ML17249A830
| ML17249A830 | |
| Person / Time | |
|---|---|
| Site: | Ginna  |
| Issue date: | 04/10/1980 |
| From: | White L ROCHESTER GAS & ELECTRIC CORP. |
| To: | Ziemann D Office of Nuclear Reactor Regulation |
| References | |
| TASK-03-12, TASK-3-12, TASK-RR NUDOCS 8004150434 | |
| Download: ML17249A830 (29) | |
Text
REGULATORY ORMATION DISTRIBUTION SYS
. 0 (RIDS)
ACCESSION NBR!8000150434 DOC ~ DATE: 80/04/10 NOTARIZFD:
NO FACIL:50 204 Rober t Emmet Ginna Nuclear Planti Unit ir Rochester G
AUTH INANE AUTHOR AFFILIATION NHZTEzL ~ DE Rochester Gas E Electric Corp.
REC IP ~ NAME REC IP IENT AFFILIATION Offjce of Nuclear Reactor Regulation ZIEMANNiD LE Office of Nuclear Reactor Regulation DOCKET 05000244
SUBJECT:
Forwards addi aualificatjon vjrtua]l.y iden analysis make DISTRIBUTION CODE A001 TITLE: Gene NOTES'nfo requested by NRC 80)328 ltr re environ of electr)cal eauipment, Info provided tice,lto utj l 790810 l,tp.Requests that use of previously suppli'ed info.
S COP IES. REC)IVEO t LTR"J ENCL'~
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I RECIPIENT ID CODE/NAME ACTION'5 BC 0~ g INTERNAL: 01 F
12 I 17 ENGR,BR 19 PLANT SYS BR 21 EFLT TRT SYS OELD EXTERNAL! 03 LPDR 23 ACRS COPIES LTTR ENCI 7
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- COPIES, LTTR ENCL 1
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1 l989 TOTAL NUMBER OF COPIES REQUIRED:
LTTR 38 ENCL 37
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ROCHESTER GAS AND ELECTRIC CORPORATION o
89 EAST AVENUE, ROCHESTER, N.Y. 14649 LEON D. WHITE, JR.
VICE PRESIDENT TELEPHONE AREA CODE TIE 546.2700 April 10, 1980 Director of Nuclear Reactor Regulation Attention:
Mr. Dennis L. Ziemann, Chief Operating Reactors Branch No.
2 U.S. Nuclear Regulatory Commission Washington, DC 20555
Subject:
Environmental Qualification of Electrical Equipment R.
E. Ginna Nuclear Power Plant Docket No. 50-244
Dear Mr. Ziemann:
Your letter dated March 28,
- 1980, which was received on April 7, 1980, presented the NRC Staff schedule for review.of environmental qualification of electrical equipment.,
Enclosure 1
to your letter requested that the plant data listed in Enclosure 2 be provided to the NRC Staff by telephone in the near future and that the plant data listed in Enclosure 3 be provided by May 1, 1980.
We have reviewed the enclosures and have found that they are virtually identical to an information request that we received on May 1, 1979 from Mr. R. Snaider of your Staff regarding SEP Topics VI-2.D and VI-3.
On August 10, 1979 we provided detailed responses to Mr. Snaider on an informal basis.
These responses, in general, referenced previous submittals.
We suggest. that your current analysis efforts make use of the previously supplied information and subsequent Staff analysis results.
For your information, we have attached our August 10, 1979 information package.
Should you have any further questions regarding these
- data, please contact us.
Very truly yours,
~
~
L. D. Whi e, Jr.
foot 5
(lg
RESPONSES TO TELECOPY.FROM R.
SNAIDER TO RGB 5/1/79 SEP TOPICS VI-2.D and VI-3, "MASS AND ENERGY RELEASE INS'IDE CONTAINMENT" GENERAL:
As will be apparent in the RGB responses to this SEP Topic quiz, much of the information requested is available from docketed material.
Question 1.
Containment Information Containment total volume Containment net free volume
Response
Containment total volume LOCA Containment Inte rit Anal sis 1.13 x 10 cu. ft.
1.13 x 10 cu. ft.
6 6
Containment net free volume 1.066 x 10 cu. ft.
6 0.972 x 10 cu. ft.
6 The LOCA analysis was performed to obtain a conserva-tively low estimate of peak containment pressure since, for purposes of determining post-LOCA peak clad temperatures, a "minimum backpressure" condition is conservative.
This "LOCA" analysis found in Exxon Topical Report XN-NF-77-58 (Ref 51).
The "Containment Integrity Analysis",
on the other hand, refers to the FSAR analysis found in Section 14.3.4 (Ref 52). This analysis was performed using assumptions which would result in a conservatively high estimate of the mass and energy released to the containment, as well as minimum containment heat removal capability.
Such assumptions, of course, result in a conservatively high value for post,-accident peak containment pressure.
8/lo/79
Question 2.
Passive Heat Sinks Identify structures, components and equipment that act as passive heat sinks within the containment.
Provide the following information:
a.
total exposed heat transfer surface area with clarification if the exposed area is for one or both sides of the material b.
total equivalent thickness c.
thermo-physical properties (i.e., density, specific heat, and thermal conductivity).
Response
The passive heat sinks within containment that were used in the LOCA analysis are listed in Table 2.4 of Reference N1.
This reference describes the heat sink, its thickness and material.
For struc-
- tures, the surface areas listed are for one side only. For beams, however, the surface area listed is for the total surface area (i. e., surface area A+B+C+D+E+F+G+H) where H
E' This convention is consistent with the inputs to the containment response codes used.
The thermo-physical properties are also listed in Reference N1.
The passive heat. sinks within con'tainment that were used in the Containment Integrity Analysis are listed in Table 14.3.4-1 of Reference N2.
The thermo-physical properties are not referenced but should be the same as those used in the LOCA analysis.
Question 3.
Initial Containment Conditions
Response
Initial containment atmosphere conditions for:
a.
temperature b.
pressure c.
relative humidity Provide minimum, maximum and nominal values of each for evaluation of conservatism and margin.
F Containment Conditions minimum nominal maximum temperature
('F) pressure (psig) humidity (8) 90-2. 0 100 0
50 120
$3. 0 100 The minimum and maximum values of containment temperature are inputs to the analyses in references 1 and 2, respectively.
The minimum and maximum pressures are taken from the Ginna Technical Specifications, paragraph 3.6.2.
Question 4.
\\
a ~
Parameters and their setpoints to activate spray system b.
Spray system activation time The time associated with each of the following is needed (indicate whether or not they are additive):
(1) time elapsed until signal to activate spray system is reached (2) time elapsed between reaching signal to activate spray and contact closure (total instrumentation lag time)
(3) time required for diesel generator to attain full operating speed (4) time required for loading of containment spray pump (5) time required to open isolation valve (6) time required for containment spray pump to achieve full speed (7) time required to fillspray system piping and deliver water to spray header c ~
d.
e.
Spray flow rate Temperature of water at spray nozzle Spray system heat exchanger (1) type of heat exchanger, such as tube and
- shell, U tube, 'ross flow, counterflow and paral lel flow (2) heat transfer surface area of heat exchanger (3) overall heat transfer coefficient for heat exch ang er (4) heat exchanger coolant inlet temperature (5)
-heat.exchanger. coolant flow rate
Pg P
Response
, The majority of this information was supplied in Reference N3.
The containment spray system is actuated on:
2 out of 3 Hi-Hi Containment Pressure signals or manually The Hi-Hi Containment, Pressure setpoint is 30 psig The fastest containment spray actuation time is stated in Reference N3 as 2 sec.
The slowest containment spray actuation time would consist of the following approximations:
delay time for containment pressure instrument 1.0 sec diesel generator startup time
- 10. 0 sec time for spray pump to come up to speed
- 5. 0 sec measured time for spray valves to open
- 12. 0 sec time to fillthe largest unfilled spray
- 22. 5 sec piping (inc. ring header)
Since the spray pumps come up to speed while the valves are opening, only the valve opening time will be used in calculating the overall delay.
There is no delay time associated with sequencing the spray system onto the diesel-backed emergency
- buses, since the spray system is loaded onto the bus as soon as the hi-hi containment pressure signal is generated, and the emergency bus is up to required voltage.
The longest containment spray actuation
=
1.0
+ 10
+ 12
+ 22.5
= 45.5 seconds.
This is very conservative, since flow would begin prior to the time the spray valves were full open, and spray would occur as the ring header was filling.
The runout. flow rate per spray pump is 1800 gpm.
This is the flow rate used in the LOCA analysis.
The spray flow used in the containment integrity analysis is 1200 gpm per pump.
The spray pump performance curve is presented in Reference N2.
The source of spray water is the Refueling Water Storage Tank (RWST) which is at ambient temperature of the Auxiliary Building.
The RNST water is assumed to be at, 37'F for spray and at 60'F for Safety Xnjection in=the LOCA analysis (Ref.
N1).
There are no spray heat exchangers;
- however, the Residual Heat Removal (RHR) heat exchanger pro-vides for long-term cooling of water being recir-culated from the containment sump.
Attachment 1
provides information on the RHR heat exchanger.
~
~
Question 5.
Fan Cooler a.
Delay time before the fan cooler becomes effective for heat removal (equivalent informa-tion to 4.6 above) b.
Heat removal capability of the fan cooler.
Provide a curve or table of the energy rate as a function of containment temperatures.
The containment temperature should be in the range of 70'F to 500'F.
Response
Reference N3 provides the requested information for minimum delay time (20 seconds)
The contain-ment integrity analysis asumes a starting time of 45 seconds (Ref N2).
The maximum heat removal capability of the fan coolers is presented in Reference N3.
The heat removal capability used in the Containment Integrity Analysis is presented in Reference N2.
Question 6.
Identify any other containment heat. removal system that affects the containment temperature response.
Provide the same type of information as in Item 4
above.
Response
There are no other heat removal systems.
~ e
~
Question 7.
Bass and EnercCrr Release Data Provide the mass and energy release rate data for a spectrum of MSLBs and LOCAs.
Reference to exist-ing data previously submitted to the staff is acceptable.
Reference or describe methods used to calculate mass and energy releases.
Enclosure II describes information needed by the staff.
Response
For LOCA mass and energy release data see Reference 4 ~
Mass and energy release data for a NSLB is generally discussed in FSAR Section 14.2.5 and steam flow curves are presented in the accompanying figures.
LOCA mass energy release has been presented in Section 14e3 of the FSAR for the containment integrity analyses and in References 1 and 4 for the most recent Appendix K analyses.
Methodology for each of these analyses is presented or referenced in each of these documents.
I r
~ a
10 Question:
ENCLOSURE II Additional Information Required Describing the Plant's Mass and Energy Inventories (PNR)
Response
Response:
1.
Reactor Rated Power.
1520 NW 2.
Steam flow rate per steam generator at full power 6
3.13 x 10 lb/hr per generator
Response
3.
Fluid mass in each steam generator at full power and hot shutdown.
1681 cu. ft. at HFP 2821 cu. ft. at HZP 4.
Fluid energy in each steam generator at full power and hot shutdown.
Reslnnse:
The energy can be calculated from the following:
513.8'F at 770 psia at HFP saturation at 547'F at HZP
Response
5.
Steam line flow area.
The area varies as illustrated below:
Steam Generator outlet Reducer Steam Piping 28.250 in. I.D.
31 in. x 30 in.
30-MS-600-1 Ref.
52 Fig. 10.2-1 36-MS-600-1 Ref.
52 Fig. 10.2-1 24-MS-600-1 Ref.
52 Fig. 10.2-1 Flow limiter 16 in. I.D.
where:
36-MS-600-1 is 36" 'OD nominal wall
= 1.656 in.
30-MS-600-1 is 30" OD nominal wall
= 1.406 in.
24-MS-600-1 is 24" OD nominal wall
= ~%4 in.
I. <54 6.
Time when steam isolation valves will close on a main steam line break.
Response
The time delay from when the required parameters reach the trip setpoint until the main steam iso-lation valves close is assumed to be 5 sec.
7.
Mass of unisolated. steam between a steam generator and the isolation valve following closure of main steam isolation valves.
4'
11
Response
Mass of unisolated steam from "A" steam generator to isolation valve equals 1176 g.
Mass of steam from "B" steam generator to isolation valve equals 2412 5.
N 8.
Additional mass of unisolated steam if the main steam isolation valve nearest the break fails to close.
Response
Response:
Additional mass, of.unisolated steam in the event of isolation valve failure equals "A" loop 50 "B" loop 50 9.
Main feedwater line flow area.
The area varies as illustrated below:
14-K')-90 0-1 20-FM-900-1 14-PM-900-1 2 0-H1-90 0-1 14-FN-900-1 Ref.
42 Figure 10.2-2 Ref.
g2 Figure 10.2-2 Ref.
52 Figure 10.2-2 Ref.
g2 Figure 10. 2-2 Ref.
52 Figure 10.2-2 where 14-H7-900-1 is 14.00 in O.D.,
12.124 in. ID.
20-FN-900-1 is 20.00 in O.D., 17.438 in. ID.
10.
Main feedwater enthalpy.
Response
The enthalpy can be calculated from:
steam generator pressure
= 774 psig feedwater temperature
= 432'F 11.
Time when main feedwater isolation valves will close following a main steam line break.
Response
8 Open FCV-466 FCV-476 Inches Time Ih Seconds Time In Seconds 50 75 100 1 1/4 1 7/8 2 1/2 4.46 6.45 9.51
- 4. 66 6.23 10.38 At full power these valves run at 50% open.
- Note These times include instrument delay time but not response time to accident parameters.
12 12.
Mass and temperature of feedwater between a
steam generator and the feedwater isolation valve.
Response
The mass of feedwater between the "A" steam generator and its first isolation valve is 9346 The mass of water between the "B" steam generator and its first isolation valve is 18,300 N.
The temperature of the feedwater between the generators and their respective isolation valves is 432 F.
13.
Mass and temperature of feedwater above 240'F between a steam generator and any redundant feedwater isolation valve.
Response
The mass of the feedwater between "A" steam generator and the redundant isolation valve (feedwater pump discharge valve) is 76,895N.
The temperature between the steam generator and number 5 heater is 432'F.
The temperature between number 5 heater and the feedwater pump discharge valve is 354'F.
The mass of the feedwater.between "B" steam generator and the "B" feedwater pump discharge valve is 85,849N.'he temperatures are the same as described for the "A" steam generator.
14.
Mass and temperature of all feedwater above 240 F.
Response
The mass and temperature of all feedwater above 240'F has yet to be determined.
The requirements to perform this task represent more than a fair amount of effort.
Since the mass has been determined to the redundant isolation valve for both a feedwater and main steam line break'in containment, the valve of performing this exercise is not clear..
15.
Time when auxiliary feedwater injection will begin following a main steam line break.
Response
A main steam line break will cause an SI which will in turn start the motor-driven auxiliary feedwater pumps (MDAFP ).
The turbine-driven auxiliary feedwater pump (TDAFP) will start only on loss of buses 11A and 11B (which are non-IE
.buses not powered from the diesel generators, and would thus be lost during a loss of offsite power) or on low-low steam generator level in both steam generators.
13 The minimum time for auxiliary feedwater injection can be conservatively determined by assuming full auxiliary feedwater flow when the pump breaker is closed.
With offsite power available; the breaker for "A" MDAFP will close 30 sec. after the generation of an SI signal.
The breaker for "B" MDAFP will close 32 sec. after the generation of,an SI signal.
The TDAFP will not start unless a low-low steam generator level is reached in both steam generators, since buses 11A and 11B should still be available.
With no offsite power; 10 sec.
must be added to the above times for the MDAFP to allow for starting the diesel generators and 5 seconds for the pumps to attain fuel flow.
The TDAFP would start a
minimum of 3 sec.
following loss of offsite power.
Response
16.
Auxiliary feedwater flow rate and enthalpy.
MDAFP design assumption 200 gpm TDAFP design assumption 400 gpm With offsite power available; a
MSLB would result in 2 MDAFP operating with a total flow of 400 gpm.
The TDAFP would not start until a low-low steam generator level is reached on both steam generators.
With.no offsite power available; a MSLB,would result in 2 MDAFP and 1 TDAFP operating with a total flow of 800 gpm.
The enthalpy can be calculated from the following:
auxiliary feedwater temperature 32 to 80'F Auxiliary feedwater pressure is slightly greater than steam generator pressure 17.
Time when core flooding system will begin in-jection following a LOCA.
Response
The first high-head SI pump reaches full flow at 15 sec.
The first low-head SI pump reaches full flow at 25 sec.
The accumulators start injecting when system pressure decreases below 700 psig.
This will naturally vary depending on the size of the break.
See Figures
- 2. 7 and, 2. 8 of Ref. 51.
18.
Fluid mass in the reactor system at full power and hot shutdown.
14
Response
Fluid mass can be calculated from the following:
HFP HZP RCS volume (cu. ft. )
6245 pressurizer steam space (cu. ft.) -320 RCS fluid volume 5925 6245
-600 5645 system pressure (psia) temperature
('F) 2250 547 2250 573.5 Tave 544.5 T
602.5 T
650 PPzr.
650 This information was obtained from Reference N7.
Response
19.
Fluid energy in the reactor system at full power and hot shutdown.
This can be calculated using the values in question 18.
20.
Hot and cold leg line flow areas.
Response
Reactor Vessel to MCP NCP to S.G.
S.G. to Reactor Vessel 27>> in ID
= 31 in ID 29 in ID
Response
21.
Core flooding system flow rate and temperature.
Minimum SI system flow rate is presented in Reference N5 Maximum SI system flow rate is presented in Reference 56 Accumulator flow rate shown in Figures 2.7 and 2.8 Reference Nl SI water is taken from the KIST.
See the response to question 4.
22.
Sensible heat in the core and reactor system metal that is above 240'F at full power operation.
Response
The information is presented in Reference N2 Table 14.3.4-2.
Response
23.
Initial hot and cold leg temperatures.
See the response to question II-18.
A ~,
15 References 2.
ECCS Anal sis f PWR Ev y is for the R. E. Ginna Reactor with ENC WRE -2 aluation Model, XN-NF-77-58, December 1977.
M-Final Facilit Descri for R.
E. Ginna y
cription and Safety Analysis Report (FSAR) 3.
Letter from K.
Amish of RGK to E.
G.
Case of the USAEC dated November 25, 1974.
I 4.
Letter from L. D. White of RGB to D. L.
2 '
d F b 2,
1979.
5.
Application for Amendment to Operating License dated March 7, 6.
Letter from L.
D dated July 29, 1977.
D. White of RG&E to A. Schwencer of USNRC I 7.
RGB Interoffice m
'ce memo, R.C.
Mecredy to B.A. Snow, G.J. Nrobel,
. Ij/I/ESTINGHOUSE ELECTRIC CORPORATION ATOMIC POM/ER DIVISION PRE LIIIINARY OUTI.IHE SKETCH DUTY RE(UIREHEHTS UA,= 7-4S IO
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DIMENSIONS SHOWN ARE APPROXIMATE AND ARE GIVEN FOR REFERENCE ONLY.
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'REMARKS<
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Rochester Gas and Electric Corporation Inter-Office Correspondence May 1, 1979
SUBJECT:
SEP Xnformation TO:
B.A.
Snow PG; J'.'sWiobelV Jim Shea asked that I check some plant data that Herb Fonticella, an SEP reviewer, was going to use.
The following are the values T.
supplied:
RCS volume 6245 ft3 (Uprating report, Tl.2-1)
RCS temp.
avg. in vessel 573.5'F (Tl. 2-1)
Letdown flow 40 gpm Steam generator pressure 770 psia (T4.1-4)
(measured in June 1978 as 774 psia)
Steam generator water volume 1681 ft3 at 100% power (T4.1-4)
Steam generator steam 'volume 2898 ft3 at 100$ power (T4.1-4)
Emergency feedwater flow 200 gpm for the motor driven pumps 400 gpm for the steam driven pump Steam flow 3.13 x 106 lb/hr per generator Blowdown 40 to 70 gpm per generator RCM/sh R.C. Mecredy'
4M.
fJ