ML20207K218

Provides Analysis Justifying Operation Up to 82% Power Based on Safe Shutdown Cooling Following 90 Minute Interruption of Forced Circulation.App R Condensate Model Train a Represents Limiting Case

ML20207K218
Person / Time
Site:	Fort Saint Vrain
Issue date:	12/30/1986
From:	Warembourg D PUBLIC SERVICE CO. OF COLORADO
To:	Berkow H Office of Nuclear Reactor Regulation
References
P-86683, TAC-66574, NUDOCS 8701090360
Download: ML20207K218 (90)

Text

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2420 W. 26th Avenue, Suite 1000, Denver, Colorado 80211 December 30, 1986 Fort St. Vrain Unit No. 1 P-86683 Director of Nuclear Reactor Regulation U. S. Nuclear Regulatory Commission Washington, D.C.

20555 Attention: Mr. H. N. Berkow, Director Standardization and Special Projects Directorate Docket No. 50-267

SUBJECT:

Analysis of Firewater Cooldown for 82% Power Operation

REFERENCES:

1) PSC Letter, Warembourg to Berkow, dated December 30, 1986 (P-86682)

2) LER 86-026, dated August 17, 1986 (P-86587)

Dear Mr. Berkow:

The purpose of this letter is to provide the NRC with the analysis that justifies power operation up to 82% power based on Safe Shutdown Cooling following a 90 minute Interruption of Forced Circulation (10FC). This letter is a followup to the Reference 1 submittal which provided the NRC with the analysis that justifies power operation up to 39% power utilizing both the steam generator reheater and economizer-evaporator-superheater (EES) sections, i

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P-86683 Page 2 D:cembsr 30, 1986 As described in Attachment I to Reference 1,

this submittal justifies the P2 power level which relies only on the EES section of the steam generator for Safe Shutdown Cooling following a 90 minute 10FC. The analysis (GA Report 909269) involves three different shutdown modes:

1) Firewater Safe Shutdown Cooling, 2) Appendix R Condensate Model Train A, 3) Appendix R Firewater Model Train B.

This analysis is included in Attachment 1 of this letter and is summarized below:

1) FIREWATER SAFE SHUTDOWN COOLING Changes from the EES Analysis in Reference 1 The P2 power level analysis takes credit for a new 6" vent line on each main steam loop header for a discharge path to the atmosphere for the once through cooling mode.

(The previous analysis took credit for the existing bypass flash tank drain lines leading to the condenser). The new 6" vent lines (one per loop) which are scheduled to be installed prior to operation above the P1 power level (39%) result in a higher firewater flow rate and greater heat removal capability.

These new 6"

vent lines will meet all requirements for Safe Shutdown Cooling including a seismic event and for Environmental Qualification.

Major Assumptions Firewater cooling utilizing the EES section of one steam generator following a 90 minute 10FC 87% reactor thermal power prior to 10FC Firewater flow path as modified above Full helium inventory Results Peak fuel temperature of 2858 degrees Fahrenheit is below the FSAR fuel temperature limit of 2900 degrees Fahrenheit The steam generator maintains its integrity since the maximum helium inlet temperature of 1501 degrees Fahrenheit is below the allowable temperature of 1660 degrees Fahrenheit as analyzed in Attachment 7 of Reference 1

._=

P-86683 Page 3 December 30, 1986 The circulators remain operable since the inlet helium temperature of 120 degrees Fahrenheit is below the allowable temperature for an operating circulator as analyzed in

' 1 of Reference 1 A

minimum of 12 degrees Fahrenheit of subcooling is maintained in the hottest steam generator EES module

2) APPENDIX R CONDENSATE MODEL TRAIN A Changes from the EES Analysis in Reference 1 The flow path has been revised to incorporate an initial 5 hour5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> open loop venting period utilizing the 6"

vent lines described above.

Subsequent to this, the closed loop flow path is re-established to for the duration of the cooldown A make-up supply is required during the initial 5 hour5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> open loop period to provide additional cooling water to the condensate system.

The revised model will be explained further in future correspondence Major Assumptions Condensate cooling utilizing the EES section of one steam generator following a 90 minute 10FC 82% reactor thermal power prior to 10FC A 5 hour5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> open loop period as described above Closed loop operation for the remaining cooldown Full helium inventory Results Peak fuel temperature of 2888 degrees Fahrenheit is below the FSAR fuel temperature limit of 2900 degrees-Fahrenheit The steam generator maintains its integrity since the maximum helium inlet temperature of 1477 degrees Fahrenheit is below the allowable temperature of 1660 degrees Fahrenheit

P-86683 Page 4 December 30, 1986 The circulators remain operable since the inlet helium temperature of 140 degrees Fahrenheit is below the allowable temperature for an operating circulator A

minimum of 16 degrees Fahrenheit of subcooling is maintained in the hottest steam generator EES module

3) APPENDIX R FIREWATER MODEL TRAIN B Changes from the EES Analysis in Reference 1 The flow path has been revised to incorporate an initial 5 hour5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> open loop venting period utilizing the' 6" vent lines described above.

Subsequent to this the closed loop flow path is re-established to for the duration of the cooldown.

A makeup supply is not required for Train B i

Major Assumptions The same assumptions for the Appendix R condensate model train A apply except that firewater provides circulator motive power and secondary cooling Results It has been determined that the analysis for train A bounds train B since train B has a greater heat removal capability utilizing the firewater pumps. Therefore, this case has not been analyzed in detail since train A is the limiting case.

It was approximated that this mode will support 87% power As summarized above, the Appendix R condensate model train A represents the limiting case.

Therefore, P2 power level is 82%

reactor thermal power.

The analysis of all other FSAR accidents that rely on the EES section i

for 82% power operation has not been completed. This analysis will be sent in a future submittal to the NRC. Along with that submittal, PSC is still scheduled to submit the proposed Technical Specification change to eliminate reliance on the steam generator reheater section for Safe Shutdown Cooling and a description of the changes to.the Appendix R models as outlined in Attachment 1 of Reference 1.

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P-86683 Page 5

-December 30. 1986 If you have any questions, please contact Mr. M. H. Holmes at (303) 480-6960.

Very truly yours,

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D.W. Warembourg, Man (ger

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Nuclear Engineering Division-DWW/KD:pa Attachment T

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ATTACHMENT 1

LPT holl 2127 GA Technologies Inc.

W A 1485 'MEv.10/82)

ISSUE

SUMMARY

1 TITLE EES C00LDOWNS FOR EQ AND APPENDIX R EVENTS O R&D APPROVAL LEVEL 2

O

&S WITH VENT LINES (1.5H DELAY) g ON DISCIPLINE SYSTEM 00C. TYPE PROJECT 00CUMENT NO.

ISSUE N0/LTR, I

01 CFL 1900 909269 N/C QUALITY ASSURANCE LEVEL SAFETY CLASSIFICATION SEISMIC CATEGORY ELECTRICAL CLASSIFICATION I

FSV-I FSV-I N/A d

APPROVAL ISSUE PREPARE 0 DESCR!PTION!

ISSUE DATE F N0iNG FFL CABLE g

ENGINEERING CW8S NO.

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REV SH 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 REV SH 1

2 3

4 5

6 7

8 9

10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 (LUTTENBBR. WOR)82,83 SR-7415 PAGE 1 OF2605

909269 N/C ISSUE

SUMMARY

(CONT.)

Issue Summary 1, la 814 2

SUPERHEAT Computer Runs

=

30 ST5961 (31 pages) 2-31

=

1 ST5256 (31 pages)

Calc.' Review Report

=

16 ST5016 (29 pages)

Appendix A

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33 ST5982 (31 pages)

Appendix B

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2 ST6205 (29 pages)

Appendix C

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ST6242 (30 pages) 507 ST6271 (30 pages) 2 RECA Computer Runs ST0416 (253 pages)

ST6327 (30 pages)

ST5728 (254 pages)

ST6350 (29 pages)

ST6547 (30 pages) 2 TAP Computer Runs

= 1026 ST6417 (29 pages)

ST7044 (445 pages)

ST6386 (29 pages)

ST4870 (581 pages)

ST6367 (30 pages)

ST6394 (30 pages) 4 SUPERHEAT Computer Runs 116 ST6435 (29 pages)

=

ST3693 (29 pages)

ST6469 (29 pages)

ST3381 (29 pages)

.ST6494 (30 pages)

ST5139 (29 pages)

ST6540 (30 pages)

ST5322 (29 pages)

ST7901 (30 pages)

ST7931 (30 pages) 2 HOT

• MODULE Computer Runs =

58 ST7952 (30 pages)

FSV 821 (29 pages)

ST7987 (31 pages) 831c (29 pages)

ST8010 (28 pages)

ST8037 (37 pages)

ST8061 (30 pages)

ST6223 (31 pages)

ST6313 (31 pages)

TOTAL 2605

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e Page -l a

909269 N/C CONTENTS 1.

SUMMARY

4 2.

INTRODUCTION...............................................

6 3

AN A LY S I S...................................................

13 3.1 Water Side Pressure Drop Evaluation..................

13 32 Secondary Sys tem Evaluation..........................

14 3.3 Pri mary Si de Evalu a tion.................~.............

15 3;4 Hot Module Analysis..............;...................

15 4

4 RESULTS....................................................

17 5.

CONCLUSIONS................................................

30 6.

R E F ER ENC ES.................................................

31 IND EP END EN T R EVI EW..............................................

32 APPENDIX A: WATER SIDE FLCW PATHS AND PRESSURE DROP CALCULATIONS.......................................

A-1 APPENDIX B: TAP, RECA, AND SUPERHEAT RESULTS...................

B-1 APPENDIX C: STOR AGE OF COMPUTER ANALYSIS.......................

C-1 FIGURES 2-1.

Firewater flow diagram for EQ case.......................

8 2-2.

Condensate flow diagram for Appendix R case, open loop...

9 2-3 Condensate flow diagram for Appendix R case, closed loop..

10 4-la.

Maximum fuel temperature, EQ case........................

20 4-1b.

Maximum fuel temperature, Appendix R case................

21 4-2a.

Steam generator average module helium inlet temperature, EQcase..................................................

22 4-2b.

Steas generator helium inlet temperature, Appendix R case..........................................

23 4-3a.

Cir culator helium flow rate, EQ case.....................

24 Page 2

909269 N/C 4-3b.- Circulator helium flow rate, Appendix R case.............

25 4

4-4a.

Primary system pressure, EQ case.........................

26 4b.

Primary system pressure, Appendix R case.................

27 4-5a.

Hot module inlet helium temperature, EQ case.............

28 4-5b.

Hot module inlet helium temperature, Appendix. R case.....

29 i

TABLES 2-1.

Summary of Operating Conditions..........................

12 4-1.

EES cooldown from max. power.............................

18 i

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909269 N/C i

l 1.

SUMMARY

i The purpose of this study was to evaluate the power level at which safe shutdown cooling can be perfccmed using EES cooldown without exceeding the maximum fuel temperature of 2900*F and without boiling in l

secondary side of steam generators.

Safe Shutdown Cooldown transients on a single loop (6 modules) following a 1.5 h interruption of forced cooling, were studied to evaluate fire water cooling capability with open vent lines. Two cases were studied: one case with cooldown on equipment satisfying Environmental Qualification (EQ) testing I

requirements, the EQ case; a second us.ng equipment satisfying 10CFR50 l

Appendix R requirements, the Appendix R case. The EQ case involves the firewater system in an open loop arrangement for supplying water to the l

steam generator and Pelton wheels. The Appendix R case involves water

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supply from the condensate system operating open loop for 5 h followed by closed loop operation.

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Conditions fce the EQ case included 940 gpm of 80*F firewater flow l

to the Economizer Evaporator Superheater (EES) sections of six steam I

generatcr modules in one loop with helium flow adjusted to maintain 255'F steam generator water exit teeperature at 76 psia indicated l

pressure. Conditions for the Appendix R case included 100*F, 939 gpm condensate flow to the EES section of one loop with helium flow adjusted to maintain 2558F steam generator water exit temperature at 76 paia indicated pressure for the first 5 h of the cooldown.

After 5 h the cooling in the Appendix R case was transferred from open to closed loop with water flow decreased to 491 gpm with helium flow then adjusted to maintain 368'F steam generator water exit temperature at 268 psia l

indicated pressure. The liner cooling system was assumed to be unavailable for both cases.

The results from the transient predictions showed a cooldown can be obtained from 85% reedwater (87.5% power) using EQ equipment and about 80% feedwater (83.2% power) using Appendix R equipment. The helium flow Page 4

909269 N/C j

required to maintain subcooled water conditions at EES exit varied between a minimum of 1.45 (13.6 lb/s) and a maximum of 3.8% (37 lb/s).

This is within the operating range of a single circulator on Pelton wheel. The peak fuel temperature, as predicted by the RECA code, was -

2858aF for the EQ case and 2888*F for the Appendix R case. These are below the FSAR 2900*F limit. Primary coolant pressure stayed below the prestressed concrete reactor vessel (PCRV) relief valve setpoint. The reheater and EES sections of the steam generator were maintained within allowable operating limits throughout the cooldown transient. The boiling margin in the hot module was 12*F below boiling for the EQ case and 16*F below boiling for the Appendix R case.

Based on the above results, it was concluded that an acceptable EES

- cooldown can be obtained from 87.55 power using firewater (EQ equipment) and from about 83.2% power using condensate (Appendix R equipment).

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909269 N/C 2.

INTRODUCTION At the request of PSC, GA Technologies Inc., in conjunction with Proto-Power Corporation, have performed evaluations of " safe shutdown cooling" a's described in updated FSAR Sections 10.3 9, 10 3.10, and 14.4.2.2.

In Ref.' 1 it was pointed out that steaming as predicted in the FSAR in the main bundle (EES) of the steam generator may degrade secondary coolant flow rate to the degree that safe shutdown cooling i

could be compromised.

The analysis in the FSAR was based upon 1000 gpm firewater flow to the EES modules of one loop and slightly less than 35 2

helium flow provided by boosted firewater to one circulator Pelton i

drive.

l This study represents a follow-on effort to the Ref. I study. This study presents evaluations made to determine power levels at which safe shutdown cooling can be performed using EES without boiling in secondary

i system'and wiutout exceeding max fuel temperature of 2900*F.

In Ref. 2, 1.5 h delay EE' S cooldowns were evaluated for firewater and condensate water flow at 395 and 785 power for the existing design configuration.-

The purpose of this study is to evaluate similar cooldowns from a higher power level with design modification in secondary water circuit. For this study a new 6-in. vent line was included in the firewater and condensate cooldown, (open loop) case that was not used in the Ref. 2 study.

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Two limiting cooldown methods were established that involve either the firewater system for a cooldown on equipment satisfying EQ require-ments or the condensate system for cooldown on equipment satisfying the 10CFR50 Appendix R requirements. The conditions specified for these two cooldown cases are as follows:

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909269 N/C EQ Case:

1.

As shown in Fig. 2-1, 940 spm of 80*F water is supplied to the EES for entire cooldown transient from the firewater system in an open- (open to atmosphere) loop configuration.

2.

Water temperature of 255'F is maintained at steam generator exit at an indicated pressure of 76 psia at PI-22129 (loop 1) or PI-22130 (loop 2).

Appendix R Case:

1.

As shown in Fig. 2-2, 939 gpm of 100*F water is supplied to the EES for initial 5-h period of the cooldown transient from the condensate system in an open loop configuration. Water flow from the steam generator is assumed to be vented to the atmosphere via the new 6-in. vent lines located in the module exit lines.

2.

After the initial period, cooling is switched to a closed-loop configuration with 491 gpm of 139'F condensate supplied to the EES as shown in Fig. 2-3 3

Steam generator water exit temperatures are controlled to 257'F at 76 psia for open loop and 368af at 268 psia for closed loop operation.

The temperatures selected for steam generator exit represent mean module temperatures that provide sufficient subcooling margin to prevent boiling in the hottest modules throughout the cooldown transient.

Two trains, A and B, are available for performing the Appendix R cooldown. These trains, which are described in Appendix A, involve the I

condensate system for train A and the firewater system for train B.

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909269 N/C l

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Firewater flow diagram for EQ case Page 8

909269 N/C

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Condensate flow diagram for Appendix R case, open loop Page 9 i

909269 N/C TO PELTou WiiEE1.

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Condensate flow diagram for Appendix R case, closed loop Page 10

909269 N/C Train A was chosen in this study for the Appendix R cooldown due to the lower heat removal (more conservative) capability of the condensate system. Conditions for the two cases including train A and B are i

summarized in' Table 2-1.

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909269 N/C TABLE 2-1

SUMMARY

OF OPERATING CONDITIONS Appendix R EQ Train A Train 8 Main Steam Open Close Open Close Parameters Vent Loop Loop Loop Loop Water flow, (gpm) 940 939 491 1038 782 Water inlet temp., (*F) 80 100 139 80 80 Water outlet temp., (*F) 257 257 368 257 257 Water outlet pressure (psia) 76 76 268 76 102 Heat Duty (10' B/hr) 88.5 73.7 56.2 91.7 69.2 (MW) 25.9 21.6 16.5 26.9 20.2

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909269 N/C 3

ANALYSIS Several computer codes were used to perform the evaluation of the EES cooldown. Steam generator performance was obtained using the TAP code.

For detailed core performance, the RECA code was used. The SUPERHEAT code was used to determine required helium flow rates for input to the RECA code. Also, the SUPERHEAT code provided a more detailed steam generator water side pressure drop. Hot and cold helium temperatures during the 1.5-h delay were obtained from a previous analysis that used the RATSAM code (Ref. 4).

The overall water side pressure drop calculations were performed by Proto-Power (see Ref. 2).

The same versions of the TAP and RECA codes, which are the basis for the FSAR analyses, were used for this analysis.

The following sections briefly discuss the analysis performed in evaluating the EES cooldown cases.

31 Water Side Pressure Drop Evaluation A key parameter in the evaluation of the EES cooldown is the water side (secondary side) pressure drop.

This pressure drop includes the line and valve pressure drops from the supply pump (either condensate or firewater pumps) to the steam generator; the pressure drop in the stean generatcr; and the pressure drop of the steam lines from the steam generator to the atmospheric vent, the condensate storage tank, or back to the supply pump, depending on the flow path.

Appendix A describes the secondary side flow paths for the EES water flow. The overall pressure required to pass the water flow through these flow paths must be within the available pressure capability of the water supply pumps.

Appendix A also shows the condensate and firewater pump head versus flow curves used in the pressure drop evaluation.

The required pressure drop of the secondary side is the sum of the i

pressure drops described above. The water side flow and pressure drops were determined by Proto-Peser Corporation. Also, the available pressure at the steam generator inlet (feedwater ring header) plotted as Page 13

909269 N/C a function of firewater flow through the steam generator was determined by Proto-Power and is presented in Appendix A.

3.2 Secondary System Evaluation The heat transfer and pressure drop for the secondary side of steam generator (water / steam) was evaluated using the TAP (Ref. 5) and the SUPERHEAT (Ref. 7) codes.

TAP is a single-loop transient analysis model of the entire plant, and SUPERHEAT is a steady-state model of the steam generator. The TAP code was used primarily to evaluate the steam generator transient performance; however, the TAP heat transfer results were verified by comparison with the SUPERHEAT results.

In order to obtain proper secondary system evaluation, the follow-l ing calculational procedure was used:

1.

Helium flow rates were determined from the SUPERHEAT code.

The SUPERHEAT calculation was performed for different time points in the cooldown transient to determine the required helium flow necessary to maintain the required water temperature at the steam generator outlet. These flow rates were then used as input for the RECA code.

2.

Steam generator helium inlet temperatures obtained from the RECA code were used as input to the TAP code to evaluate steam generator transient performance.

Circulator inlet helium temperatures cetained from the TAP code were used as input to the RECA code.

3 During the initial 1.5-h delay period (interruption of forced cooling), some reverse flow occurs in the primary coolant loop due to natural convection.

A previous analysis of this effect was performed with the RATSAM code (see Ref. 4).

Hot and cold Page 14

o 909269 N/C helium temperatures were estimated based on results from this study and were input to TAP and RECA for the 1.5-h delay period.

4 The steam generator performance for hot module was evaluated using SUPERHEAT code at the maximum hot to average module helium temperature time point.

3.3 Primary Side Evaluation The core cooling evaluation was performed using the RECA code (Ref. 6).

RECA is a detailed model of the Fort St. Vrain (FSV) core which provides calculations of the helium and solid temperatures throughout the 37 fuel regions.

Helium flow rates from the SUPERHEAT code and circulator inlet helium temperature from the TAP code were input to the RECA code, and the steam generator helium inlet temperatures from RECA were input to the TAP code.

3.4 Hot Module Analysis The inlet helium temperature for a given steam generator module could be higher or lower than the core exit plenum average temperature due to flow and temperature imbalances among the various regions and the relative location of a given module to specific core regions. Mixing occurs as the gas flows through the steam generator due to turbulence and cross-flow paths resulting from tube bundles and other flow path obstacles.

The objective in this study is to prevent boiling in the hot module, which could result in reduced water flow and increased tube temperature in the hottest module. To evaluate this condition, a hot module analysis was performed using the HOT

• MODULE code. The hot helium i

temperature transient was determined with the HOT

• MODULE code using RECA region temperature and flow results as input.

The points in the i

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909269 N/C transient showing the greatest deviation between-hot and average module helium temperature were evaluated with the SUPERHEAT code to determine

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amount of boiling margin.

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909269 N/C 4.

RESULTS Table 4-1 presents the overall results from the computer codes including the Proto-Power pressure calculations. The sequence of events for these cases was as follows:

1.

A reactor trip occurs at 1 s into the transient, helium flow was ramped to zero in 5 s, and feedwater flow was ramped to zero in 2 s.

Both main cooling loops were shut down.

2.

As a conservative assumption, the steam generator water 4

pressure was assumed to be depressurized early in the i

transient. Beginning at 1 s into transient, the steam generator outlet pressure was ramped from normal 2600 psig to i

250 psig or 75 psig in approximately 500 s.

3 A 75-min delay occurred with no feedwater or helium flow.

4 At 75 min into the transient, the water supply pump was assumed to be started, and the flow to the steam generators of one cooling loop was ramped to full flow in 5 min.

i 5.

The EES outlet water pressure was maintained via the main i

steam vent valve when venting to atmosphere, or LV-3250-2 when 1

operating in the closed-loop configuration.

6.

One helium circulator with Pelton wheel drive was started at 90 min into the transient. At this time, firewater or.

condensate flow to the EES was at full flow.

7.

Helium flow was adjusted to maintain the required water temperature at the EES outlet.-

Page 17 m

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909269 N/C TABLE 4-1 EES C00LDOWN FRO 1 MAX POWER Appendix R EQ Case Case Primary Side Results:

Min. core inlet helium temp., 'F 80.

100.

Circulator helium flow, 5 1.5 to 3.8 1.4 to 3.7 Max. fuel temp., 'F 2858.

2888.

Max. avg. module S.G. helium inlet temp., 'F 1406.

1383 Max. hot module S.G. helium inlet temp., 'F 1501.

1477.

Steam Generator Results:

Initial feedwater flow, 5 85.

80.

Initial reactor power, 5 87.5 82;3 Inlet water temperature, 'F 80.

100./139.

Water flow, gpm 940.

939./491.

S.G. outlet water temp., 'F 255.

257./368.

Max. circulator inlet temp., 'F(a) 120.

140.

Max. economizer outlet tube temp., 'F(a) go,

110, Max. superheater outlet tube temp., 'F(a)

300, 320.

Hot module boiling margin, 'F 12.

16.

S.G. outlet pressure, psia (S.G. ring header) 95.6 95.1 S.G. outlet pressure, psia (at PI-22129/22130) 76.

75.

S.G. pressure drop, paid 38.2 37.7 S.G. inlet pressure, psia 133 8 132.8 Calculated Results:

Total pump flow, gpm 1065.

1064./666.

S.G. water flow, gpm S.G. outlet pressure, psia (at PI-22129/22130) (a)940.

(b) 39./491.

9 72..

Required S.G. inlet pressure, psia (a)133.3 (b)75.

133 Available 3.G. inlet pressure, psia 137; (D}134 f*Proto-PowercalculationsfromAppendixA.

b Estimated values.

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i 909269 N/C 8.

The liner cooling system was assumed to be unavailable.

9.

The thermal capacity of the reheater module in the active loop was conservatively ignored.

The operating points shown in Table 4-1 are from the transient performance at the peak temperatures.

The results show that the EES cooldown can be performed satisfactorily within the head capability of the supply pump. The peak average steam generator helium inlet tempera-ture was 1406*F for EQ case and.1383*F for the Appendix R case.

Peak fuel temperature was 2858'F for the EQ case and 2888'F for the Appendix R case. The peak hot module steam generator helium inlet temperature was 1501*F for the EQ case and 1477'F for the Appendix R Case.

Figures 4-1 through 4-5 present the transient results for the two I

EES cooldown cases at 87.55 and 82.35 power.

Figure 4-1 presents the 1

i maximum fuel temperature, which shows the peak fuel temperature at about l

5.4 h into the transient for the EQ case, and about 5.5 h into the transient for the Appendix R case. Figure 4-2 shows the steam generator helium inlet temperature; Fig. 4-3 shows the helium flow required to maintain the required steam generator water outlet temperature; and Fig. 4-4 shows the primary system pressure.

The pressure remains below the PCRV pressure relief valve setpoint throughout the transient for both cases. Figure 4-5 shows the steam generator inlet helium temperature for the average and hot modules.

Curves from the TAP and RECA runs and tables from the SUPERHEAT code runs for the two cases in Tables 4-1 are presented in Appendix B.

i l

{

l Page 19

909269 N/C i

i h 679488 8eettees 13:40:33 854 STEM FLOW. EE8 C00 LIMO. EO 944 CM all F i

NAXINUM FUEL TEMPERATURE 3000 Y

l 2500 G

R E

E S

i y 2000-1500 0

2 4

6 8

10 TINE, HOURS Fig. fi-la.

Maximum fuel temperature, EQ case 6

Page 20

909269 N/C m ovstes sa e ss - esissies ses sm, sss, enen asw em. 4em. w a MAXIMUM FUEL. TEMPERATURE 3000 TF1AX

.e _

e l2500 f

G R

E E

S p 2000

_P 1500 9

2 4

6 8

10 TIME, HOURS 1

Fig. 4-1 b.

Maximum fuel temperature, Appendix R case Page 21

909269 N/C 8888*070416 14ettees 14:40s33 Mt $ttM FLOW. Etl C00 Lite 4 to 940 GPM 365 F STEAM GENERATOR INLET HELIUM TEMPERATURE 1500

.(

TAVOTF 3

l 1000 G

R E

E S

F 500 s

~

m 9

0 2

4 6

8 10 TINE, HOURS Fig. 4-2a.

Steam generator average module helium inlet temperature, EQ case Page 22

909269 N/C

~

mm smes w as<es wissias ses m. ses, massm asw me, 4 stem, w a STEAM GENERATOR INLET HELIUM TEMPERATURE 1566

(

TAVOTF c

g1...

G R

E E

S 1F 0

-z, 9

2 4

6 8

19 TIME, HOURS Fig. 4-2b.

Steam generator helium inlet temperature, Appendix R case Page 23

909269 N/C l

i Rap $f9448 18else86 18848:33 SS4 Sitml FLOW ECS COOLING. CO $40 GMt 366 F CIRCULATOR HELIUM FLOW RATE 40

-O FLOHTX 30 L

/

B S

/

20 S

5 L

10 6

0 2

4 6

8 10 TIME, HOURS Fig. 4-3a.

Circulator helium flow rate. EQ case Page 24 l

909269 N/C

)

i R8kST51M 184848 'ess58:38 Sea STII, EIS. 3390PR 85W 98. 49tePR. M 8 CIRCULATOR HELIUM FLOW RATE 40 W

FLOHTX

~

C 30 L

B S

/

20 S

E C

k le 0 --

0 2

4 6

8 10 TIME, HOURS Fig. 4-3b.

circulator helium flow rate, Appendix R ca.4e Page 25

... ~ _

909269 N/C mai.ste4:s isnse-s assosias es= sumi ri.ou. rss coeueis, ce see one ass r PRIMARY SYSTEM PRESSURE 700

~

PHPSI 5 )

0 a

600 w-P S

500 I

A 400 k -

m m

~

300 0

8 4

6 3

10 Tit 1E, HOURS l

i i

Fig. 4-4a.

Primary system pressure, EQ case l

e Page 26

909269 N/C mm.s m es aseasess 'esissias ses sta. ses, sasem asw me. *sen, we s PRIMARY SYSTEM PRESSURE 700 PHPSI O

A 600 w-P S

See I

A 400 k

n g

w 300 0

2 4

6 8

10 TIME, HOURS Fig. 4-4b.

Primary system pressure, Appendix R case I

Page 27 l

l l

909269 N/C 854 FW FLOW EQ 940 GPM AT 255 F WATER 2000 Legend Het noduto T

Avg Module e

1500

=

p e

'r a

{,

u 1000 r

e D

e

\\

s see F

. x'"..

i i

e e

i g

0 2

4 6

8 10 12 Time, Hours i

Fig. 4-5a.

Hot module inlet helium temperature, EQ case i

l Page 28 i

I

909269 N/C 804 FU APP. R 939 GPM AT 257 F WATER TO 6.5 HRS 1500 Legend Hot Module

~

T Ave Module 1250

., K e

P e

7 1000 a

L u

r e

750

\\

N

\\.

D i

e g

500 F

'.. -d..

250 0

2 4

6 8

10 12 Time, Hours Fig. 4-5b.

Hot module inlet helium temperature, Appendix R case i

1

)

Page 29 i

909269 N/C 5.

CONCLUSIONS From the results shown in Table 4-1, it was concluded that a satisfactory EES cooldown can be obtained from 855 feedwater flow (87.55 power) with EQ equipment. A cooldown can be performed from

[

approximately 805 feedwater flow (82.3% power) with Appendix R equipment using an open loop for 5 h followed by a closed-loop arrangement for water supply (as specified in the Fort St. Vrain 10CFR50, Appendix R evaluation).

The pressure required to supply the water to the EES is within the capability of die condensate and the firewater pumps. Maximum core fuel temperatures and steam generator tube temperatures are within the allowable limits for these components. The hot module was maintained at subcooled water conditions for both cases.

For the EQ cooldown the control setpoint at the steam generator exit was set at 255'F to prevent boiling at steam generator outlet, and for the Appendix R cooldown the setpoint was set at 257'F open loop and 368'F closed loop to prevent boiling.

l Page 30

909269 N/C 6.

REFERENCES 1.

CFL 909030 N/C " Study of Firewater Cooldown Af ter 1-1/2 Hour Interruption of Forced Cooling," by R. C. Potter, dated September 16, 1986.

2.

CFL 909268 N/C, "EES Cooldown From 395 and 785 Power Using Condensate or Firewater (1.5-Hour Delay)," by R. C. Potter, dated December 9, 1986.

3

" Safe Shutdown and Cooling with Highly Degraded Plant Conditions,"

Public Service of Colorado Document SSCHDPC Issue 14 (Fort St. Vrain Plant Operating Procedures Manual - Abnormal Procedures for ~ Shutdown Cooling), dated October 7,1985.

4 SAM:113:GJC:77, "PCRV Depressurization Analysis During LOFC - FSV (1055' Power, 2-Hour Delay Through As-Built Train with Rerouted 2-Inch Pipe)," from G. J. Cadwallader to G. C. Bramblett, dated May 3, 1977.

5.

J78-6048-TR-1, " Review of the Fort St. Vrain Transient Analysis Program (TAP)," by James R. Carlson, JAYCOR, dated July 1978.

6.

GA-A13613. "RECA2-A Program for Thermal Analysis of HTGR Emergency Cooling ~ Transients, Program Description," by J. F. Peterson.

7.

GA-D14776, " Steam Generator Daermal Performance Models and Data Reduction," by D. P. Carosella, dated February 1978.

Pago 31

G A1543(R EV.11/80)

CALCULATION REVIEW REPORT TITLE: gEs to.l.l.ws4 /ar E42 APPROVAL LEVEL 2 94 A&;x /f G&s Us#5 Ved lines (/Q// Ds/n.j}

GAL LEVEL 2

OlSCIPLINE SYSTEM 00 C. TYPE PROJECT DOCUMENT NO.

ISSUE NOJLTR.

c c1

c. F i

/100 9o9269 Nfc j

INDEPENDENT REVIEWER:

A $* l h*N' l 7~ W dt A*1 NAME ORGANIZATION W 3 4Me EdWoo*% Iras /*

REVIEWER SELECTION APPROVAL: BR MGR DATE f2/2o/i6 d~.5'lecast]

V REVIEW METHOD:

YES NO ERROR DETECTED

/

ARITHMETIC CHECK LOGIC CHECK d

ALTERNATE METHOD USED SPOT CHECK PERFORMED COMPUTER PROGRAM USED Dsomt4s TAPa J V

Sna. A ts. 3 SoFERHEAT~

W Wo REMARKS: (ATTACH LIST OF DOCUMENTS USED IN REVIEW)

I.

Aus4-nsus + ut c.L<<kas/ -fot' i+1 Lf ekaa$ss

k ow l *.A s

• k*'bA.

c.ve l.Li' mad curs ;alsb 4 *.*4e. h r's Co..e r.4# ave A c, Jens.t tpa aff=c s-A af e.Je:g.' h f A **'* d *N **t **~'S N wasa<-

No eme s se<<.4.}a I<de X* **bs*=1 ea^ '** ' k tSea. Note.4.

2.

TAP a J SuPaedEAT gaf

.f,,c gir Q c s e. 4 r e m,3fe,,,.). d e..cre. d,

sha.~3A eas redo n e.e..a.n d a g ra d M k A ed as, 3

A s**d *stes*~'~~f a& TAP s.J sapennerar te s.J+s.

3 saPetnaT Q.3 4.c h p. s R. cas <. ~ s c esah.

rs.P i ~+ Sw.sk-. y-4< %

t q

W kals~

Q.ds.n. a J f-L_-Ju-44-w.ae.ta. '.,e.o rtar:t.

Th. fsaA )u-fl r-s u s sFg.+ly kip (.wo sr i s+4.J.f 921 3r-).

k n

m 7-a t +.&/. h.4 a.,

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as. la.J4-s us. s.sh'she f RCch im for hf R tnss wss ra. sad

-he *~ - + & earrado a L,'La. TAP rs~

,J +A Ine< usa.f:.

a ws i<. -upM<. af+er s I. A c la:3..

CALCULATIONS FOUND TO VA 0A SiONS TO BE CORRECT:

INDEPENDENT REVIEWER MA 20M i

DATE SIGNATURE Page 32

909269 N/C APPENDIX A WATER SIDE FLOW PATHS AND PRESSURE DROP CALCULATIONS Page A-1

W74& T N/C PROTO POWER CORPORATION

,,,,538togoA

^

CCAPORATICN

$91 POQUONNOCK ACAD GROTON. CONNECTICUT 06340 (203) 446-9725 File:

7511482 December 15, 1986 Mr. Jack Kennedy General Atomic Technologies 10955 John Jay Hopkins Drive San Diego, CA 92121

Dear Mr. Kennedy:

Enclosed is Proto-Power Calculation No. 82-03, Rev.

B, dated December 15, 1986, "EES Safe Shutdown Cooling for PSC - Fort St.

Vrain (3. Main Steam Vent Flow Path)".

This calculation has been revised to evaluate fire water cooling through the main steam vent outlet valve, throttled to maintain 76 psia pressure at PI-22129, with a steam generator outlet temperature of 257'F.

As discussed in our meeting at PSC on December 12, this would be done in order to provide adequate subcooling on the average to accommodate hot modules and instru-ment error.

The resultant flow rate is 948 GPM, with a pelton wheel flow of 125 GPM.

Based on previous Proto-Power calcula-tions, this flow rate would be reduced to approximately 942 GPM with 175 GPM pelton wheel flow.

If you have any questions, please do not hesitate to call me at (203) 446-9725.

Sincerely, G. W. Geaney, Manager Engineering Services MJF: mas Enclosure cc:

K. Dvorak F. Tilson Apr 4-2.

~

~

^

1s9249 N/c CALCULATION COVER SHEET PROTO-P0llER CORPORATION TITLE:

EES SEAFE SHUTDOWN COOLING FOR PSC - FORT ST. VRAIN (3.

MAIN STEAM VENT FLOW PATE)

CALCULATION No.:

82-03, REv. n FILE NO.: ' 7511482 CALCULATED BY P.M. Breglio DATE /2-Y~84 CHECKED BY M.J. Fekete DATE /2-E-f6 D/aye A 3

909c2dfAl/C.

-03

• B lPAGE 1 OF 3

PROTO POWER CORPORATION

,,o 1,

g, D. moes. u s2-s6 96 GROTON, CONNECTICUT

'* Xf.TF 7511482 CuENT PROJECT psc SUNECT EES - MAIN STEAM VENT Fist PATH INDEX 1.

PURPOSE 2

2.

METHOD 2

3.

RESULTS 3

4.

REFERENCES 3

ATTACHMENTS:

A.

Computer Input Files

(

and Printouts B.

Drawings:

7511482-PF-01 Sh.

1, Rev. B 7511482-PF-01 Sh. 2, Rev. A 7511482-PF-04

, Rev. A 0

fa'p A-V

90949A//C

'^"'

82-03

"'" B 2 or 3 cac e PROTO POWER CORPORATION onio m Tom DATE GROTON, CONNECTICUT D """ "

48 %

REVIEWED j)y P

7511482 CUENT PROJECT S @ ECT EES - MAIN STEAM VENT FLOW PATH PURPOSE To determine:

1.

Fire water flow rate through EES Section of Steam Generator The flow path is through the new main steam vent valve with 257'F sub-cooled water exiting the steam generator EES section, and 76 psia steam generator back pressure.

The overall flow path can be traced on the computer input file of Page 1 of Attachment A and depicted in the drawings that consti-(

tute Attachment B.

METHOD The program described by Reference 1 was used to calculate flow rates and pressure drops.

Furthermore, in order to determine the temperatures within the steam generators, another program developed by PPC was used.

For this purpose, a primary coolant steam generator inlet temperature of 1400*F (approximately appropriate for 904 power conditions) was assumed, and primary coolant flow rate was adjusted to produce 257'F water at the steam generator outlet.

The pressure 1

at PI-22129 was controlled to 76 psia by throttling the main steam vent valve (reducing valve Cv in the input file), thereby assuring subcooled conditions throughout the flow path and in each EES module.

The average temperatures within the steam generator are then entered in the input file (see Page 1 of Attachment A).

These temperature values do not have a strong effect on the overall flow rate and pressure distribution.

It was moreover decided that the asymmetry of the flow path (the vent lines coming of f one of steam generator outlet legs) would not produce noticeably different flow rates in each of the six modules of one loop, since most of the resistance in the path is constituted by the modules themselves.

The flow path used for the input file is then representative.

Pa.p A ~f

90p69 /c.

4 82-03

""* B

' 3 catc w or 3 PROTO POWER CORPORATION on,GmTOR DATE b-GROTON, CONNECTICUT p.nessue 12-15-96 REVIEWED JOB NO CUENT PROJECT SUBJECT EES - MAIN STEAM VENT FLOW PATH RESULTS S.G. Flow Rate 948 GPM

=

76 psia (I)

Back Pressure

=

(9 PI-22129) 64 psig (1) Page 3 of Attachment A shows that even in the most re-strictive part of the flow path for the 5 other modules, the pressure drop is minor.

Therefore, the pressure drop is minor.

Therefore, the pressure measured by PI-22129 should be just slightly higher than the pressure at PT.

200

(

76 psia - see Attachment A, Page 2)

REFERENCE 1.

PPC Calculation 82-09,

" Pressure Drop Program", dated November 17, 1986.

C ap -s

9MM9 4//c CAL C. 82-e % Xed. 8 R7Mc m EAfr A

~'

}*db

/ C9/?

3

• • • FILE: FWTDMSVL.DAT ***

EL

-FL.-

TF

- MIN

- MAX ID

-WDIV-K(FIX)- K(VAR)-

EPS SECTIDN 34 1

1-4

,10.020, 0.1, 5.88, 522.1,1.500D-4, 2.1, 1,

80.0, NA NA 23 4-6

, 6.065, 0.1, 3.37, 292.7,1.500D-4, 25.9, 1,

80.0, NA NA 3:

6-7

, 7.981, 0.1,

.91, 61.4,1.500D-4, 0.2, 1,

80.0, NA NA 4

7-B 7.870, 1,

4.9, 30.1,1.500D-4, 0.3, 1,

80.0, NA NA 5

8-9 9.516, 1,

37.0, 59.7,1.500D-4, 4.3, 1,

80.0, N A ',

NA 6

9-10 9.172, 1,

.98, 136.3,1.500D-4, -60.6, 1,

80.0, NA NA 7

10 - 11 9.172,1.81,

.42, 94.2,1.500D-4,

-0.3, 1,

80.0, NA NA O: 11 - 12, 3.152, 6,

10.4, 102.1,1.5000-4, 9.0, 1,

80.0, NA NA 9

12 - 18 3.150, 6,

.62, 0.0,1.500D-4, 0.0, 1,

80.0, NA NA 10 18 - 19 3.346, 6,

.59, 26.2,1.500D-4,

-4.6, 1,

80.0, NA NA 11: 19 - 20 0.886, 108, 104.30, 495.3,8.202D-5, 27.0, 1,

80.2, NA NA 12: 20 - 21 0.874, 108,

.01, 12.2,8.202D-5, 0.9, 1,

80.0, NA NA 13: 21 - 22 0.898, 324,

.72, 0.0,0.202D-5, 0.0, 1,

80.0, NA NA 14: 22 - 23, 0.724, 324, 209.50, 26.0,8.202D-5, 2.2, 1,

80.0, NA NA 15 23 - 23A, 0.724, 324, 0.00, 2467.3,8.202D-5, 4.0, 1.

81.4, NA NA 16: '23A-23B, 0.724, 324, 0.00, 0.6,8.202D-5, 0.0, 1,

81.4, NA NA 17: 23B-24 0.724, 324, 0.00, 0.6,8.202D-5, 0.0, 1,

82.8, NA NA 10 24 - 24A, 0.550, 324, 0.11, 1818.0,8.202D-6, 2.7, 1,

96.0, NA NA 19 24A-25, 0.550, 324, 0.00, 0.0,8.202D-6, 0.0, 1,

96.0, NA NA 22: 25 - 26, 0.590, 324,

.77, 166.8,8.202D-6, 4.6, 1,

109.2, NA NA 21: 26 - 26A, 0.590, 324, 0.00, 1540.1,0.202D-6,

-3.3, 1,

183.1, NA NA 22 26A-27 0.590, 324, 0.00, 0.0,8.202D-6, 0.0, 1,

183.1, NA NA 23: 27 - 28 0.590, 324, 1.34, 270.1,8.202D-6, -11.0, 1, 257.0, NA NA 24 20 - 29 0.768, 108, 0.12, 15.3,0.202D-6,

-0.9, 1, 257.0, NA NA 25 29 - 30 0.969, 108, 1.48, 525.6,8.202D-6, -27.0, 1, 257.0, NA NA 21: 30 - 31 3.803, 6,-

.66, 23.0,1.500D-4, 4.6, 1,

257.0, NA NA 27: 31 -200, 5.826, 6,

1.5, 182.2,1.5000-4, 49.0, 1,

257.0, NA NA 20: 200-201 4.411, 1,

.60, 4.3,1.500D-4, 0.0, 1, 257.0, NA NA 29:

HV-A 4.411, 1,

0.0, 0.0,1.500D-4, 0.0, 6,

257.0,1130.0, 1.0 l

32: 201-202, 4.411, 1,

.11, 14.2,1.500D-4, 1.3, 1,

257.0, NA NA 31:

HV-B 4.411, 1,

0.0, 0.0,1.500D-4, 0.0, 6,

257.0, 168.0, 1.0 32: 202-203, 4.411, 1,

.11, 17.4,1.500D-4, 1.3, 1, 257.0, NA NA 33: 203-204 4.411, 1,

1.0, 0.0,1.5000-4,-

0.0, 1,

257.0, NA NA 34: 204-204A, 4.411, 2,

1.0, 0.8,1.500D-4, 0.0, 1, 257.0, NA NA e

/kpA7 m

90116 9 A//c C AL C. 92-05, EEU. B

)?77ACWMF#7 /?

74 L

of 3

FLOW = 948 GPM AT 80 xF7 USE PUMP CURVE CDR ENTER PRESSURE 3 (Y/N):Y?

TYPE OF PUMP (ENTER NO. FROM 1 TO 5): 17

~ PUMP (S) ARRANGEMENT (ONE=0 - PARALLEL =1 - SERIES =2): 0?

ADDITIONAL FLOW (USE WDIV=0.1 IN INPUT FILE!)= 125 GPM7 FLOW e PUMP =1073.00 GPM AT BB.BxF PUMP HEAD

= 103.17 FT/ STAGE FILE FWTOMSVL.DAT - NO. OF SECTIONS = 34

- TWO-PHASE SECTIONS' DIVIDER = 10 SECTION ID K

FLOW P(IN)

P(OUT) 1 :

1-4 10.020 14.1 533,595 145.5 142.8 23 4-6 6.065 8.1 533,595 142.0 124.0 3:

6-7 7.981 1.9 533,595 124.0 123.3 4:

7-8 7.870 5.4 471,433 123.3 121.8 5:

8-9 9.516 38.7 471,433 121.8 115.2 6:

9 - 10 9.172 3.1 47*,433 115.2 140.8 7

10 - 11 9.172 2.0 260,460 140.8 140.8 0: 11 - 12 3.152 12.4 78,572 140.8 133.5 9 : 12 - 18 3.150 0.6 78,572 133.5 133.3 10: 18 - 19 3.346 1.1 78,572 133.3 135.0 11: 19 - 20 0.086 116.9 4,365 135.0 107.1 12: 20 - 21 0.874 0.3 4,365 107.1 106.7 oo PRESS

<CR>

TO CONTINUE **

SECTION ID K

FLOW P(IN)

P(OUT) 13 21 - 22 0.898 0.7 1,455 106.7 106.7 14: 22 - 23 0.724 210.3 1,455 106.7 98.4 15: 23 - 23A 0.724 74.7 1,455 98.4 93.7 to: 23A-23B 0.724 0.0 1,455 93.7 93.7 17: 23B-24 0./24 0.0 1,40b Y3.7 YJ./

10 24 - 24A 2.550 46.2 1,455 93.7 87.7 19: 24A-25 0.550 0.0 1,455 87.7 87.7 22: 25 - 26 0.590 4.9 1,,455 87.7 85.4 21: 26 - 26A 0.590 33.7 1,455 85.4 84.0 22 26A-27 0.590 0.0 1,455 84.0 84.0 23: 27 - 28 0.590 6.8 1,455 84.0 88.0 24: 28 - 29 0.768 0.4 4,365 88.0 88.2 25: 29 - 30 0.969 10.8 4,365 88.2 98.1 23: 30 - 31 3.803 1.1 78,572 98.1 96.1 27: 31 -200 5.826 4.5 78,572 96.1 76.0 20 200-201 4.411 0.7 471,433 76.0 74.1 29:

HV-A 4.411 0.0 471,433 74.1 73.4 Wer=3,581,731 30: 201-202 4.411 0.3 471,433 73.4 71.9 31:

HV-B 4.411 0.0 471,433 71.9 38.4 Wcr=

518,497 32; 202-203 4.411 0.4 471,433 38.4 36.8 33: 203-204 4.411 1.0 471,433 36.8 34.0 oo PRESS (CR>

TO CONTINUE **

SECTION ID K

FLOW P(IN)

P(OUT) 34: 204-204A 4.411 1.0 235,717 34.0 13.0 X:IN= 0.00 OUT=

4.10

/QtIe A-8 oo PRESSURE AT END OF SYSTEM = 13.0 PSIA REPEAT WITH NEW CONDITIONS (Y/N)?

CALC. 82-03 2e a E 9'W

'R

1. 77ACAMENT

~ T 57

.9

?F. 3

.* :.. i '..

e

.v.

.:. o.

• • • FILE: 32TO290.DAT ***

MIN

- MAX EL

-FL.-

TF ID

-WDIV-K(FIX)- K(VAR)-

EPS SECTION 1

1 a 32-299

, 5.826, 1,

.21, 34.6,1.589D-4, 0.0, 1, 257.8, NA NA FLOW = 798 GPM AT 257 xF7 USE PUMP CURVE COR ENTER PRESSURE 3 (Y/N):N7 GTARTING PRESSURE = 76.4 PSIA 7 ADDITIONAL FLOW (USE WDIV=8.1 IN INPUT FILE!)= 125 GPM7 FILE 32TO299.DAT - HO. OF SECTIONS = 1

- TWO-PHASE SECTIONS' DIVIDER = 18 SECTION ID K

FLOW P(IN)

P(DUT) 1 a 32-298 5.826 9.7 371,348 76.4 76.2

• • PRESSURF AT END OF SYSTEM = 76.8 PSIA REPEAT WITH NEW CONDITIONS (Y/N)?

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CURVE 1.:

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NO PSA PSI PSI PSI PSI i

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APPENDIX C STORAGE OF COMPUTER ANALYSIS l

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i 909269 N/C APPENDIX C STORAGE OF COMPUTER ANALYSIS The results presented in Appendix A were generated with the TAP, RECA, and SUPERHEAT codes. The SUPERHEAT code is stored in production file GA* PROD. SINGLE /2777FSV2. The basic TAP code is stored in the archive file SYSD1619. The RECA code, the TAP plot code, and the runstreams (contained code changes and data changes) for all the l

computer runs described in this study are stored in archive file SYSD4040. The computer runs made for this study are identified as follows:

TAP RECA SUPERHEAT HOT

• MODULE EQ case ST7044 ST0416 ST3693 FSV821 Appendix R case ST4870 ST5728 ST5139 831C The SUPEREEAT cases obtained to. determine the helium flow rates for the other cases are as follows:

EQ case Appendix R Case 940 gpm 939 gem 491 gpm ST5961 ST6547 ST7901 ST5256 ST6417 ST7931 q

ST5016 ST6386 ST7952 ST5982 ST6367 ST7987 ST6205 ST6394 ST8010 ST6242 ST6435 ST8037 ST6271 ST6469 ST8061 ST6327 ST6494 ST6223 ST6350 ST6540 ST6313 l

The SUPERHEAT runs made to study the hot module were:

ST3381 ST5322 Page C-2 L_