a permissive manual connection after all LOCA loads are sequenced on. The 30KVA, 600VAC trans-formers and the 3 horsepower, 575VAC pump motors are powered from 600 volt,
. Class 1E motor control centers as listed in sequence number 1, Table 8.3.1-1.
The 600VAC Essential Auxiliary Power System is divided into two redundant and independent safety trains, each of which consists of two load centers and their associated motor control centers. Each load center normally receives power from its associated 4160 volt essential switchgear via a separate 1500KVA, 4160/600 volt essential load center transformer. The two load centers in each safety train are provided with a spare transformer which can be manually con-nected to either load center should the normal load center transformer be un-available. A key interlock scheme is provided to prevent the spare transformer from being connected to both load centers simultaneously. In the event of a blackout or blackout coupled with a LOCA, the diesel gener-ator load sequencer automatically sheds the load centers by tripping the load center incoming breakers. Essential loads required during the blackout or blackout /LOCA condition are then automatically sequenced onto their respective bus by the sequencer. Protection devices on the 600VAC Essential Auxiliary Power System are selected and set to achieve a selective tripping scheme so that a minimal amount of equipment is isolated from the system for adverse conditions such as a fault. The load center breakers are set to protect the cable feeding the essential motor control centers and coordinate with essential motor control center feeder breakers. The relays on the essential load center transformer fcedars are set to protect the transformers and coordinate with the load center breakers. The protective relay settings for essential systems / equipment are calculated based on equipment manufacturer's data and system parameters. The initial setpoints are verified during system pre-operational testing. The setpoints are determined as follows: ANSI Number and Function Setting
- 1) Load Center Incoming Breakers Set to protect the cable and equip-ment and coordinate with feeder breaker settings.
- 2) Load Center Feeder Breakers Set to protect the cable and equip-ment.
8.3-9 Rev. 7
CNS dependent measurements of lube oil pressure which requires two-out-of-three coincident logic to trip the diesel generator. The voltage controlled over-current ~(51V) relays are used in a two-out-of-three logic scheme to isolate the generator from faults on the 4160 volt essential switchgear bus. These relays are set to operate at approximately rated full load current on the diesel generator if the voltage falls below 80% rated; however, they will not operate for any magnitude of current if the voltage is above 80%. These set points prevent relay actuation during motor starting transients as load acceptance testing has demonstrated that bus voltage remains above 80%. Furthermore, the voltage controlled overcurrent relays have been coordinated with the 4160 volt feeder breakers such that the feeder breakers will clear downstream faults prior to 51V actuation. The following mechanical trips are provided to protect the diesel generators during test periods:
- 1. Low Pressure Turbo Oil
- 2. Low Pressure Lube Oil
- 3. High Pressure Crankcase
- 4. High Temperature Bearings
- 5. High Temperature Lube Oil Out
- 6. High Temperature Jacket Water
- 7. High Vibration These seven trips are bypassed in the event of an accident condition. Even-though the trips are bypassed while the diesel is running during and accident condition, these parameters are annunciated on the local diesel control panel and in the control room and are logged on the events recorder.
In addition, the following electrical trips are provided to protect the diesel generators during testing periods:
- 1. Generator Instantaneous Overcurrent Protection
- 2. Generator Loss of Field Protection
- 3. Generator Reverse Power Protection
- 4. Generator Ground Protection These electrical trips are bypassed in the event of an accident condition.
The diesel generator protective relay setpoints are determined as follows: ANSI Number and Function Setting
- 1) 87G (Generator Differential) No Setting - Variable Percentage Instantaneous Differential Relay 8.3-13a Rev. 7 Carry Over
. CNS I
'rovide sufficient cooling water to operate the engine at 7700 output.
p I
. Actual vendor tests on engines of the same size and model show that the diesel -
can start from warm standby and operate for a minimum of two minutes without nuclear service water being supplied to the diesel generator heat exchanger.
- A detailed description'of the Diesel Generator Engine Cooling Water System is presented in Section 9.5.5. .
8.3.1.1.3.9 Prototype Qualification Program . The test program implemented for the qualification of the emergency diesel generators is outlined below. A. At the factcry, one of the four Catawba diesel engines was connected to its mating generator and subjected to:
- 1. The factory commercial test for adjustments, check-out, and loading.
- 2. A load test to demonstrate the ability of the diesel generator to start and trip a 1000HP electric motor and sustain operation after a trip and re-start. The diesel generator was loaded to 7000KW before the motor was tripped and then restarted.
B. Each subsequent diesel engine was placed on the factory test stand and connected to the factory test absorption dynamometer and subjected to the standard commercial shop test for adjustment, check-out and loading. This test included testing each diesel engine up to 110% of the continuous full-load rating. C. Start load tests have been conducted on a diesel generator with an iden-tical engine and generator and equivalent auxiliaries. These tests " type
, qualify" the Catawba diesel generators in accordance with IEEE-387-1977 as modified by Regulatory Guide 1.9, except the IEEE-387 standard was followed regarding the (24) twenty four hour continuous load test. Test-ing the diesels for 22 hours at 100% load more closely simulates actual plant loading conditions. To verify additional capability of the diesel Q430.22 generator set, a 2 hour load test at 110% load follows the 22 hour load test. However, this additional load is not utilized during actual diesel operation. Based on discussions with the diesel manufacturer, there is i no significant difference between the order in which the test is conducted.
I The Catawba diesels, generators, governors, exciters, regulators, and control panels were used in the following tests, along with equivalent auxiliaries: Sequential Loading Test Load Rejection Test Margin Test Load Capabi Mty' qualification Test 8.3-16 Rev. 7
l
. . j CNS
~
The diesel, generator, governor, exciter, regulator, control panels, and auxiliaries were used to " type qualify" the Catawba diesels for the following tests: No Load Endurance Test (7-Day) 300 Start Test The Catawba diesels, generators, governors, exciters, regulators, control panels and auxiliaries were used for the following: Factory Testing Seismic Testing / Analysis 8.3.1.1.3.10 Preoperational and Periodic Testing In addition to the factory tests described in Section 8.3.1.1.3.9, the following preoperational on-site acceptance tests and periodic tests will be conducted on each dies ' generator and their associated auxiliary systems. A. Preoperau onal Testing: Tests as described in: l 1. IEEE 387-1977, Sections 6.4 and 6.5.
- 2. Catawba Technical Specifications, Sections 4.8.1.1.2.a.3, 4.8.1.1.2.a.4, and 4.8.1.1.2.c.2 thru 12.
- 3. Regulatory Guide 1.9, Rev.' 0, Section C.3 and C.4.
- 4. Regulatory Guide 1.41, Rev. O, Section C.
l l l 8.3-16a Rev. 7 Carry Over
CNS
^
The diesel generator Sequential Loading Tests indicate that the maximum volt-age dip experienced, below 90% of nominal system voltage, was to 86.2% and recovered to 90% voltage in 0.23 seconds and to 98% frequency in 0.28 seconds. These recoveries are within the requirements of Regulatory Guide 1.9. Q430.24 At these voltage levels, analyses of the essential power system indicate that the 90% and 85% motors will' start and accelerate their loads when powered from the diesel generator. For offsite power operation refer to Section 8.3.1.1.2.1. The starting torque for all Class IE motors is sufficient to provide acceler-ation of driven equipment at minimum motor operating voltage. Additionally, these Class 1E motors deliver the torque required over pump torque to accel-erate their loads within the required time with at least 10% margin. Motor insulation is selected to be compatible with ambient environmental conditions. Temperature rises are selected to provide long insulation life. Selected insulations have temperature characteristics of NEMA Class F or Class H insulation. l l 8.3-17a Rev. 7 [ ..
CNS 8.3.1.4.5.1 Cable Installation
" ~ Cables are installed in open ventilated ladder type trays, open ventilated electray channels, conduit, or wireways. A seismically qualifted cable support system is provided for all raceways containing Class 1E cables. Additionally, all raceways are of non-combustible construction.
Cables are routed in separate raceway systems according to voltage level and function. Where practical, a vertical stack of trays is arranged such that the highest voltage level is on top with the lower trays in descending order of voltage levels and finally control and instrumentation trays at the lowest level. Cable splicing is not allowed in raceways. Class 1E cables routed outside the plant structure are run underground. This underground Class 1E cable system consists of two redundant Category 1 conduit banks designed such that any single design basis event applicable to the loca-tion of the conduit banks cannot result in the failure of redundant Class 1E cables. 8.3.1.4.5.2 Cable Separation The minimum separation between Class 1E cables and between Class 1E and non-Class 1E cables external to equipment enclosures and without the use of barriers is:
- 1. Three feet horizontal and five feet vertical for the general plant areas.
- 2. One foot horizontal and three feet vertical for the control complex area (i.e., the area of the Auxiliary Building that houses the control room, cable room, and battery room).
This separation distance is free of interposing structures, equipment, or materials which could aid in the propagation of fire.or which could disable Class 1E cables or equipment and is measured between the closest points of the raceways. Where plant arrangements preclude maintaining the minimum separation distance as outlined above, the cables are run in enclosed raceways that qualify as barriers or other barriers are provided. Interlocked armor cable has been demonstrated through short circuit testing conducted by Duke Power Company to provide an adequate barrier for preventing damage to adjacent cables and I may serve as a barrier in these areas with the following restrictions:
- 1. 12 inch separation is maintained between redundant Class 1E circuits or additional barriers are supplied, and i 2. Six inch separation is maintained between Class 1E and non-Class 1E cables or additional barriers are supplied.
! The minimum separation distance between enclosed raceways or between en en-closed raceway and an interlocked armor cable is one inch. Based on the i cable construction and/or limited power available, field routed cables used , for communication, fire detection and lighting applications are exempted ! from the above criteria. The cables used in these applications are enclosed l in a welded seam corrugated aluminum armor. 8.3-22 Rev. 7 i
CNS .
.=- .- >
. The minimum separation between redundant Class 1E wiring or between Class IE and non-Class 1E wiring inside equipment enclosures and with potentials less than 150 volts is:
- 1. Six inches of free air-space without barriers
- 2. One inch of free air space between the wiring on both sides of a single barrier
- 3. One inch free air space between two barriers (the barriers may be directly
. adjacent to the wiring)
- 4. 1/8 inch asbestos thermal insulation between two barriers (the barriers may be directly adjacent to the wiring or device)
Barriers extend beyond the wiring to the extent that the straight line, free air distance between redundant wiring is a minimum of six inches. Physical separation and isolation devices are used to eliminate the need for 4 associated circuits. If a circuit is used for a non-Class 1E function and 4 is 1) connected to a Class 1E power supply or 2) connected to a Class 1E Q430.29 device and physical separation from Class 1E circuits cannot be maintained, the circuit is treated as Class 1E up to and including an isolation device. The portion of the circuit that is on the Class 1E side of the isolation device is identified as Class-1E and routed only in Class 1E raceways. The portion of the circuit on the non-Class 1E side of the isolation device is routed only with non-Class 1E cables. The only device acceptable as a power circuit isolation device is one that is automatically tripped by an accident signal generated within the same train. Electrical circuits enter the containment through penetration assemblies
' Q430.11 which are provided with integral connectors (qualification information per-taining to electrical penetrations is provided in Section 3.11.2.1.5). The cables associated with Train A circuits are routed through penetrations which contain no Train B circuits, and vice-versa. The minimum separation between penetrations carrying mutually redundant circuits is five feet in all direc- ;
Q430.31 tions. The minimum separation between Class 1E and non Class 1E penetrations is one foot six inches. 8.3.1.5 Cable Derating and Cable Tray Fill 8.3.1.5.1 Cable Derating-4 The cable ampacities for both ac and de power cables are derated to assure minimum degradation of cable insulation caused by high temperatures'should the cables be loaded to their maximum ampacity rating. 8.3-23 Rev. 7
.n = _= - =
CNS
"- ' 8. 3. 2.1.-2 Class 1E DC Power Systems
[ ~ 8.3.2.1.2.'1 125VDC and 120VAC Vital Instrumentation and Control Power System The 125VDC and 120VAC Vital Instrumentation and Control Power System provides a reliable, continuous source of power to Class 1E instrumentation and controls. The system consists of four~ independent and physically separated load groups that supply instrumentation and control channels A, B, C, and D. Each load group includes a battery, a battery charger, a dc distribution center and associated de panelboard, an inverter, and an ac panelboard. This system is shown on Figure 8.3.2-3. The 125VDC and 120VAC Vital Instrumentation and Control Power System is a seismic Category 1 system and is located in the Auxiliary Building. Each of the four 125 volt batteries are located in separate rooms within the Auxiliary Building. The de portion of the vital instrumentation and control power system is an ungrounded system. Table 8.3.2-1 provides a listing of the loads supplied by the 125VDC and 120VAC Vital Instrumentation and Control Power System. 8.3.2.1.2.1.1 125VDC Vital Instrumentation and Control Power Battery Chargers Each load group of the 125VDC Vital Instrumentation and Control Power System is provided with a separate and independent 125 volt battery charger. The battery chargers of load groups A and C are powered from Train A of the Essential Auxiliary Power System; the chargers of load groups B and D are powered from Train B. Each charger is capable of supplying the steady-state loads of its own load group while recharging its associated battery. A spare battery charger is provided to serve as a backup for any one of the normal battery chargers. Each battery charger normally supplies the loads of its associated distribution center while maintaining a float charge on its associated battery. The battery chargers are designed to prevent a battery from discharging back into any , internal charger load in the event of a charger malfunction or ac power supply ! failure. I Each battery charger is provided with an overvoltage sensing board which is set to operate at 155 volts. This setpoint was selected so as to provide protection for the battery during equalization as well as for the DC equip-ment during normal operation. Although this setpoint is at,ove the operating voltage range for most DC equipment, past experience indicates that the out-put voltage on a charger will rise instantaneously to high values should a 1 failure occur. If an overvoltage is sensed on the charger output, the output l circuit breaker will automatically be tripped. In addition, procedures re- i quire the operator to verify that each charger is in the float mode prior to connecting it to its associated distribution center. The battery chargers are designed to function properly and remain stable in the event they are isolated from their associated battery. However, it is l not anticipated that a charger will be connected to its load group without 8.3-26 Rev. 7 i _____ _ x _
CNS
~
a.. - train A of the'125VDC Diesel Essential Auxiliary Power System. The other auctioneered distribution center is powered from vital load group D and train B of the 125VDC Diesel Essential Auxiliary Power System. The two auctioneered
. distribution centers, along with their associated auctioneering diode assemblies, are located in separate rooms in the Auxiliary Building so that a fire in the control complex would not result in the loss of control power to the minimum equipment required to safely shutdown the unit.
The two de distribution centers whose battery chargers are powered from the same train of essential auxiliary power may be interconnected. A tie breaker
- is provided in each of these four load group distribution centers to allow the
- train-associated distribution centers to be cross-connected.
An additional 125 VDC distribution center (1EDS) is provided for use with the spare battery charger. This distribution center contains two circuit breakers which are kirk-key interlocked such that only one can be closed Q430.107 at any one time so as to prevent interconnecting Train A and B related
- channels. The spare charger also has a power panel on the AC side (IEMS) with two kirk-key interlocked breakers to prevent interconnecting Trains A and B. An annunciator is provided in the control room to alert the operator should the spare charger be connected to Train A on the input and Train B on the output or vice-versa.
The bus tie breakers between 1 EDA-1EDC and 1EDB-1EDD are used as follows:
- 1. To allow the standby charger to feed a vital bus in case its normal charger is out of service.
Q430.36 2. To allow the opposite battery to float on the bus when performing an equalizing charge on the buses main battery. The tie breakers are manual breakers and are operated in accordance with approved procedures. The breakers alarm in the Control Room when they are closed. 8.3.2.1.2.1.4 .120VAC Vital Instrumentation and Control Power System i The 120VAC Vital Instrumentation and Control Power System consists of four
- separate and independent 120 volt ac power panelboards, each powered from a 125 l volt dc load group distribution center via a 125VDC-120VAC static inverter.
) Each 120 volt ac power panelboard supplies one channel of ac vital instru-mentation and controls. The 120VAC Vital Instrumentation and Control Power System is shown in Figure 8.3.2-3. 4 A regulated 120 volt ac power supply is provided to serve as an alternate power source to any one of the 120 volt ac panelboards in the event an inverter is not available. Regulated power is supplied to the 120 volt ac panelboards via a 120 volt ac distribution center. A tey interlock scheme between the four circuit breakers of the regulated 120 volt ac distribution center allows only one power panelboard to be supplied from the alternate source. Additionally, each 120 volt ac panelboard is provided a manual bypass switch to select the normal or alternate power source. 8.3-28 Rev. 7
CNS
~
e
- 5. The following indication is provided locally on the 125 volt de load group .
equipment:
~
- a. Vital instrumentation and control dc distribution center bus voltage
- b. Battery leg-to ground voltage
- c. lattery charger output current and voltage
- 6. Indication of the load group vital instrumentation and control de distri-bution center bus voltage is provided in the control room.
8.3.2.1.2.2 125VDC Diesel Essential Auxiliary Power System i The 125VDC Diesel Essential Auxiliary Dower System provides a separate and independent train of 125 volt dc power to each diesel generator. Each train consists of a 125VDC battery and a battery charger powered from its associated train.of 600 volt essential auxiliary power. The 125VDC Diesel Essential Auxiliary Power System is shown in Figure 8.3.2-5. Each battery charger normally supplies its associated diesel generator control panel loads and fuel oil booster pump motor while maintaining a float charge on its associated battery. Each diesel battery is available to assume its associated loads upon the loss of its battery charger or ac power source. Each diesel generator control panel supplies the auxiliaries of its associated i diesel generator and also supplies an auctioneering diode assembly which serves as one of the power sources to a 125VDC Vital Instrumentation and Control Power System distribution center as described in Section 8.3.2.1.2.1.3. Each of the two load groups of the 125VDC Diesel Essential Auxiliary Power i System are provided with the following status indications:
- 1. A 125 volt DC essential power train trouble annunciator is provided i in the control room for each train and is initiated by any of the
- following load group conditions:
I a. Battery charger output circuit breaker open
- b. Battery circuit breaker open
- c. Battery charger output voltage low
- d. Battery charger output voltage high
- e. Loss of AC input to battery charger
- f. Battery positive or negative leg ground
- g. Battery undervoltage
- h. Auctioneering diode assembly input voltage low
- i. Diesel generator control panel undervoltage j Indication of the specific condition that initiated the 125VDC train trouble alarm is provided on a local alarm module near the 125VDC diesel essential auxiliary power equipment.
8.3-31 Rev. 7
CNS _.. . o
- 2. A po~nt description printout and a graphics display based on the system one-line diagram.are provided in the control room by the unit computer.
The computer output provides the status of all conditions that initiate the'125VDC train trouble annunciator described in 1 above.
- 3. The following indication is provided locally on the 125 volt DC load group equipment:
- a. Battery charger output current and voltage
- b. Battery leg-to ground voltage
- 4. Indication of the load group diesel generator control panel bus voltage is provided in the control room.
8.3.2.1.2.3 Testing 8.3.2.1.2.3.1 Preoperational Tests Preoperational testing of the Class 1E de systems is performed in accordance with the recommendations of Regulatory Guide 1.41 to verify proper design, installation, and operation. Testing of panelboard circuit breakers and all circuit breakers associated with the 120 volt regulated ac power system consists of operating the breakers to assure proper functioning. System voltage levels are verified and, in the 120 volt ac system, the capability to perform manual transfers from the inverters and regulated power supply is demonstrated. Independence of the redundant power sources and load groups is verified in the Engineered Safety Features Actuation System Functional Test. DC loads are verified to be in accordance with battery sizing assumptions. The battery capacity is verified by a discharge performance test in accordance with IEEE 450-1975. Operability of vital loads is verified at reduced system voltage. 8.3-31a Rev. 7 Carry Over
1 Table 8.3.2-1 125VDC Vital Instrumentation an'd Control Power System Class IE Loads Inrush Continuous. Current Current Load (0-1 Min) (1-60 Min) Miscellaneous Loads 12.7 12.7 Residual Heat Removal Solenoid Valves 2.6 ' 2.6 Air Handling Units Glycol Supply Valves .5 .5 Containment Purge Solenoid Valves 5.5 5.5 Auxiliary Feedwater Pump control (Turbine and Motor Driven) 15.3 6.9 Auxiliary Safeguards Cabinet 1.0 1.0 Auxiliary Shutdown Panel 6.6 6.6 Battery Ground and Undervoltage Detection 2.0 2.0 Chemical and Volume Control Systems Solenoid Valves 16.7 16.7 Diesel Generator Load Sequencer Panel 17. 4.0 Feedwater Control and Control Bypass Relay Control 2.5 2. 5 Main Feedwater Containment Isolation Control 13.2 3.4 i Component Cooling Solenoid Valves 4.8 4.8 Nuclear Service Water System Solenoid Valves 5.6 5.6 l Reactor Coolant System Solenoid Valves 3.0 3.0 Reactor Trip Switchgear Control 8.0 1.0 Safety Injection System Solenoid Valves 1.8 1.8 Static Inverters (2 channels) 95.6 90.2 Turbine Trip Control 1.4 0.1 4160 Volt Essential Switchgear Control 100 5. 0 , , 600 Volt Essential Load Center Control 23 3.0 Totals 338.8 178.9
- l. This table lists the loads that could be supplied by a single 125 volt dc vital instrumentation and control battery with two channels connected via a bus-tie.
Rev. 7
\ .. l CNS l l
- 1. Maintenance. circuit: This circuit consists of phone jacks located through-out the plant which can be patched together to establish communication between areas as necessary.
2. Refuelingcircuiti: This circuit consists of sound powered' phone stations connecting areas required for refueling operations.
- 3. Emergency circuit: This circuit consists of sound powered phone stations connecting the auxiliary shutdown panel with areas of the plant that may require local operation during an emergency shutdown.
The sound powered telephone systems are powered from the diesel backed emer-gency AC lighting panelboards located in their respective areas. The loca-tions of the emergency sound powered telephone stations are indicated on Figures 9.5.2-1 through 9.5.2-16. 9.5.2.2.4 Emergency Offsite Communication Emergency offsite communication independent of the PABX system is provided by public telephone lines and Duke microwave lines connected directly to specific telephones in critical areas of the station. Emergency telephones are color coded to distinguish them from the intraplant telephones. The locations of emergency public and microwave telephones are indicated on Figures 9.5.2-1 through 9.5.2-16. Additionally, a security radio system is provided in ac-cordance with 10CFR73.55(f), and a crisis management radio system is pro-vided in accordance with NUREG 0654. 9.5.2.2.5 Power Supply Separation The Intraplant Td ephone System (PABX) is powered from three (3) battery backed, 120VAC, 1 9 power panelboards that are located in the Auxiliary Building and are independent of each other. These panelboards are 1KXPA, 1KXPB, and 2KXPA and feed the switch via cables 1ECI541, 1ECI542, and 1ECI585 respectfully. The minimum separation distance between panelboards is 25 feet. Cables 1ECI541 and 1ECI542 are run in the seme cable tray from
' the Auxiliary Building to the Telephone Equipment Room in the Administration Building, however,. Cable 1ECI585 is run in a separate tray system in excess of 20 feet from the 1ECI541 and 1ECI542 cables to a point in the Service Building, E1. 594'-0" at Column U-7, where all three cables enter a final Q430.54 tray run to the Telephone Equipment Room.
The Intraplant Public Address (PA) System is powered from two (2) shared Motor Control Centers that are located independent of each other. Motor Control Center SMXC is located in the Auxiliary Building and feeds PA Power Panelboard PAP-1 also located in the Auxiliary Building. Motor Control Center SMXS is located in the Service Building and feeds PA Power Panel- - board PAP-2 also located in the Service Building. Therefore, the PA is fed from two (2) sources located in different buildings. The Emergency Sound-Power Telephone System is powered on a per Unit basis, via a double feed circuit through a power transfer contactor. For Unit 1, the system is fed from diesel-backed Emergency Lighting Panelboard 1ELB1 and Normal Lighting Panelboard ILA6. Panelboard 1ELB1 is located in the 9.5-6 Rev. 7
CNS
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Auxiliary Building, EL. 560'-0". Panelboard ILA6 is located in the Auxi-liary Building, El. 543'-0", thus separation is one floor elevation (17 feet). Unit 2 is similarly installed. The cabling running from 1ELB1 and Q430.54 ILA6 to the Power Transfer Contactor is 2/C #12ALS. __ See Figures 9.5.2-17 and 9.5.2-18 for one-line representations of the telephone systems. ' 9.5.2.3 Communication During Transient and Accident Conditions In order to achieve a safe cold shutdown, it may be necessary for plant per-sonnel to communicate with the control room or the emergency shutdown panel from selected working stations. These work stations and the communication systems available at each station are identified in Table 9.5.2-1. The types and locations of these communication devices / stations are indicated on Figures 9.5.2-1 through 9.5.2-16. The emergency sound powered telephone system is the means of communication in-tended for use during accident conditions. Effective communication is provided by the emergency sound powered phones in background noise levels as high as 110 dBA. PABX handsets are also available at all of the subject work stations and can be effectively used in noise levels or approximately 90 to 95 dBA. 9.5.2.4 Inspection and Testing All communication systems are inspected and checked for operability after installation to assure proper operation and coverage. After a unit is op-erational, plant noise levels will be measured during normal and simulated accident conditions. Based on these measurements, an evaluation will be made to determine the need for sound isolation booths or noise-cancelling devices. The communication systems are used routinely and do not require periodic testing. l l i l 9.5-6a Rev. 7 Carry Over
4 i CNS ,
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9.5.4.2 System Description .
! 9.5.4.2.1 General Plans and sectional elevations of the Diesel Building showing locations of major equipment and components, piping layouts for the fuel oil and other :
systems, and the fuel oil storage area with associated piping and components l are shown in Figures 9.5.4-3 through 9.5.4-12. The fuel oil system dia-grammatics are shown in Figures 9.5.4-1 and 9.5.4-2. A separate and complete fuel oil storage and transfer system is provided for each diesel generator engine. Two underground storage tanks provide 90,000 gallons of fuel oil for each engine, which is sufficient to operate at full load for a period of time no less than seven days plus a margin to allow per-iodic testing. Fuel oil is transferred by gravity from the storage tanks to the day tank which.is located within retaining walls inside the Diesel Building. The day Q430.63 l tank dieselcapacity generatorof 550 gallons engine is a sufficient in excess supply of 60 minutes of fuel at full load.oil to operate A set the of level switches located within the day tank control the position of the fuel oil transfer valve: opening the valve to allow fuel to flow to the day tank at i low level, closing the valve to shut off the supply of fuel at high level. High and low level alarms are also provided both on the storage tanks and on the day tank. In the event of a transfer valve failure in the closed posi-tion, the day tank low level alarm, indicating 60 minutes of fuel reserve Q430.63 at full load, allows the operator to take corrective action. In such an event, a bypass line allows for manual filling of the day tank. In the event of a transfer valve in the open position, fuel oil would continue to
,g430.60 flow from the storage tanks to the day tanks until the system reached hydro-static equilibrium. Since there is no day tank overflow pipe fuel oil would rise in the Duke Class C day tank vent pipe to an elevation equivalent to that of the fuel oil in the storage tnak, but well below the top of the vent.
l The day tank vent pipe is missile protected. l The fuel oil lines cross under the condenser cooling water lines which are moderate energy (70 psi) lines. It is anticipated that a break in these CCW lines would have minimal affect on the fuel oil lines. The fuel oil lines are bedded in a trench excavated into rock (minimum rock elevation is 587.6 , on Unit 1 and 574.03 on Unit 2 which is above the fuel oil pipe at 572.2). Further, the CCW pipes are bedded in a 90 degree concrete support saddle which would virtually eliminate direct impingement on the fuel oil lines. Q430.64 Also, there are no structures above the fuel oil lines that would prevent near vertical seepage from occurring, therefore, insignificant undermining of the fuel oil lines is expected. Postulated loss of water will be detected at yard level due to the impervious zone of group I earth backfill confining these areas and the underlying rock. The fuel oil tanks would not be affected by a possible loss of cooling water ( because they are located a considerable distarfce from the CCW lines. l l 9.5-9 Rev. 7 . l
CNS Fuel oil is pumped from the day tank to the engine by either the engine-driven fuel oil pump or the motor-driven fuel oil booster pump. The day tank provides sufficient positive suction to both the motor-driven fuel oil booster pump and the engine-driven fuel oil pump. The motor-driven booster pump is used during starting until the engine-driven pump has reached full i Q430.65 speed. Each pump is provided with a duplex suction strainer and a discharge pressure relief valve, and an engine-mounted dual element fuel oil filter is provided on the common discharge header. Pressure gauges are located on the inlet and outlet sides of both strainers for local indication and an alarm is provided with each strainer to alert the operator of high differen-tial pressure. Differential pressure indication and a high differential pressure alarm are also provided with the fuel oil filter. Two fuel oil drip headers, one located on each bank of the diesel generator
+
engine, ccntain unburned fuel leakage within the engine. The unburned fuel is removed from the drip headers through a piloted valve and ejector driven by l l l l ( 9.5-9a Rev. 7 Carry Over
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'The periodic testing and maintenance of all diesel engine coolini water sys- ' 'Q430.82 tem instruments is controlled by the Preventive Maintenance Recall prcgram.
This program insures that instruments are periodically calibrate <1 and tested,i ' , assuring reliability. , / , p e; t 9.5.7.3 Safety Evaluation : I .I The Diesel Generator Engine Lube Oil System is a Duke Class.C piping *ystem. with the exception of the Clean and Used Lube Oil Transfei System which is '
/-
a Duke Class G piping system. The two systems are seperated by. Duke Class C 1, isolation valves. The diesci engina and engine mountes; components are con'- 5' structed in accordance with IEEE Standard 387. The oftjaigine essential- . , Q430.62 equipment and components and trie nonessential (i.e., Clean!and Used Lube Oil Transfer System) equipment and components are designed in.accordince with the requirements of the codes listed in Table 3.2.2-2( Eacn' diusal generator unit is housed seperately in a Seis*ic Category I strecture whichtforms half 4 of the Diesel Building, and the un' i themselves are fully independent and 4 redundant for each nuclear unit. ' f , The results of a failure modes and effects analysis are presentN in Table s 9.5.7-1. ,i The exterior of carbon steel tanks.and otheriundergrosnd icarbon steel cog ( ponents is sandblasted to a'SSPC-SP10-63, Near White Metal Blast Cleaning.J , , Q430.86 A coal tar epoxy coating which meets.the requirements of. Corps of Engineers 3 Specification C-200 and Government Specification MIL-P-23236 is ap,nii,ed';o j exterior surfaces at a dry fih '.nickness of 16 mils. This coal tar epuy is also applied to the exterior of stainless steel piping. -
, )L 0 l
Inadditiontobeingcoated,theexternaksurfacesofburiedmetallic$1 ping, ' and tanks are protected from corrosion by.. c.n~ impressed current cathodic' pro- - tection system in accordance with NACE Standard RP-01-69 (1972 Revirion) 3 Periodic monitoring, as described by the maintenance procedure, will' remove ' ' any accumulated moisture from the tanks. ' ' The governor lube oil coolers on the dicdei generator engines (Delaval"RV Q430.G5 16-4) are located at an elevation below c.he governor lube oil level, thdreby, not affecting the starting reliability of3the engines. 1 3 ,
, i ! .4 t The interior of the clean lube oil ste-zge /s'.t ak is not coated since thp '
presence of lube oil will act as a detsrant to internal corrosion. O. iring; Q430.61 the surveillance intervals for sampling the lube oil in the storage ' tait G, asoutlinedpertheTechnicalSpecification,anyaccumulatedwater%il ! be removed, f i t y I ' i 9.5.7.4 Tests and Inspections 1 1 i'I, i, l System components and piping a:*e tested to pressures designated by appropriate codes. Inspection and furctional testing are perfordd prior te initial op-eration; thereafter the system will be tested in accordance with the Technical Specifications. . i l 9.5-23 Rev. 7
I 500- , 466.4A .- 4#- vs y 300 - m
$ 265.8A 262.9A I I I
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1 I I I I l 1 I i 100 - ' I I l
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, 125VDC VITAL INSTRUMENTATION AND CONTROL BATTERY DUTY CYCLE CATAWBA NUCLEAR STATION Figure 8.3.2-4 l Rev. 7
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. Table 14.2.12-1 (Page 20)
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EMERGENCY DIESEL GENERATOR FUNCTIONAL TEST ' Abstract - l Purpose i To demonstrate that the emergency diesel generators are capable of automatically I providing the required power to equipment vital to safe reactor shutdown under l emergency conditions, and other equipment necessary to maintain the plant in a safe condition during loss of power conditions. Prerequisites Diesel generator support systems are operational. Switching relays are cali-brated and all normal bus protection is operational. Diesel generator area ventilation and fire protection are functional. The portion of this test involving automatic starting and loading tests performed immediately following i the 24-hour run will be run concurrently with the Engineered Safeguards Func- ! tional Test. Test Method Automatic diesel generator starting is demonstrated for a simulated safety injection signal and for a simulated loss of normal power signal. Diesel generator loading is demonstrated for a simulated loss of normal power sig-nal and diesel generator sequenced loading is demonstrated for the combined safety injection and loss of normal power simulated signals. ! Diesel generator full-load-carrying capability is demonstrated for an interval ( of not less than 24 hours, of which 2 hours should be at 110% load followed by 22 hours at 100% load, in accordance with Regulatory Guide 1.9. During the 24 hour run demonstration, the ability to swap from on e fuel oil filter to i the other is demonstrated along with the ability to swap from one fuel oil l l strainer to the other. Automatic diesel generator starting and loading is again demonstrated for a combined safety injection and for a loss of normal I power simulated signals, immediately following the 24 hour run. Simultaneous starting of both diesel generators will be demonstrated. Diesel generator load rejection will be demonstrated at 100% load and at a load equivalent to the largest sequenced load. The ability to transfer the emergency load to offsite power will be demonstrated. Diesel generator emergency response is demonstrated not to be impaired during testing. Die-sel generator emergency reliability is demonstrated by means of any 35 con-secutive valid tests with no failures. These demonstrations are accomplished for each of the two generators utilizing only one at a time, except as noted above. In addition, the manual operation of the generators is verified by loading each generator to its continuous operation rating. Rev. 7 i
CNS determined in the original analyses should.never be less than
-the Class 1E equipment rated voltages.
~
. ' Response: .
A second level undervoltage scheme will be incorporated in the design. The design of this scheme is under review at the present. Information will be provided upon design completion. 430.10 . Recent experience with Nuclear Power Plant Class IE electrical sys-(8.3.1) tem equipment protective relay applications has established that re-lay trip setpoint drifts with conventional type relays have resulted in premature trips of redundant safety related system pump motors when the safety system was required to be operative. While the basic need for proper protection for feeders / equipment again!,t permanent j faults is recognized, it is the staff's position that total non-availability of redundant safety systems due to spurious trips in protective relays is not acceptable. Provide a description of your circuit protection criteria for safety systems / equipment to avoid incorrect initial setpoint selection and the above cited protective relay trip setpoint drift problems.
Response
A description of the circuit protection criteria for safety systems / l equipment to avoid incorrect initial setpoint selection and protec-l tive relay trip setpoint drift problems is described in Sections 8.3.1.1.2.1, 8.3.1.1.2.2, and 8.3.1.1.3.4. I 430.11 Provide a listing of the following for the containment electrical I (8.3.1) penetrations by voltage Class: Izt ratings, maximum predicted fault currents, identification of maximizing faults, protective equipment j setpoints, and expected clearing times. Provide a description of the physical arrangement utilized in your design to connect the field cables inside containment to the contain-ment penetration, e.g. connectors, splices, or terminal blocks. Pro-vide supportive documentation that these physical interfaces are l qualified to withstand a LOCA or steam line break environment. I Response: Refer to Table Q430.11-1 and Section 8.3.1.4.5.2. Current versus time curves (Figures Q430.11-1 through -7) illustrate the coordina-tion of the primary and back-up protection devices with the penetra-tion ratings. The penetration test values were selected on the basis of the system dependent variables associated with their specified application (s) and do not represent equipment limits. l 430-7 Rev. 7
. _ . _ . . - ~ _ . . . . _ , _ . _ _
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For example, the low voltage penetrations were subjected to antici-pated maximum fault currents for ten cycles. The penetration as-semblies maintained both mechanical and electrical integrity when
' subjected to these tests. To demonstrate the conservatism in these values, the graphs-for the Type A and B penetrations show the fusing time for the associated cables when subjected to current levels used in the 30 second penetration tests.
l l 430-7a Rev. 7 Carry Over
l Table Q430.11-1 . Listing of Containment Electrical Penetrations PENETRATION MAXIMUM DESIGN EXPECTED TYPE /VOLTAGF CLASS 12t RATING FAULT CURRENT CLEARING TIME (2) A/ Medium 50,0002.20 cycles 39,290 Amps .10 seconds B/ Low 17,1002.10 cycles 20,497 Amps .023 seconds C/ Low 16,5002.10 cycles 19,363 Amps .016 seconds D/ Low 16,5002.10 cycles - 14,286 Amps .01 seconds F/ Low 11,0002.10 cycles 10,893 Amps .016 seconds G/ Low 5,0002.10 cycles 3,248 Amps .017 seconds (1) Maximum Design Fault Current is, in all cases, equal to or greater than the maximum predicted fault current. , . , (2) Envelopes the primary and backup device clearing times. Protective equipment setpoints are listed in Table 3.8-1 of the Catawba Technical Specifications. Maximizing faults are determined by using the maximum design level fault current at the corresponding voltage level and using fifty (50) feet of cable impedance from the bus to the fault location for Type B, C, F and G penetrations and the minimum installed cable lengths for the Type A and D penetrations.
. Rev. 7 1 5
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PENETRATION PROTECTION
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