ML20087C705

Nonproprietary Rev 1 to Vols 1 & 2 of AP600 Design Certification Program SPES-2 Tests Final Data Rept

ML20087C705
Person / Time
Site:	05200003
Issue date:	07/31/1995
From:	Conway L, Hundal R, Loftus M WESTINGHOUSE ELECTRIC COMPANY, DIV OF CBS CORP.
To:
Shared Package
ML19330G155	List: ML20087C698 ML20087C705
References
WCAP-14310, WCAP-14310-R01, WCAP-14310-R1, NUDOCS 9508090331
Download: ML20087C705 (150)

Text

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n AP600 RECORD OF CHANGES Form 582M (1-91) b AP600 DOCUMENT NO. PXS-TZR-100 REVISION 1 ALTERNATE DOC. NO. WCAP-14309 (W Proo. Class 2). WC E 3Jo (W P roc. DESIGN AGENT ORGANIZATION Westinghouse Electric Corporation Class 3) TITLE AP600 Desian Certification Procram. SPES-2 Final Data Reoort =___ CHANGE PARAGRAPH CHANGE DESCRIPTION AND REASON ENGINEER NUMBER NUMBER APPROVAUDATE

1) Sections 4.2.10, The initial issue of the results gMA 4.2.13, and 4.2.14 of the blind tests performed at e dW/MTl4 added.

SPES-2 have been added to the 7//p/' 7 Figures 5.1-1,5.1-2 report. (Tests No.s 500908, 501211, and 5.4-2 (pp.5.1-5, and S01512) 5.1-6 and 5.4-4) added. Table 5.1-1 (pp.5.1-3 and 5.1-4) revised. Pages 5.4-2, 6-1 and O 6-2 revised. O Appendix G revised, adding blind test file references.

2) Plot 30 for Sections The reported rod bundle collapsed gg g )

4.2.2 through 4.2.13 liquid levels and resulting fluid 7[M[@f, were revised to show steam fractions were revised. These corrected rod bundle values have been re-determined using collapsed liquid level the sum of the delta-pressures ob-vs. time, tained from instruments OP-011P, DP-012P, and DP-013P. The pressure Pages 4.2.2-6, 4.2.2-9, taps of these instruments extend 4.2.3-2, 4.2.4-9, from 3.82 in, below the bottom of the 4.2.5-6, 4.2.5-9, heated portion of the rod bundle, to 2.24 in, below the top of the heated 4.2.6-9, 4.2.7-9, 4.2.8-7, 4.2.8-8, portion of the rod bundle; and there-4.2.8-9, 4.2.8-10, fore they will directly provide a'close 4.2.9-9, 4.2.12-7, approximation of the above parameters and 5.3-3 revised. over the 12 ft, long heated portion of the bundle. This change was prompted Figures 5.3-5 and by the fact that the previous rod bundle 5.6-6 (pp. 5.3-10 collapsed levels were determined based l and 5.6.9) were on DP-000P. The range of this instrument revised. used in the data reduction was found to be error as discussed in item 3 below. p U Y 0 aM y 21:n

AP600 RECORD OF CHANGES h m 18 PA O 91) REVISION 1 AP600 DOCUMENT NO. Px5.TZR-100 ALTERNATE DOC. NO, WCAP-14309 (W Proo. Class 2). WCAP-14310 (W Prop. Class 3) CEstGN AGENT ORGANIZATION ,,4, p,, ,,,4 SPES-2 Final Data Report TITLE AP600 Design Certification Program, CHANGE PARAGRAPH CHANGE DESCRIPTION AND REASON ENGINEER APPROVAUDATE NUMBER NUMBER

3) Appendix G, DP-000P The range of instrument

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data in the listed DP-000P was corrected, and files have been revised. the upper tap of this instrument 7/g/f5 Appendix C, p. C-6 coincides with the upper tap of Appendix F, p. F-13 instrument DP-014P. Figures 2,4-1 and 2.4-2 (pp. 2.4-5 and 1 2,4-6) 3 AP600 volumes listed are in M,

4) Table 2.2-2 ft.3 SPES-2 accumulator and (p. 2.2-6) not IRWST volumes corrected.

7//f. Revised to clearly state that g

5) Page 2.6-22 SPES,2 power did not match specified power for test 500706.

7//9/9 / Revised to properly reflect

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6) Appendix F conversion of OP's from raw data to English unit pressure and level.

7/j,7/gf Minor revisions / corrections based

7) Appendix C, pages on updated SIET documentation (Ref'

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8) Pages 5.6-2 and E{'s ca 5 6'3 7/g/%2 i

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AP600 DOCUMENT COVER SHEET Form 58202G(5/94) AP600 CENTRAL FILE USE ONLY: 0058.FRM RFS#: RFS ITEM #: } AP600 DOCUMENT NO. REVISION NO. ASSIGNED TO '^ PXS-TZR-100 1 Page 1 of 4 ALTERNATE DOCUMENT NUMBER: 14310 WORK BREAKDOWN #: 2.6.16.1 DESIGN AGENT ORGANIZATION: WESTINGHOUSE TITLE: AP600 DESIGN CERTIFICATION PROGRAM SPES-2 TESTS FINAL DATA REPORT ATTACHMENTS: N/A DCP #/REV. INCORPORATED IN THIS DOCUMENT REVISION: N/A PXS TZR-100/Rev. O CALCULATION / ANALYSIS

REFERENCE:

klECTRONIC FILENAME ELECTRONIC FILE FORMAT ELECTRONIC FILE DESCRIPTION U:\\1625W.WPF Wordperfect 5.1 WINDOWS DOCUMENT TEXT AND FIGURES U:\\1625.FRM Wordperfect 5.1 WINDOWS COVER SHEET (C) WESTINGHOUSE ELECTRIC CORPORATION 1995 O WESTINGHOUSE PROPRIETARY CLASS 2 -,(d This document contains information proprietary to Westinghouse Eledric Corporation; it is submitted in confidence and is to be used solely for the ) puroose for which it is furnished and returned upon request. This document and such information is not to be reproduced, transmitted, disclosed or used otherwise in whole or in part without prior written authorization of Westinghouse Eledric Corporation, Energy Systems Business Unit, subject to the legends contained hereof. O WESTINGHOUSE PROPRIETARY CLASS 2C This document is the property of and contains Proprietary information owned by Westinghouse Electric Corporation and/or its subcontractors and suppliers. It is transmitted to you in confidence and trust, and you agree to treat this document in strict accordance with the terms and conditions of the agreement under which it was provided to you. @ WESTINGHOUSE CLASS 3 (NON PROPRIETARY) COMPLETE 1 IF WORK PERFORMED UNDER DESIGN CERTIFICATION OR COMPLETE 2 IF WORK PERFORMED UNDER FOAKE. 1 @ DOE DESIGN CERTIFICATION PROGRAM - GOVERNMENT UMITED RIGHTS STATEMENT ISee pag 2] Copyright statement: A license is reserved to the U.S. Government under contract DE ACO3 90SF18495. O DOE CONTRACT DELIVERABLES (DEUVERED DATA) Subject to specified exceptions, disclosure of this data is restricted until September 30,1995 or Design Certification under DOE contract DE ACO3-90SF18495, whichever is later. EPRI CONFIDENTIAL: NOTICE: 1 20 3 4 5 M CATEGORY: A G B C D E F 2 O ARC FOAKE PROGRAM - ARC UMITED RIGHTS STATEMENT ISee page 2) Copyright statement: A license is reserved to the U.S. Government under contract DE FCO2 NE34267 and subcontrad ARC-93-3 SC 001. O ARC CONTRACT DEUVERABLES (CONTRACT DATA) Subject to specified exceptions. disclosure of this data is restricted unde,r ARC Subcontract ARC-93-3 SC-001. j ORIGINATOR / O3 SIGNATURE /DATlE MMa kWr M95 AP600 RESPONSIBLE MANAGER SIG ' ~ ( APgVAL DATE f gg ,hgg{ E. J. Piplica ' Approval of the responsible manager signifies that docume complet all required reviews are com ele

fils (Vaftached and document is released for use.

m hrannsu m w w., n m

AP600 DOCUMENT COVER SHEET Page 2 LIMITED RIGHTS STATEMENTS For A '3202G(5,94) i DOE GOVERNMENT UMITED RIGHTS STATEMENT . These data are su_bmitt_od with rimeted right_s under government contract _No DE.A.Cc3 90$F18495. These p) .sedb,me,_e e o e.,e,s o - o, ~ w we en,.,. of th. con.. r - s.s of n anu actu er not d:s:iosed outsee the governrrert. encept trat the government may d,sdose these data outsae the governm.nt r r for the following purposes, if any, provided that the government makes such disclosues subied to prohibet.on aga,r si further use and d<scicsure: This *Proprie'ary Data

• may be discicsed for evaluation purposes under the restrictions above.

(1) The *Propr.etary Csa' rray be d:sclosed to the Eiedric Power Research InstitJte (EPRI) electnc utaity representat4es and ths't (11) direct consuRants, esclud.ng direct commersal competaors, and the DOE National Laboratories under the prohibitcns arel restriders above. (3) This notice shall be marked on any reproduction of these data, in whole or in part. ARC UMITED RIGHTS STATEMENT: This proprietary data, furnshed under Subcontsact Number ARC 93 3 SC 001 with ARC may be duplicated and used by the government and AFIC, sutdoct to the limitations of Article H 17.F. of that subcontrad. with the express limaations that the proprietary data may not be disclosed outside the government or ARC, or ARC's Class 1 & 3 members or EPRI or be used for purposes of manufacute wrthout prior permission of the Subcortractor, except that further disdosure or use may be made sonety for the following purposes: r This proprietary data may te disclosed to other than commercial competbrs of Subcontractor for evaluston purposes of this subcorttact under the restr etion that the proprietary data be reta.ned in confidence and not be further disclosed, and subject to the terms of a non d:sclosure agreement between the Subcortractor and that organization, excluding DOE and as contractors. DEFINITIONS CONTRACT /DEUVERED DATA - Consists of docurnents (e.g. specifications, drewings, reports) which are generated under the DOE or ARC contracts which contain no background proprietary data. EPRI CONFIDENTIALITY / OBLIGATIONNOTICES 6 NOTICE 1: The data in this document is subjed to no confidentiarity obligations. NOTICE 2: The data in this document is proprietary and confidertialto Westinghouse Electric Corporation and/or as Contiseto s. It ' forwarded s to recipient under an obligation of Confidence and Trust for limaed purposes only. Any use. disdoeure to unauthorged persons, or copying of this document or parts thereof is prohibited except as agreed to in advance by the Electric Power Research instnute (EPRI) and Westinghouse Electric Corporaten. Recipient of this data has a duty to enquire of EPRI and/or Westinghouse as to the uses of the information cortained herein that are permrtted NOTtCE 3: The data in this document is proprietary and confidentialto Westinghouse Electric Corporaton and/or ks Contractors. It is forwarded to recipient under an obligation of Confidence and Trust for use only in evaluaten tasks spoofical:y authorized by the Electric Power Research Institute (EPRI). Any use, disclosure to unauthorized persons, or copying this document or parts thereof a prohibited except as agreed to in advance by EPRI and Westinghouse Electric Corporaten. Recipiert of the data has a duty to inquire of EPRI and/or Westinghouse as to the uses of the information conta.ned heisen that are permitted. The document and any copies or excerpts thereof that may have been generated are to be returned to Westinghouse, directh or through EPRI, when requested to do so. NOTICE 4: The data in this document is proprietary and confidentia: to Westinghouse Electric Corporation and/or its Contractors, it is being rev eaisd in confidence and trust on9 to Empluyees of EPRI and to certain contractors of EPRI for Gmned evaluaten tasks authorized by EPRt. Any use, d;sdosure to unauthor.2ed persons, or copying of this documert or parts thereof is prohibAed Th;s Document and any copits of escerpts thereof that may have been generated are to be returned to Westinghouse, directly or through EPRI, when requested to do so. NOTICE 5: The data in this documert is proprietary and confidential to Westinghouse Electric Corporation and/or its Cortractors. Access to this data e given in Confidence and Trust onPy at Westinghouse facilit es for Gmrted evaluaton tasks as. signed by EPRI. Any use, disclosure to unauthorged persons, or copying of this documert or parts thereof is prohibited. Netther this document not any excerpts therefrom are to be removed from Westanghouse facilaies. EPRI CONFIDENTIALITY / OBLIGATION CATEGORIES C ATEGORY 'A' - (See Dehered Data) Consists of CONTRACTOR Foreground Data that is contained in an issued reported. C ATTGORY 'B'-(See Defkered Data) Consists of CONTRACTOR Foreground Data that is not contained in an issued report except for ) computer programa. C ATEGCRY 'C' - Consists of CONTRACTOR Background Data except for computer programs. C ATEGORY 'D'- Consists of computer programs de.etoped in the course of performing the Work C ATECCRY *E' - Consists of computer programs developed prior to the EffectNe Date or aP.er the Eftectrve Date but outside the scope of the Work. CATEGORY *F' - Corsists of adm;n;s'.ratNe p:ans and adm.nistratrve reports. l -N! 1

'l INSTRUCTION SHEET FOR REVISION 1 OF THE AP600 SPES-2 TEST - ^[^') FINAL DATA REPORT - VOLUME I %./ Enclosed you will find Section 2.2 and subsections 4.2.2, 4,2.3, 4.2.4, 4.2.5, 4.2.6 and 4.2.7. Please remove and replace the following wetions and subsections of the Final Data Report, Volume I as follows: Section Remove: Replace with: Cover and Spine Cover and Spine Cover and Spine (Revision 1) Table of Contents v v 2.2 2.2-5 and 2.2-6 2.2-5 and 2.2-6 ] 2.3 2.3-5 and 2.3-6 2.3.5 and 2.3-6 2.4 2.4-5 2.4-5 2.4-7 2.4-7 2.6 2.6-21 and 2.6-22 2.6-21 and 2.6-22 4.2.2 4.2.2-3 and 4.2.2-4 4.2.2-3 and 4.2.2-4 4.2.2-5 and 4.2.2-6 - 4.2.2 5 and 4.2.2-6 p 4.2.2-9 and 4.2.2-10 4.2.2-9 and 4.2.2-10 V PLOT:30*. PLOT:30* 4.2.3 4.2.3 1 and 4.2.3-2 4.2.3-1 and 4.2.3-2 PLOT:30* PLOT:30* I 4.2.4 4.2.4-9 and 4.2.4 10 4.2.4-9 and 4.2.4-10 PLOT:30* PLOT:30* 4.2.5 4.2.5-5 and 4.2.5-6 4.2.5-5 and 4.2.5-6 4.2.5-9 and 4.2.5-10 4.2.5-9 and 4.2.5-10 PLOT:30* PLOT:30* _j 4.2.6 4.2.6-9 and 4.2.6-10 4.2.6-9 and 4.2.6-10 PLOT:30* PLOT-30* 4.2.7 4.2.7-9 and 4.2.7-10 4.2.7-9 and 4.2.7-10 PLOT:30* PLOT:30* .I l ) O aevieed di=ox 'o's ooi proviaeo ror *c^e-i43io nev i: the ci ss 3 "oo-eroerietary aenort-n e m:W6n1625. ins.non: th073105 REVISION: 1 i

m e i <a m ) W..,X ~ TABLE OF CONTENTS (Cont.) D ~' '~ Section' - Title. Page. 4.2.6 One-In. Cok! Leg Break with Three PRHR liX Tubes, without Non-Safety Systems (S01613)............................. 4.2.6 l ' l 4.2.7. ' Two-In. Direct Vessel Injection Line Break................... 4.2.7-1 '4.2.8 Double-Ended Guillotine DVI Line Break (S00706)............. 4.2.8-1 ~ . 4.2.9. Two-In.' Cold-Leg / Core Makeup Tank Balance Line Break without . Nonsafety Systems................. ...................-4.2.9-1 u 4.2.10 Double-Ended Guillotine Cold Leg to CMT Balance Line Break without Nonsafety Systems (S00908)....................... 4.2.10 4.2.11 Steam Generator Tube Rupture with Nonsafety Systems Operational and Operator Action (S01309)................,........... 4.2.11-1 4.2.12 Steam Generator Tube Rupture without Nonsafety Systems (S0ll10)................................... 4.2.12-1 4.2.13 Steam Generator Tube Rupture without Nonsafety Systems, with Inadvertent ADS (S01211).............................

4. 2.1 3-1 4.2.14 Large Steam Line Break at Hot Standby Conditions without Nonsafety Systems (S01512)............................ ' 4.2.14 L 5.0 TEST DATA CO MPARISON.......................................... 5 l '

LO: 5.i Compeson Basis for LOC As...................................

5. i-i 5.2 Comparison Basis for non-LOCA Events...........................

5.2 5.3 Comparison of Break Loc'ations.................................. 5.'3-1 5.4 - Comparison of Break Sizes '.................................... 5.4-l' 5.5 Effects of Nonsafety' Systems.................................. 5.5-1 5.6 Other Key Test Results....................................... 5.6-1 5.6.1 Comparison of PRHR Performance........................ 5.6-1 5.6.2 Test Repeatability...................................... ' 5.6-2 5.6.3 Comparison of Steam Ger.erator Tube Rupture................. 5.6 2, 6.0 OBSERVATIONS AND CONCLUSIONS. ..............................61 7.0 REFE RENC ES.................................................... 7-1 Appendix A Data Reduction Methods and Validation Process......................l A-1 i Appendix B Data Vali datio n................................................ B - 1 Appendix C SPES-2 Instrument List....................... ................C-1 j - Appendix D SPES-2 Inoperable and Modified Instruments....... ..................D1 Appendix E Error Analysis ................................................E1 Appendix F Full-Height Full-Power Integral Systems Test Delta-P Instrumentation Data Reduction ..............................................F-1 Appendix G SPES 2 Test Data Files.... ..........................G1 i 1 ? ? m Aap60m1625 wifraimi&c.non: l t>072705 y

t .O, TABLE 2.2-1 V. ELEVATION COMPARISON AP600 SPES 2 Difference - Component ft. ft. ft. Lower Plenum Bottom (-7.571) (-7.515) (0.056) i Downcomer Bottom (-6.168) (-6.168) (0) Bottom of Active Fuel (-5.484) (-5.482) (0.002) Top of Active Fuel (-1.827) (-l.822) (0.005) l Top of Upper Head (3.819) (2.779) (1.04) DVI Nozzle (-0.508) (-0.508) (0) Hot-Leg Centerline (0) (0) (0) j Cold-Leg Centerline (0.445) (0.445) (0) \\ Pressurizer Bottom (5.856) (5.856) (0) ] Pressurizer Top (16.953) (12.M6) (4.307) Top of Steam Generator Tube Sheet (4.107) (4.107) (0) Top of U Tubes (14.734) (12.43) (2.304) O CMT Bottom (1.801) (1.801) (0) CMT Top (8.041) (8.041) (0) Accumulator Bottom (-4.026) (-4.026) (0) j Accumulator Top (0.734) (-0.982) (1.716) PRHR HX Bottom (average) (2.667) (2.667) (0) PRHR HX Top (average) (8.026) (8.026) (0) IRWST Bottom (0.533) (0.533) (0) IRWST Water Level (8.53) (8.53) (0) I O m.\\aptm1625ww2.non:lN072895 2.2-5

TAllLE 2.2 2 O VOLUME COMPARISON AP600 SPES-2 SPES-2 volume ideal volume actual volume Component (m') (deca meter') (deca meter') Hot Leg 3.542 8.967 32.6 Inlet Plenum 6.142 15.549 3.72 U-Tubes 25.366 64.218 40.65 Outlet Plenum 6.6(M 16.724 3.72 Pump Suetions 28.51/28.62 Pumps 5.04 12.76 4.33 Cold Legs 3.717 9.41 13.38 Total Loop 1/2 50.413 127.628 126.91/127.02 Surge Line 2.878 7.286 9.63 Pressurizer 36.757 93.056 95.4 Total 39.635 100.34 105.03 Power Channel: Downcomer 21.479 54.377 54.38** Lower Plenum 9.005 22.797 22.83 Riser 20.929 52.985 5 8.81 * *

• Upper Plenum 17.798*

45.058 41.27 Upper Head 21.157 53.562 53.83 j l Total 72.57 228.779 231.12 i Total Primary Circuit 230.819 584.37 590.08 I 4 i Core Makeup Tank 56.634 143.377 143 Accumulator 56.634 143.377 143 IRWST 2006 5078 5078 g SG Secondary Side 157.159 398 388

• DVI nonles included; ** DC-UH bypass included; *" Core bypass included mwunio:5.o:.nonsm:N5 2.2-6 REVislON: 1

Y f h /7' TAlltE 2.31 ~ U PRESSURE VESSEL MAIN CHARACTERISTICS Pressure nominal 2250 psi (15.5 MPa) design 2900 psi (20.0 MPa) Temperature 1 core inlet 529.0 F (276.1 C) core outlet ' 594.3"F (312.4 C) design 688.8*F (364.9 C) Fksw rate hot leg 27.8 lb/sec (12.6 kg/sec.) core bypass 0 lb/sec (0 kg/sec.) downcomer upper-head bypass 0.55 lb/sec (0.25 kg/sec.) Overall Height 34.3 ft. (10.45 m) Net Volume 7.73 ft.' (218.75 dm') Nonle Diameter i hot leg 2.63 in. (66.7 mm) cold leg 2.13 in. (54.0 mm) direct vessel injection 0.463 in. (11.8 mm) tubular downcomer 3.62 in. (92.0 mm) downcomer upper-head bypass 0.957 in. (24.3 mm) Vessel Material AISI 316 Loose Flanges Number lower plenum I riser I core 21 upper plenum / head a m:Vo.1625 02.noa: b-072795 2.3-5 REVISION: 1

O P B{ TABLE 2.3-2 9 POWER CHANNEL MAIN CHARACTERISTICS E ti Flow Huid Body Flange Bolting e Elevations Length D Area Area Volume Volume Mass Mass Mass j Description (mm) . (mm) (mm) (dm') (dn') + (dm') (dn') (kg) (kg) (kg) { Lower Plenum -7515 -66m 915 152 1.81 1.13 16.60 10.30 221 36 27 -6600 -6168 432 216 3.66 2.97 15.50 12.53 Riser -6168 -5568 600 152 1.81 1.13 10 83 6 76 66 40 -5568 -1458 4110 141* 1.65 0.97 67.04 39.68 541 794 329 Uoner Plenum -1458 683 2141 158 1.96 1.96 41.27 41.27 158 39 Unoer Hea! 683 871 188 158 1.96 1.96 3.57 3.56 467 18 [ 871 2709 1838 187 2.75 2.75 50.26 50.26 6 Annat =r Downcomer -878 652 1530 202/168 0 99 0.99 14.87 14.87 3(4 *

• Tubular Downcomer

-800 6076 6270 87.3 0.60 0 60 37.53 37.53 M6 M 23 'k 6020 6168 148 216/182 1.06 0.37 1.57 1.57 Downcomer Upper-600 1425 825 24 3 0.05 0.05 0.38 0 41 11 21.52 6.12 Head Byt+ ass Core Bvoass -5812 -1058 M73 42.9 0 145 0.145 12.37 12.37 93 20.54 3.8 Total 211.12 - 2207 996.06 44 6 Note: The rod bundle mass, upper plate, and grids included, is 239 kg. Octagonal section

• • The metal mass of the separmion cylinder is included in the upper plenum O

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4 2.6.5 Facility Operation for Test S00706 The purpose of S00706 was to investigate the plant behavior and system response following a double-ended guillotine (DEG) break of the DVI-B line (complete Ims of one of two passive injection lines) with passive safety systems only for mitigation. He break is located on DVI-B prior to entry to the power channel. The DEG is simulated by using a spectacle flanp: in the DVI-B line with the blind portion installed; and with a break line, break orifice and break valve installed off the DVI-B line on both the power channel side and CMT sik of the spectacle flange as shown in figure 2.6.5-1. He break valve identified in Figure 2.6.5-1 as BR-05 had an orifice installed at its inlet described in Figure 2.6.5-2. The break valve identified it; Figure 2.J.5-1 as BR-04 had a venturi tube installed at its inlet described in Figure 2.6.5-3 in order to simulate the flow venturi in the AP600 reactor vessel i DVI nozzle. The other orifices installed in the facility are< listol in Table 2.6.5-1. Once the facility was at initial conditions, the test was initiated by simultaneously. opening the break valves. It should be noted that when the reactor trip (R) signal was generated (pressurizer pressure P-027P = 12.41 MPa = 1800 psia), the heater rod bundle power control did not match the specified power decay as shown.in Appendix B (pages B-45, B-46, and B 47). The steam generator MSLIVs were to close with a 2-second delay after the (R) signal. When the S signal occurred (pressurizer pressure P-027P = 11.72 MPa = 1700 psia), the PRHR isolation valve and the CMT injection valves were to be opened and the MFWlVs were to be closed, all with a 2-second delay, and the RCP coastdown was to be initiated with a 16.2 second delay. G: he CVCS, NRHR, and SFW were off throughout the whole transient. The test simulated the failure of one of two stage 1 and 3 ADS valves. The ADS valves were programmed to open versus either CMT level L-A40E or L-B40E or with the delay time shown in Table 2.6.5-2. The accumulators were I pressurized to inject water via DVI when the primary pressure was lower than 4.9 MPa (~700 psia). De IRWST was full to its nominal normal water level so that it would inject water via DVI when the primary pressure at the DVIline was lower than approximately 0.18 MPa (26.1 psia). De test was terminated when the flowrates (F-A60F1F-B60E) from the IRWST were stable (without significant fluctuation), i O mwm25 mowib-072795 2.6-22 REVISION: I Wv -**-*w. w w 2 a

The ADS phase began with the actuation of ADS-1 (at approximately [ ]*" seconds into the O eve t). ^ " s-2 =# d -3 oce"rred withia the eexi t 1"'" ecoed8-Tue "e=t iess comne='atio# nor ie, of the rod hundle power was terminated when ADS-1 occurred, and power was reduced to approximately 90 kW. The ADS actuation increased the rate of primary system depressurization and resulted in high injection How from the accumulators. The rapid injection of cold fluid frota the cecumulators (at [ ]"^" seconds into the event), temporarily refilled the rod bundle, lower-upper plenum, hot legs, and the pressurizer. When the accumulator discharge ended, the flow through the rod bundle was reduced to the injection rate of the CMTs and the PRHR HX flow, a'id two-phase fluid flow occurred again through the rod bundle, lower-upper plenum, hot leg-A, the PRHR HX, and to the pressurizer. The discharge of liquid through the break was replaced by steam at approximately [ l b' mod During this ADS phase, approximately [ ];'6lbm of steam and water were discharged from ADS-1, -2, and -3. This water was primarily supplied by the accumulators. After the accumulators drained the collapsed liquid level in the rod bundle decreased (steam fraction increased) since only the CMTs were providing injection flow. The post-ADS phase began when ADS-4 actuated and fluid was discharged through ADS-4. The fluid discharge through ADS-1, -2, and -3 stopped, and the pressurizer water level decreased. A small amount of CMT flow was still being provided via the DVI line to the annular downcomer. When O sy tem eres ure ned been redeced beiew the gressere corresgendins to the water eievetion head er the IRWST, flow from the IRWST began. Shortly thereafter, the CMT flow ended. The flow from die IRWST refilled and subcooled the power channel and hot legs, and the upper-upper plenum partially refilled. The PRHR HX supply line emptied approximately [ ]*" seconds into the test and was no longer effective. A steady flow of subcooled water was then flowing from the IRWST into die annular downcomer, through the power channel, and left the primary system through the ADS-4 flow paths. The heater bundle remained fully cooled by single-phase water or two-phase mixture flow at all times during this test (data plots 30 and 31). There was no indication of an increase in heater rod temperatures due to lack of cooling (data plot 3). Discussion of Test Transient Phases Initial Depressurization Phase (0 to [ ]*" Seconds) l l The initial depressurizauon phase (IDP) began with the initiation of the break (at time 0) and continued until primary systent pressure reached the saturation pressure of the fluid in the upper plenum and the hot legs (Figure 4.2.2-1). This phase included the following events: R signal at i 1800 psia (decay power simulation initiated and the MSIV closed), and S signal at 1700 psia (the MFWlV closed. the CMT injection line isolation valves opened, and the PRHR heat exchanger m Aa;Wel625w. l.non:lt>.072898 4,2,23

return line isolation valve opened-all with a [ ]'**-second delay, and RCP coastdown started after a [ l*"-second delay). See Table 4.2.2-1. Facility Response during the IDP: From time 0 until the R signal occurred, the system depressurized due to the fluid loss through the break resulting from the expansion of the pressurizer steam volume. The pressurizer partially compensated for the loss of pressure by flashing, however it was drained after [ ]'***' seconds (data plot 32). De R (at [ ]*" seconds) and the S (at [ ](**" seconds) signals were based on pressurizer pressure only. When the R signal occurred, the MSLIV was closed, and power was reduced to 20 percent after a 5.75 second delay and began to decay after a 14.5 second delay. As a result of the power reduction without flow reduction, the core AT decreased due to the low power / flow ratio, and the upper plenum temperature dropped toward the cold-leg temperature. Since system pressure was controlled by the saturation pressure at the hot-leg / upper-plenum temperature, system pressure dropped to the saturation pressure at [ ]('*" (approximately [ ]**' psia at approximately [ ]*" seconds). See Figure 4.2.2-2. When the RCPs tripped (at [ J*" seconds), the rod bundle and the lower-upper plenum temperatures increased due to the increased rod bundle power / flow ratio at the lower flow. System pressure increased temporarily until the decreasing decay power and the decreasing lower-plenum temperature (due to CMT injecting cold fluid into the downcomer) started to reduce the upper-plenum temperature. De primary system pressure decrease resulted from the balance between the steam generation rate h (from flashing primary fluid), the volumetric flow of liquid out the break, and the steam condensation rate by the PRHR HX. Steam was generated by boiling due to the rod bundle power. As system pressure continued to fall, more and more water reached its saturation pressure j and began to flash. PRHR flow started before the RCPs were tripped and continued by natural circulation afterward (data plot 37). Primary system pressure stabilized at the saturation pressure for the bulk hot fluid in the system (approximately [ ](**"), his ended the IDP. Pressure Decay Phase ([ ))'**" Seconds) The pressure decay phase (PDP) began when system pressure (Figure 4.2.2-2) reached saturation pressure corresponding to the fluid temperature on the hot-leg side of the power channel. The phase ended when ADS-1 was opened on low CMT level and augmented the system depressurization. His phase was characterized by a slow decrease in overall system pressure and temperature. The rod bundle power was reduced from 340 kW to 240 kW (data plot 1). The PRHR HX heat removal rate was approximately [ l^" kW He recirculating CMTs provided approximately [ l*" kW of heat removal from the primary system due to the removal of hot water from the primary system, which was replaced with cold CMT water. De initial CMT natural circulation operating mode was followed by draindown injection when the loop B cold legs drained (data plot 38). De U-tubes of the steam generators were completely drained at this time (data plots 20 to 23). De steam generators did not affect the rest of the mwis 5..tnoa:ib.072 95 4.2.2-4 REVislON: I

event. The accumulator injection was initiated when the primary system pressure dropped below -711 psia prior to ADS-1 actuation. However, the injection rate was low (less than l [ ]"^" Ibm /sec.) due to the small difference between primary system pressure and accumulator gas pressure.(data plot 39). Facility Response during the PDP: Following reactor coolant pump shutdown, the oscillating flow in the tubular downcomer and in the rod bundle region continued into the PDP. The flow oscillations resulted in large cscillations of the steam fraction of the mixture exiting the core and flowing into the hot legs (data plots 30 and 31). These oscillations in steam fraction had a significant effect on the thermal buoyancy. head that drove the flow through the primary system at this time, since it affected the mixture density. The steam fraction oscillations were observed through the hot leg and the steam generators (data plots 20 and 21). De steam fraction oscillations were converted to flow oscillations in the cold legs, since the two-phase mixture entering the steam generators left the steam generators as saturated water (data plots 24 through 27). It is postulated that some of the steam was condensed in the U-tubes since the primary-side pressure was higher than the secondary-side pressure at this time, allowing some heat to be transferred to the secondary-side fluid. De remaining steam was separated from the two-phase mixture in the high point of the U-tubes (due to the low velocity), which eventually stopped natural circulation in the U-tubes. For steam generator-A, the flow continued until [ ]"*" seconds into the transient. From LO i 1"^" secoaas u=tii t 1"A" seco#as. iatermit1e=t fiow - s observed thro"8 steam seeerator-h A (plots 20 and 22) A free-water surface occurred at the top of the U-tubes. However, the buoyancy head in the hot leg was high enough to spill over the top of the U-tubes at the peaks of the oscillating buoyancy head. At [ ]"A" seconds, all flow stopped in steam generator-A, since the free-water surface had fallen too low to be overcome by the buoyancy head oscillations. Oscillations were measured in temperatures and pressures.throughout the primary system. When the steam generator U-tubes were drained (approximately [. ]"*" seconds), the oscillations stopped. For steam generator-B, flow stopped earlier than for steam generator-A due to the higher steam fraction in the fluid from hot leg-B. De primary system pressure decay during the PDP started at a slow rate of [ }"** psi /sec. At approximately [ ]"A* seconds into the event, the primary system pressure decay rate increased to [ ]"*" psi /sec. His happened when the transition of the CMTs from their recirculation mode of operation to their draindown mode occurred. De increased rate of pressure j decay was due to the increased injection rate of the cold liquid from the CMTs, which occurred at different times for the two CMTs, and steam flow from the cold legs to the top of the CMTs. De CMTs began injecting cold fluid into the annular downcomer via the DVI line when the S signal occurred. Initially this injection was by natural circulation (at approximately I i [ ]"*" Ibm /sec, from each CMT), with hot water flowing from the cold leg through the cold-' l-O ies beiance iine <Ct8t> into the ton of <he CMT and ceid water fiowins from the bottom of the CMT into the downcomer. In the time period from [ ]"*" seconds to [ ]"*" seconds (data 1 tunapS0m162$el.non:lb-072895 4.2.25

plot 38), CMT-A transitioned to draindown when the cold leg balance line (CLBL) for CMT-A drained, and a free-water surface developed in the top of CMT-A as the level began to drop (data h plot 33). The injection flow, when draindown started, increased to approximately [ l"' lbm/sec. and gradually decreased as the CMT level decreased (reducing the driving head). Steam from the cold legs Howed to the CMTs after the cold legs drained and condensed on the cold CMT and water surfaces, heating them to saturation temperature. For CMT-B, the break of the recirculation in the CLBL occurred at approximately [ l ** ' seconds (earlier than for CMT-A), and the transformation from natural circulation to CMT draindown occurred between [ ]* seconds and [ lb sed W MMa'n @du flow began at approximately [ ]('* lbm/sec. and gradually decreased. The free-liquid surfaces in the CMTs were established after recirculation through the CLBLs ended (the end of recirculation was caused by steam flowing from the cold legs to the CMTs). However. flashing in the CMTs seemed to occur after this time due to the high temperature of the fluid in the top of the CMTs (data plots 15 and 16) and the decreasing primary system pressure. Die steam above the liquid surface in the CMTs was superheated after [ ]('6 in CMT-B. Flashing occurred in order to keep the water temperature at saturation temperature as the pressure decreased. Ele accumulators began to inject into the annular downcomer via the DVI lines when system pressure dropped below 711 psia (at approximately [ l**' seconds). However, the injection h rate was very low prior to ADS-1 (data plot 39). Throughout the PDP, the PRHR removed energy from the primary system. The combined effect of the PRHR cooling the primary fluid and the injection flow from the CMTs was sufficient to lindt the steam fraction of the fluid in the rod bundle to [ ]**) percent (steam fraction was actually decreasing), and to maintain adequate cooling of the rod bundle during this phase (data plots 30 and 31). Automatic Depressurization System Phase ([ ]*' Seconds) Ble automatic depressurization system (ADS) phase began with the actuation of ADS-1 and ended with the actuation of ADS-4 (Figure 4.2.2-1). Facility Response during the ADS Phase: With the actuation of ADS-1, followed by ADS-2 and ADS-3 within approximately [ ] * seconds, the rate of system depressurization increased from [ j* psi /sec. (at the end of the PDP) to [ l^ psi /sec. (at the stan of the ADS phase). Dus rate gradually decreased as system pressure decreased. mvuiusmi.non1wn"5 4.2.2-6 REVISION: I

The fluid in the upper-upper plenum Dashed when the RCPs were shut off and coasted down, and ( ) the measured water level dropped to the hot-leg elevation. This level remained at the hot-leg elevation until the end of the accumulator injection, when the upper-upper plenum became sufficiently subcooled to temporarily condense the steam bubble in the top of the upper plenum (see temperatures in data plot 4). liowever, when the accumulator injection ended, the level again decreased to the hot-leg elevation or below. At[ l**' seconds, the upper plenum was subcooled again and filled with water injected from the IRWST. The presence of liquid level in the lower-upper plenum indicates that the rod bundle was covered with two-phase fluid throughout the entire event. He maximum steam fraction of fluid in the lower-upper plenum was estimated to be [ ]* percent during the PDP from about [ l ' * *"' seconds to [ ]*" seconds. Data plot 30 shows the collapsed levels in the rod bundle oscillating after the pump coastdown (period approximately [ ](**#' seconds). His indicates apparent average steam fractions in the rod bundle region ranging from [ ]'***' percent to [ l**' percent in this period. When the oscillations ended at [ J* seconds, the maximum steam fraction in the rod bundle was [ ]A percent. The accumulator injection completely suppressed boiling in the rod bundle. Flowever, when the accumulation injection ended, the boiling again started and the steam fraction increased and reached a maximum of [ ](***' percent, just before the IRWST injection started during the post-ADS period. The lower-upper plenum showed an apparent higher steam fraction O ofi i' * ' eerceet erior io ADS-4. which was dee ie the fact that the two-cha e mixture ievei in the upper plenum temporarily dropped below the hot leg elevation. Re collapsed level measured just above the top of the heated portion of the rod bundle (TAF, data plot 31) indicates the steam fraction of the fluid exiting the heater rods and are higher than those measured for the rod bundle during this test. l Pressurizer i The pressurizer began to drain when the break occurred and was completely drained in approximately [ l*" seconds (data plot 32). He water in the pressurizer flashed due to the loss of system pressure, and the temperature of the water dropped from [ l"*"*F during this initial depressurization (data plot 18). The hot water leaving the pressurizer surge line into hot j leg-A caused a slight increase in the hot-leg temperature during this period, since it mixed with the flow from the power channel / upper plenum. De pressurizer stayed drained until after ADS-1 occurred, at which time it partially refilled and discharged steam and water via the ADS-1, -2 and

3. De pressurizer level temporarily decreased at about [

]*" seconds when the upper-upper plenum partially refilled. The level slowly decreased as the ster.m fraction of fluid from the power channel increased prior to ADS-4. His contmued until ADS-4, when the pressurizer again drained and its water level reached manometric agreement with the water level pressure in the O V primary system. maapNNA162$w-l.non:Ib-072795 4.2.2-9 REVISION: I

Steam Generator g The steam generators acted as die heat sink until the MSLIV closed and prevented furdier energy removal from the secondary side. This caused the temperature of the secondary side to increase toward the primary system hot-leg temperature, which at the same time was dropping due to the reduced power / flow ratio, When the RCPs coasted down, a temporary temperature increase occurred due to the increased power / flow ratio with natural circulation flow in the primary system (Figure 4.2.2-2). He steam generator temperatures stabilized at approximately [ l'**F at the end of the IDP. For the first part of the PDP, the pressure on the primary side of the steam generator U-tubes was higher than the secondary side (data plot 2). This indicated that some heat transfer from the primary to secondary side was occurring and caused some condensation of the steam in the two-phase fluid coming from the hot leg. The primary system pressure did not drop below the secondary side pressure until approximately [ l6 seconds into the test, at which time the U-tubes were nearly drained. At the end of the pump coastdown, flow oscillations began to occur in the tubular downcomer and through the power channel. This caused significant oscillations in the collapsed liquid levels in the power channel and, consequently, in the density of the two-phase mixture flowing from the power channel into the hot leg and to the steam generators (data plots 20 and 21). Since the driving force for the natural circulation flow was the density difference between the single-phase fluid in the cold legs and downcomer entering the power channel and the two-phase mixture in the tube bundle, upper plenum, and the hot legs, the flow oscillations were sustained as long as there was now through the steam generators (primary system natural circulation). The level in the hot leg side of the steam generator U-tubes gradually decreased to about [ ] *' ' of the tube height at [ ]^ seconds and they drained completely when ADS-1 was actuated. Re level in the cold leg side of the steam generator U-tubes exhibited significant level oscillations from about [ l6' seconds until they drained completely at about [ l**' seconds (data plots 22 and 23). Hot Legs Hot legs-A and -B contained two-phase mixture when ADS-1 was actuated (data plots 20 and 21). After ADS-1, the collapsed level began to decrease. De hot legs were nearly drained by ADS-4 ([ l^ seconds) and partially refilled later after IRWST injection began.- The principal difference between hot legs-A and -B was the influence of the PRHR HX on the steam fraction of the fluid in the hot legs. He mixture discharged from the upper plenum into the hot legs had the same steam fraction as in the upper plenum fluid. However, the PRHR HX preferentially removed steam from hot leg-A (as seen in,:he very high steam fraction in the PRHR inlet fluid), thereby reducing the steam fraction of th; mixture in hot leg-A to less than the steam fraction in hot leg-B. mwmich t.non ib-07:895 4.2.2-1()

4.2.3 Two-In. Cold Leg fireak without Nonsafety Systems (S01703)-Repeat of S00303 Matrix test 501703 was a repeat of test S00303 and was performed to determine the repeatability of the SPES-2 facility response. Test S00303 was the first matrix test to be performed, and test S01703 was performed at the end of the matrix tests. Matrix test S01703 simulated a 2-in. break in the bottom of cold leg-B2. He test began with the initiation of the break in cold leg-B2, which was the cold leg with the CMT-B pressure balance line connection. The break location just downstream from the cold leg to core makeup tank (CMT) balance line connection. This test was performed without any nonsafety systems (chemical and volume control system [CVCS] makeup pumps, steam generator startup feedwater [SFW] pumps and normal residual heat removal system [NRHR] pumps) operating. Results are provided in the data plot package at the end of this section. The sequence of events for S01703 is listed in Table 4.2.3-1. The AP600 SPES-2 test were marked by distinctly different phases. These phases were characterized by the rate at which the primary system pressure decreased and the thermal-hydraulic phenomena i occurring within the primary and safety systems. He different phases selected for purpose of detailed evaluation of this LOCA are shown in Figure 4.2.3-1 and are as follows: O initia> deeressurization nha e <iDe>-eeint i to 2-Pressure decay phase (PDP)-Point 2 to 3 i = Automatic depressurization system (ADS) phase-Point 3 to 4 ) Post-automatic depressurization system (post-ADS) phase-Point 4 to 5 4 Overall Event Observations i Since this is a repeat of test S00303 that has already been evaluated in detail (in Section 4.2.2), only l notable differences in the system response and behavior are discussed for test S01703. Most of those which are apparent can be explained as minor differences in initial conditions for the test and as a j i difference in the amount of mass discharged from the break. Figure 4.2.31 shows the primary system pressure during test 501703 (as measured at the top of the pressurizer), with selected component actuations and plant responses shown in relation to the primary system pressure. A detailed comparison of the system pressures for these two tests is shown in Figures 4.2.3-2 and 4.2.3-3. In the first figure, the initial depressurization phase (IDP) and the beginning of the pressure decay phase (PDP) are compared for the two tests. De two tests are almost I I identical in terms of absolute pressure and timing of the system responses. A slightly earlier reactor coolant pump (RCP) trip for S01703 caused a slight time shift in the pressure increase that follows the trip and resulting decrease in flow rate through the power channel. At the start of the PDP, both the overall pressure and the small pressure oscillations were essentially identical for the two. ) m:\\ap6fMM625w 2 noo:lb-072895 4.2.3 1

~ 1 Figure 4.2.3-3 compares the end of the PDP, the ADS phase in its entirety, and the start of the post-ADS phase. The PDPs ended at identical pressures and times in both tests. There was a slight h) difference in the pressure decay following ADS-test 501703 followed a slightly higher curve for most of the ADS phase. Also, the pressure increase associated with the end of the accumulator discharge (water splashed into the steam generator U-tubes and flashed, causing a system pressure increase) occurred approximately [ l6 seconds earlier for test S01703 For the rest of the ADS and post-ADS phases, the pressures were identical. Figure 4.2.3-4 compares the power channel upper plenum temperature for both tests to the end of accumulator discharge. There was no notable temperature difference during the IDP and PDP. During the ADS phase-the upper plenum in test S01703 was at a slightly higher temperature during the accumulator discharge (which agrees with the higher system pressure observed for S01703 in Figure 4.2.3-3). Figure 4.2.3-5 shows that in both tests, the upper plenum temperature rose to the saturation temperature after the accumulators emptied at identical times. Since ADS-4 occurred approximately [ l*# seconds later for the S01703 test, the effect of the IRWST injection flow began decreasing the upper plenum temperature 50 seconds later than for test S00303 Figure 4.2.3-6 shows the power channel lower plenum temperature was F.pproximately 10*F cooler for test S01703 during and after the accumulator injection. This was due tc the fact that the accumulator and IRWST initial water temperatures were [ l*"*F cooler for test 591703. This is attributed to the difference in ambient conditions. Figure 4.2.3-7 shows that the IRWST injection occurred later for test S01703, but that the magnitude of the flows were similar. Figure 4.2.3 8 shows that the annular downcomer drained earlier in the post-ADS phase for test S00303, but that the retill was initiated at identical times. Figure 4.2.3-9 shows that the levels i dropped to nearly the same elevation in the tubular downcomer during the post-ADS phase. Test S01703 reached a minimum level of [ l*" ft. at [ ]('** seconds, and test S00303 reached - 6.2 ft. at 2050 seconds. In both tests, the tubular downcomer was completely refilled at identical times. Figure 4.2.3-10 shows that the minimum collapsed levels in the rod bundle after the accumulator injection, were identical (bundle void fraction calculated to be [ ](*** percent for both test S00303 and test S01703). Similarly, the level change versus time and the minimum water levels in the tubular downcomer were essentially identical in both tests. These figures show that the two tests were similar, especially considering the complexity of this test facility and the differences in the initial conditions. This comparison shows that the test facility and instrumentation had a high level of repeatability and that no noticeable change in response could be atuibuted to changes in the test facility from the first test (S00303) to the last test (S01703). Table 5.1-1 in Section 5.0 provides comparison of key parameters for the two tests. O mwunio25w.2.nonwo72895 4.2.3-2 REVISION: 1

ranging from [ ji'*" percent. Tne oscillations ended at a maximum rod bundle gb steam fraction of [ j6 percent at approximately 600 seconds. From about [ l*" seconds, the steam fraction at the top of the rod bundle was approximately [ ] Ad percent. After ADS actuation, the accumulator injection completely filled the rod bundle. The amount of subcooling of the lower-upper plenum during the accumulator discharge was greater in test S00504 than in S00303. When the injection ended, single-phase water flow was maintained through the rod bundle for the rest of the test. Pressurizer The pressurizer began to drain when the Nak occurred and was completely drained in approximately 100 seconds (data plot 32). The water in the pressurizer flashed due to the loss of system pressure, and the temperature of the water dropped below [ ]b' during this initial depressurization (data plot 18). The hot water exiting the pressurizer surge line into hot leg-A caused a slight increase in the hot-leg temperature during this period, since it mixed with the flow from the power channel / upper plenum. The pressurizer stayed drained until ADS occurred. At this time, it refilled completely and discharged water through the ADS. After accumulator injection ended, the collapsed liquid level 4 7ased to approximately [ ]'* 6* ft. NRHR (and j CVCS) injection flow gradually refilled lla p:essurizer with water. O Steam Generator The behavior of the steam generators in test S00504 was essentially identical to test S00303 from break initiation until the steam generator U-tubes were drained. The steam generators acted as the heat sink until the MSLIV closed and prevented further energy removal from the secondary side. This caused the temperature (and pressure) of the steam generator secondary side to increase toward the primary system hot-leg temperature (Figure 4.2.4-2). However, through the IDP and for the first part of the PDP, the pressure on the primary side of the steam generators U-tubes was higher than the secondary side (data plot 2). This indicated that some heat transfer from the primary to secondary side was occurring and causing some condensation of the steam in the two-phase fluid coming from the hot leg. The primary system pressure did not drop below the steam generator secondary-side pressure until approximately [ ]A" seconds into the test, at which time the U-tubes had mostly drained. At the end of the RCP coastdown, flow oscillations began to occur in the tubular downcomer and through the power channel. This caused significant oscillations in the measured collapsed liquid level in the rod bundle and, consequently, in the density of the two-phase flow from the rod bundle into the hot legs and to the steam generators (data plots 20 and 21). Since the driving force for the natural circulation flow was the density difference between the single-phase fluid in A the cold legs and downcomer entering the power channel and the two-phase mixture in the rod V bundle, upper plenum and the hot legs the flow oscillations were sustained as long as there was flow through the steam generators. mwanto25+2tnoawo72895 4.2.4-9 REVISION: 1

The level in the hot-leg side of the steam generator U-tubes gradually dropped to about 1/3 of the tube height at approximately 500 seconds, and they drained completely when ADS-1 was actuated. The level in the cold-leg side of the steam generator U-tubes exhibited significant level oscillations from about 200 seconds until they drained completely at approximately [ l*" seconds (data plots 22 and 23). Primary system flow dirough the steam generators stopped at about the same times in this test as in test S00303, and the hot-leg side of the U-tubes drained at ADS-1 actuation in both tests. Once the steam generator U-tubes were drained, they remained drained for the rest of the test. Hot Legs Hot legs-A and B were full of two-phase mixture until ADS-1 was actuated (data plots 20 and - 21). After ADS-1, hot leg-A partially drained and remained partially drained for the rest of the test. Hot leg-B drained completely when the accumulator injection ended and then partially refilled as the NRHR injection refilled the primary system. The principal difference between hot legs-A and -B was the influence of the PRHR HX on the steam fraction in the hot legs.' The PRHR HX preferentially removed steam from hot leg-A (as seen in the very high steam fraction of the PRHR HX inlet fluid), thereby reducing the steam fraction in hot leg-A to less than that in hot leg-B. The hot leg steam fraction affected the draindown of the steam generator U-tubes, with steam generator-B draining earlier than steam generator-A. Cold legs Cold legs-Al and -A2 remained full until ADS 1 (data plots 22 through 27), when flashing occurred and their level started to decrease. Accumulator injection refilled the cold legs into the vertical pipe section at the RCP discharge. After accumulator delivery ended, the level decreased until the horizontal pipe sections were drained at approximately 1720 seconds and the liquid level decreased into the annular downcomer (approximately [ l**' below the hot-leg elevation [ data plot 24]). When the NRHR (and CVCS) injection refilled the annular downcomer, cold legs-Al and -A2 horizontal sections were refilled beginning at [ ]"*" seconds. Cold legs-B1 and -B2 remained full until [ ]"*" seconds into the event. At this time, both cold legs-B1 and -B2 drained and CMT gravity injection started. Cold leg B2 (where the simulated break was located) drained prior to cold leg-Bl,'as evidenced by CMT-B switching to draindown mode before CMT-AI A. Cold legs-B1 and -B2 started to refill at [ l*" seconds and steady liquid flow out the break was restored. After [ ]"*" seconds, the cold leg to CMT balance lines were partially filled. O map 60mt625 2uoa:ib-072895 4.2.4-10

1 rod bundle power (decay power plus heat loss compensation) was reduced from 330 kW to (j 240 kW (data plot 1). At [ ]*" seconds (rod bundle power was about 250 kW), the PRHR HX heat removal rate was approximately [ l*" kW. The recirculating CM1 rovided approximately [ ]*"-kW effective heat removal from the primary system at this time. His heat removal plus energy lost through the break and the facility heat losses exceeded the rod bundle heat input to the primary system. The initial CMT natural circulation operating mode was followed by draindown injection when the loop-B cold legs drained (data plot 38). The U-tubes of the steam generators had completely drained at this time (data plots 20 through 23) and had no effect on the rest of the test. Accumulator injection was initiated when the primvy system pressure dropped below 711 psia (at approximately [ j*" seconds) prior to ADS-1 actuation; however, the injection rate was low (less than [ l*"lbm/sec.) due to the small difference between system pressure and accumulator gas pressure (data plot 39). Facility Response during the PDP: The oscillating flow in the primary system that began after the RCPs were shutoff continued into 1 the PDP. These flow oscillations resulted in wide variations in the steam fraction of the two-phase mixture exiting the rod bundle and flowing into the hot legs (data plots 30 and 31). These oscillations in steam fraction had a significant effect on the thermal buoyancy head that drove the OV flow in the primary system at this time, since it affected the two-phase flow density. These steam fraction oscillations were observed through the hot leg and the steam generators (data plots 20 and 21). However, the steam fraction oscillations were converted to flow oscillations in the cold legs since the two-phase mixture entering the steam generators left the steam generators as saturated water (data plots 24 through 27). Some of the steam was condensed in the steam generator U-tubes (the primary-side pressure was higher than the secondary-side pressure at this time, allowing some heat to be transferred to the secondary-side fluid). The remaining steam was separated from the two-phase mixture in the high point of the U-tubes (due to low velocity), eventually causing the U-tubes to begin to drain, and a free-water surface appeared at the top of the U-tubes (plots 20 and 22). At [ J*" seconds, all flow through steam generator-A stopped, since the free-water surface in the U-tubes had fallen too low to be overcome by the buoyancy head steam fraction oscillations. The oscillations were seen in temperatures and pressures throughout the primary system. When the steam generator U-tubes drained, these oscillations stopped. The steam generator-B U-tubes drained earlier than for steam generator-A due to the higher steam fraction in the fluid from hot leg-B. The primary system pressure decay during the PDP began at a slow rate ([ l** psi /sec.). At approximately [ l*" seconds, the primary system pressure decay rate increased to [ l*" psi /sec., (Figure 4.2.5-1). This happened when the CMTs transitioned from their recirculation mode to their draindown mode of operation. His transition occurred when the steam generator O u.tebes ee the ceid-ieg side draieed and the B.ieep ceid iegs pe,tieiiy draieed. aiiewing the ceid leg mwwl625w-Lova:lb-072895 4.2.55 REVISION: 1

to CMT balance lines to drain. The increased rate of pressure decsy was due to the increased injection rate of the cold liquid from the CMTs. g The CMTs began injecting cold Guid into the annular downcomer via the DVI lines when the S signal occurred. Initially, this injection from each CMT was driven by natural circulation (at approximately [ j*" Ibm /sec.), with hot fluid flowing from the cold leg through the cold-leg balance line (CLBL) into the top of the CMT, replacing the cold fluid flowing from the bottom of the CMT The CMT natural circulation How rate slowed to [ l^" lbm/sec. at [ l'**" seconds as the CMT filled with hot water and the cold-leg fluid temperature decreased, reducing the natural circulation driving head. When the loop-B cold legs were partially drained at about [ ]'**" seconds, the CLBLs of both CMTs drained, and the CMTs transitioned to their draindown mode. For this 1-in. LOCA, the break flow at this time was less than the nominal CMT draindown injection flow rate from the two CMTs. Therefore, when a free-water surface developed in the top of each CMT and the injection flow rate increased significantly, the cold-leg water level apparently increased. His blocked the path for steam to enter the balance lines and they refilled with water. This caused the CMT injection to consist of intermittent short periods of draindown, alternating with short periods of refill with water from the cold legs (data plot 38). This resulted in a slow net drop of the CMT level. Complete transition to draindown occurred earlier in CMT-B than in CMT-A. The free-liquid surfaces in the CMTs were apparently established by both flashing of the water in the CLBLs and steam flowing to the CMTs from the cold legs. O The steam flow from the cold legs into the top of the CMTs heated / maintained the upper CMT surfaces and water surface at saturation temperature. However, flashing also occurred in the CMTs due to the high temperature of the fluid in the top of the CMTs (data plots 15 and 16) and the decreasing system pressure. The steam above the liquid surface in the CMTs and in the balance lines was superheated after ADS-l. Flashing kept the water temperature at saturation temperature while system pressure decayed. The accumulators began to inject fluid when the primary system pressure dropped below 711 psia (at approximately [ ]"*" seconds); however, the injection rate was low prior to ADS-1 (data plot 39). However, this small accumulator flow contributed to maintaining sufficient water level in the loop-B cold legs to cause the observed intermittent CMT draindown/ refill. Throughout the PDP, the PRHR HX removed energy from the primary system. The combined effect of the PRHR HX heat removal and CMT heat removal and injection of cold water were sufficient to limit the steam fraction of the two-phase mixture exiting the rod bundle to approximately [ ]*" percent during this phase (above TAF, data plot 31). Automatic Depressurization System Phase ([ ]"" Seconds) The automatic depressurization system (ADS) phase began with the actuation of ADS-1 and ended h with the actuation of ADS-4 (Figure 4.2.5-1). l mwmis25..tnon:ltwo72795 4.2.5-6 REVISION: 1

Data plots 30 and 31 show the collapsed liquid levels at various sections of the power channel () during the S00401 test. The liquid level in upper head started to decrease when system pressure decreased to the saturation pressure of the fluid temperature in the upper head (at about [ l*" seconds). Initially, the upper-head fluid temperature was only [ ]***F and was therefore considerably cooler than the upper-plenum fluid temperature. Flashing of the fluid in the upper head began at [ l*" seconds, and the upper head was completely drained at approximately [ l*" seconds (data plot 4), i The upper-upper plenum began to flash when the primary system pressure decreased below [ l*" psia, and its level decreased reaching the hot-leg elevation at about [ ]** seconds. The top of the upper-upper plenum remained filled with steam until the end of the accumulator injection, when subcooled water in the lower portion of the upper plenum condensed the steam bubble in the upper-upper plenum (data plot 4). Howt ver, when accumulator injection ended, the upper-upper plenum again filled with steam. At [ /*** seconds, the upper-upper plenum again filled when water injected from the IRWST restored subcooled flow through the power channel. The collapsed liquid level measurement just above the heated portion of the rods (above TAF) provided a measurement of the steam fraction of flow exiting the rod bundle. During the PDP, this two-phase flow had a maximum steam fraction of [ ]** percent (data plot 31). Data plot 30 shows the collapsed water level in the rod bundle oscillating following pump coastdown up until [ ]'*6 seconds. This indicates apparent steam fractions in the rod bundle varying from [ l'**" percent (with an approximately [ ]*"-second period). After the oscillations ended, the steam fraction of the rod bundle region increased from [ ]('A') percent to [ PA" percent, just before accumulator injection. The accumulator injection completely j subcooled the rod bundle. However, when the injection ended, the two-phase flow was again produced, and the steam fraction of fluid in the rod bundle region reached a maximum ([ ](*^" percent) Just before IRWST injection during the post-ADS phase. The lower-upper plenum steam fraction increased to [ }"^* percent at this time, but this high steam fraction was due to the fact that the level of the two-phase mixture temporarily dropped below the hot-leg elevation. The collapsed level measured just above the heated portion of the rod bundle (data plot 31) provided steam fractions that correlated well with those measured for the rod bundle and provided evidence of the steam / water fraction of the two-phase flow exiting the top of the rod bundle. Pressurizer a The pressurizer began to drain when the break occurred and was completely drained in approximately [ l*" seconds (data plot 32). The water in the pressurizer flashed due to the O ies, a sxstem eres,ere. end me tempererere a me water dmened fmeo r *' F derins this initial depressurization (data plot 18). The hot water flowing fror the pressurizer surge line into menis25.anoo:ib-072795 4.2.5-9 REVISION: 1

hot leg A caused a slight increase in the hot-leg temperature during this period, since it mixed with the flow from the power channel / upper plenum. The pressurizer remained drained until about g [ l* seconds, at which time it was slightly refilled by alternating and pulsed flow in the pressurizer surge line widch occurred until about [ l*" seconds, and then by a steady flow until [ l**' seconds. The pressurizer drained again at [ f'^" seconds and remained drained until ADS-1 occurred, at approximately [ l*" seconds, when it refilled and reached a collapsed liquid level of approximately [ l^" feet and a two-phase mixture was discharged from the top of the pressurizer via the ADS-1, -2 and -3 flow paths. The collapsed liquid level decreased as the steam fraction of the two-phase flow through the rod bundle increased. A sharp decrease in level occurred at approximately [ l6 mod wM h upmp Nmm pi@ dlW wM w-m Ms cominued after ADS-4, the pressurizer drained again at I l*" seconds, and its level then reached manometric agreement with the water level / pressure in the primary system. Steam Generator The steam generators acted as the heat sink until the MSLIV closed and prevented further energy removal from the secondary side. This caused the temperature of the secondary side to increase toward the primary system hot-leg temperature, which at the same time was dropping due to the reduced power / flow ratio When the RCPs coasted down, there was a temporary temperature increase due to the increased power / flow ratio with natural circulation flow in the primary system (Figure 4.2.5-2). The steam generator secondary-side water temperature then stabilized at approximately [ T'*" F at the end of the IDP. hl For the first pan of the PDP, the pressure on the primary side of the steam generator U-tubes was higher than the secondary side (data plot 2). This indicated that some heat transfer from the primary to secondary side occurred and caused some condensation of the steam in the two-phase fluid coming from the hot leg. Primary system pressure did not drop below the steam generator secondary-side pressure until approximately [ l*" seconds into the event, at which time the steam generator U-tubes were nearly drained. At the end of the pump coastdown, flow oscillations began in the tubular downcomer and through the power channel. This caused significant oscillations in the collapsed liquid level in the rod bundle and, consequently, in the density of the two-phase flow from the rod bundle into the lower-upper plenum, the hot legs, and to the steam generators (data plots 20 and 21). Since the driving force for the natural circulation flow was the density difference between the single-phase fluid in the cold legs and downcomer entering the power channel and the two-phase mixture leaving the rod bundle in the lower-upper plenum and the hot legs, the flow oscillations were sustained as long as there was flow through the steam generators. The flow oscillations in the hot legs reached the steam generators. In steam generator-A, the U-tubes were full until approximately [ l^ seconds into the transient. At this time, a free-water surface began to develop in the top of the U-tubes, primarily due to the separation of steam from the two-phase mixture from the hot leg at the low-flow velocities existing at natural mvui625ano.. is-m:m 4.2.5-10 REVISION: 1

8 l_ upper plenum, and hot leg (data plots 30 and 31).L When the flow decreased, the steam fraction L increased and resulted in an increase of the overall' system pressure and the lower-upper plenum l temperature (Figure 4.2.6-2).- The overall system pressure ' oscillations were therefore out of phase - g with the tubular downcomer flow oscillations. i i Data plots 30 and 31 show the collapsed liquid levels at various ' sections of the power channel f during the S01613 test. The liquid level in upper head started to decrease when system pressure decreased to the saturation-i pressure of the fluid temperature in the upper head (at about [ ]"* seconds). Initially, the upper-head fluid temperature was only [ ]'dd*F and'was therefore considerably cooler than ' the upper-plenum fluid temperature. Flashing of the fluid in the upper head began at [ l'" seconds, and the upper head was completely drained at approximately [ l'" seconds (data plot 4). j he upper-upper plenum began to flash'when the primary system pressure decreased below - I [ ]'" psia, and its level decreased reaching the hot-leg elevation at about [ _ ]"**' seconds. The top of the upper-upper plenum remained filled with steam until the end of the accumulator injection, when subcooled water in the lower portion of the upper plenum condensed the steam q bubble in the upper-upper plenum (data plot 4). However, when accumulator injection ended, the upper-upper plenum again filled with steam. At.[ ]"**' seconds, the upper-upper plenum again ] O iiiied when water in;ected from the iawSr re tored subceeied fiew ihrough the power channei. ne collapsed liquid level measurement above the beated portion of the nids (above TAF) .j provided a measurement of the steam fraction of flow exiting the rod bundle.' During the PDP,'. this two-phase flow had a maximum steam fraction of [ ]"*'8 percent (data plot 31). Data plot 30 shows the collapsed water level in the rod bundle oscillating following pump coastdown up until [ ](" seconds. This indicates apparent steam fractions in the rod bundle varying from [ ]** percent (with an approximately [ - ]'"second period). After the-oscillations ended, the steam fraction of the rod bundle region increased from ! - ]** per' ent to c [ Ji"#' percent, just before accumulator injection. De accumulator injection completely subcooled the rod bundle. However, when the injection ended, the two-phase flow was again produced, and the steam fraction of fluid in the rod bundle region reached a maximum ([ ]"* percent) just before IRWST injection during the post-ADS phase. He lower-upper plenum steam fraction increased to [76)("#' percent at this time, but this high steam fraction was due to the fact - 1 that the level of the two-phase mixture temporarily dropped below the hot-leg elevation. The collapsed level measured just above the heated portion of the rod bundle (data plot 31) r provided steam fractions that correlated well with those measured for the rod bundle and provided - evidence of the steam / water fraction of the two-phase flow exiting the top of the rod bundle. L -1 mweio25. 4 wpr;tb-07ms 4.2.6-9 REVISION:.I

Pressurlier The pressurizer began to drain when the break occurred and was completely drained in approximately [ l* seconds (data plot 32). The water in the pressurizer flashed due to the loss of system pressure, and the temperature of the water dropped from [ T** F during this initial depressurization (data plot 18). The hot water flowing from the pressurizer surge line into hot leg-A caused a slight increase in the hot-leg temperature during this period, since it mixed with the flow from the power channel / upper plenum. The pressurizer remained drained until ADS-1 occurred, at approximately [ l* seconds, when it refilled and reached a collapsed liquid level of approximately [ f** feet and a two-phase mixture was discharged from the top of the pressurizer via the ADS-1, -2 and -3 flow paths. The collapsed liquid level decreased as the steam ) function of the two-phase flow through the rod bundle increased. A sharp temporary decrease in level occurred at approximately [ f** seconds when the upper-upper plenum partially refilled with water. Level decrease continued after ADS-4, the pressurizer drained again at [ f ** seconds and its level then reached manometric agreement with the water level / pressure in the i primary system. Steam Generator i The steam generators acted as the heat sink until the MSLIV closed and prevented further energy removal from the secondary side. This caused the temperature of the secondary side to increase toward the primary system hot-leg temperature, which at the same time was dropping due to the h reduced power / flow ratio, When the RCPs coasted down, there was a temporary temperature i increase due to the increased power / flow ratio with natural circulation flow in the primary system (Figure 4.2.5-2). The steam generator secondary-side water temperature then stabilized at approximately [ T***F at the end of the IDP. For the first part of the PDP, the pressure on the primary side of the steam generator U-tubes was higher than the secondary side (data plot 2). This indicated that some heat transfer from the primary to secondary side occurred and caused some condensation of the steam in the two-phase fluid coming from the hot leg. Prin.ary system pressure did not drop below the steam generator secondary-side pressure until approximately [ f** seconds into the event, at which time the steam generator U-tubes were nearly drained. At the end of the pump coastdown, flow oscillations began in the tubular downcomer and through the power channel. This caused significant oscillations in the collapsed liquid level in the rod bundle and, consequently, in the density of the two-phase flow from the rod bundle into the lower-upper plenum, the hot legs, and to the steam generators (data plots 20 and 21). Since the driving force for the natural circulation flow was the density difference between the single-phase fluid in the cold legs and downcomer entering the power channel and the two-phase mixture leaving the rod bundle in the lower-upper plenum and the hot legs; the flow oscillations were sustained as long as there was flow through the steam generators. h m%aut625w 4 non:Ih07:895 4.2.6-10

+ upper plenum fluid temperature. Flashing of the fluid in the upper head started at [- j " seconds, and the upper head drained completely when ADS-1 occurred at approximately ( ]""*' seconds (data plot 4). The upper-upper plenum flashed when the primary system pressure decreased below [ ](***' psia, and its level decreased to the hot-leg elevation. De upper-upper plenum remained filled with steam until IRWST injection refilled the power channel with subcooled water j at [ ]"**' seconds. The upper-upper plenum steam bubble was partially condensed (data plot 4). 4 %e collapsed liquid level in the region above the heated portion of the rods.(above TAF) indicates the steam fraction of the two-phase flow exiting the rod bundle steam. This measurement. j indicated that the maximum steam fraction of the two-phase, cooling flow exiting the rods during _ "**' percent at [ ]"*#' seconds. the PDP was approximately [ ] t Data plot 30 shows the oscillating collapsed levels in the rod bundle following the coastdown of the RCPs, indicating steam fractions varied from [ ]"**' percent to [ ]"*#' percent in this phase, i with a period of approximately [ ]"*#' seconds. The accumulator injection reduced the sieam fraction in the rod bundle; however, when the accumulator injection ended, the rod bundle steam fraction increased again and reached a maximum steam fraction ([ ]**d' percent) just before the IRWST injection started. He lower upper plenum showed a steam fraction of [ ]"**' percent O d#rins this neriod. nis hi h steam frection was d#e. in ven. to the fect ihat the ievei of two-8 phase mixture in the lower-upper plenum temporarily dropped below the hot-leg elevation. I Re' collapsed level measured just above the heated portion of the rod bundle (data plot 31) provides fluid steam fractions that correlated well with those measured in the rod bundle. Pressurizer The pressurizer started to drain when the break occurred and was completely drained in approximately [ ]"**' seconds (data plot 32). De water in the pressurizer flashed due to the loss of system pressure, and the temperature of the water dropped from [ ]**F during this initial depressurization (data plot 18). He hot water exiting the pressurizer surge line into the hot leg A caused a slight increase in the hot leg temperature during this period, since it mixed with the flow from the power channel / upper plenum. He pressurizer stayed drained until ADS occurred, at j which time it refilled, reaching a collapsed liquid level of [ ]"**' ft. and discharged two-phase - 1 mixture. De pressurizer collapsed liquid level decreased after accumulator injection ended in response to the increasing steam fraction exiting the power channel his continued until ADS-4, at which time the pressurizer again drained completely at [ ]"**' seconds and the level reached j manometdc agreement with the water level in the primary system. O mwum625.us25w.5 non:ib-072795 4.2.7-9 REVISION: 1

Steam Generator O The steam generators acted as the heat sink until the MSLIV closed and prevented further energy i removal from die secondary side. This caused the temperature of the secondary side to increase toward the primary system hot-leg temperature, which at the same time was dropping due to the reduced power / flow ratio. When the RCPs had coasted down, a temporary temperature increase occurred due to the increased power / flow ratio with natural circulation flow in the primary system. The steam generator secondary-side water temperature stabilized at approximately [ ]"^* Fat the end of the IDP. For the first part of the PDP, the pressure on the primary side of the steam generators was higher than the secondary side, indicating that some heat transfer from the primary to secondary side was occurring, causinE some condensing of the two-phase fluid coming from the hot leg. The primary system pressure did not drop below the steam generator secondary-side pressure until approximately [ ]"**' seconds into the event, at which time the cold-leg side of the U-tubes was completely drained, and the hot-leg side was partially drained. At the end of the RCP coastdown, flow oscillations started to occur in the tubular downcomer and through the power channel. This caused significant oscillations in the collapsed liquid level measured in the rod bundle, caused by oscillations in the steam fraction of the two-phase liquid flowing through the rod bundle into the hot legs and to the steam generators. Since the driving force for the natural circulation flow was the density difference between the single-phase fluid in h, the cold legs and downcomer entering the power channel and the two-phase mixture leaving the pov cr channel and in the hot legs, the flow oscillations were sustained as long as diere was flow through the steam generators. The fluid level on the hot-leg side of the steam generator U-tubes dropped below the top of the U-tubes in cycles, resulting in intermittent flow from the hot-leg side to the cold-leg side of the U-tubes. This condition continued until approximately [ l**' seconds into the transient for steam generator-A, at which time the oscillating two-phase fluid steam fraction did not have sufficient buoyancy to lift the free surface in the U-tube hot-leg side to the top of the U-tubes. In steam generator-B, there were *ess defined flow oscillations, due to the higher void fraction in hot leg-B then hot leg-A. Intermittent flow over the top of the U-tubes ended approximately [ ]"** seconds into the transient. For both steam generators, the water in the hot-leg side of the U-tubes drained completely with ADS 1 actuation. The cold-leg side of the U-tubes exhibited significant level oscillations until they drained completely at about [ l*" seconds for steam generator-A, and [ ]"A" seconds for steam generator-B. O O maap60m1625w 5.wpf;1b-072895 4.2.7-10 REVISION: 1

j L INSTRUCTION SHEET FOR REVISION 1 OF THE AP600 SPES-2 TEST - () FINAL DATA REPORT-VOLUME II Enclosed you will find subsections 4.2.8,4.2.9,4.2.10,4.2.11,4.2.12,4.2.13,4.2.14; Sections 5 and 6; Appendices C and F. Please remove and replace the following sections and subsections of the Final ) Data Report, Volume 11 as follows: Section Remove: Replace with: j Cover and Spine Cover and Spine Cover and Spine (Revision 1) Table of Contents v v l 4.2.8 4.2.8-7 and 4.2.8-8 4.2.8-7 and 4.2.8-8 l 4.2.8-9 and 4.2.8-10 4.2.8-9 and 4.2.8-10 i PLOT:30* PLOT:30* 4.2.9 4.2.9-9 and 4.2.9-10 4.2.9-9 and 4.2.9-10 PLOT:30* PLOT:30* 4.2.10 4.2.10-1 4.2.10-1 thru 4.2.10-26, and Plots I thru 44 (S00908) 4.2.11 PLOT:30* PLOT:30* 4.2.12 4.2.12-7 and 4.2.12-8 4.2.12-7 and 4.2.12-8 ) PLOT:30* PLOT:30* O 4.2.13 4.2.13 1 4.2.13.i thre 4.2.13-30. and Plots 1 thru 44 (S01211) ) 4.2.14 4.2.14-1 4.2.14-1 thru 4.2.14-34, and Plots 1 tluu 44 (S01512) 5 5-0 5.1-3 and 5.1-4* 5.1-3 and 5.1-4* 5.1-5 * . 5.1 5

• l 5.1-6
• 5.1-6
• 5.3-3 and 5.3-4 5.3 3 and 5.3-4 5.3-10*

5.3-10* 5.4-1 and 5.4-2 5.4-1 and 5.4-2 5.4-4

• 5.4-4
• l 5.6-1 and 5.6-2 5.6-1 and 5.6-2 5.6-3 5.6-3 5.6-9
• 5.6-9
• l 6

6-1 and 6-2 61 and 6-2 Appendix C C-5 through C-10 C-5 through C-10 Appendix F F-1 through F-18 F-1 through F-18 Appendix G G-1 through G-3 Revised blank figures and plots not provided for WCAP-14310, Rev.1; the Class 3, non-proprietary report. i mwwxxi625-ins.non:ib.072795 REVISION: 1

m L ) { 4 4 Ma b 0' 1 TABLE OF CONTENTS. '(Cont.) nv' J Section Title ,P_ggg v ~4.2.6 One-In. Cold Leg Break with Three PRHR HX Tubes, without' Non Safety Systems (S01613)............................ 4.2.6;1 ' - 4.2.7 Two-In. Direct Vessel Injection Line Break ;....................E4.2.7 1 4.2.8 Double-Ended Guillotine DVI Line Break (S00706).............. 4.2.8-1 ' 4.2.9.Two-In. Cold-Leg / Core Makeup Tank Balance Line Break without - Nonsafety Systems.................................... 4.2.9 4.2.10 Double-Ended Guillotine Cold Leg to CMT Balance Line Break-without Nonsafety Systems (S00908) :........................ 4.2.10-1 4.2.11 Steam' Generator Tube Rupture with Nonsafety Systems Operational a7, and Operator Action (S01309)........................... a 4.2.11-1 4.2.12 Steam Generator Tube Rupture without Nonsafety. Systems (S01110).................................... < 4.2.12 4.2.13 Steam Generator Tube Rupture without Ncnsafety Systems, with ~ Inadvertent ADS (S01211) '............................. 4.2.13 4.2.14 Large Steam Line Break at Hot Standby Conditions without'. Nonsafety Systems (S01512)............................. ; 4.2.1411 5.0 TEST D ATA COMPARISON......................................... 5-1. - O-5.r C-ge s-B-is f-LOCAs........................ m.........

5. i e 5.2 Comparison Basis for non-LOCA Events........................... 5.2-1 5.3 Comparison of Break Locations................................. 5.3 1 -

5.4 Comparison of Break Sizes................................... 5.4-1 5.5 Effects of Nonsafety Systems....................... ............'5.5-1l 5.6 Other Key Test Results...................................... 5.6. 5.6.1 Comparison of PRHR Performance......................... 5.6-1 5.6.2 Test Repeatability..................................... 5.6-2 ' 5.6.3 Comparison _of Steam Generator Tube Rupture.................. ' 5.6-2 6.0 OBSERVATIONS AND CONCLUSIONS.................................. 1

7.0 REFERENCES

..................................................... 7-1 " Appendix A Data Reduction Methods and Validation Process......................... A-1 . Appendix B Data Validation.............................................. B - 1 - Appendix C SPES 2 Instrument List........... .............................C-1 Appendix D SPES-2 Inoperable and Modified Instruments........................... D Appendix E Error Analysis............................................... E-1 Appendix F Full-Height Full-Power Integral Systems Test Delta-P Instrumentation Data Reduction ................. F-1 eO Appendix G SPES 2 Test Data Files........................................ G-1 m:\\ap600\\l 625 w\\f rat mtruoc.noa:l b.072895 y

_h i R p L CMT-B emptied quickly through the CMT side of the break. After it was drained, CMT-B was c f ~ the path to the CMT side of the break for steam from cold leg-B2 for the rest of the test. ~ L %roughout the PDP, the PRHR HX removed energy from the primary system. De PRHR HX .) cooling and the cold injection flow from CMT-A were insufficient to subcool the core during this period. De observed void fraction in the core oscillated from [ l**'. percent ' data ( plots 30 and 31). . Automatic Depressurization System Phase ([ ]" Seconds) i he automatic depressurization system (ADS) phase began approximately 65 seconds after the - l actuation of ADS 1 (when accumulator-A injection began) and ended with the actuation of ADS-4 l (Figure 4.2.8-1). l Facility Response during the ADS Phase-l With the actuation of ADS-1, followed by ADS-2 and ADS-3 within 186 seconds, the rate j - of system depressurization increased from [ ](***) psi /sec. at the end of the PDP to [ ](***) psi /sec. during the'early part of the ADS phase. Bis depressurization rate gradually decreased as the primary system pressure decreased. During the rapid depressurization from [ l ]"A*' seconds, flashing occurred in the annular and the tubular downcomers (data plot 25).- ] h his resulted in increased break flow through the downcomer side of the break as downcomer j water was lifted to the break elevator. .I A high rate of water injection was provided from accumulator-A (data plot 39) and draindown o'f the CMT-A continued (data plot 33). Accumulator-A injected cold water into the downcomer for - approximately [ ]"A*' seconds (from [ . ](***) seconds) and was then drained. The accumulator injection was insufficient to maintain / restore the water level in the downcomer. De water in the tubular downcomer flashed and level decreased during accumulator injection. De pressurizer began to refill after ADS-1 actuation occurred and reached a collapsed liquid level of about [ ](***) seconds. Pressurizer level (and ADS-1, -2, and '-3 flow). q decreased through [ ]"**' seconds. De pressurizer remained partially filled until about [ ~ l**) seconds, and there was little or no steam flow through ADS-1, -2, and -3, after 4 ADS-4 occurred (at [ ]"**) seconds). During the ADS phase, the break flow from the downcomer side of the break consisted mostly of. steam with some water from the flashing downcomer. The break flow from the CMT side of the break included steam from cold leg-B2 (via CMT-B), accumulator-B water, and a small amount of IRWST water. O i mew 625.u s25. 5.*pfa un:195 4.2.8 7 REVISION: 1

Post-Automatic Depressurization S3 stem Phase ([ ]*" Seconds to End-of-Test) The post-automatic depressurization system (post-ADS) phase began when ADS-4 occurred (at [ ]*" seconds) and continued to the end of the test (Figure 4.2.8-1). System Response during the Post-ADS Phase: The accumulator-A delivery continued into the post-ADS period and ended at approximately [ l'**' seconds. Near the end of the accumulator delivery, the water !cvel in the downcomer dropped to a level [ ]**' ft. below the hot-leg elevation at [ ]**) seconds ([ l**' percent of tubular downcomer was drained, data plot 25), since the accumulator-A and CMT-A injection could not keep up with the ADS and break Hows. During the accumulator-A injection, the CMT-A injection was partially suppressed, until the accumulator injection ended. Concurrent with the decrease in water level in the downcomer, the steam fraction of the fluid in the rod bundle region increased to a maximum of [ J*"' percent (data plots 30 and 31) and the lower-upper plenum steam fraction almost reached [ l*" percent; however, there was no indication of heater rod heat up due to lack of cooling. The maximum rod bundle steam fraction and minimum water level in the tubular downcomer occurred at [ ]*" seconds. After ADS-4 was actuated (at [ l**' seconds), only a small amount of sa.urated steam was vented through ADS-1, -2, and -3. h The primary system pressure was [ ]*"' psia when ADS-4 was actuated, and it was reduced to approximately [ l**' psia when the IRWST injection through the DVI-A nozzle into the downcomer started at [ ]*" seconds (data plot 40). De combined effect of the IRWST-A and the CMT-A injection began to refill the downcomer and simultaneously reduced the steam fraction of flow through the rod bundle, through the upper plenum and into the hot legs. The PRHR HX stopped flowing at approximately [ ] Ad seconds; however, as the IRWST flow decreased the steam fraction of fluid leaving the power channel, flow restarted at approximately [ l^ seconds. De cold flow from the IRWST and the PRHR gradually reduced boiling in the rod bundle and refilled the downcomer to the elevation of the troken DVI line. This steady-state condition was considered the end of the test. Component Responses Power Channel The power channel consists of 5 volumes: the lower plenum, the riser with the heater rod bundle, the lower upper-plenum below hot leg, the upper-upper plenum above hot leg, and the upper head. When the break occurred, the system pressure decreased to the R trip point (1800 psia) and the S mwm625.us25. 5ampr:ib-072795 4.2.8-8 REVISION: 1

trip point of 1700 psia. However, since all the water in the primary system was below the saturation temperature for the system pressure, no boiling or flashing occurred up to this point. Nothing significant happened in the power channel until the core power had been reduced to 20 percent (1000 kW) at [ l*#' seconds. At this time, the AT across the rod bundle decreased due to the reduced power flow ratio (still full Cow), and the lower upper-plenum temperature decreased toward the lower-plenum temperature (Figure 4.2.8-2). The upper-upper plenum water, which was at [ J**' fluid temperature, flashed when the primary system pressure dropped below [ l* psia and decreased to [ ](***' at [ ](** seconds. When the RCPs coasted down (from [ ]*#' seconds into the event), the power flow ratio increased and the power channel outlet temperature again increased. Boiling in the rod bundle and the flashing in the upper plenum produced sufficient amounts of steam to temporarily increase the system pressure; and the lower upper-plenum temperature increased momentarily until the upper-upper plenum was drained down to the hot leg elevation at [ ]**' seconds (data plot 30 and 31). The primary system pressure reached [ ]**' psia at [ ]**' seconds. At [ ]**' seconds, the temperature of the fluid in the lower-upper plenum dictated the primary system pressure (data plot 4 and Figure 4.2.8 2). A short period of oscillations of the fluid in the rod bundle (period of [ l'***' seconds) began when the RCPs had coasted down and disappeared at about [ l**' seconds into the test. mQ Data plots 30 and 31 show the collapsed liquid levels at various sections of the power channel during the S00706 test. The upper head started to drain when the system pressure reached the saturation pressure of the fluid temperature in the upper head (at about [ l*') seconds). The upper head fluid temperature was initially only [ ]**' and was, therefore, considerably cooler than the upper-upper plenum fluid temperature. Fluid flashing in the upper head caused its water level to decrease and it had drained completely by [ l*#' seconds (data plot 4). The upper-upper plenum started to flash at [ ]**' seconds and continued to flash during the RCP coast down. The level dropped to the hot leg elevation by [ l*#' seconds (Figure 4.2.8-3). The upper-upper plenum level never recovered during this test and it stayed at or below the hot-leg elevation until the end of this test (temperatures in data plot 4). The steam fraction in the rod bundle increased from the time the RCPs coasted down to [ l**' seconds (data plots 30 and 31). At this time, the steam fraction reached [ l**' percent in the region just above the heated portion of the rods (above TAF), and the collapsed liquid level in the lower-upper plenum decreased below the bottom of the hot legs. However, the top of the heated portion of the rod bundle was covered by two-phase raixture, and there was no indication of heater rod heat-up due to lack of cooling (data plot 3). 'V mnappl625w\\l625w-5a *pf:IMn2795 4.2.g.9 REVtslON: 1

Concurrent with the increase in rod bundle steam fraction and decrease in fluid level in the lower-upper plenum, the water level in the downcomer decreased to [ f**" ft. (hot-leg elevation is 0) g at i J*" seconds. Data plot 30 shows that the collapsed levels in the rod bundle exhibited a short period of oscillations following the RCP coastdown, with apparent steam fractions in the rod bundle ranging fro m [ J*" percent. The injection from accumulator-A ([ ]'*^" seconds) did not reduce the steam fraction in the rod bundle, and the maximum steam fraction (mirVmum collapsed liquid level) occurred near the end of the injection. When the IRWST-A injection started at [ ]*" seconds, combined with the CMT-A injection. the water level in the downcomer started to recover. The tubular downcomer was refilled by approximately [ ]*" seconds, and the level continued to rise into the annular downcomer. The steam fraction of flow through the rod bundle decreased steadily, and the two-phase mixture level in the lower-upper plenum increased to the hot-leg elevation. However, the flow through the rod bundle remained two-phase (steam fraction about [ ](**" percent) for the rest of the test. This test resulted in a [ l6 in the rod bundle; however, there was no indication of a temperature increase in the rod thermocouples. Also, this test was more severe than intended due to the higher than specified rod bundle power simulation. Pressurizer O The pressurizer started to drain when the break occurred and was completely drained in 18 seconds (data plot 32). The water in the pressurizer flashed due to the loss of system pressure, and the temperature of the water dropped from [ l*" during this initial depressurization (data plot 18). The hot water exiting the pressurizer surge line into the hot leg-A caused a slight increase in the hot leg temperature, since it mixed with the flow from the power channel / upper plenum. The pressurizer remained empty until ADS-1 occurred, at which time it partially refilled to a collapsed liquid level of about [ ](**" seconds, and discharged some two-phase mixture from the top via the ADS. The pressu-izer level decreased to approximately [ l*" seconds as ADS-1, -2, and -3 flow decreased to almost zero. At [ l*" seconds the pressurizer again drained completely. Steam Generator ne steam generators acted as the heat sink until the MSLIV closed and prevented further energy removal from the secondary side. This caused the temperature of the steam generator secondary-side fluid to increase toward the primary system hot leg temperature, which at the same time was dropping due to the reduced power / flow ratio. For the first part of the PDP, the pressure on the primary side of the steam generators U-tubes was higher than the steam generator secondary-side, indicating that some heat transfer from the primary h to secondary side occurred and causing some condensing of the two-phase fluid coming from the m%pNu l 625 w\\l 625 w-5ampf: l b-072795 4,2,8 10 REVISION: 1

flashing started at [ j*" seconds. he upper head quickly emptied when ADS-1 occurred at (] approximately [ ]*" seconds (data plot 31). l The upper-upper plenum water level, which had decreased to the elevation of the hot legs after the l RCPs had coasted down, stayed at the hot-leg elevation until the end of the accumulator injection. When the rod bundle and lower-upper plenum were refilled with subcooled water, the steam l bubble in the upper-upper plenum was partially condensed (see temperatures in data plot 4). l However, when the accumulator injection ended, the level again decreased to the hot-leg elevation l or below. At [ ]('^" seconds, the water injected from the IRWST again condensed the steam bubble in the upper-upper plenum and it refilled (plot 31). The collapsed level measured just above the top of rod bundle (data plot 31) provides a good indication of the steam fraction of the two-phase fluid exiting the top of the rod bundle. This l measurement indicates that the maximum steam fraction of this fluid was [ ]** percent prior to accumulator injection, and reached [ ]** percent prior to IRWST injection. Data plot 30 shows the collapsed levels in the rod bundle oscillating following the coastdown of the RCPs. This indicated apparent steam fractions in the rod bundle ranging from [ l** percent to [ ]*" percent with a period of approximately [ l*" seconds. He oscilla' ions ended at a maximum fluid steam fraction of [ l*" percent before the accumulator injection. The accumulator injection completely refilled and subcooled the rod bundle. However, when the O. in;ection ended. the beiiine besen asein and reeched e maximum <t i' * " Perce ni tea m fraction > just before the IRWST injection started. Ec lower-upper plenum level indicates a steam fraction of[ l*" percent just prior to IRWST injection. His high steam fraction was due to the two-phase mixture level in the upper-upper plenum temporarily dropped below the hot-leg elevation. Pressurizer The pressurizer began to drain when the break occurred and was completely drained in approximately [ J*" seconds (data plot 32). The water in the pressurizer flashed due to the loss of system pressure, and the temperature of the water dropped from [ J*"*F during this initial l depressurization (data plot 18). The pressurizer remained drained until ADS-1 occurred. At this time, the collapsed liquid level increased to about [ l*" ft, during the time the accumulator was injecting. His level then decreased to [ j*" ft. by the time IRWST injection started, apparently in response to the increasing steam fraction of the fluid flowing from the power channel to hot leg-A; into the pressurizer; and out through the ADS-1, -2, and -3 flow paths. After ADS-4 actuation, the pressurizer level decreased to [ j*" ft. where it reached manornetric agreement with the primary system. l e mweam o:5.-o non. ib.o72795 4.2.9-9 REVISION: 1

Steam Generator The steam generators acted as the heat sink until the MSLIV closed and prevented further energy removal from the secondary side. This caused the temperature (and pressure) of the secondary side to increase toward the primary system hot-leg temperature. De steam generators stabilized at approximately [ l**F (and [ ]*" psia) at the end of the IDP. For the first part of the PDP, the primary system pressure was higher than the steam generator secondary-side pressure (data plot 2). His indicated that some heat transfer from the primary to secondary side occurred and caused some condensation of the steam in the two-phase Guid coming from the hot leg. De primary system pressure did not drop below the steam gecerator secondary-side pressure until approximately [ l^ seconds into the event, at which time the U-tubes had already nearly drained. At the end of the RCP coastdown, flow oscillations began in the primary system. This caused wide variations in the collapsed liquid level (fluid steam fraction) in the core and, consequently, in the density of the two-phase flow from the rod bundle into the hot legs and to the steam generators (data plots 20 and 21). Rese hot-leg steam fraction oscillations reached the steam generators. In steam generator-A, the U-tubes began to have a free-water surface at the top of the U-tubes, at approximately [ l** seconds due primarily to the separation of steam from the two-phase mixture at the low-h flow velocities existing at the natural circulation flow conditions. However, as the fluid level on the hot-leg side dropped below the top of the U-tubes the oscillation from the hot leg would refill the tube. At [ l*" seconds the top of the hot-leg side of the steam generator-A U-tubes remained filled with saturated vapor and primary system flow through the steam generator-A stopped. He cold-leg side of the steam generator-A U-tubes showed significant level oscillations from about [ l*" seconds until they were completely drained at about [ l#" seconds and affected the draindown of the steam generator U-tubes. De steam fraction / flow oscillations in steam generator-B were reduced, due to the higher steam fraction of the fluid in the hot leg-B. Consequently, the steam generator-B U-tubes started draining earlier (at about [ ]('*" seconds) since it took less time to fill the top of steam generator-B U-tubes with steam. De level in the hot leg side of the steam generator-B U-tubes decreased to nearly zero in about [ l*" seconds. The cold-leg side of the steam generator-B U-tubes was nearly drained at [ l*" seconds (data plots 22 and 23). Ilot Legs = llot legs-A and -B were full of two-phase mixture until ADS-1 (data plots 20 and 21). Prior to h ADS-1, the observed collapsed liquid levels in the hot legs indicated that the PRHR preferentially maarmm:5.sio25..a.wpf ib-072895 4.2,()- 1() REVISION: 1

. 4.2.10 Doubled-Ended Guillotine Cold Leg to CMT Halance Line Break without Nonsafety Systems (S00908) This matrix test simulated a double-ended guillotine (DEG) break in the AP600 8-in., Sch.160 cold leg B2 to CMT B balance line. The test started with the simultaneous opening of two break isolation valves. De two break lines were connected to the cold leg-B2 balance line with a tee connection on cach side of the CMT balance line isolation valve. The CMT-B balance line isolation valve was closed just prior to test initiation to isolate the two sides of the breaks from each other. This test was ] performed without any nonsafety systems operating chemical and volume control system (CVCS) makeup pumps, steam generator startup feedwater (SFW) pumps and normal residual heat removal (NRHR) pumps. l Tids break arrangement resulted in high break flow from cold leg-B2 through the cold-leg side of the break, since it provided a direct flow path from the cold leg. The CMT side of the break produced no out-flow from the primary system because the check valve in the CMT-B injection line prevented backflow of primary system fluid through CMT-B to the break. 1 Results are provided in the data plot package at the end of this sectica. The sequence of events for S00908 is listed in Table 4.2.10-1. The SPES-2 Msts are marked by distinctly different phases. These phases are characterized by the rate O at which the primary system pressure decreases and the thermal hydraulic phenomena occurring within the primary and safety systems. The different phases selected for purpose of detailed evaluation of this LOCA are shown in Figure 4.2.10-1 and are as follows: Initial depressurization phase (IDP)-Point I to 2 Pressure decay phase (PDP)-Point 2 to 3 - Automatic depressurization system (ADS) phase-Point 3 to 4 Post-automatic depressurization system (post ADS) phase-Point 4 to 5 = Overall Test Observations Figure 4.2.10-1 shows the plant primary system pressure during test S00908 (as measured at the top of the pressurizer) with selected component actuations and facility responses shown in relation to the primary system pressure. The IDP started with the initiation of the break, which resulted in a rapid reduction in pressure. The reactor trip (R) and the safety systems actuation (S) signals initiated at 1800 and 1700 psia, respectively. The R and the S signals initiated in the following actions: Decay power simulation (with heat loss compensation) Main steamline isolation valves (MSLIVs) closed Main feedwater isolation valves (MFWIV) closed m:\\a;WWec4\\l625w-6a.non:1two72695 4.2.10-1 s.,

l Core makeup tank (CMT) injection line isolation valves opened Passive residual heat removal (PRHR) heat exchanger (HX) return isolation valve opened - h i Reactor coolant pumps (RCPs) shut off Recirculation flow through the CMT-A and PRHR flow started immediately after their isolation valves were opened. Due to the rapid decrease in primary system pressure to the saturation pressure for the water in the rod bundle region and power channel upper plenum, rod bundle boiling was initiated and the upper-upper plenum water flashed. The water level in the upper-upper plenum decreased quickly to the hot leg elevation. This flashing on the hot-leg side of the power channel briefly slowed the l rapid decrease in primary system pressure. When the RCPs were shut off (at [ ]A seconds), a l short period of oscilhting flow through the primary system began (with a period of approximately l [ ] seconds), which resulted in oscillations in the steam fraction of fluid flowing through the rod bundle, lower-upper plenum, and hot legs. During 6e PDP, the rod bundle steam fraction initially increased. This resulted in an increasing steam fraction in the lower-upper plenum and the hot legs. The steam fraction of the two-phase fluid in hot leg-B was the same as fluid flowing from the lower-upper plenum. However, the steam fraction in hot leg-A was lower due to the selective removal of steam from hot leg-A into the PRHR HX inlet line. I The two-phase flow in the hot legs caused the steam generator U-tubes to drain, since steam from the two-phase mixture collected in the top of the U-tubes. This stopped the flow through the steam i generators, and the power channel flow consisted only of the flow through the PRHR HX and the l CMT and accumulator injection flows. The steam fraction oscillations observed through the rod bundle lower-upper plenum and hot legs stopped when the steam generators U-tubes drained at approximately [ l* seconds. The two phase flow to the PRHR HX, consisting of alternating slugs of steam and water, had an average steam fraction significantly greater than the fluid coming from the power channel. The average steam fraction at the PRHR HX inlet was as high as [ ](***) percent, which enhanced the PRHR HX heat removal as compared to its heat removal capability with single-phase saturated or subcooled water When.the primary system flow stabilized after the initial oscillations, a PRHR HX heat removal rate of [ l"**' kW was calculated. This calculation was based on the average steam fraction of the fluid flowing to the PRHR HX (as calculated from the dP instnament readings in data ) plot 29), the average return flow rate, the HX inlet and outlet temperatures, and the pressure. It I assumes a slip coefficient of I between steam and water and may, therefore, be slightly lower than the actual heat transfer. It should be used only for test-to-test comparison. l When the loop-B cold legs had partially emptied, CMT-A transitioned from the recirculation mode to its drain down mode of operation at approximately [ l^ seconds. 'this resulted in increased CMT-A injection flow and helped increase the rate of primary system pressure decay. Because the CMT-B balance line was completely broken, no flow to or from CMT-B could occur. i m Aapowcmo:5.-6..ece.ib o7:695 .$.2.10-2

When the primary system pressure decreased to the saturation pressure of the water in the upper head, d,, the upper head started to drain (at [ ]'*" seconds). During the first [ ]'* seconds prior to ADS-1 actuation, [ l'*"lbm of water were discharged through the break, draining the pressurizer, the steam generator U-tubes, the power channel upper head, the power channel upper-upper plenum above the hot leg, the cold legs, approximately [ l'** ' percent of accumulators-A and -B, and approximately [ ]'** percent of CMT-A. Also, the two-phase mixture in the rod bundle, lower-upper plenum contained approximately [ ]'*" percent steam. ne rod bundle decay heat simulation had reduced the power level to approximately 270 kW at [ ]('" seconds, consisting of 120-kW decay heat and 150-tw heat loss compensation. He cold-leg side break flow rate had decreased, indicating that the cold i g-B2 contained mostly steam. The ADS phase started with the actuation of ADS-1 (approximately [ ]'** seconds) with ADS-2 and -3 occurring within the next [ ]'*" seconds. The heat loss compensation portion of the rod bundle power was stopped when ADS-1 occurred, and the rod bundle power level was reduced to approximately 120 kW. De ADS actuation increased the rate of primary system depressurization and markedly increased the injection flow rate from the accumulators. The rapid injection of cold water from the accumulators ([ ]'** seconds) decreased the steam fraction of the two-phase fluid flowing through the rod bundle, lower-upper plenum, and hot leg. Also the pressurizer, annular downcomer, and the horizontal portion of the cold legs were refilled. When the accumulator discharge ended, the flow through the heater bundle was reduced to the injection rate of the CMT-A and the PRHR HX flow, and the steam fraction of the two-phase mixture in the rod bundle again increased. The two-phase fluid flowed into hot leg-A, the PRHR HX, and the ADS via the pressurizer. He fluid discharged through the break was again replaced by steam at approximately [ ]'*" seconds. During the ADS phase, [ ](*" Ibm of water and steam were discharged from the ADS-1, -2, and -3 and approximately [ ](*"lbm were discharged through the break. His water was primarily supplied by the accumulators. The post ADS phase began when ADS-4 actuated. ADS-4 occurred at [ l'*" seconds, discharge through ADS-1, -2, and -3 ended, the pressurizer again emptied, and fluid was now discharged through ADS-4. When the primary system pressure had been reduced below the pressure corresponding to the water elevation head of the IRWST, flow from the IRWST started and CMT-A flow decreased and, shortly thereafter, ended. The CMT-B began to drain by gravity about the same time as the IRWST flow started. He flow from the IRWST and CMT-B refilled the primary system and single-phase water flow through the rod bundle was restored and the upper-upper plenum partially refilled. The flow through the PRHR HX ended at approximately [ l'*" seconds. The test was terminated when there was a steady flow of subcooled water flowing from the IRWST into the downcomer, I {] through the power channel, and out of the primary system through the ADS-4 flow paths. %J

i t

mAmtWWc4\\l625w 6a non:1t>07:t95 4.2.10-3

This test demonstrated that the heater bundle was covered (single-phase or twog e fluid) at all times during this event (data plots 30 and 31). There was no indication of heater rod te wature increase h due to lack of cooling (data plot 3). Key parameters describing the S00908 test are listed in Table 5.1-1, in Section 5.0. Discussion of Test Transient Phases Initial Depressurization Phase ([ ]* seco nds) The initial depressurization phase (IDP) started with the opening of the break valves (at time 0) and lasted until the primary system pressure was dictated by the saturation pressure of the fluid in the lower-upper plenum and the hot legs (Figure 4.2.10-1). Bis phase included the following events: initiation of the break, R signal at 1800 psia (initiated decay power simulation, closed the MSLIV), and S signal at 1700 psia (closed MFWIV, opened CMT injection line valves, and opened PRHR HX return line isolation valve, all with a 2-second delay; and initiated RCP coastdown after a 16.2-second delay a able 4.2.10-1). Facility Response during IDP: The break was initic.ted at time 0 and the primary system pressure rapidly decreased due to the rapid expansion of the pressurizer steam bubble resulting from the large fluid loss through the break. The pressurizer partially compensated for the loss of pressure by flashing; however, it was completely drained within the first [ ]* seconds of the event (data plot 32). De R (at [ l**' seconds) and the S (at [ ]* seconds) signals were based on pressurizer pressure only. When the R signal occurred, the MSLIV was closed and the power was reduced to 20 percent of full power after a 5.75-second delay and began to decay after a 14.5-second delay. As a result of the large flow rate out of the break, the primary system pressure rapidly decreased. When the primary pressure had decreased to about [ ](** psia, the [ ]* upper-upper plenum fluid flashed. This flashing temporarily slowed the primary pressure decrease at about [ l* seconds. De primary system pressure then decreased to about [ ]* psia at [ J * seconds. The pressurizer at this time was empty and the system pressure was determined by the bulk fluid temperature in the primary system. The PRHR HX flow started before the RCPs were turned off and continued by natural circulation after the RCPs were turned off (data plot 37). His ended the IDP. Pressure Decay Phase ([ ]* Seconds) The pressure decay phase (PDP) started when the system pressure (Figures 4.2.10-1 and 4.2.10-2) was supported at the saturation pressure corresponding to the bulk system fluid temperature. De phase ended when ADS-1 was opened on low CMT-A level and augmented the system depressurization. This phase was characterized by a steady decrease in overall system pressure and temperature. The core power (decay heat plus heat loss compensation) was reduced from m \\aptaNec4\\1fC5w etnon:1l>072th5 4.2.10-4

l l 420 kW to 270 kW (data plot 1). At 400 seconds (core power 280 kW), the PRHR HX heat ) removal rate was approximately [ l*" kW. j The initial CMT-A injection was in its natural circulation mode but the transition to draindown occurred quickly (data plot 38). De U-tubes of the steam generators were completely drained, j and they did not effect the rest of the test (data plots 20 to 23). The accumulator injection ) initiated at about [ l6" seconds when the primary system pressure dropped below 711 psia, but the injection rate remained low (less than [ ](**" Ibm /sec) until ADS actuation (data plot 39). Facility Response During the PDP: Following shutdown of the RCPs, the flow rate in the primary system rapidly decreased while oscillating. Rese flow oscillations resulted in oscillations of the steam fraction of the two-phase mixture exiting the rod bundle and flowing into the hot legs (data plots 30 to 31). Because of the rapid primary system depressurization, the overall effect of these oscillations on primary system pressure and temperature were insignificant. Rese oscillations in steam fraction did affect the thermal buoyancy head which drove the flow through the primary system at this time, since it affected the two-phase fluid density. De steam fraction oscillations were observed through the hot leg and the steam generators (data plots 20 to 21). However, the two-phase mixture entering the steam generators left the steam generators as saturated water (data plots 24 through 27). Some of the steam was condensed in the steam generator U-tubes (the primary-side pressure was higher {} than the secondary-side pressure until about [ l** seconds, allowing some heat to be transferred to the secondary-side fluid). De rest of the steam was separated from the two-phase mixture in the high point of the U-tubes (due to the low velocity), eventually causing the U-tubes to drain. Primary system flow continued through the steam generators until about [ ](**" seconds into the transient (plots 20 and 22) and a free water surface appeared at the top of the U-tubes. At approximately [ l'**" seconds, the steam generator U-tubes were drained and the flow oscillations stopped. The system pressure decay during the PDP started at a rate of [ ](**" psi /sec. When the loop-B cold legs became partially filled with steam and CMT-A transitioned to draindown mode the pressure decay rate increased to [ J*" psi /sec, at approximately [ l'* 6 *) seconds (Figure 4.2.10-1). At this time, the mass flow through the break sharply decreased, indicating that the break flow was transitioning from liquid to steam. The pressure decay rate slowed significantly before ADS-1 occurred (average [ J*" psi /sec.). After the cold legs were drained at about [ l*" seconds, flashing began in the tubular downcomer, lower plenum, and at the bottom of the power channel increased. The steam fraction reached [ l*" pm in the tubular downcour M [ T'6* pm in tk lower plenum. The CMT-A injection and PRHR HX steam flow were apparently not sufficient to subcool the fluid in the tubular downcomer. De accumulator injection started at about [ l'*6" seconds and tubular p downcomer and the lower plenum subcooling were restored. At this time, the water level in the C annular downcomer quickly decreased to about the elevation of the DVI nozzle, indicating that the mvouaus:46. no.wonss 4.2.10-5 REVISION: I

steam in the tubular downcomer and lower plenum collapsed. The annular downcomer was refilled when high accumulator injection occurred after ADS-1 (data plots 24,25,26, and 27). CMT-A started to inject cold Huid into the downcomer when the S signal occurred. Initially this injection was by natural circulation at approximately [ l**' lbm/sec., with hot Guid flowing from the cold leg-B1 through the CLBL into the top of the CMT-A, as cold fluid flowed from the bottom of CMT-A. After cold leg-B was partly drained (at about [ l**' seconds), there was flashing and draining of the CMT-A CLBL and CMT-A transitioned to its draindown mode in the [ j**' seconds time period (data plot 38). When the CLBL emptied, steam could now from the cold leg-Al to the CMT-A. However, flashing in the CMT-A may have o(cuired after this time due to the high temperature (saturatio temperature) of the fluid in the top of the CMT (data plot 15), and the rapidly decreasing system pressure. Flashing occurred to reduce the water temperature to saturation temperature while the primary system pressure decreased. When the free-water surface developed in the top of the CMT-A and its level began to drop (data plot 33), the injection flow rate increased from approximately [ l**' lbm/sec. This How rate decreased as the CMT-A level decreased and the draindown driving head was reduced (data plot 38). There was no flow from CMT-B because the simulated break on the CMT side of the cold leg-B2 to CMT-B balance line kept the CMT-B at atmospheric pressure. The accumulators started to inject fluid into the downcomer via the DVI lines when the system pressure dropped below 711 psia (at approximately [ ]**' seconds); nowever, the injection rate was low prior to ADS-1 (data plot 39). Throughout the PDP, the PRHR HX removed energy from the primary system. The combined effect of the PRHR cooling the primary fluid and the cold injection flow from the CMT-A and accumulator was sufficient to cool the core and to decrease the steam fraction of the fluid flowing I through the rod bundle from [ ]t'* percent during this phase (data plots 30 and 31). Automatic Depressurization System Phase ([ ]'** Seconds) ' Die automatic depressurization system (ADS) phase started with the actuation of ADS-1 and ended with the actuation of ADS-4 (Figure 4.2.10-1). Facility Response during the ADS Phase: With the actuation of ADS-1, followed by ADS-2 and ADS-3 within approximately [ l**' seconds, the rate of system depressurization increased from [ l^') psi /sec at the end of the PDP to [ l**' psi /sec. at the start of ADS. This rate gradually decreased as the system g pressure decreased. mwwnwiec4us25..c. non ib-072795 4.2. l()-6 REVISION: 1

After ADS-1 actuation, the accumulator-A and -B injection flow rate increased from approximately b,, [ l*" lbm/sec. (data plot 39). The accumulators injected cold water into the primary system for approximately [ ]6 seconds (from [ l*" seconds) and were then drained. The accumulator injection reduced the steam fraction of the rod bundle and lower-upper plenum fluid refilled the annular downcomer and the horizontal portion of the cold legs and panly suppressed the CMT-A injection. However, after accumulator injection ended the annular downcomer level decreased and the rod bundle steam fraction increased prior to ADS 4 actuation. The pressurizer started to refill [ l^ sed du @S4 mmd W m' W a dgd x liquid level of approximately [ ]*" ft. (data plot 32). Two-phase fluid was vented from the top of the pressurizer and flowed out of the primary system through the ADS-1, -2 and -3 flow paths. After ADS-4 occurred, the pressurizer drained and only a small amount of steam was vented through ADS-1, -2, and -3. Level oscillations occurred in the pressurizer at approximately [ l*" seconds. De first oscillation resulted from a temporary filling of the upper-upper plenum (data plot 31). The remaining oscillations coincided with oscillations in the whole primary system; that is, oscillations in the rod bundle steam fraction, system pressure, and temperature. The break flow rate increased at the end of the accumulator injection as the cold legs were refilled by the high accumulator injection flow rate. A high break flow rate continued until q [ ]h seconds. Then the mass flow through the break slowed down and converted from v liquid to predominately steam, as the cold legs again emptied. Post-Automatic Depressurization System Phase ([ J**" seconds to End of-Test) The post-automatic depressurization system (post-ADS) phase started when ADS-4 occurred (Figure 4.2.10-1) and continued to the end of the event. Facility Response During the Post-ADS Phase: j ADS-4 actuation rapidly decreased the primary system pressure to near atmospheric pressure. De water level in the tubular downcomer decreased sharply in response to the increased ADS flow rate out of the hot legs (data plot 25). His resulted in a significant increase in the steam fraction in the rod bundle and lower-upper plenum. However, rod bundle cooling was maintained by two-phase fluid flow at the increased flow rate (data plots 30 and 31). Gravity flow from the IRWST and CMT-B into the downcomer began at approximately [ jA" seconds (data plots 40 and 38). Gradually subcooled water flow through the power channel to the hot legs and out through the ADS-4 flow paths was established (data plot 30). This steady-state condition was considered the end of the test. p After ADS-4 was actuated, the pressurizer drained and only a small amount of steam was vented through ADS-1, -2, and -3. The PRHR stopped flowing at approximately [ l*" seconds as the hot leg subcooled (data plot 37). mwumetto25.-6. non n>on695 4.2.10-7

i 1 Component Responses g Power Channel The power channel consisted of five volumes: the lower plenum, the riser with the heater rod bundle, the lower-upper plenum below the hot leg, the upper-upper plenum above the hot leg, and the upper head. When the break occurred, the primary system pressure decreased rapidly to the R signal (1800 psia) and the S signal (1700 psia) actuation set-points. However, since the water everywhere in the power channel was at a temperature below the saturation temperature for the primary system pressure, no boiling or flashing had yet occurred. When the rod bundle power was reduced to 20 percent,5.75 seconds after the R signal, the temperature gradient across the core decreased due to the reduced power / flow ratio (still full flow), and the power channel outlet temperature dropped toward the lower-plenum inlet temperature (Figure 4.2.10-2). The upper-upper plenum still contained water at [ l**' F, which started to flash when the primary system pressure dropped below [ j 6 pb -M k gygm pmm @iWy &ded Ws flashing and draining of the upper-upper plenum temporarily slowed the primary system pressure decrease. The boiling in the rod bundle and the flashing in the upper-upper plenum continued. The pressure stabilized at the saturation pressure corresponding to the bulk primary system fluid temperature (approximately [ ]* psia ([ l**F) at the end of the IDP at [ l**' mod The temperature of the fluid in the rod bundle and lower-upper plenum controlled the system pressure during the PDP (data plot 4). Flow oscillations in the tubular downcomer and in the steam fraction of fluid flowing through the rod bundle (period of [ ]**' seconds) started when the RCPs coasted down and continued until about [ J6 seconds into the event. These oscillations in the rod bundle steam fraction continued into the lower-upper plenum and hot legs (data plots 30 and 31). ) Data plots 30 and 31 show the collapsed liquid levels at various sections of the power channel during the S00908 event. The upper-head fluid temperature was initially only [ l'***'*F and started to flash and to drain when the primary system pressure decreased to about [ J 6' pia -a[ j**' seconds. The upper head was completely drained at approximately [ l* seconds (data plot 31). During this time, oscillations (period 4 seconds) in the upper head collapsd liquid level due to flashing were observed. The upper-upper plenum flashed and drained completely down to the hot-leg elevation during the IDP. This level stayed at the hot-leg elevation until the end of the accumulator injection, when the water flow and through the power channel subcooled and condensed the steam bubble in the upper-upper plenum (see temperatures in data plot 4) at [ ]**' seconds. However, when the accumulator injection ended, the level rapidly decreased to the hot leg elevation or below. At g [ l seconds, the upper-upper plenum was again subcooled and filled with water injected from IRWST and CMT-B. nvwce 625+6..non:tho72695 4.2.10-8

The level in the lower-upper plenum indicated that there was single-or two-phase flow through the rod bundle throughout the whole test; however, high steam fraction ([ ]"*" percent) flow occurred during the PDP from about [ l^ seconds, and just after ADS-4 actuadon. Data plot 30 shows the collapsed levels in the rod bundle oscillating following RCP coastdown, indicating apparent steam fractions in the rod bundle from [ ]**' percent to [ l" percent (with a period of approximately [ J'*6 seconds. De oscillations ended at a maximum rod bundle steam fraction of [ ]'* 6 *) pcent M [ T** seconds). Accumulator and CMT-A injection and PRHR hX heat removal were sufficient to increase the rod bundle collapsed liquid level from [ l'** percent during the PDP. The accumulator injection during the ADS reduced the steam fraction of fluid in the rod bundle to about [ ]"" percent; however, when the injection ended the boiling and two-phase fluid flow again started and reached a maximum ([ ]'*6** percent steam fraction) just before the IRWST and CMT-B injection started during the post-ADS phase. The lower-upper plenum indicated a steam fraction of [ l**) percent at this time, which was due to the fact that the level of two-phase mixture in the lower-upper plenum temporarily decreased below the hot-leg elevation. The collapsed level measured just above the top of heated section of the rod bundle (above TAF [ ]) provided steam fractions that correlated well with those measured through the rod bundle during this event. i O 1 Pressurizer De pressurizer started to drain when the break occurred and was completely drained in approximately [ ]"" seconds (data plot 32). He water in the pressurizer flashed due to the loss of system pressure, and the temperature of the water dropped below [ l6*F during this initial depressurization (data plot 18). De hot water exiting the pressurizer surge line into hot leg-A caused a slight increase in the hot-leg temperature during this period, since it mixed with the flow from the power channel-upper plenum. De pressurizer stayed drained until about [ }"" seconds after ADS-1 occurred, at which time it began to refill and reached at collapsed liquid level of approximately [ ]"" ft. Two-phase fluid was discharged from the top into the ADS. This continued until ADS-4 ([ ]** seconds), at which time the pressurizer level decreased and it was drained at about [ ]"* seconds. During the ADS phase and during the draining after ADS-4 actuation, the pressurizer level oscillated. De first oscillation at [ ]"" seconds resulted from the condensation of steam in the upper upper plenum and subsequent refilling (data plot 31). De remaining oscillations occurred both before and after ADS-4 was actuated and coincided with pressure, level, and flow oscillations throughout the primary system. Steam Generator The steam generators acted as the heat sink until the MSLIV closed and prevented further energy removal from the secondary side. His caused the temperature (and pressure) of the secondary maa;wwum625 -6 gtt>cn 95 4.2.10-9 REVISION: 1

side to increase toward the primary system hot leg temperature, which at the same time was dropping due to the reduced power / flow ratio. h For the first part of the pressure decay phase, the pressure on the primary side of the steam generators was higher than the secondary side (data plot 2), indicating that some heat transfer from the primary to secondary side occurred and caused some condensation of the steam in the two-phase fluid coming from the hot leg. The primary system pressure did not drop below the secondary side until approximately [ ]** seconds into the event, at which time the steam generator U-tubes were nearly drained. At the end of the RCP coastdown, oscillations in the collapsed liquid level in the rod bundle and in the density of the two-phase liquid flowing into the hot leg reached the steam generators (data plots 20 and 21). For steam generator-A, the U-tubes were full until approximately [ l* seconds into the j transient. At this time, a free surface started to develop in the top of the U-tubes, due to the separation of steam from the two-phase mixture at the low flow velocities existing at the natural circulation flow conditions. The fluid level in the U-tubes decreased in steps until due to the i oscillating density of the primary fluid. The cold-leg side of the steam generator U-tubes drained completely by approximately [ l** seconds. The hot-leg side of the steam generator U-tubes did not drain completely until ADS-1 actuation (data plots 20; 21,22, and 23). At about [ l** seconds, the measured differential pressures (dPs) of the steam generator-A cold-leg side U-tubes indicate that the water in the instrument reference legs begins to flash. These dP measurements should therefore be ignored after [ }(**" seconds. Hot L.egs Hot legs-A and -B were full of two-phase fluid until ADS-1 (data plots 20 and 21). After ADS-1, the levels started to decrease. The hot legs were temporarily drained after ADS-4 at [ l** seconds and partially refilled later due to IRWST and CMT-B injection. The principal difference between hot legs A and -B was the influence of the PRHR on the steam fraction in the hot legs. The two hot legs had similar steam fractions at the power channel; however, the PRHR HX preferentially removed steam from hot leg-A, as seen in the very high void fraction for the fluid at the PRHR HX inlet. This reduced the steam fraction of the fluid in hot leg-A as compared with hot leg-B. Cold Legs = Cold legs-Al and -A2 remained full until about [ l** seconds (data plots 22,23,24,25,26, and 27). Den they were rapidly drained to the elevation of these horizontal pipe sections at about [ l*" seconds. De small flow from PRHR HX (oscillating after ADS-1) was obsen.1 in the g cold leg A2. The cold legs A1 and A2 were partially refilled from about [ l*" seconds due to high injection from accumulators. o m \\aptabec4\\l625w fa non Ib-072695 4.2.1()- 1()

The liquid level decreased into the annular downcomer after accumulator injection. When ADS-4 nC occurred, the level dropped [ J**' ft. below the elevation of hot legs (data plot 24). He IRWST and CMT-B injection started at [ l**' seconds into the event, and the annular downcomer was refilled at [ ]**' seconds. Cold leg-A and hot leg-A were partially refilled to the level of [ ]**) ft above the hot leg. Cold legs-B1 and -B2 remained full until about [ l**' seconds. Then both cold legs-B1 and -B2 drained rapidly and CMT-A draindown started. Cold legs-B1 and -B2 remained empty since they were the break flow path, but were refilled after [ l** seconds to the level of [ J* ft. above the hot-leg test. Flow through these cold legs can be observed until ADS-1 actuation. PRIIR and IRWST Break At the initiation of the event, the PRHR subsystem was filled with subcooled liquid. When the S signal occurred, the PRHR return flow isolation valve opened, and a flow started through the HX at high flow rate due to the still operating RCPs. When the RCPs were shut off, flow through the HX was by natural circulation. As the hot legs fluid became two-phase, a large portion of the steam in the hot leg-A flowed to the PRHR (void fraction is [ ]"** percent based on data plot 29). His two-phase mixture, consisting of slugs of steam and water, was condensed and subcooled in the PRHR HX (data plot 28). During the PDP (prior to ADS-1), there was a o\\ significant decrease in the flow through the PRHR, caused by the decrease in the steam fraction of >v the fluid in the hot leg A and decreasing primary system pressure and temperature. A well behaved condensation process was observed in the HX during the PDP as evidenced by the flow and dP measurements (data plots 28,29, and 30). The initiation of ADS-1 and the following primary system depressurization at low PRHR flow (about [ ]"** lbm/sec. before ADS-1) resulted in flushing in the PRHR supply line fluid. Condensation of the steam occurred in the PRHR heat exchanger. This resulted in periodic changes in the buoyancy driving head and periodic flow rates (period about [ ]"** seconds). Rese flow rate oscillations continued until ADS-4. The PRHR flow stopped at about [ l* seconds. The PRHR heat exchanger was submerged in the IRWST and heatup of the water witidn the IRWST is shown in data plot 17. Following ADS-4, the primary system pressure decreased to near ambient, and IRWST gravity flow into the downcomer began, due just to the water elevation head in the IRWST (data plots 32 and 40). Core Makeup Tanks (CMTs) De CMT-A injection was initiated 2 seconds after the S signal by opening the CMT injection line p valve isolation. Initially, the flow from the CMT-A was by natural circulation with hot water from 'd the cold leg-B flowing through the cold leg-balance line to the top of the CMT-A, replacing cold mwanmm:5wuooo:n,-072tAs 4.2.10-11

t water which Dowed from the bottom of CMT-A drained into the downcomer via the DVI. Initially this recirculation occurred at approximately [ l6 lbWn fm NTA h When cold legs-B1 and -B2 were drained at [ j* seconds, flashing and draining began in the cold leg-B1 balance line. When the temperature at the top of the CMT reached the saturation temperature corresponding to the primary system pressure, a free-water surface was established in the CMT-A, and the tank began to drain at [ ]*" seconds. Because the balance line was l empty, the driving head for the CMT flow increased and the CMT-A draindown flow increased to l I [ l*" lbm/sec. at [ ]*" seconds. During the accumulator injection ([ l* seconds), the CMT-A injection was reduced to about [ ]*" Ibm /sec. i Since the break was in CMT-B balance line, there was flow to or from CMT-B. However, gravity draindown from CMT-B did occur at about [ ]*" seconds, after ADS-4, when primary system j pressure dropped below the water elevation head of the water CMT-B. Because there was no hot water or steam flow in the CMT-B, the water temperature remained approximately [ ]^" F throughout the test. The CMT-A was heated, first by the hot fluid from the CLBL, and later by steam from the cold leg condensing on the free-water and metal surfaces in the upper part of the CMT-A. A stratified thermal gradient was established and maintained in the CMT-A water (data plot 15), where the free-water surface temperature was at or near saturation temperature, while the water at the bottom h remained cold. When IRWST and CMT-B injection started at [ ]('*" seconds CMT-A injection decreased and stopped at about [ ](**" seconds. CMT-A was never drained completely. 1 Accumulators The accumulators provided water injection into the downcomer by a polytropic expansion of a compressed air volume stored within the accumulator. Water from the accumulators was injected, when the primary system pressure dropped below 711 psia. 'Ihe accumulator injection started at about 180 seconds (before ADS-1) at a low flow rate. However, when ADS-1 occurred, the l injection rate increased rapidly to about [ ]6 lbm/sec.) [dats plot 39]. The accumulator injection for the 500908 test lasted approximately [ ]*" seconds, and the accumulators were completely drained when the injection ended (data plot 34). l l The effective polytropic coefficient of expansion was calculated for the accumulators l (Figures 4.2.10.3 and 4.2.10.4) to be [ l b W [ T'**' for accumulators-A and B, respectively. This is near the midpoint between isothermal expansion (k=1) and adiabatic expansion (k=1.4) and shows that some heat was picked up by the nitrogen gas from the ir.ternal metal surfaces of the accumulator during the expansion. I mWem 4sio:5* *non:t two72695 4.2.10-12

J i Mass Discharge and Mass Balance is:. . Re catch tank weight measurements are shown in plot 43 for the break flow (for the cold-leg side of the break), for the ADS-1, -2, -3 flow, and for the ADS-4 flow. Data plot 44 provides an' estimate of .l the flow rate of each of these discharges. The break flow was stable with a decreasing flow rate as the system pressure dropped during the IDP j and the PDP, he mass flow rate through the break started at approximately [ ]*#) lbm/sec. .j decreased sharply when the loop-B cold legs drained at [ ](***) seconds. When the water level in a the annular downcomer increased above the cold-leg elevation due to injection of the accumulators i (cold legs partially refilled), the break flow increased to [ ]('*#) lbm/sec. at about [ ](***) j seconds into the event. The break flow rate rapidly decreased to [ ](**#' lbm/sec. after [ l*#' seconds (cold legs drained again) and completely stopped at 'about [ ]*" seconds when the IRWST injection refilled the cold leg. Be discharge from ADS-1, -2, and -3 was stable throughout the accumulator injection and increased j l temporarily when the injection ended in response to the low steam fraction of fluid from the power channel. When ADS-4 occurred, ADS 1, -2, and -3 discharge from the top of the pressurizer stopped and the fluid was discharged from ADS-4. He ADS-4 fluid discharge was relatively stable and continued until the end of the test. At about [ ](***) seconds, the ADS-4 flow rate temporarily decreased when the upper-upper plenum refilled. The discharged masses are shown in Table 4.2.10-3. De mass balance results for test S00908 were calculated based on water inventory before and after the j . S00908 test. Table 4.2.10-1 gives a detailed listing of the inventories of water in the various j components before the test. Table 4.2.10-2 lists the inventories after the event and the amount of f water injected into the vessel from the IRWST. De water level in the vessel was determined by the j DP-B16P measurement to be [ ]i'*#' in. ([ l*#) mm) above the hot-leg centerline at the end of the test. Table 4.2.10-3 compares the mass balance for the system before and after the test and shows. ~ an agreement of 3 percent of measurements before and after testing. i .i 1 O i mwwwu4u625.w.no :nson695 4.2.10-13 I

TABLE 4.2.101 SEQUENCE OF EVFNIS FOR TEST S00908 Event Specified Instrument Channel Actual Time Break Opens 0 p.o R Signal P = 1800 psia P-027P MSLIV Z_ANSO, F_AN3 Z B04SO, F_BNS S Signal P = 1700 psia P-027P MFWIV S + 2 sec. Z_B02SO, F_B0IS Z_A02SO, F_A0lS CMT S + 2 sec. Z_AN0EC. F-A40E Z_BM0EC, F-840E RCPs S + 16.2 sec. I-AIP, S.AIP l BIP, S-BIP PRHR Heat Exchanger S + 2 sec. Z_A81EC, F_A80E Actuation ADS-1 CMT level 67% L_A40E +30 sec. Z.001PC Accumulators 696.1 psia F_A20E F_B20E ADS-2 CMT level 67% L_B40E +125 sec. Z_002PC ADS-3 CMT level 67% L_B40E +245 sec. Z_003PC ADS-8 CMT level 20% L_B40E +60 sec. Z_0NPC, Fo*0P IRWST Injection 26.1 psia F_A60E F_B60E l 1 mwmNu4xio25. c.non:tho72695 4.2.10-14 j i

l. ').; TABLE 4.2.10-2 ~ WATER INVENTORY BEFORE EVENT Component Volume Net Vol Temp Relative M ass (ft.')/(1) (ft.8)/(I) ('F) Density (Ibm /sec.) Loops 8.97 ft.' 8.97 ft.' J (254.0 l) (254.0 l) Pressurizer 3.37 ft.' l.89 ft.' (95.4 I) (53.5 l) Surge Line 034 ft.' 034 ft.' (9.6 f) (9.6 l) Tubular Downcomer 1.38 ft.' 138 ft.' (39.1I) (39.1l) Annular Downcomer and 0.54 ft.' O.54 ft.' High. Pressure Bypass (15.3 f) (15 3 l) Core Bypass 0.44 ft.' O.44 ft.' ) (12.4 I) (12.4 f) l Lower Plenum 0.81 ft.' O.81 ft.' (22.8 l) (22.8 l) O Riser 1.64 ft.' l.64 ft.' (46.4 f) (46.4 l) Upper Plenum 1.46 ft.' l.46 ft.' (41.3 I) (413 4 j l Upper Head 1.90 fL' !.90 ft.' (53.8 l) (53.8 I) i CMTs 10.1 ft.' 10.1 ft.' (286.0 l) (286.0 () Accumulator 10.1 ft.' 7.80 ft.' (286.0 l) (220.9 I) IRWST 0.18 ft.' O.18 ft.' (5.1 l) (5.1 11 i TOTALINVENTORY 1 O m:\\apMbec4\\l 625 w-6a. noo : l l>072695 4.2.10-15

TAllLE 4.2.10 3 - WATER INVENTORY AFTER EVENT WAS COMPLETED Water level as measured by DP B16P ( 0.50 psi) is 352 mm above Hot Leg Component Volume Net Vol Temp (*F) Relative Mass (ft*)(l) (ft.')(f) Density (Ibm /sec.) Loops 8.97 ft.' O.0 ft.' (254.0 l) (0.0 l) Pressunzer 3.37 ft.' O.0 ft.' (95.4 l) (0.0 l) Surge Line 0.34 ft.' O.0 ft.' (9.6 l) (0.0 l) Tubular Downcomer 1.38 ft.' l.38 ft.' (39.1f) (39.1l) Annular Downcomer and 0.54 ft.' O.42 ft.' High-Pressure Bypass (15.3 I) (12.0 l) Core Bypass 0.44 ft.' O.44 ft.' (12.4 l) (12.4 l) Lower Plenum 0.81 ft.' O.81 ft.' (22.8 I) (22.8 f) Riser 1.64 ft.' l.64 ft.' (46.4 I) (46.4 l) Upper Plenum 1.46 ft.' l.23 ft.' (41.3 l) (34.9 l). Upper Head 1.90 ft.' O.0 ft.' (53.8 l) (0.0 l) CMT-A 5.05 ft.' O.32 ft.' (143.0 l) (9.1 l) CMT.B 5.05 ft.' 2.61 ft.' (143.0 l) (73.8 l) Accumulator 10.1 ft.' O.0 ft.' (286.0 l) (0.0 l) IRWST 0.18 ft.' O.0 ft.' (5.1 f) (0.0 l) TOTAL INVENTORY WATER INJECTED IVOM THE IRWST DURING EVENT IRWST Injection dP (psi) Area (in') Mass (Ibs) 0.855 1007.5 ( l* O m%ptaAsec4\\l625w-6a non:lt>072695 4.2.10-16

['; TAllLE 4.2.10-4 MASS BALANCE FOR TEST S00908 Starting Inventory Ending Inventory Ohm) (thm) "A" Total Primary System IRWST Injections Break

• ADS-1,2,3 ADS-4" TOTAL Ending Inventory / Starting Inventory (Ibm)

Ending Inventory / Starting Inventory (%) i Includes only the break Dow from the cold-leg side of the break. Includes the break Dow from the CMT-side of the break plus the ADS-4 How. i /~~'s V ( m:satwxNec4\\t625 4mo:itvo72695 4.2.10-17

.. y _ .x ...r 4 M j v ?6 d v l' 1 1 g 9f% l (h,, /2g-( * .. h ,rx-

• fJ F

f p.-r! 4 4 p' i 3.. l Figures 4.2.10-1 through 4.2.10-4 (pages 4.2.10-18 through 4.2.10 21) . contain proprietary information and are not provided. 6 r l t 3 I l 1 i I r ~ I l . ? L 1 4-r .1 d i i 4 ; . ) mAap600,ec4si625w.6 agit>w2795 4.2.10-18 REVISION:.1

J: g j 1 i W TEST S00908 PLOT PACKAGE (_) CHANNEL LIST BY COMPONENT COMPONENT CHANNEL UNITS PLOT COMMENT 1 ACCA F_A20E ' lbm/sec. 39 ACCA L_A20E ft. 34 ACCB F_B20E lbm/sec. 39 ACCB L_B20E ft. 34 ) ADS 1, 2, & 3 IF30FLW lbm/sec. 44 Flow rate derived from IF030P ADS 1, 2, & 3 IF030P lbm 43 Catch tank ADS 4 & SG IF40FLW Ihm/sec. 44 Flow rate derived from IF040P ADS 4 & SG IF040P lbm 43 Catch tank ANNDC DP-A021P psi 24 To cold leg-Al ANNDC DP-A022P psi 25 To cold leg-A2 ) 1 ANNDC DP-8021P psi 26 To cold leg-B1 ANNDC DP-B022P psi 27 To cold leg-B2 BREAK LINE IF05FLW lbm/sec. 44 Flow rate derived from IF005P BREAK LINE IF005P lbm 43 Catch tank CLA DP-A00lP psi 24 To cold leg-Al CLA D'P-A002P psi 25 To cold leg-A2 CLA DP-A09P psi 22 Pump suction CLA T-A10P

• F 11 Steam generator outlet CLA1 F_A0lP lbm/sec.

36 l CLA1 T-A021PL

• F 13 Downcomer inlet j

CLAl T-AllP

• F 11 Pump outlet l

CLA2 F_A02P lbm/sec. 36 j CLA2 T-A022PL

• F 13 Downcomer inlet CLB DP-B00lP psi 26 To cold leg-BI O

mwwwc4u6:5. 6..non:tb 07 695 4.2.10-22

TEST S00908 PLOT PACKAGE CHANNEL LIST BY COMPONENT (Cont.) h COMPONENT CHANNEL UNITS PLOT COMMENT CLB DP-B002P psi 27 To cold leg B2 CLB DP-B09P psi 23 Pump suction CLB T-B10P 'F 12 Steam generator outlet CLBI F_B0lP lbm/sec. 36 CLBI T-B021PL 'F 14 Downcomer inlet CLB1 T-B 11P "F 12 Pump outlet CLB2 F B02P lbm/sec. 36 CLB2 T-B022PL F 14 Downcomer inlet CMTA F_A40E lbm/sec. 38 CMTA L A40E ft. 33 CMTA T A401E "F 15 Top (242.25 in.) CMTA T-A403E

• F 15 216.75 in.

CMTA T-A405E 'F 15 191.25 in. h, CMTA T A407E "F 15 165.75 in, CMTA T-A409E

• F 15 140.25 in.

CMTA T-A411E

• F 15 114.75 in.

CMTA T-A413E

• F 15 89.25 in.

CMTA T-A415E 'F 15 63.75 in. i CMTA T-A417E 'F 15 38.25 in. CMTA T-A420E

• F 15 Bottom (0 in.)

CMTB F_B40E lbm/sec. 38 l CMTB L_B40E ft. 33 ) CMTB T-B401E 'F 16 Top (242.25 in.) i CMTB T B403E 'F 16 216.75 in. CMTB T-B405E F 16 191.25 in. CMTB T-B407E 'F 16 165.75 in. CMTB T-B409E

• F 16 140.25 in.

CMTB T-B411E F 16 114.75 in. ] g CMTB T-B413E

• F 16 89.25 in.

CMTB T-B415E "F 16 63.75 in. 1 mh *%ec4\\l625w-6a.non:th072695 4.2.1043 i

i; A~ TEST S00908 PLOT PACKAGE 1 O-CHANNEL LIST BY COMPONENT- (Cont.) COMPONENT CHANNFL UNITS PLOT COMMENT l CMTB T-B417E - 'F 16 38.25 in. CMTB T-B420E

• F 16 Bottom (0 in.)

CVCS F-001 A psi 42 DVIA T-A00E

• F 13 l

DVIB T-800E 'F 14 HLA DP-A04P psi 20 l HLA T-A03PL 'F 5 Vertical, near power channel HLA T-A03PO F 5 Horizontal, near power channel i HLA T-A04P 'F 5 Near steam generator inlet HLB DPB04P psi 21 HLB T-B03PL 'F 6 Vertical, near power channel HLB T-B03PO 'F 6 Horizontal, near power channel HLB T-B04P "F 6 Near steam generator inlet IRWST F_A60E lbm/sec. 40 IRWST F_B60E lbm/sec. 40 j IRWST L 060E ft 32 IRWST T-061E

• F 17 Bonom IRWST T-062E

'F 17 Below middle IRWST T-063E F 17 Middle IRWST T-064E

• F 17 Above middle IRWST T-065E
• F 17 Top PC W_00P kW l

PC-HB L_000P ft 30 Heater bundle PC-HR TW018P20 'F 3 Heater rod PC-HR TW018P48 "F 3 Heater rod PC-HR TWO20P87 'F 3 Heater rod PC-UH T-016P

• F 4

Upper head PC-UP L_AISP ft. 30 Lower upper plenum O-ec-ur ' ^i6e <t. 3i upper-PPer P e - i PC-UP T-015P F 4 Upper plenum m:\\a:WXhec4\\l625w 6a.noa:lh072695 4,2.10-24

r TEST S00908 PLOT PACKAGE h CHANNEL LIST HY COMPONENT (Cont.) COMPONENT CHANNEL UNITS PLOT COMMENT. PC-UH L_017P ft. 31 Upper head PC-UP L_A14P ft. 31 Above top of the active fuel PRHR DP-A81 AE psi 29 Supply Ime inverted U-tube PRHR DP-A81BE psi 29 Supply line inverted U-tube PRHR DP-A81E psi 28 Supply line PRHR DP-A82E psi 28 Heat exchanger PRHR DP-A83E psi 28 Return line PRHR F_A80F-Ibm /sec. 37 Return line PRHR T-A82E

• F 19 Inlet PRHR T-A83E
• F 19 Exit PRZ L_010P ft.

32 PRZ P-027P psia 2 PRZ T-026P

• F 18 487 in.

h. ;

SGA DP-A05P psi 20 Hot side SGA DP-A06P psi 20 Hot side SGA DP-A07P psi 22 Cold side SGA DP-A08P psi 22 Cold side SGA F_A0lS lbm/sec. 41 Main feed SGA F_A20A lbm/sec. 41 Secondary feed SGA L_A10S* ft. 35 Overall level SGA P A04S psia 2 Secondary system SGA T.A0lS F 10 MFW A SGA T-A05P

• F 7

Hot side SGA T-A05S

• F 9

Hot side riser SGA T-A%P

• F 7

Hot dde SGA T A08P "F 11 Cold side SGA TW A06S

• F 7

Hot side SGB DP-BOSP psi 21 Hot side g SGB DP-B06P psi 21 Hot side SGB DP-B07P psi 23 Cold side m:saiuxuec4xio25. eanon:t ho72695 4.2.10-25

? r t /% TEST S00908 PLOT PACKAGE d CHANNEL LIST HY COMPONENT (Cont.) COMPONENT CHANNEL UNITS PLOT COMMENT l SGB DP-B08P psi 23 Cold side SGB F_BOIS lbm/sec. 41 Main feed SGB F_B20A lbm/sec. 41 Secondary feed SGB L_ BIOS

• ft.

35 Overall level SGB P B04S psia 2 Secondary system l SGB T-B0IS

• F 10 MFW-B '

SGB T-BOSP

• F 8

Hot side l SGB T-BOSS 'F 9 Hot side - riser SGB T-B06P F 8 Hot side SGB T-B07P 'F 8 U-tube top P SGB T-B08P 'F 12 Cold side SGB TW-B06S 'F 8 Hot side SL T-020P

• F 18 Surge line near pressurizer Q

U TDC DP-00lP psi 25,26 Top TDC DP-002P psi 24,25,26,27 Bottom TDC T-00lPL 'F 13,14 Top TDC T-003P F 4,13.14 Bottom TSAT-PRZ n/a

• F 18,19 Based on P-027P

] TSAT-UH n/a 'F 4 Based on P-017P ' Failed channels i ) O m% wwec4sio25.* non:it>o72695 4.2.10-26 i I

1 i ADS-1, -2, -3 flow from the primary system decreased from approximately [ ]**' lbm/sec. to [D approximately [ l^ lbm/sec. at [ ]"* seconds (data plot 44). This was apparently in u) response to the suppression of steam production caused by the combined accumulator and CMT injection flow rates. ADS-1, -2, -3 flow then stecreased steadily to approximately i [- J** lbm/sec. at [ ]"**' seconds when ADS-4 was actuated. Break flow from the primary to the faulted steam generator-B quickly reversed once ADS depressurization began. His reverse flow continued throughout the ADS-1 -2, -3 phase at an average rate of approximately [ ]"Albm/sec., decreasing slightly as steam generator-B pressure decreased. Steam generator-B level also decreased steadily (Figure 4.2.13-5 and data plot 35). His reverse flow had no apparent impact on overall plant depressuriz'aion or passive safety system operation. Reverse flow from steam generator-B was always sigraficantly less than passive safety system injection flow. 1 Post-Automatic Depressurization System Phase ([ ](*** Seconds to End-of-Test) ] Re post-automatic depressurization system (post-ADS) phase began when ADS-4 occurred (Figure 4.2.13-2) and continued to the end of the event. l Facility Response during the Post ADS Phase: O ADS-4 actuation decreased sr tem pres ure to near ambient at angroximateix i i" " seconds (data plot 2). De actuation of ADS-4 initially resulted in a significant increase in total ADS flow, which exce<,ded the injection rate from the CMTs and IRWST (data plots 38,40,44). His resulted in a level drop in the annular downcomer into the tubular downcomer (data plot 25) and a significant increase in the steam fraction in the rod bundle and lower-upper plenum; however, sufficier.t two-phase mixture flowed through the rod bundle for cooling (data plots 30 and 31). Gravity flow from the IRWST quickly increased to full flow while the CMT flow decreased. At this time, system pressure was very low, and the liquid left the system through the ADS 4, with no flow through ADS-1, -2, -3. He cold flow from the IRWST gradually refilled the rod bundle, lower-upper plenum and hot legs with subcooled water. He water levels in the primary system stabilized; the upper-upper plenum i became subcooled and refilled; the CMTs slightly refilled; and the pressurizer drained. His steady-state condition was considered to be the end of the test. Reverse flow from the faulted steam generator-B into the primary system continued through the post-ADS phase at approximately [ ]"^*' lbm/sec. until the steam generator-B was drained to the level of the break at [ ]"^*) seconds (Figure 4.2.13 5 and data plot 35). mwumo2swuo25..tonon wo7269s 4.2.13-6

i 4 Component Responses O Power Channel The power channel consisted of five volumes: the lower plenum, the heater rod bundle, the lower-upper plenum (below the hot leg), the upper upper plenum (above the hot leg), and the upper head. When the break was initiated at time 0, the pressurizer internal and external heaters were turned off and the pressurizer level decreased, causing primary system pressure to decrease. When pressurizer level reached 10 percent (2.2 ft.), the R and the S signals were actuated. At 5.75 seconds after the R signal, the heated rod power was reduced to approximately 20 percent of full power (1000 kW), reducing the power / flow ratio (RCPs still running). This caused the rod bundle, the lower-upper plenum and hot-leg temperatures to rapidly drop toward the lower-plenum temperature (Figure 4.2.13-2). When the RCPs were shut off, the power / flow ratio increased and caused the rod bundle outlet temperature to increase. The lower-upper plenum temperature increased to [ l 'A*F and then i decreased due to the power decay and decreasing lower-plenum temperature. The power channel and the entire primary system remained subcooled, and little or no boiling was observed in the rod bundle region until ADS-1 was actuated. After ADS-1 was actuated ([ ]** seconds), primary system pressure decreased rapidly to approximately [ l^" psia. Flashing started in the upper-upper plenum, lower-upper plenum, hot legs, and rod bundle region, temporarily stabilizing primary pressure. Depressurization and continued flashing caused level in the upper-upper pienum to empty to the elevation of the hot leg at h [ l*" seconds (data plots 30 and 31). Accumulator injection started at [ l*" seconds and limited the steam fraction in the lower-upper plenum. After accumulator injection, the upper-upper plenum partially refilled above the hot-leg elevation ([ ]**' seconds). The upper head began to drain when system pressure reached saturation pressure for the fluid temperature in the upper head (at [ ](**" seconds). The upper head fluid temperature was initially only [ l*" F and flashing began at [ l(**" seconds, and the upper head was drained at [ l'* b seconds (data plot 4). After this time, the upper head contained superheated steam. Data plots 30 and 31 show the collapsed liquid levels at variou1 sections of the power channel. Data plot 30 shows the collapsed levels in the heater bundle following the pump coastdown, indicating void fractions from [ l*" percent until accumulatoi injection began at 800 seconds. Accumulator injection suppressed boiling and refilled the power channel; however, when accumulator injection ended, the boiling again increased and reached a maximum ([ l^" mum em kho just before the IRWST injection started during the post-ADS period. The lower-upper plenum had a steam fraction of [ l*" percent prior to ADS-4, which was due, in part, to the fact that the two-phase mixture temporarily dropped below the hot-leg elevation. O mvnto25ei6241o waM2795 4,2 I3-7 REVISION: I

' The collapsed level measured just.above the top of the heated portion of the rod bundle (above TAF, h data plot 31) indicates steam fractions that correlated well with those measured for the heater rod - bundle. Pressurizer The pressurizer began to drain when the break occurred and was fully drained at approximately j [500]*" seconds after the S and the R signals occurred (data plot 32). The water in the pressurizer flashed due to the loss of system pressure, and the temperature of the water dropped from [ ]"#* F during this initial depressurization (data plot 18). The hot water leaving the pressurizer surge line into hot leg-A caused a slight increase in the hot-leg temperature during this period, since it ndxed with the flow from the power channel / upper plenum. De pressurizer remained drained until ADS-1 'l occurred, at which time it refilled to a collapsed liquid level of approximately [ l## ft. (full level at [ ]*" percent void fraction) and discharged steam and water to the ADS. Level dropped when the upper-upper plenum refilled. After accumulator injection caded. the pressurizer level steadily decreased in response to the increasing steam fraction of the flow from the rod bundle. This continued until [ l*" seconds when the pressurizer again rapidly drained and reached manometric agreement with the level in the primary system. Steam Generator i O De steam generators continued to function as the primary system heat sink until the R and the S signals occurred and the MSLIV closed and prevented further energy removal from the secondary side. His caused the temperature of the secondary side to increase toward the primary system hot-leg temperature, which at the same time dropped due to the reduced power / flow ratio. When the RCPs coasted down, a temporary temperature increase occurred due to the increased power / flow ratio at the natural circulation flow condition (Figure 4.2.13-2). The U-tubes were full (the siphon was maintained) until approximately [ }*" seconds into the transient. At this time, a free-water surface started to develop in the top of the U-tubes, primarily due to the separation of steam from the two-phase mixture at the low-flow velocities existing at the natural circulation flow conditions. De fluid level on the hot side dropped below the top of the U-tubes. This condition continued until approximately [ l*" mod when the top of the U-tubes was filled with saturated vapor. The pressure on the primary side of the steam generators was higher than the secondary side until [ l*" seconds (data plot 2), indicating that some heat transfer from the primary to secondary side occurred and caused some condensation of the steam in the two-phase flow coming from the hot leg. At this time ([ l*" seconds), the U-tubes were nearly draited. O m Aap601A1625 w\\l 625 w.10.non : l b 072 H95 4.2.13-8 ~.,

The level in the steam generator-A U-tubes hot side gradually dropped, and it drained completely at approximately [ l'** seconds. The cold side of the U-tubes was drained at approximately g i l*" seconds and pump A suction drained at [ l* seconds. The level in the steam generator-B U-tubes hot side gradually dropped, and it drained completely at about [ l*" seconds. The cold side of the steam generator-B U-tubes drained at [ ] *" seconds, the cold side of pump B suction drained at [ l*" seconds (data plots 22 and 23). The fluid level on the steam generator-A secondary side was nearly constant. The steam generator-B level increased slightly because of the break flow from the primary side until ADS actuation. When the break flow was reversed, steam generator-B secondary-side level steadily decreased and at about [ j*" seconds dropped below the break line elevation (data plot 35). Ilot Legs Hot legs-A and -B were completely full of water from the power channel outlet to the steam generator tubesheet until ADS-1 (data plots 20 and 21). After ADS-1, the level started to decrease and the void fraction increased. The hot-leg measured level dropped (void fraction increased) when ADS-2 and -3 were actuated and the steam generator hot-side tubes were drained. The hot legs were completely drained to the horizontal elevation from [ ]*" seconds (just prior to ADS-4) to [ j*" seconds and partially refilled after IRWST injection began. Hot leg-B refilled slower than hot leg-A. since steam from the reverse flow from steam generator-B must be h vented via the hot leg-B ADS-4 flow path (Figure 4.2.13-7). Cold Legs (Including Tubular Downcomer and Annular Downcomer) Cold legs-Al and -A2 remained full until about [ l6') seconds (data plots 22 through 27). Then the level rapidly decreased and completely drained, and the cold legs were filled with superheated steam. After [ l*" seconds, the annular downcomer level dropped to [ j*" ft. above the bottom of the annular downcomer. The accumulator refilled the annular downcomer; however, after the accumulator injection, the annular downcomer level again decreased. At [ ]*" seconds (PRHR flow had stopped and CMT injection flow rate was decreasing), the level in the tubular downcomer began to decrease. When ADS-4 occurred, the fluid level in the tubular downcomer temporarily dropped [ l*" ft. below the hot-leg elevation at [ j*" seconds (data plot 24). The rod bundle void fraction reached a maximum of approximately [ l*" percent. After [ l*" seconds, the tubular and annular downcomers were rapidly refilled due to the IRWST injection, and cold leg-A and the hot legs were partially refilled. 'Ihe cold and hot legs were refilled to the level of approximately [ ]*" ft. above their horizontal level by the end of the test. After [ l*" seconds, CMT-to-CLBLs began to refill. This indicated that the horizontal ponion of cold leg-B1 and -B2 were filled. l m%rNul625w\\l615* 10.non 1b-072695 4.2.13-9

Channel DP-A00lP reading, which was expected to be similar to the DP-A002P reading, was ) failed (data plots 24 and 25). He channel DP-A01IP was affected in a similar way; apparently because of the common reference leg for both channels. ] l PRHR and IRWST At the initiation of the event, the PRHR subsystem was filled with subcooled liquid. When the R and the S signals occurred at [ l*" seconds, the PRHR return valve opened after a 2-second delay, and a high rate flow started through the heat exchanger due to the still operating RCP. After the pumps were shut off and until ADS-1 actuation, the PRHR natural circulation flow rate was approximately [ J*"lbm/sec. The PRHR heat transfer from the primary system was approximately [ ](*** kW during this period. After ADS-1 actuation at [ j'**" seconds, the i power channel / outlet plenum and the hot legs contained two-phase flow, and a significant portion. j of the steam in hot leg-A flowed to the PRHR HX (void fraction was [ ]'* 6 *> to [ l*" percent based on data plot 29). De two-phase mixture, consisting of slugs of steam and water, was condensed and subcooled in the PRHR HX (data plot 28). Condensation spikes were observed in the PRHR HX, resulting in very large oscillations in data plots 28,29, and 37. Accumulator injection starting at [ ]*" seconds did not subcool the fluid in the hot leg. The fluid void fraction in hot leg-A increased from [ l*" percent at [ j*" seconds to [ ]*" percent at [ ]*" seconds. More importantly, cold leg-A drained at approximately [ j** seconds. This resulted in a decrease in driving head for flow in the PRHR, and the flow decreased. The ,d simultaneous flashing in the supply line and condensation in the HX resulted in large oscillations on the flow signal from the PRHR return line. After the accumulators completed injection, the flow in the PRHR decreased to a very low flow rate and stopped at approximately [ j*" seconds. The PRHR heat exchanger was submerged in the IRWST (heatup of the water within the IRWST is shown in data plot 17). The IRWST bulk water temperature did not increase significantly due to the limited time that the PRHR HX operated. The water temperature at the top of the IRWST, which heated up first, increased by approximately [ l**'*F. As the IRWST drained, the heated top layer of water remained thermally stratified. Following ADS-4 actuation at approximately [ ]*" seconds, primary system pressure decreased to near ambient, and gravity flow due to the water elevation head in the IRWST started to inject water into the power channel at [ l*" seconds. As shown in data plot 32, the IRWST level decreased from [ l**' ft. at [ ]** seconds when the transient was terminated. Core Makeup Tanks (CMTs) The CMT injection was initiated 2 seconds after the R and the S signals by opening the CMT-A 3 C) and -B injection line isciation valves. Initially, the injection flow from the CMTs was by natural maaiw m 6:5.u6:5w.io on:it,-on695 4.2.13-10

circulation; hot water from cold legs-B1 and -B2 flowed through the CLBL to the top of the CMTs; and cold water from the CMTs drained into the power channel via the DVI nozzles. g, This CMT recirculation mode of operation occurred at approximately 0.13 lbm/sec. for each CMT but provided approximately [ ]* lbm/sec. per CMT net mas addition to the primary system. j When cold legs-B1 and B2 drained to the cold-leg horizontal elevation at [ l* seconds, the CMT CLBLs drained, allowing steam to flow to the top of the CMTs from the cold legs. When the temperature of the water at the top of the CMTs neared the saturation temperature for primary system pressure, the CMTs transitioned to their draindown operating mode. This increased injection flow, since the injection flow driving head was cssentially the full elevation of the CMT water-instead of the density difference (buoyancy head) between the CMT water elevation and the balance line water elevation. For CMT-A, this transition occurred at about [ Jt'^ seconds and flow increased to [ l**) Ibm /sec. (Net CMT injection increased from [ l**' to [ ]* lbm/sec.) During the time the accumulators were injecting ([ ]* seconds), the CMT injection flow decreased to approximately [ j**)lbm/sec., due to the increase in flow back pressure in the common CMT and accumulator injection piping. When the accumulators emptied, the CMT injection flow increased to approximately [ ]**' lbm/sec., and then slowly decreased to approximately [ J**) Ibm /sec. at [ J* seconds due to decreasing gravity head driving h force as CMT level decreased (data plot 38). When ADS-4 was actuated, the injection flow for both CMTs temporarily increased to [ l*lbm/sec. This indicated that a slight pressurization of the CMT due to flashing of the CMT heated water occurred when ADS-4 quickly decreased primary system pressure. CMT injection flow then quickly decreased and stopped at approximately [ j^ seconds, before the CMTs were completely drained. This was expected, since the IRWST gravity head at this time affected the pressure at the common injection line, similar to the primary pressure compensated CMT water level gravity head. Also, after [ ]**' seconds, the cold legs refilled, blocking the cold metal surfaces. Condensation due to heat losses caused a small increase in level and resulted in a vacuum in the CMTs. As shown in Figures 4.2.13-8 and 4.2.13-9, this vacuum was suffi,: lent to draw water from the cold legs and to refill the CMTs. As seen in previous tests, the CMT water inventory was heated first by the hot primary system fluid from the cold legs, and later by steam from the cold legs. A stratified temperature gradient was established in the CMTs (data plots 15 and 16), where the highest or free-water surface temperature was at or near saturation temperature, and the bottom temperature was cold. e' O m Aaponm1625.\\t 625.. t o.n= i so72695 4.2.I3-11

l . Accumulators g 'O De accumulators provided injection into the power channel by a polytropic expansion of air volume stored within the accumulator when the primary system pressure dropped below 711 psia. The accumulator injection staned at [ J* seconds shortly after ADS-1 (data plot 39) and continued approximately [ ]"^*' seconds. ne accumulator injection flow rates quickly peaked at [ ]^ lbm/sec., and decreased to [ ]'*lbm/sec. before quickly stopping at [ l**' seconds. De effective polytropic coefficient of expansion (Figures 4.2.13-3 and 4.2.13-4) was calculated to be [ ]* for accumulator-A and [ l^ for accumulator-B. His is near the midpoint between isothermal expansion (k = 1) and adiabatic expansion (k = 1.4) and shows that some heat was picked up by the nitrogen gas from the internal metal surfaces of the accumulator during the expansion. Mass Discharge and Mass Balance The break mass flow (from primary side to secondary side) started at approximately [ l**' lbm/sec. when the break valve opened at 0 time. The flowrate rapidly decreased to 0 after ADS-1 actuation when the primary-and secondary-side pressures equalized at about [ l#*' seconds. After that time, the flow was reversed from steam generator-B to the primary system in response to primary system rapid pressure decay versus steam generator B pressure (Figure 4.2.13 5). The total mass g discharged to the secondary side due to the break was approximately [ ](** lbm; and the total mass V returned to the primary side was [ ](***' lbm (Figure 4.2.13-6). The mass balance results for test S01211 were calculated based on primary side water inventory before and after the 501211 test taking into account the SGTR break flow between the primary and secondary side. Table 4.2.13-1 gives a detailed listing of the inventories of water in the various components before the test. Table 4.2.13-2 lists the inventories after the event. The water level in the vessel was determined by the DP-B16P measurement to be [ ]"**' in. ([ ]"^ mm) above the hot-leg centerline at the end of the test. Table 4.2.13-3 provides a mass balance of all the primary side components before and after the test and shows that these masses agreed to within 0.4 percent. Note that the Quick Look Report (Reference 2, PXS-T2R-031), which incorporated a rough estimate of the steam generator secondary side mass, did not include the flow through the SGTR break line in the mass balance calculation. Therefore, a primary side only calculation, which includes the integrated SGTR break flow, lessens the amount of uncertainty in the mass balance a^d best assures the validity of pertinent test data. 1 maain ui6:5.uo:siowiwnms 4.2.13-12

t t i TABLE 4.2.131 g SEQUENCE OF EVENTS FOR TEST S01211 y Event Specified Instrument Channel Actual Time (sec.) Break Opens 0 Z_002B0 Pressurizer Low Level Pressurizer low L-010P level = 2.2 ft MSL IV Closure Pressurizer low Z_ANSO, F_ANS level + 2 sec. Z_BNSO, F_BNS MFW IV Closure Pressurizer low Z_B02SO, F_BOIS level + 2 sec. Z_A02SO, F_AOIS CMT IV Opening Pressurizer low Z_AN0EC, F-A40E level + 2 sec. Z_B040EC, F-B40E PRHR Heat Exchanger Pressurizer low Z_A81EC, F_A80EG Actuation level + 2 sec. Scram Pressurizer low g' level + 5.7 sec. Reactor Coolant Pumps Pressurizer low 1-AIP, S AIP Tripped level + 16.2 sec. 1-BIP, S BIP ADS 1 Pressurizer low level + 150 sec. Z_00lPC ADS-2 Pressurizer low level + 245 sec. Z_002PC Accumula' ors P-027P = 710 psia F_A20EG i F_B20EG e ADS-3 Pressurizer low level + 368 sec. t Z_003PC ADS-4 CMT Level = 3.9 fL L_B40E +60 sec. Z_0NPC, F-N0P IRWST Injection P-027P = 26 psia F_A60EG h F_B60EG m:\\ap6fkh ! 625 w\\l 625 w.10 non:1 b-o72605 4.2.13-13

D TABLE 4.2.13 2 'V WATER INVENTOMY BEFORE TEST S01211 i Volume Net Vol Temp Relative Component (ft.')/(0 (ft.')/(0 (*F) Density Mass (thm) ~*d ~ ' Loops 8.97 ft.' 8.97 ft.' 570 (254.0 0 (254.0 0 Pressurizer 337 ft.' l.97 ft.' 660 (95.4 0 (55.9 0 f Surge Line 034 ft.' O.34 ft.' 570 (9.6 0 (9.6 0 Tubular Downcomer 138 ft.' 138 ft.' 540 (39.1 0 (39.1 0 Annular Downcomer 0.54 ft.' O.54 ft.' 540 ) + High-Pressure (153 0 (153 0 Bypass i Core Bypass 0.44 ft ' O.44 ft.' 540 i (12.4 0 (12.4 0 Lower Plenum 0.81 ft.' O.81 ft.' 540 (22.8 0 (22.8 0 i Q Riser 1.64 ft.' l.64 ft.' 570 b (46.4 0 (46.4 0 Upper Fienum 1.46 ft.' l.46 ft.' 600 (413 0 (41.3 0 Upper Head 1.90 ft.' l.90 ft.' 520 (53.8 0 (53.8 0 i CMTs 10.1 ft.' 10.1 ft.' 80 i (286.0 0 (286.0 0 Accumulator 10.1 ft.' 7.88 ft.' 80 (286.0 0 (223.1 0 1RWST Injection Line 0.18 ft.' O.18 ft.' 80 (5.10 (5.10 TOTAL INVENTORY l O i myn1625.\\l625..to.non:Ib-072695 4.2.13-14 -Y

l . TABLE 4.2.13 3 WATER INVENTORY ALTER TEST S01211 WAS COMPLETED (7300 seconds) Water lesel as measured by DP B16P (-0.80 psi) was 24.4 in. (610 mm) above hot leg l Volume Net Vol Temp Relative Compiment (ft.')/(0 - (ft.')/(0 ('F) Density Mass (lhm) l Loops 8.97 ft.' l.48 ft.' ~ ~ (254.0 0 (42.0 0 Pressurizer 3.37 ft.' O.0 ft.' (95.4 0 (0.0 I) Surge Line 0.34 ft.' O.0 ft.' l (9.6 0 (0.00 Tubular Downcomer 1.38 ft.' l.38 ft.' f (39.1I) (39.1 0 Annular Downcomer & 0.54 ft.' O.52 ft.' High-Pressure Bypass (15.3 0 (14.7 l) Core Bypass 0.44 ft.' O.44 ft.' (12.4 0 (12.4 0 Lower Plenum 0.81 ft.' O.81 ft.' (22.8 0 (22.8 0 Riser 1.M ft.' l.M ft.' (46.4 l) (46.4 0 Upper Plenum 1.46 ft.' l.43 ft.' (41.3 0 (40.5 0 Upper Head 1.90 ft.' O.0 ft.' (53.8 0 (0.00 i CMTA 5.05 ft.' l.56 ft.' l (143.0 0 (44.2 0 CMTB 5.05 ft.' l.68 ft.' l (143.0 0 (47.6 0 Accumulator 10.1 ft.' O.0 ft.' (286.0 0 (0.0 0 IRWST Injection Line 0.18 ft.' O.18 ft.' (5.10 (5.10 TOTAL INVENTORY WATER LNJECTED FROM THE 1RWST DUEING EVENT IRWST Injection dP (psi) Area (in" Mass (thm) 4.25 1007.5 [ ] " ** 1 O maaruolo:5.\\io:5 ionon:itan:cas 4.2.13 15 9

<"s TAllLE 4.2.13-4 O M ASS IIALANCE FOR TEST S01211 Starting Inventory Ending Inventory (thm) (Ibm) Total Primary System iao IRWST Injection 1 Net Mass Through SGTR Break ADS-1, -2, -3 Catch Tank ADS-4/ Steam Generator Catch Tank TOTAL Ending Inventory / Starting Inventory (Ibm) Ending Inventory / Starting Inventory (%) O O m:sapem i o25.s t e25.. i o.non : i t>.07 w)5 4.2.13-16

i + s LF l -l l ) o 1 Figures 4.2.131 through 4.2.13-9 (pages 4.2.13-17 through 4.2.13-25). j contain proprietary information and are not provided. t l l -l 1 'i 0: ' I -J .i 1 Lo m:$1A1625-ins.aos:ItHD72795 REVISION: I a.,

E TEST S01211 PLOT PACKAGE .f~s. CHANNEL LIST BY COMPONENT ~7 (, COMPONENT CHANNEL UNITS PLOT COMMENT ACCA F_A20E lbm/sec.- 39 ACCA L_A20E ft. 34 ACCB F_B20E lbm/sec. 39 ACCB L_B20E ft. 34 ADS 1, 2, & 3 F_030P lbm/sec. 44 Flow rate derived ADS 1, 2. & 3 IF030P lbm 43 Catch tank ADS 4 & SG FJMOP lbm/sec. 44. Flow rate derived ADS 4 & SG IF040P lbm 43 Catch tank ANNDC DP-A021P psi 24 To cold leg-Al ANNDC DP-A022P psi 25 To cold leg-A2 ANNDC DP-B021P psi 26 To cold leg B1 ANNDC DP-B022P psi 27 To cold leg-B2 BPIAK LINE F_00$P lbm/sec. 44 Flow rate derived O BatixtiNE iF005e ibe 43 Ca<chtaek CLA DP-A00lP psi 24 To cold leg-Al CLA DP-A002P psi 25 To cold leg-A2 CLA DP-A09P psi 22 Pump suction CLA T-A10P

• F 11 Steam generator outlet CLAl F-A0lP lbm/sec.

36 CLA1 T-A021PL

• F 13 Downcomer inlet CLA1 T-AllP
• F i1 Pump outlet CLA2 F_A02P lbm/sec.

36 CLA2 T-A022PL

• F 13 Downcomer inlet

~ CLB DP-B00lP psi 26 To cold leg-B1 i i O m:\\agwe1625m\\l625w 10.non:th072ws 4.2.13-26

i TEST S01211 PLOT PACKAGE 1 h' CIIANNEL LIST BY COMPONENT (Cont.) COMPONENT CilANNEL UNITS PLOT COMMENT CLB DP-B002P psi 27 To cold leg-B2 2 CLB DP-B09P psi 23 Pump suction CLB T-BIOP F 12 Steam generator outlet CLBI F_Bol? lbm/sec. 36 CLBI T-B021PL F 14 Downcomer inlet CLB1 T-BilP F 12 Pump outlet CLB2 F-B02P lbm/sec. 36 CLB2 T_B022PL F 14 Downcomer inlet CMTA F_A40E lbm/sec. 38 CMTA L A40E ft. 33 CMTA T-A401E

• F 15 Top 242.25 in.

CMTA T-A403E 'F 15 216.75 in. CMTA T A405E 'F 15 191.25 in. 4 CMTA T-A407E F 15 165.75 in. g CMTA T-A409E

• F 15 140.25 in.

CMTA T-A411E

• F 15 114.75 in.

CMTA T-A413E F 15 89.25 in. CMTA T-A415E "F 15 63.75 in. i CMTA T-A417E "F 15 38.25 in. CMTA T A420E 'F 15 Bottom 0 in. CMTB F_B40E lbm/sec. 38 CMTB L_B40E ft. 33 CMTB T-B401E

• F 16 Top 242.25 in.

CMTB T-B403E F 16 216.75 in. CMTB T-B405E F l 16 191.25 in. CMTB T-B407E

• F 16 165.75 in.

CMTB T-B409E F 16 140.25 in. CMTB T-B411E F 16 114.75 in. CMTB T-B413E

• F 16 89.25 in.

CMTB T-B415E

• F 16 63.75 in.

CMTB T-B417E F 16 38.25 in. o m:WW5^th25w\\t625.1o non ib-07:695 4.2.13-27

TEST S01211 PLOT PACKAGE g \\J CHANNEL LIST BY COMPONENT (Cont.) COMPONENT CHANNEL UNITS PLOT COMMENT CMTB T-B420E

• F 16 Bottom 0 in.

CVCS F-001 A psi 42 DVIA T.A00E F 13 DVIB T-800E

• F 14 HLA DP-ANP psi 20 HLA T-A03PL
• F 5

Vertical, near power channel i HLA T-A03PO F 5 Horizontal, near power channel HLA T-ANP F 5 Near steam generator inlet HLB DP-B04P psi 21 i HLB T-B03PL F 6 Vertical, near power channel 4 HLB T-B03PO

• F 6

Horizontal, near power channel i HLB T-BNP

• F 6

Near steam generator inlet i IRWST F_A60E Ibm /sec. 40 F_A61E for S00303 IRWST F_B60E lbm/sec. 40 F_B61E for 500303 1RWST L_060E ft 32 1RWST T_061E

• F 17 Bottom IRWST T-062E

'F 17 Below middle IRWST T-063E 'F 17 Middle IRWST T-064E 'F 17 Above middle IRWST T-065E 'F 17 Top NRHRA F-A00E psi 42 NRHRB F-B00E psi 42 PC W 00P kW I PC-HB L_000P ft 30 Heater bundle PC-HR TW018P20 "F 3 Heater rod PC-HR TO018P48

• F 3

Heater rod i PC-HR TW019P82 "F 3 Heater rod PC-HR TWO20P24 'F 3 Heater rod PC-HR TWO20P61 'F 3 Heater rod PC HR TWO20P87 F 3 Heater rod PC-UH T-016P

• F 4

Upper head 1 m aapu n1625 wst 62% Io.non: I b-072695 4.2.13-28

i hI TEST S01211 PLOT PACKAGE CHANNEL LIST BY COMPONENT (Cont.) COMPONENT CHANNEL UNITS PLOT COMMENT PC-UP L_AISP ft. 30 Bottom of the upper plenum PC-UP L_A16P ft. 31 Top of the upper plenum i PC-UP T-015P

• F 4

Upper plenum l PC-UH L_017P ft. 31 Upper head PC UP L_A14P ft. 31 Above top of the active fuel PRHR DP-A81 AE psi 29 Supply line inverted U-tube PRHR DP-A81BE psi 29 Supply line inverted U-tube PRHR DP-A81E psi 28 Supply line PRHR DP-A82E psi 28 Heat exchanger PRHR DP-A83E psi 28 Return line PRHR F_A80E lbm/sec. 37 Return line PRHR T-A82E F 19 Inlet PRHR T A83E

• F 19 Exit g

PRZ L_010P ft. 32 PRZ P-027P psia 2 PRZ T-026P "F 18 487 in. SGA DP-A05P psi 20 Hot side SGA DP-A06P psi 20 Hot side SGA DP-A07P psi 22 Cold side SGA DP-A08P psi 22 Cold side SGA F_A0lS lbm/sec. 41 SGA F_A20S lbm/sec. 41 SGA L_A10S ft. 35 Overall level SGA P-A04S psia 2 Secondary system SGA T A0lS -

• F 10 MFW A SGA T-A05P

F 7 Hot side SGA T-A055 "F 9 Hot side - riser SGA T A06P "F 7 Hot side SGA T-A08P 'F 11 Cold side SGA TW-A06S 'F 7 Hot side SGB DP-B05P psi 21 Hot side maarwat625.il625 10 non:th-072835 4.2.13-29

L 'hf_. TEST S01211 PLOT PACKAGE CHANNEL LIST BY COMPONENT (Cont.) COMPONENT CHANNEL UNITS PLOT COMMENT SGB DP-B06P psi 21 Hot side SGB DP-B07P psi 23 Cold side SGB DP-B08P psi 23 Cold side SGB F_BOIS lbm/sec. 41 SGB F_B20S lbm/sec. 41 SGB L_ BIOS ft. 35 Overall level SGB P-B04S psia 2 Secondary system SGB T-BOIS

• F 10 MFW-B SGB -

T-B05P

• F 8

Hot side SGB T-BOSS 'F 9 Hot side - riser SGB T-B06P 'F 8 Hot side SGB T-B07P 'F 8 U-tube top SGB T-B08P "F 12 Cold side p) SGB TW-B06S "F 8 Hot side SL T-020P

• F 18 Surge line near pressurizer TDC DP-00lP psi 25 Top TDC DP-00lP psi 26 Top TDC DP-002P psi 24 Bottom TDC DP-002P psi 27 Bottom TDC DP-002P psi 26 Bottom TDC DP-002P psi 25 Bottom TDC T 00lPL

'F 13 Top TDC T-00lPL 'F 14 Top TDC T-003P 'F 13 Bottom TDC T-003P

• F 14 Bottom TSAT-PRZ "F

18 Based on P-027P UH TSAT "F 4 Based on P-017P -. mvn1625.s1625..s o non.Ib-07:605 4.2.13-30

f'W'%- U Section 4.2.13, Plots _I through 44 contain proprietary information and are not provided. i l l l 'nVU1625 int noo:I6072795 REVISION: j

4.2.14 Large Steam Line Break at liot Standby Conditions with Passive Safety Systems (') (S01512) v This matrix test simulated a large steam line break with the facility at 0 power hot standby conditions and only passive safety systems for mitigation of the accident. The purpose of this test was to demonstrate that the core makeup tanks (CMTs) would not drain and initiate the automatic depressurization system (ADS); therefore, cooldown of the primary system was maximized by having j no decay heat simulated, no heat loss compensation, and using three passive residual heat removal (PRHR) heat exchanger (liX) tubes. No pumped injection was provided by the chemical and volume control system (CVCS) and normal residual heat removal system (NRiiR). De startup feedwater j system (SFWS) was not operated for this test since it would have been isolated by low-low T-cold in the AP600 plant. The break was simuiated by opening the steam generator-A PORV. The check valves in the main steam lines were removed to permit flow from the intact steam generator to the faulted steam generator until the individual steam generator steam line isolation valves closed. The steam generator-A PORV line had an orifice installed with a diameter of [ ]**) in. that corresponds to a single-ended steam line break area of [ l^ ft.2 in the AP600 plant. Results are provided in the data plot package at the end of this section. He sequence of events for S01512 is listed in Table 4.2.14-1. Bere was no CMT draindown throughout the transient and O therefore no ^DS act etion or iRwST in;ection. ne feciiity Pre sure remained efficientix hi h to 8 prevent any accumulator injection until [ l('*" seconds into the transient. i Two event phases, selected for the purpose of detailed evaluation of this test, are shown in Figure 4.2.14-1, and are as follows: Initial depressurization phase (IDP)-Point I to 2 Pressure decay phase (PDP)-Point 2 to 3 = Overall Test Observations Figure 4.2.14-1 shows the facility primary system pressure during matrix test S01512 (as measured at the top of the pressurizer) with selected component actuations and plant responses shown in relation to the primary system pressure. De IDP started with the opening of the break valve (steam generator-A PORV). All power to the heated rods and pressurizer heaters was stopped immediately at break opening. De safety system actuation (S) signal was actuated I second after the break opening signal. When the S signal was activated, the CMT and PRHR isolation valves were opened with a two-second delay, the steam generator-A and -B steam line isolation valves were closed with a [ l**'-second delay, and the RCPs were shutdown with a [ l**'-second delay. The opening of the break valve resulted in a rapid depressurization and level decrease in both steam generators until the individual steam generator steam isolation valves closed at about 10 seconds. m Aap6mM 625 esec 4\\ l 625 w.12.non: l b-072695 4.2.14-1

Steam blowdown from steam generator-A continued until the water inventory in steam generator-A flashed and boiled away. De large amount of heat removed from the primary system by the steam g generators (primarily the faulted steam generator-A), combined with PRHR HX and recirculating CMTs, resulted in a rapid initial cooldown, water shrinkage, and depressurization of the primary system. He rate of primary system depressurization began to decrease as the steam generator-A secondary side inventory decreased. This depressurization rate decrease was apparentiy due to a decrease in the heat transfer (decrease in the tube surface area covered with water) to steam generator-A. The primary system depressurization rate then increased when the pressurizer was completely drained. After steam generator-A had boiled dry at [ ]"** seconds, the primary system continued to depressurize toward the pressure / temperature of the intact steam generator-B. Primary system flow through the faulted steam generator-A stopped at [ l*" seconds when the steam generator-A dried out. Flow continued through steam generator-B only until approximately [ l**' mod a which time the steam generator-B U-tubes began to drain. Also at this time, the rate of the primary-side pressure decrease slowed, since primary-side pressure was controlled and matched the steam generator-B saturation pressure corresponding to the steam generator-B secondary temperature of [ l*"*F. His ended the IDP. The PDP for this test began at [ ]"*" seconds and ended at approximately [ ]"*" seconds, when the test terminated. This steam line break event was characterized by a slow, continuous decrease in h the primary system pressure in conjunction with the intact steam generator-B secondary-side pressure / temperature. He primary system pressure was maintained by continued voiding in the steam generator-B U-tubes, and liy tne expanding steam bubble in the power channel upper head. As shown in data plots 21,23. and 31, the u[.ner-head water level decreased slowly from approximately [ ]"*" ft. to [ ]"*" ft., and steam enerator-B U-tubes were approximately [ l6 percent drained at approximately i ]"*" seconds, at which time the test was terminated. The power channel temperatures (with the exception of the uppei lead) decreased continuously during tids test. Data plot 4 depicts the power channel inlet and outlet water temperature:, which decreased from approximately [ ' '*" F to ( l**'*F, and approxii.rtely l ]"*"*F to [ ] 6 E myd 4 during th: PDP Re primary system cooldown was due to heat removal by the PRHR HX, heat removal resulting from energy stored in the CMTs during their recirculation mode of operation and facility heat losses. Heat transfer to and from the steam generators was lirnited because there was no secondary water in steam generator-A, and steam generator-B U-tubes were voided. There was, therefore, essentially no primary system flow through either steam generator. He primary system water inventory, with the exception of the upper head, remained subcooled throughout the test. The pressurizer, which emptied at approximately [ l*" seconds, began to refill at approximately [ ]"^" seconds. Therefore, at this time the volume addition due to CMT recirculation, and upper head and steam generator U-tube voiding was comparable to the primary water shrinkage (density -E increase) due to the temperature decrease. Pressurizer level had increased to approximately [ l"'*" ft. when the test was terminated. Part of tids increase (approximately [ ]"*" ft.) was due l m%ptm1625m\\sec4\\l625* 12 aon:1b-072695 4.2.14-2

3 ' ',k>'c 4 \\ l .i 1 ., 1 l JJ a. \\ l i Section 4.2.10, Mots I through 44 'contain proprietary information and are not provided. .1 T. 2 1. LO 1 i 4 1 4 m:\\apNXA1625-ins non:1bO72795 ' REVISION: 1 ..x,,,,, ..__.c..._;_.__,

[ f**" seconds, indicating apparent void fractions in the bundle from [ ]"* to [ l*" percent with a period of approximately [ J*" seconds. The collapsed level measured h just above the heated portion of the rod bundle (above TAF, data plot 31), provided an indication of the steam fraction of the fluid leaving the rod bundle ([ l*" to [ l'*6 p e m W m m fraction variations are temporarily reduced at approximately [ ]^" seconds due to draining of the steam generator-B tubes. Pressurizer Be pressurizer began to drain when the break occurred and was completely drained in approximately [ l*" seconds (data plot 32). De pressurizer internal heater remained on at about [ l*" kw until the pressurizer level reached ~ [ ]"** ft. at approximately [ ]**" seconds. The water in the pressurizer flashed due to the loss of system pressure, and the temperature of the water dropped from [ ]"**)*F during this initial depressurization (data plot 18). De hot water leaving the pressurizer surge line into hot leg-A caused a slight increase in the hot-leg temperature during this period, since it mixed with the flow from the power channel upper plenum. He pressurizer remained drained until [ ]"*" seconds, at which time it began to refill in response to draining of the upper-upper plenum and upper head. The pressurizer was completely filled to [ ]"*" ft. at [ }"*" seconds and remained filled for the rest of the test. Steam Generator = O Because of the break, fluid was lost from the primary system to the secondary side of steam generator-B. The steam generators acted as the heat sink until the MSLIV closed and prevented further energy removal from the secondary side. This caused the temperature of the secondary side to increase until [ ]"*" seconds toward the primary system hot-leg temperature, which at the same time was dropping due to the reduced power / flow ratio. When the RCPs had coasted down, a temporary temperature increase occurred on the steam generator's primary sid-due to the increased power / flow ratio at the natural circulation flow condition. The temperature then stabilized at approximately [ ]"*"*F at the end of the IDP. The secondary-side B temperature was lower than that on secondary-side A. Both secondary-side temperatures decreased after [ l*" seconds to approximately [ }"*"*F at the end of the test. The water level in steam generator-A was almost unchanged, while on side B it had increased by [ 1"*" ft. at the end of test due to the break flow into steam generator-B (Figures 4.2.12-4 and 4.2.12-5). This level began to oscillate after [ ]"*" seconds following pressure oscillations on the primary side (data plot 35). For the IDP and the first part of the PDP (until [ ]"*" seconds), the pressure in the primary system was higher than the steam generator secondary side pressure (data plot 2). His indicated that some heat transfer (in addition to break flow) was occurring from the primary to secondary side of the steam generators. O mwwoi625 \\is25.-7.non ib-07:795 4.2,12-7 REVISION: 1

At approximately [3000]'*b seconds, flow oscillations began to occur in the tubular downcomer. h As the same time, oscillations occurred in the collapsed liquid level measured in the bundle, which indicated there were oscillations of the steam fraction of the two-phase liquid flowing through the rod bundle into the hot legs and to the steam generators (data plots 20 and 21). Thus the driving forces for the natural circulation flow, the density difference between the single-phase fluid in the cold legs and downcomer to the power channel and the two-phase mixture leaving the rod bundle and filling the hot legs, were oscillating. The two-phase mixture entering the steam generators left the steam generators as water. Some of the steam was condensed in the U-tubes, and the rest of the steam was separated from the two-phase mixture in the high point of the steam generator-B U-tubes (due to the low flow velocity). This resulted in oscillating steam fractions in the upper part of the U-tubes of both steam generators. Since the fluid steam fraction in the hot leg-B was higher (steam from two-phase mixture was selectively drawn into the PRHR supply line from hot leg-A) the steam generator-B U-tubes were filled with steam and drained. From [ l*" seconds until [ l*" seconds, intermittent flow was observed through steam generator-B. At [ J^" seconds, the flow through steam generator-B stopped, and the U-tubes cold-leg side were drained at [ l*" seconds, and the U-tubes hot-leg side were drained at [ l^" seconds. After this time, water level oscillations occurred in the RCP-B suction piping (data plots 21 and 23). %) Also at [ ]*" seconds until the end of the test, significant temperature oscillations were observed in both cold legs-A and -B from the RCP suction piping into the annular downcomer. Ilot Legs = Hot legs-A and -B contained single-phase water (data plots 20 and 21) until [ ]*" seconds. Starting at [ l*" seconds, the steam fraction of the fluid in the hot legs began to oscillate with the same frequency as in the power channel. The PRHR preferentially removed steam from the two-phase mixture in the hot leg-A, which reduced the steam fraction of fluid in hot leg-A to [J**)to[ J*" percent. The steam fraction in hot leg-B was similar to that in the lower-upper j plenum and varied between [ ]** and [ l*" percent. Cold Legs = 'Ihe cold legs contained subcooled water throughout the test (data plots 22 through 27). After [ l'*" seconds, the flow in the cold legs oscillated (greater amplitude was seen in cold leg-A because of oscillating flow in the PRHR return line). In addition, the temperature in both cold legs also oscillated. Oo mMp6(XA1625 w\\l 625 w -7.non: l two72895 4.2.12-8

l 4.2.13 Steam Generator Tube Rupture with Inadvertent Automatic Depressurization System Actuation (S01211) g This matrix test simulated a double-ended rupture of a single steam generator tube followed shortly by inadvertent automatic depressurization system (ADS) actuation. This test was performed without any nonsafety systems operating. The chemical and volume control system (CVCS), normal residual heat ] removal system (NRHR), and startup feedwater system (SFWS) were shut-off for this test. The single j steam generator tube rupture (SGTR) was simulated via a line connected from the primary side (coolant pump B suction piping) to the secondary side of steam generator-B (3.94 ft. above the tube sheeO, with a break orifice diameter scaled to simulate [ ]"** times the area of a single AP600 steam generator tube; in order to obtain the same flow as a double-ended break of a single AP600 steam generator tube. The ADS-1 flow path was opened 2.5 minutes after the reactor trip (R) and the safety systems actuation (S) signals were generated. Results are provided in the data plot package at the end of this section. The sequence of events for S01211 is provided in Table 4.2.13-1. Because this event became a loss-of-coolant accident (LOCA) after ADS-1 actuation, primary system pressure phases similar to LOCA tests were selected for detailed evaluation of this test. These phases are shown in Figure 4.2.13-1 and are as follows: Initial depressurization phase (IDP)-Point I to 2 h Automatic depressurization system (ADS) phase-Point 2 to 3 Post-automatic depressurization system (post-ADS) phase-Point 3 to 4 Overall Test Observations Figure 4.2.13-2 shows facility primary system pressure versus time during matrix test S01211 (as measured at the tcp of the pressurizer), with selected component actuations and plant responses shown in relation to primary system pressure. The IDP began with the opening of the SGTR break valve at time O seconds and ended at 626 seconds when ADS-1 was actuated. When the break valve was opened, the primary system fluid flow to the secondary side of steam generator-B resulted in a decrease in pressurizer level and pressure. The pressurizer level decreased to [ ]"*" ft. at [ ]"*" seconds, simultaneously actuating both the R and the S signals. The steam generator main steamline isolation valves (MSLIVs) closed. The core makeup tank (CMT) injection line isolation and passive residual heat removal (PRHR) heat exchanger (HX) return line isolation valves opened after a [ 1"*"-second delay. The heater rod power step changed from 100 percent to 20 percent power after a 5.7-second delay. The reactor coolant pumps (RCPs) were shut off after a 16.2-second delay. Flow through the PRHR HX and CMTs began immediately, when their isolation valves opened. Rod bundle power remained at 20 percent through 14.5 seconds after the R signal. At this time, the SPES-2 integrated heater rod power into the primary hI system matched the scaled AP600 core power decay. The SPES-2 heater rod power remained at 20 m.\\qwul62$w\\l625w.10 non 11,-072695 4.2.13-1

percent until 2: 14.5 seconds after the R signal and then began to decrease, simulating the scaled ) AP600 core decay heat but maintaining an additional 150 kW to compensate for the SPES-2 facility heat losses. This heat loss compensation was shutoff when ADS-2 was actuated later in the transient. The pressurizer level rapidly decreased to [ J**' ft. when the R and the S signals occurred due to rapid cooldown and sluinkage of the power channel hot-leg side water prior to RCP shutoff. De pressurizer pressure decreased rapidly from approximately [ ]**' psia to ! l** psia as a result of this momentary cooldown. Pressure increased slightly after the RCPs were shutoff as the hot-leg side fluid temperature increased, and then rapidly decreased toward the power channel hot-leg side fluid saturation pressure. There was little or no boiling in the power channel throughout the IDP. After the RCPs coasted down, some heat transfer from the primary to secondary side occurred since primary system pressure was higher than the secondary-side pressure until approximately [ ]** seconds. The ADS phase began with the actuation of ADS-1 at [ ]**' seconds (approximately [ ]('** seconds after the R and the S signals). ADS-2 and -3 occurred at [ l** and [ ]('** seconds. The heat loss compensation was removed from the decay heat simulation when ADS-2 opened, reducing the rod bundle power to approximately 150 kW. The ADS actuation increased the rate of primary system depressurization and resulted in a high h, injection flow from the accumulators beginning at approximately [ ]('^* seconds. The CMTs transitioned from recirculation mode to draindown mode of injection when the B-loop cold legs had partially emptied from [ l** seconds. After ADS actuation, the primary system pressure rapidly decreased to the saturation pressure of the upper-upper plenum at approximately [ l*" seconds and it quickly drained. At approximately [ l*" seconds, the primary pressure decreased to the saturation pressure of the upper head and it began to drain, soon after ADS-2 was opened. It was completely drained at [ ]('6 seconds. After that time until the end of the test, the upper head was filled with superheated steam. De rapid depressurization also resulted in an increased rod bundle steam fraction and an increased steam fraction in the upper plenum and the hot legs. The hot legs contained two-phase mixture, and the hot leg-B flow had a steam fraction very close to that shown in the upper plenum. De steam fraction in hot leg-A was lower due to the selective removal of steam into the PRHR HX inlet line. De two-phase flow in the hot legs resulted in draining of the steam generator U-tubes at approximately [ l*" seconds into the event as steam collected in the top of the U-tubes. This stopped the primary system flow through the steam generators, and the power channel flow was predominantly composed of the flow through the PRHR and the accumulator and CMT injection flows. The rapid injection of cold fluid from the accumulators ([ l*" seconds) cooled the primary system, temporarily refilling the annular downcomer, power channel, and lower-upper plenum. When m:wto25.u625.10.non:1b-072695 4.2.13-2

e,-,-. the accumulator discharge ended, the flow through the rod bundle decreased to the injection flow of the CMTs. We PRHR HX flow decreased and stopped soon after the accumulator injection ended. h Boiling increased in the heater bundle and two-phase flow again occurred in hot leg-A. The liquid discharge through the break reversed after ADS was actuated and primary-side pressure was -l less than secondary-side pressure after approximately [ ]*" seconds. Flow from the faulted steam generator-B into the primary system continued throughout this phase, averaging approximately [ l*"lbm/sec. Injection flow from the passive safety system components always exceeded this reverse flow throughout this phase. Re post-ADS period began when ADS-4 actuated. ADS-4 occurred at [ ]*" seconds, and the pressurizer pressure fell from approximately [ l*" psia, reaching approximately [ ]*" psia at approximately [ ]*" seconds. He fluid discharge through ADS-1, -2, and -3 ended, and fluid was now discharged through ADS-4. The pressurizer drained very rapidly beginning at [ ](**" seconds, and shortly thereafter, the CMT flow ended. The flow from the in-containment refueling water storage tank (IRWST) refilled the primary system with subcooled water, ended boiling in the rod bundle, and partially refilled the upper-upper plenum. A steady flow of subcooled water then flowed from the IRWST into the downcomer, through the power channel, and left the primary system through ADS-4. Flow continued from the faulted steam generator-B into the primary system throughout this phase. He secondary to primary flow slowly decreased to approximately [ ]*" Ibm /sec. as steam generator-B pressure decreased. This reverse flow caused steam generator-B level to continuously decrease until the level fell to the break elevation at approximately [ ]*" seconds. l This test demonstrated that the rod bundle was fully covered (single-phase or two-phase fluid) at all times during this test (data plots 30 and 31). There was no indication of an increase in heater rod l ' temperatures due to lack of cooling (data plot 3). The secondary to primary flow from the faulted l steam generator-B did not appear to affect the ability to depressurize the primary system and obtain IRWST injection. Also, the flow rate from the steam generator was always smaller than the CMT, accumulator, or IRWST injection flow. Key parameters comparing the S01211 test are listed in - Table 5.1-1 in Section 5.0. l Discussion of Test Transient Phases Initial Depressurization Phase ([ l*" Seconds) The initial depressurization phase (IDP) began with the initiation of the break (at time 0) and continued until ADS-1. This period included the following events: shutoff of pressurizer internal and external heaters at time 0, and R and S signal actuation at [ l*" seconds (the MSLIV closed, the main feedwater isolation valve (MFWIV) closed, the CMT injection line valve opened, and the PRHR HX return line isolation valve opened-all with a 2-second delay; power decrease m:\\apsom1625.u6:5..to.noa:isone95 4.2.13-3

to 20 percent initiated with a 5.7-second delay; power decay initiated after a 14.5 second delay; (oj and RCP coastdown inidated after a 16.2-second delay). See Table 4.2.13-1. Facility Response during the IDP: From time 0 until the R signal occurred (at [ l**' seconds), the primary system pressure and pressurizer level decreased due to the fluid loss through the break. He pressurizer partially compensated for the loss of pressure by flashing until [ ]**) seconds (data plot 32). When the R and the S signals occurred, the MSLIV was closed, and the rod bundle power was reduced to 20 percent of full power after 5.7 seconds and began to decay after 14.5 seconds. As a result of the power reduction without flow reduction (RCPs still operating), the core AT decreased due to the lower power to flow ratio, and the lower-upper plenum temperature decreased temporarily toward the rod bundle inlet temperature. System pressure decreased to a pressure of [ ]'***' psia at [ l**' seconds (Figure 4.2.13-2). The pressurizer at this time was nearly drained, and system pressure was controlled by the temperature of the saturated fluid in the surge line. When the RCPs were shut off (at [ J* seconds), the rod bundle and the lower-upper plenum temperatures increased to [ J**F due to the increased power / flow ratio at the lower flow. System pressure increased temporarily to [ ]**' psia and then resumed decreasing as rod bundle power decreased and the lower-plenum temperature (due to CMT injecting cold fluid into the downcomer PRHR flow into the cold legs and steam generator cooling) began to reduce the lower-upper plenum temperature. The pressure decay rate was [ J^ psia /sec. in this period V ( ]**' seconds). The CMT PRHR HX and steam generator heat removal were sufficient to subcool the power channel during this time period. The PRHR flow began before the RCPs were shut off and then continued by natural circulation (data plot 37). He primary system pressure decreased to approximately [ ]**' psia at the end of the IDP ([ l**) seconds). The SGTR flow from the primary to the secondary side of steam generator-B was initially approximately [ l'***'lbm/sec. and decreased slightly during the IDP to [ ]**' lbm/sec. prior to ADS actuation. Automatic Depressurization System Phase ([ l" Seconds to [ ]M Seconds) = De automatic depressurization system (ADS) phase began with the actuation of ADS-1 and ended with the actuation of ADS-4 (Figure 4.2.13-1). Facility Response during the ADS Phase: With the actuation of ADS-1, the primary system was rapidly depressurized at the rate of [ l**' psi /sec. at the start of the ADS phase. This rate gradually decreased as system pressure decreased. The hot-leg / upper-plenum temperature ([ l**F) controlled the primary system pressure at about [ ]* psia for a short time starting from about [ ](***' seconds until ADS-2 bq actuation at [ l*" seconds. The pressurizer began to refill shortly after ADS-1 occurred, reaching approximately [ l**' ft. collapsed level (data plot 32). The pressurizer level fell rapidly m:\\aptchl625w\\l625w to non:Ibon695 4.2.13-4

to [ l*" ft. collapsed level at about [ l^" seconds, rose to about [ l*" ft. during accumulator injection, and then decreased to approximately [ ]"#*' ft. at [ l*" seconds. This g level response reflected the steam fraction of the flow exiting the rod bundle during the ADS phase (data plots 30,31, and 32). He two-phase mixture entering the steam generators tubes left the steam generators as saturated water. Some of the steam was condensed in the U-tubes (the primary-side pressure was higher than the secondary-side pressure until [ ]"*" seconds, allowing some heat to be transferred to the secondary-side fluid). The remaining steam was separated from the two-phase mixture in the high point of the U-tubes (due to the low velocity) and eventually caused the U-tubes to begin to drain. Flow through the steam generators continued until about [ l**' seconds into the transient. A free-water surface appeared at the top of the U-tubes at approximately [ 1"^* seconds. After ADS-2 actuation, the primary system depressurization rate was approximately [ ]6" psi /sec. When ADS-3 was actuated at [ ]*" seconds, the primary system depressurized at a rate of approximately [ ]"**' psi /sec. He principal system response staning after ADS-2 actuation was a high rate of water injection from accumulators-A and -B (data plot 39) and the transition to draindown mode of the CMTs (data plot 33). He accumulators injected cold water into the primary system for approximately [ l*" seconds (from [ ]"^" seconds to [ ](***) wmd) W wm kn hxd W accumulator injection refilled the rod bundle and the lower-upper plenum and annular downcomer (data plots 25 through 27 and 30 through 32). It partly suppressed the CMTs' injection. h initially the CMTs operated in their natural circulation mode; hot liquid flowed from cold legs-B1 and D2 through the cold-leg balance lines (CLBLs) into the top of the CMTs; and cold water flowed from the bottom of the CMTs to the downcomer via the DVI nozzles. The net CMT injection into the primary system during this recirculation mode of operation was small; i.e., [ ]"^" lbm/sec. per CMT recirculation rate provided approximately [ ]"*" Ibm /sec. per CMT net mass to the primary system. At approximately [ 1"*" seconds, the cold legs flashed and drained (see annular downcomer DP, data plots 24 through 27), causing the CMTs to transition to their draindown mode of operation. The CMT net injection flow increased from [ ]*" lbm/sec. to [ ]"*"lbm/sec. per CMT (data plot 33). At the same time, the accumulators began to inject. De CMT injection and accumulator injection (approximately [ l*" lbm/sec. average per accumulator from [ ]*" seconds until [ ]"*" seconds) provided sufficient water to restore the power channel liquid inventory, i From [ ]"*" seconds to [ ]"** seconds (until ADS-4 actuation), only the CMTs provided injection, with CMT injection flow decreasing from [ ]"A*' lbm/sec. to [ ]"*" lbm/sec. per CMT due to their continuing drop in level and, therefore, gravity driving head. Power channel water inventories decreased during this period with the rod bundle region steam fraction reaching approximately [ ]"" percent at the time of ADS-4 actuation (data plot 30). mvuis:5.us:5.. ion uson695 4.2.13-5

s us i y to water addition from the accumulators.that began to inject' beginning at [ l*" seconds. M f iThroughout the test the CMTs did not draindown but maintained operation in their recirculation mode-M - of operation. Therefore, during the steam line break recovery the primary loop cold. leg piping remained water filled,'so the CMTs remained water filled and no ADS actuation was required. . Discussion of Test Transient Phases

Initial Depressurization Phase ([ ]"#' to [-

- ]*d' Seconds) = .A The initial depressurization phase (IDP) began with the initiation of the steam line break at time 0 and lasted until the primary system pressure was supported by the saturation pressure for the fluid in the upper part of the steam generator-B U-tubes (Figure 4.2.14-2).. The IDP included the'-

following events: termination of the all heated rod power and pressurizer internal heater power; j

i and actuation of the S signal [. J*#'second after the break opening, which opened CMT injection line valves and PRHR HX return line isolation valve (all at [ l*d) seconds), closed the MSLIVs (at [ ]('*') seconds), and initiated coastdown of the RCPs at [. ]**) seconds (Table 4.2.14-1). -i Facility Response during 'the IDP: When the steam generator-A PORV opened, there was a rapid drop in pressure and secondary-side water temperature (data plot 2 and Figure 4.2.14-2) in both steam generators, resulting in a rapid 'l drop in primary system fluid temperature. Because the steam generator-B steam line was isolated from the break at [. J*" secands, the steam generator-B pressure / temperature decrease was limited and the steam generator D r.econdary-side pressure / temperature were rapidly restored to match the primary side temperature. The rapid drop in primary, system water temperature resulted in a rapid water density increase (shrinkage), which caused a rapid drop in the pressurizer level - (expansion of the pressurizer steam bubble), thereby causing a rapid drop in the pressurizer pressure ([ ]*#' psi /sec.). When the RCPs shut-off at [ '](***' seconds, the primary system depressuliction rate decreased to approximately [ l**) psi /sec. due to reduced heat transfer to. the faulted steam generator-A as the primary flow decreased. As the steam generator-A water inventory continued to decrease due to flashing and boiling, the wetted heat transfer area on the secondary side of the U-tubes decreased, decreasing the rate of primary system heat removal. which resulted in a decrease in primary system water shrinkage rate, decreased rate of pressurizer steam expansion, and a decreasing rate of depressurization. At approximately [- ]*#) seconds, steam generator-A had completely depressurized and was essentially dried out. The pressurizer had also completely drained and the pressurizer steam bubble was vented into hot leg-A, which increased the rate of primary system depressurization to [ ']*" psi /sec. The primary system . continued to depressurize to approximately [ El(**" psia at approximately [ ]**) seconds, at which time the primary side pressure matched the steam generator-B secondary side saturation pressure. ~O The overall primary-side temperature was reduced rapidly during the IDP, as shown by the heater rod temperatures (data plot 3). During the first [ l** seconds (prior to RCP shut-off) mAalWXhl625wkec4\\t625w 12.non:Ib 072695 ~4.2.14-3

temperatures throughout the primary system dropped due to the large heat transfer to both steam generators during the first [ ]**' seconds, and to steam generator-A only aftar the steam isolation h, valves closed. After [ l^*' seconds, steam generator-B became a source of heat input to the primary system, maintaining the primary side steam generator-B outlet temperature (data plot 12) even though the hot leg temperature was decreasing. His resulted in a decrease of natural circulation flow driving head through loop B. since the highest loop temperatures were in the l steam generator-B. From [ ]**' seconds to approximately [ l**' seconds when steam generator-A had dried out, steam generator-A continued to remove heat. In addition, the CMTs and PRHR recirculation flows, which began approximately [ ]**' seconds after the S signal, removed heat from the primary system with cold water entering the downcomer via the DVI nozzles, and the PRHR HX return water returning via the A loop cold leg (s). This was reflected in data plots 13 and 14 where cold legs-Al and -A2 and the downcomer decreased in temperature to approximately [ j**'*F at approximately [ ]*" seconds, while cold legs-B1 and -B2 temperatures decreased to only approximately [ l**'*F at [ ]**' seconds. At [ l**' seconds, the cold legs-Al and -A2 showed a rise in temperature from approximately [ ]** to [ ]('A')*F, possibly due to reduced steam generator-A heat removal (hot leg-A steam generator inlet temperature was approximately [ l***F at [ ]* seconds (data plot 5). Data plot 14 shows that the primary-side flow through the intact steam generator-B stopped or reversed prior to [ ]*" seconds, as the temperatures of cold legs-B1 and -B2 dropped from [ l**'*F m apodm-ah[ J* *F M [ ]^ seconds. Following diis, the steam generator-B outlet temperature (data plot 12) decreased independently of the temperature in the steam generator tubes, and the steam generator-B inlet temperature (data plot 6) remained in agreement with the secondary side temperature. He PRHR and CMT flows are shown in data plots 37 and 38. De PRHR flow was initially high until the RCPs stopped. After this, PRHR flow was driven by natural circulation and was about approximately [ J^"lbm/sec. after the RCPs had coasted down and decreased gradually to approximately [ ]**' lbm/sec. at the end of the IDP. Similarly, CMT recirculation flow was high (approximately [ ]** lbm/sec. per CMT) until the RCPs stopped. De CMT flow then decreased to the expected natural circulation flow approximately [ l*" Ibm /sec. per CMT. The CMT recirculation flows gradually decreased as the buoyancy head decreased as the CMTs heated up and temperatures in cold legs-B1 and -B2 decreased, with CMT-A and B flows approximately [ l*" and [ ]*" lbm/sec. respectively, at [ ]*" seconds. CMT recirculation flows equalized later in the transient. De IDP ended at approximately [ ]*" seconds, when the primary system pressure had fallen to approximately [ ]*" psia, the saturation pressure of the intact steam generator-B (approxir.;ately [ l**'*F), and flow through the intact steam generator-B stopped (Figure 4.2.14-2). -E 1 I l i m TapNU 1625 w\\sec4\\l 62$ w. I 2. con: I b-072695 4.2. I4-4

F Pressure Decay Phase ([ ]** Seconds to End of Test) p. i l V The pressure decay phase (PDP) began when voiding in the intact steam generator-B U-tubes occurred, causing the primary side system pressure to be controlled at the saturation pressure corresponding to the temperature of primary fluid in the upper portion of the intact steam generator-B U-tubes, which was controlled by the steam generator-B secondary-side temperature / pressure. This phase of the test was characterized by a slowly decreasing primary system pressure in concert with the steam generator secondary side. The primary system decreased in temperature as dictated by the continued heat removal by the PRHR, the recirculating CMTs, and system heat losses versus the heat capacity of the primary system. As in the IDP, there was no boiling or flashing in the primary system, with the exception of the primary fluid in the intact steam generator-B U-tubes and in the power channel upper head. It should be noted that in this test there was no power to the heated rods. Beginning at approximately [ ]('*" seconds, the level in the pressurizer was restored by the continued addition of mass to the primary system, which was provided by CMT recirculation in combination with the drained volume of the steam generator-B U-tubes and power channel upper head. A small amount of accumulator injection began at approximately [ ]*# seconds, as system pressure (steam generator-B pressure) finally decreased to approximately [ j** psia, further increasing the pressurizer level to approximately [ ]('** ft., at which time the test was terminated ([ ]** seconds). Facility Response during the PDP: The primary system and intact steam generator-B pressure decay throughout this phase was approximately [ l*" psi /sec., and, as pointed out above, was controlled by the intact steam generator-B secondary-side pressure / temperature. 'Ihis was accomplished by voiding in the top of the U-tubes forming a steam bubble that was maintained at secondary side temperature / pressure. Data plots 21 and 23 show that the steam generator-B U-tubes began to drain at approximately [ l*" seconds, and that the U-tubes drained (steam bubble increases in volume) smoothly until the end-of-test. At approximately [ ]** seconds, the power channel upper-head began to drain when primary pressure decreased to approximately [ l** psia, the saturation pressure corresponding to the upper head water temperature of approximately [ lb"*F, as shown in data plot 31. The power channel rod bundle, lower upper plenum, and upper-upper plenum remained water-filled throughout the test (data plots 30 and 31). The primary system temperature, with the exception of the power channel upper head and portions affected by steam generator-B, decreased rapidly throughout the PDP phase; for example, data plot 4 shows the tubular downcomer (core inlet) temperature decreased from approximately [ l*" F to approximately [ l*" F and the lower-upper plenum temperature decreased from approximately [ l*" F to approximately [ l*" F from [ l*" seconds to mAap60iA1625w\\sec4\\l625w 12 noa:lb-072695 4.2.14-5

? { [' l*"' seconds, respectively. Similarly, data plots 5 and 6 show that temperatures in both hot j legs agreed with the power channel lower-upper plenum temperature throughout the PDP. Data plots 5,6,13 and 14 show that the hot legs and cold legs were cooled to approximately [ y.2.*F from [ T'***F at [ f'* seconds. Cold legs-Al and -A2 temperatures do not l agree after [ 1"**' seconds as explained below. { As discussed previously, the overall temperature decrease of the primary system was a result of j PRHR HX heat removal, heat removal due to CMT natural circulation flow, and primary system heat losses, versus the heat capacity of the primary system components. Figures 4.2.14-3 and [ 4.2.14-4 show the PRHR HX heat removal and the heat removal due to CMT natural circulation versus time throughout the event. Shortly after [ f***' seconds, the steam generator-A U-tube l temperatures remained constant throughout the rest of the test and did not contribute to primary system heat losses. Similarly, the steam generator-B had little effect on overall primary system heat loss since its small temperature decrease was only reflected in the temperature of U-tube water that entered the cold legs-B1 and -B2 as the tubes voided (drained). The CMT recirculation flow to the top of the CMTs from cold leg-B1 and -B2 had to come via backflow in the loop-B l cold legs from the annular downcomer, since there was no flow through steam generator-B and f since the voiding of the U-tubes occurred at a very slow rate. At [ f'*#' seconds into the event, there was a change in the loop-A flow pattern. Data plots 5,7, and 11 show that after [ f***' seconds, and up until approximately [ f'*#' seconds, the faulted steam generator-A gl ~ inlet / hot side and outlet / cold side primary fluid temperatures were very similar. This, along with l the fact that these steam generator-A temperature was higher than the loop-A hot-leg and cold-leg temperatures, would indicate that natural circulation flow through steam' generator-A was small and 4 decreasing to [ f'##'.. This was confirmed by Figure 4.2.14-5, which shows the differential pressure across the cold leg-Al and -A2 flow venturis. At approximately [ ' f**#) seconds, the { measured differential pressure in cold leg-Al increased significantly while the cold leg-A2 differential pressure decreased, indicating that cold leg-A2 reversed flow while cold leg-Al 7' forward flow increased. This was confirmed by Figure 4.2.14-6, which shows that the cold leg-A2 temperature changed suddenly at this time to match the cold leg B1 and -B2 temperatures (which - were already in a reverse flow condition). The cold leg Al temperature remained lower than the other cold legs due to the cold PRHR HX return flow. At the time of the cold leg-Al and -A2 l flow pattern change at appr0ximately [ f**#' seconds, the flow rate through the PRHR HX j began to exceed the combined natural recirculation flow rates through the CMTs (Figure 4.2.14-7). Also, the PRHR HX and CMT circulation flows were slightly affected by the shift in the primary system flow pattern (Figure 4.2.14-8 and data plot 38). It was evident that with essentially no primary k>op flow through or heat transfer to the steam generators; the primary system loop flows-are dictated by the PRHR HX, CMT, and power channel natural circulation patterns. I e:l ] 2 maap6004625wbec4\\l625w 12.non lb-072695 4.2.14-6 r

l \\ p i l. Component Respamses i Power Channel I. i The SPES-2 power channel consists of five volumes: the lower plenum, the heated rod bundle, L the lower-upper plenum (below the hot leg), upper-upper plenum (above the hot leg), and the upper head. When the steam line break (SLB) was initiated, all power to the heated rods and to the pressurizer heater was shutoff. Since there was no decay heat and since an SLB is a large cooldown event, and since both the PRHR HX and CMT natural circulation flow remove heat, the power channel, with the exception of the upper head,' remained subcooled during the test. The upper head began to drain after [ ]*# seconds when the primary system pressure reached the saturation pressure for the fluid temperature in the upper head, and flashing started in the upper head (data plot 4). The upper head continued to drain slowly until it contained approximately [ ]"**' ft. of water (approximately [ l** percent drained) at the end-of-test. l A AT increase of approximately [ ](***'*F was quickly established and maintained between the bottom of the tubular downcomer to the power channel lower-upper plenum throughout the event. This AT was the result of metal heat input to the water from the lower plenum, rod bundle, and lower-upper plenum structures, and it indicated the presence of a small natural circulation flow through the power channel. Pressurizer ne pressurizer began to drain when the SLB was initiated, and was drained in approximately j i l'***' seconds (data plot 32). De water in the pressurizer flashed due to the loss of primary I system pressure, and the temperature of the water dropped below [ ]"***F during this initial depressurization (data plot 18). The hot water exiting the pressurizer surge line into the hot leg-A j caused a slight increase in the hot-leg temperature during this period, since it mixed with the flow from the power channel lower-upper plenum. De pressurizer remained empty until about [ l*" seconds, at which time it started to slowly refill due to the mass wided to the primary system by CMT recirculation and continued voiding of the steam generator-B U-tubes and upper head. After approximately [ l**' seconds, the pressurizer refill was partially due to the small accumulator injection. Steam Generator He faulted steam generator A acted as a heat sink to the primary system until its secondary side was empty at [ l*" seconds (Figure 4.2.14-9), and flow through the steam generator A was greatly reduced or stopped. The steam generator A primary side stayed water-solid throughout the Q event. Flashing began in the steam generator-A secondary side immediately after the break valve opened due to loss of pressure. maa Rul 625 w\\sec4\\l 625 w.12.non: lt>072695 4.2.14-7 =-

The intact steam generator-B acted as the heat sink for a short period of about [ l* seconds since the steam generator steam isolation valves were closed beginning at [ l* seco nds. Until its U-tubes began to drain at [ l* seconds and the primary flow through the steam generator-B U-tubes stopped, steam generator-B acted as a heat source (Figure 4.2.14-10). The steam generator-B U-tubes were full until the end of the IDP ([ l**' seconds ). At this time a free water surface began to develop in the top of the U-tubes due to the separation of steam from the boiling Water in the top of the U-tubes. The fluid level on the hot and cold sides dropped below the top of the U-tubes and the flow in steam generator-B stopped. The level in the steam generator-B U-tubes gradually dropped during the event. The U-tubes were [ l 6 pa m drained by the end of the test (data plots 21 and 23). The fluid level on the steam generator-B secondary side was nearly constant, while the steam generator-A level dropped rapidly to nearly [ ]"* at about [ l**' mm6 ' W k Md s -Ae d was opened (data plot 7). Ilot Legs Hot legs A and -B were full of single-phase water in this test (data plots 20 and 21). Cold Legs g The cold legs remained full of single-phase water in this test (data plots 22 through 27). PRilR and IRWST For thic SLB test, three PRHR tubes were utilized in order to maximize the primary system cooldown. At the initiation of the event, the PRHR subsystem was illied with subcooled liquid. When the S signal was activated, the PRHR return valve opened after a [ l6 cm es W a high dow started through the system due to the still running RCPs. When these pumps were shut off, the PRHR flow rate reduced to about [ l**'lbm/sec. The flow in the PRHR supply line was single-phase (void fraction was [ l**' percent based on data plot 29). The driving head for the flow in the PRHR decreased as the hot leg-A temperature was reduced and the flow decreased to [ l**' lbm/sec. by the end of the test (data plot 37). Based on the PRHR flow and the PRHR inlet and outlet temperatures (data plots 19), the heat removal rate was calculated (Figure 4.2.14-3). The PRHR HX was submerged in the IRWST, and a heatup of the water within the IRWST is shown in data plot 17. Gravity injection flow from the IRWST never. began idthis test since there was no ADS actuation to depressurize the primary system to near atmospheric pressure. mhrmA1615*\\sec4\\l625w.12 non lb-072695 4.2.14-8

n Core Makeup Tanks (CMTs) = L) CMT operation was initiated after the S signal by opening the CMT discharge line isolation valve. The flow from the CMTs occurred by natural circulation in this test, hot water from the cold leg-B flowing tinough the cold leg break line to the top of the CMTs, while cold water from the CMT flowed int ) the downcomer and into the power channel annular downcomer. The CMTs were heated by lhe hot fluid from the cold-leg break line and a stratified temperature gradient was estaitlished in the CMTs (data plots 15 and 16), where the highest temperature occurred at the top of the CMTs, while the bottom temperature was the coldest. InitiaHy, the recirculation flow was approximately [ ]"*" Ibm /sec. from each CMT. The decreasing temperature in the primary system combined with the increasing temperature in the CMTs decreased the buoyancy driving head for the injection flow, causing the injection flow to drop to about [ ]*" lbm/sec. for each CMT by the end of the test (data plot 38). The CMTs remained full of water throughout this test and did not drain. Here was, therefore, no ADS actuation. Based on the CMT flows and the temperatures in the balance and the injection lines, the CMTs heat removal rate was calculated as shown in Figure 4.2.14-4. Based on the CMT level (L-A40E and leB40E), the mass addition to the primary system provided by CMT recirculation was p calculated and is provided in Figure 4.2.14-11. De rate of mass addition started at about U [ l*" lbm/sec. at approximately [ ]"*" seconds and gradually decreased to [ ]"*" at about [ ]"*" seconds. Accumulators Accumulator injection began at [ ]"A" seconds at a very low flow rate (data plot 39) due to the slow primary system pressure decay rate, and continued until the end-of-test at [ ]'*" seconds. De amount of cold water injected into the power channel from the accumulators was only [ l*"lbm total (data plot 34). Mass Discharge and Mass Italance he break mass flow staned after the break valve was opened with a high flow rate of [ ]**"lbm/sec. He flow rate rapidly decreased until about [ ]"*" seconds, at which time steam generator-A had completely emptied. Approximately [ ]"*"lbm of steam were condensed and collected in the two catch tanks during this period. For the rest of the test the flow was very small, and only [ ]**" Ibm of additional steam were condensed (Figure 4.2.14-12). There was a small, unintended SFW injection into steam generator-A from about [ ]"*" to [ ]"A" seconds which added about [ ]"*" Ibm of water. O t Re mass balance results for test S01512 were calculated based on water inventory before and after the S01512 test, both for the primary and secondary systems. Table 4.2.14-2 gives a detailed listing of the m w w m 6:5.we a e :5. a.onatso7:o95 4.2.14-9

inventories of water in the various components before the test. Table 4.2.14-3 lists the inventories af ter the test. Table 4.2.14-4 compares the mass balance for the primary and secondary systems before and after the test. The calculated primary-side mass inventory at the end of the test was within [ l'* percent of the starting inventory. The secondary-side mass inventory was [ l* percent higher than the starting inventory. 'Ihe complex geometries of the steam generators may have contributed to the disagreement between staning and ending secondary side inventories. O 9 m \\aptan1625 wvu4st o25w.12.non:!b-072695 4,2, ]4. ]()

M TABLE 4.2.14-1 SEQUENCE OF EVENTS FOR TEST S01512 Event Specified Instrument Channel Actual Time (Sec.) Break Opens (PORV A) 0 Z-00280 ~ S Signal Break opening + 1 sec. N/A i CMT-IV Opening S signal + 2 sec. Z_AN0EC, F-A40E Z_BNOEC. F-B40E PRHR HX Actuation S signal + 2 sec. Z_A81EC, F A80EG MSLIV Closure S signal + 4 sec. Z_ANSO, F_ANS Z_BNSO, F_B04S RCPs Tnpped S signal + 16.2 sec. DP-A(X)P DP-BOOP SFW-A Flow Began N/A F-A20A SFW A Flow Ended N/A F A20A Accumulator / Injection P-027P = 710 psia F_A20EG F_B20EG ADS-1 CMT level 67% L_B40E Note 1 +30 sec. Z_00lPC Note 1 ADS-2 CMT level 67% L_B40E Note ! +125 sec. Z_002PC Note 1 ADS 3 CMT level 67% L_B40E Note ! +245 sec. Z_003PC Note 1 ADS-4 CMT level 20% L_B40E Note 1 +60 sec. Z_0NPC, F4 MOP Note 1 IRWST Injection P-027P = 26 psia F_A60EG Note i F_B60EG Note i NOTE 1: ADS did not actuate due to CMT level, and the IRWST did not inject throughout this transient. O m:\\apNWAl 625 m \\acc 4\\ l 625 w.12.non : l b-072695 4.2.14-11

h TABLE 4.2.14 2 WATER INVENTORY BEFORE TEST S01.413 PRIhf ARY SIDE Volume Net Vol. Temp Relatis e Mass Component (ft.')/(I) (ft.')/(I) ('F) Density (lbm/sec.) Loops 8.97 ft.' 8.97 ft.) (a b,c) (254.0 0 (254.0 0 Pressurizer 3.37 ft.' l.06 f t.' (95.4 0 (30.1 0 Surge Line 0.34 ft.' O.34 ft.' (9.6 I) (9.6 0 Tubular Downcomer 1.38 ft.' l.38 ft.' (39.1 0 (39.1 0 Annular Downcomer + 0.54 ft.' O.54 ft.' High-Pressure Bypass (15.3 0 (15.3 I) Core Bypass 0.44 ft.' O.44 ft.' (12.4 0 (12.4 I) Lower Piemun 0.81 ft.' O.81 ft.' (22.8 0 (22.8 0 0 Fiser 1.64 ft.' l.64 ft.' (46.4 0 (46.4 0 Jpper Plenum 1.46 ft.' l.46 ft.' (41.3 0 (.11.3 0 3 Upper Head 1.90 ft.' l.90 ft.' (53.8 0 (53.8 I) CMT-A 5.05 ft.' 5.05 ft.' (l43.0 0 0 43.0 i) CMT-B 5.05 ft 5.05 ft.' (143.0 0 (143.0 0 Accumulator-A 5.05 ft.' 3.97 ft.' (143.0 0 (112.4 0 Accumulator-B 5.05 ft.' 3.99 ft.' (143.0 0 (112.9 0 1RWST Injection Line 0.18 ft.' O.18 ft.' (5.10 (5.10 TOTAL PRIMAPY INVENTORY (Note 1) m:\\apNul6:5w\\sec4\\l625 *.12.non: t h-072695 4.2.14-12

( TABLE 4.2.14 2 (Cont.) WATER INVENTORY BEFORE TEST S01512 SECONDARY SIDE Steam Generator-A 388 212.4 (a.b.c > (water) Steam Generator-B 388 218.8 (water) Steam Generator-t 388 175.6 (steam) Steam Generator-B 388 169.2 (steam) Main Steam Lines 172.4 172.4 TOTAL SECONDARY INVENTORY L l i 1 l O ) I mM;WV1625w\\sec4T1625w 12.non:Ib-072695 4.2.14.]3 )

h, TABLE 4.2.14 3 WATER LNVENTORY AFTER S01512 WAS COMPLETED PRIMARY SIDE Water level as measured by DP B16P l( 0.85 psi) was 23.92 in. (598 mm) above hot legl Water lesel as measured by DP-017P l( 0.90 psi) was 25.32 in. (633 mm) above the upper head dP tap] Volume Net Vol. Component (ft.')/(l) (ft.')/(0 Temp (*F) Rei Dens Mass (LBS) Loops 8.97 ft.' 8.42 ft.) (a.b.c n (254.0 0 (238.4 D Pressurizer 3.37 ft.' O.52 ft.' (95.4 0 (l4.60 Surge Line 034 ft.' O.34 ft.' (9.60 (9.60 Tubular Downcomer 1.38 ft.' l.38 ft.' (39.1 0 (39.1 0 Annular Downcomer + 0.54 ft.' O.54 ft.' High-Pressure Bypass (15.3 0 (15.3 0 Core Bypass 0.44 ft.' O.44 ft.' gi (12.4 0 (12.4 0 Lower Plenum 0.81 ft.' O.81 ft.' (22.8 0 (22.8 0 Riser 1.M ft.' l.M ft.' (46.4 0 (46.4 0 Upper Plenum 1.46 ft.' l.42 ft.' (41.3 0 (40.3 0 Upper Head 1.90 ft.' O.55 ft.$ (53.8 0 (15.5 0 CMT-A 5.05 ft.' 4.84 ft." (143.0 0 (137.1 0 CMT-B 5.05 ft.' 4.87 ft.' (143.0 0 (137.8 0 Accumulator-A 5.05 ft.' 3.83 ft.' (143.0 0 (108.4 0 Accumulator-B 5.05 ft.' 3.87 ft.' (143.0 0 (109.7 0 IRWST Injection Line 0.18 ft.' O.18 ft.' (5.10 (5.10 h TOTAL PRIMARY INVEN11)RY [ ]"M m:\\apNul625wvec4\\l625w 12 non:lb-072695 4.2.14-14

l mt. : Qjp TABLE 4.2.14-3 (Cont.) i WATER LNVENTORY AFTER S01512 WAS COMPLETED PRIMARY SIDE - I Water level as measured by DP-B16P [( 0.85 psi) was 23.92 in. (598 mm) above hot legl Water level as measured by DP 017P [( 0.90 psi) was 25.32 in. (633 mm) above the upper head dP tap] ] Volume Net Vol. Component (ft.*)/(1) (ft.8)/(1) Temp ('F) Rei Dens Mass (LBS) .j l i SECONDARY SIDE [ l*6 Steam Generator-A 388 0.0 Steam Generator-B 388 167.3 [ 1**" TOTAL SECONDARY INVENTORY [ l*" l WATER INJECTED FROM THE IRWST DURING EVENT ) 2 IRWST Injection dP (psi) Area (in ) M ass L BS ('Ad Note 1 [ ] O Q [ Note 1: The IRWST did not inject for this transient.] l i i O m.\\apedul625 \\sec4\\l625w 12.non:Ib 072695 4.2.14-15

TABLE 4.2.14-4 MASS IIALANCE FOR TEST S01512 PRIMARY SIDE Starting Insentory Ending Inventory (thm) (thm) Total Primary System 1975.3 ("M IRWST Injection during transient 0.0 TOTAL 1975.3 Ending Prunary inventory / Starting Primary Inventory (Ibm) Ending Primary Inventory / Starting Primary Inventory (G) SECONDARY SIDE Total Secondary System 741.6 SFW-A Added During Transient 27.0 SFW-B Added During Transient 0.0 Break Catch Tank 0.0 ADS-l. -2, -3 Catch Tank 0.0 ADS-4/ Steam Generator Catch Tank 0.0 TOTAL 768.6 Ending Secondary Inventory / Starting Secondary Inventory (Ibm) Ending Secondary Inventory / Starting Secondary Inventory ('1) l 9 1 m \\apNul625 ssect,1625* 12.non ib-072695 4.2.14-16

.. ~.,... .. - ~ -., -.., 4 + .} l r e J in. -. t-J,:.I dl y ^ 1 <, i l i ? Figures 4.2.14-1 through 14.2.14-12 (pages 4.2.14-17 through 4.2.14-28) . contain proprietary information and are not provided. i ,1 ? L i 1 O I i l i m:Mul625-ins.nos:Ib-072795 REVISION: 1

) TEST S01512 PLOT PACKAGE CHANNEL LIST BY COMPONENT COMPONENT CHANNEL UNITS PLOT COMMENT ACCA F._A20E lbm/sec. 39 ACCA L_A20E ft. 34 ACCB F_B20E lbm/sec. 39 ACCB L_B20E ft. 34 ADS 1, 2, & 3 F_030P lbm/sec. 44 Flow rate derived ADS 1, 2, & 3 IF030P lbm 43 Catch tank ADS 4 & steam F_040P lbm/sec. 44 Flow rate derived generator ADS 4 & steam IF040P lbm 43 Catch tank generator ANNDC DP-A021P psi 24 To cold leg-Al ANNDC DP A022P psi 25 To cold leg-A2 ANNDC DP-B021P psi 26 To cold leg-B1 ANNDC DP-B022P psi 27 To cold leg-B2 BREAK LINE F_005P lbm/sec. 44 Flow rate derived j BREAK LINE IF005P lbm 43 Catch tank Cold leg-A DP-A00lP psi 24 To cold leg-Al 4 Cold leg-A DP-A002P psi 25 To cold leg-A2 Cold leg-A DP-A09P psi 22 Pump suction Cold leg-A T-A10P

• F 11 Steam generator outlet Cold leg-Al F-A0lP lbm/sec.

36 Cold leg Al T-A021PL 'F 13 Downcomer inlet Cold leg-Al T-A11P 'F 11 Pump outlet Cold leg-A2 F_A02P lbm/sec. 36 I Cold leg-A2 T A022PL 'F 13 Downcomer inlet I 1 Cold leg-B DP 800!P psi 26 To cold leg-B1 { )O l myxx1625.vu4u s25. 12.no.. t ho72695 4.2.14-29

g TEST S01512 PLOT PACKAGE CIIANNEL LIST HY COMPONENT (Cont.) COMPONENT CilANNEL UNITS PLOT COMMENT Cold leg-B DP-8002P psi 27 To cold leg-B2 Cold leg-B DP-B09P psi 23 Pump suction Cold leg-B T-B10P

• F 12 Steam generator outlet Cold leg-B1 F_B0lP lbm/sec.

36 Cold leg-B1 T-B021PL

• F 14 Downcomer inlet Cold leg-B1 T-BilP
• F 12 Pump outlet i

Cold leg-B2 F-B02P lbm/sec. 36 Cold leg-B2 T_B022PL

• F 14 Downcomer inlet CMTA F_A40E lbm/sec.

38 CMTA L_A40E ft. 33 CMTA T-A401E

• F 15 Top 242.25 in.

g CMTA T-A403E

• F 15 216.75 in.

CMTA T-A405E

• F 15 191.25 in.

CMTA T-A407E

• F 15 165.75 in.

CMTA T-A409E

• F 15 140.25 in.

CMTA T-A411E

• F 15 114.75 in.

CMTA T-A413E

• F 15 89.25 in.

CMTA T-A415E

• F 15 63.75 in.

CMTA T-A417E

• F 15 38.25 in.

i CMTA T-A420E

• F 15 Bottom 0 in.

CMTB F_B40E lbm/sec. 38 CMTB L_B40E ft. 33 CMTB T-B401E

• F 16 Top 242.25 in.

CMTB T-B403E

• F 16 216.75 in.

CMTB T-B405E

• F 16 191.25 in.

) CMTB T-B407E

• F 16 165.75 in.

E CMTB T-B409E

• F 16 140.25 in.

m \\aptuR1625wVec4\\1625w.12.non:1N072695 4.2.14-30

t O TEST S01512 PLOT PACKAGE-CHANNEL LIST BY COSIPONENT (Cont-) COMPONENT CHANNEL UNITS PLOT COMMENT CMTB T-B411E

• F 16 114.75 in.

CMTB T-B413E F 16 89.25 in. CMTB T-B415E F 16 63.75 in. CMTB T-B417E

• F 16 38.25 in.

CMTB T-B420E

• F 16 Bottom 0 in.

CVCS F-001 A psi 42 DVIA T-A00E

• F 13 DVIB T B00E
• F 14 Hot leg-A DP ANP psi 20 Hot leg-A T-A03PL
• F 5

Vertical, near power channel Hot leg-A' T-A03PO

• F 5

Horizontal, near power channel Hot leg-A T-ANP

• F 5

Near steam generator inlet Hot leg-B DP-BNP psi 21 Hot leg-B T-B03PL

• F 6

Vertical, near power channel Hot leg-B T-B03PO

• F 6

Horizontal, near power channel Hot leg B TBNP

• F 6

Near steam generator inlet IRWST F_A60E lbm/sec. 40 F._A61E for S00303 IRWST F_B60E lbm/sec. 40 F_B61E for S00303 IRWST L_060E ft 32 IRWST T_061E

• F 17 Bottom IRWST T-062E
• F 17 Below middle IRWST T-%3E
• F 17 Middle IRWST T-064E
• F 17 Above middle IRWST T-065E
• F 17 Top NRHRA F A00E psi 42 NRHRB F-B00E psi 42 PC W (X)P kW l

m:\\ap60m1625=\\sec4\\l625w 12.non:ltr072695 4.2.14-31

g, TEST S01512 PLOT PACKAGE CHANNEL LIST BY COSIPONENT (Cont.) COSIPONENT CHANNEL UNITS PLOT COSISTENT PC-HB L_000P ft 30 Heater bundle PC-HR TWOl8P20

• F 3

Heater rod PC-IIR TOOL 8P48

• F 3

Heater rod PC-HR TW019P82

• F 3

Heater rod PC-HR TWO20P24

• F 3

Heater rod PC HR TWO20P61

• F 3

Heater rod PC-HR TWO20P87

• F 3

Heater rod PC-upper head T-016P

• F 4

Upper head PC-UP L_A15P ft. 30 Lower-upper plenum PC-UP L_A16P ft. 31 Upper-upper plenum PC-UP T-015P

• F 4

Upper plenum PC-upper head L_017P ft. 31 Upper head g PC-UP L_Al4P ft. 31 Above top of the active fuel 9 PRHR DP A81 AE psi 29 Supply line inverted U-tube PRHR DP-A81BE psi 29 Supply line inverted U-tube PRHR DP-A81E psi 28 Supply line PRilR DP A82E psi 28 Heat exchanger PRHR DP A83E psi 28 Return line PRHR F_A80E lbm/sec. 37 Return line PRHR T-A82E

• F 19 Inlet PRHR T-A83E
• F 19 Exit PRZ L_010P ft.

32 PRZ P-027P psia 2 PRZ T-026P

• F 18 487 in.

i Steam generator-A DP-AOSP psi 20 Hot side h Steam generator-A DP-A06P psi 20 Hot side Steam generator-A DP-A07P psi 22 Cold side m aywn t o256u4\\i s25. - 12.non: i b-072695 4.2.14-32

i-(7 TEST S01512 PLOT PACKAGE CHANNEL LIST BY COMPONENT (Cont.) 1 COMPONENT CH.ANNEL UNITS PLOT COMMENT Steam generator-A DP-A08P psi 22 Cold side Steam generator-A F_A0lS lbm/sec. 41 Steam generator A F_.A20S lbm/sec. 41 Steam generator A L._A10S ft. 35 Overall level Steam generator-A P-A04S psia 2 Secondary system Steam generator-A T-A0lS

• F 10 MFW-A i

Steam generator-A T-A05P

• F 7

Hot side Steam generator-A T-AOSS

• F 9

Hot side - riser Steam generator-A T-A06P 'F 7 Hot side Steam generator-A T-A08P

• F 11 Cold side Steam generator-A TW-A06S
• F 7

Hot side (} Steam generator-B DP-BOSP psi 21 Hot side Steam generator-B DP-B06P psi 21 Hot side Steam generator-B DP-B07P psi 23 Cold side f Steam generator-B DP-B08P psi 23 Cold side Steam generator-B F_BOIS lbm/sec. 41 Steam generator-B F_B20S lbm/sec. 41 Steam generator-B L_ BIOS ft. 35 Overall level ) Steam generator-B P-BO4S psia 2 Secondary system Steam generator-B T-B0IS 'F 10 MFW B Steam generator-B T B05P

• F 8

Hot side Steam generator-B T-BOSS

• F 9

Hot side - riser Steam generator-B T-806P 'F 8 Hot side Steam generator-B T-B07P 'F 8 U-tube top Steam generator-B T-B08P

• F 12 Cold side O)

( Steam generator-B TW-B06S 'F 8 Hot side SL T-020P 'F 18 Surge line near pressurizer m:\\agwel625m\\secol625w 12 non:Ib-072695 4.2.14-33 i a

g' TEST S01512 PLOT PACKAGE CHANNEL LIST BY COh1PONENT (Cont.) COh1PONENT CHANNEL UNITS PLOT CON 151ENT TDC DP-00lP psi 25 Top TDC DP-00lP psi 26 Top TDC DP-002P psi 24 Bottom TDC DP-002P psi 27 Bottom TDC DP-002P psi 26 Bottom TDC DP-002P psi 25 Bottom TDC T-00lPL

• F 13 Top TDC T-00lPL
• F 14 Top TDC T-003P

'F 13 Bottom TDC T-003P

• F 14 Bottom TS AT PRZ
• F 18 Based on P-027P g

upper head TSAT

• F 4

Based on P-017P l l l m;\\a;641625 w\\sec 4\\l 625 =- 12.non ; 1 b-072695 4.2.14-34

[T LJ Section 4.2.14, Plots 1 through 44 contain proprietary information and are not provided. O n LJ m:WuxA1625 ins.non:Ib-072795 REVISION: I

A period, which starts after the RCPs have coasted down,2) the period just prior to the accumulator \\d injection, and 3) the period just prior to IRWST injection. 1 The rod bundle steam fractions during the oscillation period are very similar for the three break locations. As discussed in Section 5.4, the void fraction range is primarily determined by the j depressurization rate at this time and is, therefore, related to the break size. He pre-accumulator injection period is characterized in Table 5.1-1 lists the steam fractions that occurred in the rod bundle, in the rod bundle exit (TAF) and in the lower-upper plenum, during the pre-accumulator injection period. De most notable difference between these events is that the rod i bundle steam fraction for the DVI line break is higher ([ ](** percent) than for the cold-leg and balance-line breaks ([ l* percent and [ l* percent), This indicates that the flow through the rod bundle and the fluid inventory is lowest for S00605 (DVI line), and highest for S01007 (balance line). Figure 5.1-1 shows that this is the reverse of the break flow rates and that the flow through breaks on the cold-leg side of the power channel directly reduce coolant flow to the rod bundle. Figure 5.3-3 shows that the downcomer level (measured as @) for S00605 is rapidly decreasing to the DVI nozzle level before accumulator injection starts at approximately [ ]**' seconds. De annular downcomer is full for S00303 and S01007 prior to accumulator injection at [ J* *) seconds. I The high steam fractions that occur in the rod bundle, rod bundle outlet, and lower-upper plenum prior j O to IRWST injection are listed in Table 5.1-1 as is the minimum level in the downcomer. For these V three tests the level in the lower-upper plenum drops below the hot-leg nozzle elevation (most for the DVI line break) and therefore do not reflect the actual fluid steam fraction. The rod bundle, and rod bundle outlet steam fractions for test S00303 (cold leg break) and test S01007 (balance line break) are j very similar, as are the minimum downcomer levels. Test S00605 (DVI line break) shows twice the rod bundle fluid steam fraction, higher rod bundle outlet steam fraction, and a much lower minimum level (measured as a dP) in the tubular downcomer, as shown in Figure 5.3-4. This low water inventory in test S00605 is due in part to the fact that there is less downcomer and power channel water inventory after accumulator injection, than in S00303 and S01007. During the accumulator injection for the cold leg and the balance line breaks, the rod bundle is subcooled and completely j l refilled, as seen in the increasing collapsed level for the rod bundle shown in Figure 5.3-5. However for the DVI line break, the collapsed level in the rod bundle indicates two-phase flow with approximately a [ ]('**' percent void fraction ([ 1('* psi lower than S00303) still exists at the end of accumulator injection. 1 Table 5.31 shows the instantaneous fluid losses and injection flows from/to the primary system for S00303 and S00605 at three times: during accumulator injection, after accumulator injection, and during IRWST injection. De table shows that the changes in collapsed level in the rod bundle shown in Figure 5.3-5 are in direct response to the net change in the primary system water inventory. During the accumulator injection, more water is injected into the primary system O than is ejected through the break and the ADS. De rod bundle collapsed level increases and the void a fraction for the rod bundle fluid decreases as the system water inventory increases. Conversely, after the accumulator injection ends [ l* seconds for S00605, [ l**' seconds for myntoz5.es.non:t h-072795 5.3-3 REVtslON: 1

%fNTINGHot SE PRol'RIETARY CLA5S 2 i SIX)303), the water inventory decreases, the rod bundle void fraction increases, and the downcomer level decreases into the tubular downcomer. When the IRWST flow begins (12000]'26" mm& W S00605, [2200]'**" seconds for S00303), there is a net gain in water inventory, and the rod bundle collapsed level again increases. Figures 5.3-6 through 5.3-1I show the coolant inventory for the primary system (consisting of the power channel, hot legs and cold legs, and the steam generators) for the three 2-in. break events. The first figuie for each event shows separately the coolant mass loss and the injected fluid mass from/to the primary system (Figure 5.3-6 for S00303). The second figure shows the change in coolant inventory (coolant deficit) during the test from the initiation of the break (Figure 5.3-7). It takes approximately [940]*"lbm of coolant deficit to completely empty the power channel. These figures show that the minimum coolant inventory occurs at the same time as the minimum level is observed in the downcomer and correlates well with the downcomer level and the rod bundle void fraction (Table 5.1-1). The PRHR performance, as calculated after the oscillation period, is very similar for these three events. The PRHR heat removal rates are similar, despite the some differences in the average steam fraction. In summary, the break location had a significant impact on the simulated 2-in. LOCAs. The break elevation affected the amount of reactor coolant loss through the break, which significantly influences the power channel coolant inventory prior to start of IRWST injection. Also, a 2-in. break in the cold leg to CMT balance line will initially prevent CMT recirculation and delay the transition to draindown of the affected CMTs. However, this did not greatly affect overall coolant inventory or the ADS-4 timing, since it is actuated by the level of the unaffected CMT. 9 mwunitc5.mpr:isom9s 5.3-4

p 5.4 Comparison of Hreak Sizes v Re LOCA events listed in Table 5.1-1 include four break sizes: the 1-inch, the 2-inch, and two DEGs. The 2-in. and the DEG breaks were performed at two or more break locations. The effect of break size will be examined by a direct comparison of the baseline test S00303 (2-in. LOCA in the bottom of CLB-2) with test S00401 (1-in. LOCA in the bottom of the CLB-2). This comparison will be extended to evaluate other break locations. A separate comparison will be made between tests S00706 (DEG break of the DVI nozzle B) and S00908 (DEG break of the cold leg-B2 to CMT-B balance line). These two tests are both DEG breaks, but they are very different in terms of effective break size, break location, and injection capability of the passive safety system components. Figure 5.4-1 shows the coolant inventory for the primary system (except pressurizer) during S00303 and S00401. For the 2-in. break (S00303), the coolant inventory rapidly decreases to the [ ](**" Ibm level (corresponding to the elevation of cold-leg nozzles on the vessel) and the CMT draindown mode of operation is initiated. Since the CMT draindown flow rate (approximately [ J** lbm/sec.) is less than the break flow rate (approximately [ l*" lbm/sec.), the CMT draindown is uninterrupted and ADS-1 actuates at [ l*" seconds. Although the primary system pressure has dropped to approximately [ ]"^* psia before ADS-1, there is very little discharge of coolant from the accumulators. When ADS-1 occurs, the coolant inventory is still near [ ]A" lbm and essentially all of the accumulator water inventory is still available for refilling the power channel. He O minimum cooiant inventorx is t i' *" ibm. and occurred ai t i< ' > 8ecoed8 ;u i erior to iRwST injection. Test S00401, the 1-in. break, is four times smaller than the S00303 2-in. break, and therefore, the inventory decreases to the [ ]*"lbm net coolant inventory level at a slower rate. As the inventory approaches [ ](**"lbm, the cold legs begin to void, causing the CMT balance lines to drain. He CMTs then start a period of natural circulation combined with intermittent periods of draindown, which increases their overall injection rate sufficiently to keep the water level at the cold-leg nozzle elevation. At this time, the break flow is less than the overall injection from the CMTs and accumulator injection. (Because of the long time for draindown, the primary system pressure had dropped below [ l*" psia, and the accumulators provided a small amount of injection and delivered [ ]"*" percent of their water inventory). Following ADS-1 (about [ ]"*" seconds), the accumulators have less coolant inventory to inject. Therefore, the minimum coolant inventory prior to IRWST injection at [ l** seconds is [ ]"*" Ibm. This is [ ]"*"lbm less than the minimum inventory for S00303 and resulted from the expenditure of accumulator inventory prior to ADS-1: so less water was available for injection between ADS-1 and ADS-4. Berefore, a lower minimum coolant inventory occurs for the 1-in. break (S00401) compared to the 2-in. break (S00303). De lower minimum inventory is also reflected in the higher rod bundle steam fraction prior to IRWST injection, at the time of the minimum inventory for the 1-in. break. Figure 5.4-2 shows the coolant inventory for S00908 (DEG of the CMT-B balance line) and S00706 (DEG of the DVI-B line). Rese two large-break events are very different from the small breaks and also from each other. S00908 is effectively a single-ended break, since the check valve in the CMT-B mwic5m5 noo;tunm5 5.4-1

discharge line prevented break flow from the CMT side of the break. The average total break Dows for the first [ l b n w m [ ]**' IWm for SW908 W [ T'**' lbMm fm SWE Additionally, the break clevations are different. In S00908, the break location is effectively on the top of cold-leg B2 at [ l** ft.; and in S00706, it is at [ l'^* L dmxM m M4 mmh elevation. The discussion in Section 5.3 shows that the break elevation has an impact on the break How and coolant inventory. In S00706, there is a complete loss of injection from CMT-B, accumulator-B, and only one of two IRWST injecdon lines. This, in addition to the high break flow, resulted in the lowest minirr.um coolant inventory of all the tests performed at SPES-2. De coalant inventory in the power chamel at [ j* seconds is calculated to be approximately [ l** lb.n, which still provided cooling of the rod bundle with a high steam fraction ([ ]('A" percent) two-phate fluid flow (see subsection 4.2.8, data plots 30 and 31). Figure 5.4-3 demonstrates that rod bundle cooling is adequate. His figure shows the difference between the temperature of heater rod no. 87 (at the highest elevation in the core (TWO20P87) and the saturation temperature corresponding to primary system pressure for S00706 and S00303. In S00706, the rod temperature exceeded saturation temperature by approximately [ ]^'* F when the highest void fracdon occurred in the rod bundle and was about [ ](****F above saturation when minimum coolant inventory occurred. This compares to test S00303, shown in Figure 5.4-5. He S00706 rod temperature was not much different from the reference test S00303, despite the much higher void fraction in the rod bundle. In test S00908 (the DEG balance line break), the break flow was greater than the injection flows until h [ lt**4 seconds, and the inventory to decreased to [ ](**4 lbm (below the [ ](*** lbm seen for the smaller breaks). The injection flow from CMT-A and from both accumulators was greater than the break flow from [ l('*" seconds until [ ]('** seconds, and the coolant inventory increased to [ l^d Ibm by the end of the accumulator injection. He break location for S00908 in the CMT-B balance line eliminates normal injection from CMT-B. Comparison of coolant inventory of S00908 (Figure 5.4 2) with S00303 (Figure 5.3-7) shows that the S00908 inventory was only [ ](**#lbm lower for S00908 after the accumulator injection. Also, the minimum inventory (occurring at [ )('** seconds for S00908) was only [ ](' Ad Ibm lower than S00303. Test S00908, in terms of severity (power channel inventory), was more similar to Test S00303 than Test S00706. His similarity is also reflected in the minimum downcomer level and steam fraction in the rod bundle shown in Table 5.1-1. In summary, the 2-in. breaks at or above the cold-leg elevation, with only passive safety systems, resulted in minimum downcomer levels near [ ](**" ft. He 1 in. break, at or above the cold-leg elevation, resulted in a downcomer levels near [ l*0 ft. due to the delayed ADS-1 actuation, which resulted in the expenditure of accumulator inventory prior to ADS-1. Test S00706 (the DEG of the DVI-B), had a minimum downcomer level below [ J'*6') ft This low level was the combined result of the high break flow, the complete loss of the B side passive safety systems injecdon. and the low elevation of the break location. Comparison of S00706 with S00605 g (2-in. DVI break) indicates that the larger break size of S00706 results in a downcomer level that is [ l*" ft lower at the time of minimum inventory (prior to the IRWST injection). mwuna.:3wos nonat>072895 5.4-2 REVISION: 1

e3 5.6 Other Key Test Results v This section discusses some of the special purpose LOCA tests that were performed in SPES, and the non-LOCA events (steam generator tube ruptures and SLB). 5.6.1 Comparison of PRIIR Performance The effect of additional PRHR capability on the LOCA mitigation can be assessed by comparing test S00401 (performed with one PRHR tube) with test S01613 (performed with 3 PRHR tubes). Both of these tests are 1-in. breaks in the bottom of cold leg-B2. Table 5.1-1 indicates only a few differences between S01613 and S00401 that exceed expected normal test data scatter. The PRHR performance measured for S01613 is [ ]**' percent higher than for S00401, which shows that the [ ](***' percent increase in heat transfer area for the PRHR HX yielded some additional heat transfer. The PRHR flow is slightly higher for S01613; however, the biggest difference is that the PRHR HX exit temperature is [ ]**'*F to [ l6*F lower for S01613 than for S00401. ADS 1 occurred [ ]**' seconds later for S01613, which showed that the CMTs drained at a slower rate during the time when alternating recirculation /draindown was occurring, than S00401. The minimum downcomer level was [ l*#' ft. lower in S00401. p" Figure.5.6-1 shows the primary system pressures for the two tests and clearly shows that S01613 j pressure is decreasing more rapidly than SOG401. This is a result of the higher PRHR heat removal for S01613. The faster pressure decrease resulted in more accumulator injection, which delayed the full transition to draindown injection from the CMTs and accordingly delayed the ADS-1 actuation. Figure 5.6-2 shows the coolant inventory for tests S00401 and S01613. Both tests spend an extended time period at the [ lt***' lbm inventory level. In S01613, however, the CMTs expended less inventory maintaining the coolant inventory at the [ ]**' lbm level, due to the additional injection from the accumulators caused by the lower system pressure. ADS-1 was therefore delayed for S01613 relative to S00401. When ADS-1,2, and 3 occur, approximately [ ]**' lbm less fluid was discharged through ADS for S01613 due to the lower initial system pressure at the start of ADS. Therefore, S01613 had more coolant inventory than S00401 after the accumulator delivery, as shown in Figure 5.6-2. The net coolant losses from the end of accumulator delivery until the start of IRWST injection were very similar for the two events. However, since S01613 started this period with more 1 coolant inventory, it also ended with more inventory than S00401, at the point of minimum coolant inventory in the vessel. The greater PRHR heat removal in S01613 increased the pnmary system pressure decrease relative to S00401 prior to ADS-l. The overall effect of the lower system pressure mitigated the severity of the test. 3(0 m Aa;WXN 625 weltsupt05bu.non:I b.072895 5,6-]

5.6.2 Test Repeatability g The repeatability of the SPES-2 facility is demonstrated by a comparison of baseline test S00303, which was the first matrix test performed, with test S01703. Matrix test S01703 was the last matrix test and was performed at the conclusion of the SPES-2 test program. Test S01703 was performed at initial conditions as similar as possible to S00303. Subsection 4.2.3 provides a detailed comparison of S01703 and S00303. There are very small differences shown in the comparison, and those that are shown can be explained as slight differences in initial conditions (Figure 5.6-3). Table 5.1-1 shows that there are no significant differences between the two tests, beyond what would be expected based on normal data scatter. The test facility repeatability demonstrated by tests S00303 and S01703 is clearly very good, and gives good confidence that the test to test differences observed in the matrix tests (as shown in Table 5.1-1), are real differences resulting from the differences in the transients being simulated. 5.6.3 Comparison of Steam Generator Tube Rupture he steam generator tube rupture events S01110 (SGTR without nonsafety systems) and S01309 (SGTR with nonsafety systems and operator actions) are individually discussed in subsections 4.2.12 and 4.2.1I respectively. There were significant differences between the two tests and these are attributable to the effects of the nonsafety systems operating for S01309. Specifically the use of the g SFW system and the steam generator-A PORV to maintain the primary system cooldown rate provided sufficient heat removal to maintain single-phase flow conditions in the primary system. Also, the pressurizer heater operation was maintained in S01309 until low pressurizer level occurred. Figure 5.6-4 shows the primary system pressure for the two tests, depicting the S01309 pressure to be lower than S01110 due to the additional cooling provided by CVCS injection, SFWS addition, and steam generator-A PORV actuation. Figure 5.6-5 shows that the primary system pressure is higher than the steam generator-A pressure throughout the test for S01309. The steam generator-A provides sufficient heat removal from the primary system to maintain the primary system at single phase flow conditions. This, as seen in the dPs in the steam generator-A U-tubes, showing that primary system natural circulation flow was maintained through steam generator-A. Figure 5.6-6 compares the rod bundle collapsed level for the two transients, showing that significant two-phase flow conditions staned at approximately [ l*" seconds for S011Id, while S01309 maintained single phase flow through the core until the test termination. Figure 5.6-7 shows that the pressurizer levels differed greatly between the two tests. In S01110 the pressurizer refills completely by approximately [ l*" seconds, at which time the only steam volume in the primary system is in the upper head. In S01309, the pressurizer partially refilled at [ l*" seconds in response to venting through the ADS-1 flow path by operator action, and a low gi level was maintained for the rest of the test. The measured temperatures in the pressurizer in S01110 indicated that the pressurizer was subcooled at [ l*" seconds, at which time the pressurizer i I m wwm625wmunne.n=w072795 5.6-2 REVISION: 1

. (q completely filled. In S01309, the top of the pressurizer was superheated throughout the test, which is \\/ the reason it never fills completely. This occurred in part, because in S01309, the pressurizer heater was kept on and maintained full pressure / temperature until the pressurizer water level decreased to approximately [ ](** ft. at [ /**#' seconds, and the two bottom external pressurizer heaters were left on during the test. 'This was apparently sufficient to offset pressurizer heat losses. In test S01110, no pressurizer heater power was used and heat losses were sufficient to reduce pressurizer pressure and temperature. In both of these tests the ADS was not actuated since the CMTs remained in their natural recirculation mode throughout the test. ( O mynt625msunest=2<wib 072795 5.6-3 REVISION: 1

t 6.0 OHSERVATIONS AND CONCLUSIONS The primary purpos_e of the test data discussed in this report is to provide a basis for validating computer codes developed for analysis of transients in the AP600 plant. The observations and conclusions made in this document are only applicable to the SPES-2 facility. Key observations and conclusions are made from the SPES-2 testing in the following categories: Overall Test Observations

1. No dryout or significant heater rod temperature increase was detected in any_ test'(loss-of-coolant accident [LOCA], steam generator tube rupture {SGTR), and steam line break [SLB]).

1

2. The core makeup tanks (CMTs), in-containment refueling water storage tank (IRWST),

accumulators, automatic depressurization system'(ADS), and passive residual heat removal.(PRHR) heat exchanger (HX) functioned as expected and as predicted in pretest predictions ~for the SPES-2 facility. t

3. De initiation of CMT draindown was always observed as a consequence of cold. leg-B' voiding.

4 De water in the CMTs remained thermally statified throughout'all events, during both the' natural 'O circulation and draindown CMT operating modes.

5. Flow oscillations throughout the primary system were observed before steam ' generator draindown -

in SPES-2 when two-phase flow occurred in the power channel rod bundle and the hot legs.. Specific Observations for Small Break Loss-of Coolant Accident Tests 6. Following a 2-in. LOCA, operation of the active, nonsafety chemical and volume control system (CVCS) and/or normal residual heat removal system (NRHR) had little effect prior to ADS-1 actuation; however, increased primary system inventory was observed after ADS-1, due to the active safety systems. 7. Following a 2-in. LOCA, operation of the active, nonsafety NRHR system prevented CMT draindown and ADS-4 actuation.

8. De 1-in. cold leg-B break resulted in higher void fraction / lower water inventory in the vessel than all 2-in. breaks simulated.

9. De 2-in. direct vessel injection (DVI) line betak resulted in higher void / lower water inventory in the vessel than other 2-in. LOCA locations. De DVI break was the worst break location tested.

mwanis:5.mno iun2ns 6-1 REVISION: 1

x f l10. He double-ended guillotine (DEG) DVI line break simulated in S00706 resulted in'the highest heated rod bundle steam fraction and also the lowest water inventory in the power channel prior. IRWST injection and the~ subsequent refill o_f the primary i;ystem. I1. Increasing the PRHR HX heat transfer area by 200 percent (from one tube to three tubes) resulted in only a (36]A" percent increase in heat transfer rate with two-phase flow inlet conditions. Specific Observations for Steam Generator Tube Rupture Steam Line Break Tests

12. De passive safety systems. (without acdve safety system operation or operator actions) midgated 3

the single SGTR and large SLB events without resulting in' ADS actuation.

13. Nonsafety system operation and operator actions following the SGTR maintained the primary system in a subcooled condition and prevented hot leg voiding.

Test and Data Quality Conclusions

14. Thirteen of 17 tests performed in SPES-2 were determined to be acceptable for code validation purposes.

15. The repeatability of the facility and measured data was excellent, as evidenced by the comparison

.g of S00303 with repeat test S01703 and by the consistency of test initial and boundary conditions. j

16. The SPES 2 upper-head initial temperature was approximately [45]**) 'F ha h k temperature originally specified in the test specification; however, consistent upper head initial temperatures were maintained from test to test.

] )

17. The gamma-densitometer and turbine flow meters did not provide useful data. The use of gamma-densitometers in small, heavy walled piping caused alignment and signal strength problems. Flow slugs /high flow velocity resulted in damage to the turbine flow meters. Electro-magnetic interference from the heater rods and power source caused problems with the signals from both the gamma-densitometer and the turbine meters.

18. He failure rate of the heated rod thermocouples was very high, but a sufficient number of thermocouples were operational to monitor the bundle temperature.'

i i Ol .l mwnuc5.u mwom95 6-2 REVislON: 1

y;,9; hhn.p'

J

-m n

/f.( '

iThe ' main characteristics of the Venturi tubes and of the orifices used to measure the SPES-2 flow- /b -

rates are reported in Table C-2. The columns have the following meaning

i TAG; SPES-2 instrument identification code ? ..i D' . Pipe inside diameter (mm) ] d Nozzle throat diameter (mm). ot, Calibrated or calculated nozzle flux coefficient (m ) j 2 1 2 . Aa, ' Maximum error of the nozzle flux coefficient ( m) 2 ca, Standard deviation of the nozzle flux coefficient ( m) TYPE-Type of the nozzle ] l i O 4 m$aph0lAl625w\\npp-c.non:lt>072805 -

C.$

9 TABLE C-1 SPFS-2 INSTRUMENT LIST g { hlANU. g PLANT SIET h K M Q ACCtMCY CODE INSTitt' MENT LOCATION MANtTACTURER MODEL CODE SPAN hl0-(m) (kPal (M 11JhsV) IM.U. + 15 DE40lPA Veerwn/DP-Transa Break hoe GAAMATOM AM DE001 I : 1000 kshn' 0.125 12368 54 9 ss DE40lPfl Gammadea Break line GAMMATOM AM DE001 1 : 1000 kg/m' 0.I25 -12368 54 DE430PA Gammadet ADS-1.-2 -3 header GAMMATOM CS DE002 1 : 1000 kg'm' 0.125 -123 t4 5% DE430PB Gammades. ADS-I,-2,-3 header GAMMATOM CS DE002 1 : 1000 kg/m' 0.125 -123.68 55 DE430lO Gammades ADS-I.-2,-3 header GAMhlATOM CS DE002 I : 1000 kg/m' 0.125 -123 68 5% DE440PA l' 'a ADS-4 header GAMMATOM CS DE003 1 : 1000 kg/m' 0.125 -12) 68 5% DE440fB Gammaden. ADS-4 header GAMMATOM CS DE003 I : 1000 kg/m' 0.125 -12368 59 DE440lr Gammadea ADS-4 header GAMMATOM CS DE003 i: 1000 kg/m' 0.125 123.68 51 DE AOIPA Gammadea fileA GAMMATOM CS DE-004 1 : 1000 kg/m' 0.125 -12368 51 DE A0lPB Gammadet III A GAhBIATOM CS DE404 1 : 1000 kg/m' 0.125 -123 68 5% DE-A0 llc Gammadet IReA GAMMATOM CS DE404 1 : 1000 kg/m' 0.125 -12368 5% O DP400E DP - Tramd. DVI-A/DVI B SENSOTIC Z/1901-12 TSD 038 -M : 34 kPa 0 0 1.731 44585 0.25 % DP 000P DP - Transa PC reur llONEY%T11 TIDI30 TMD 110 -60 : 60' kPa 5.306 52.0M 0.03 -37.9% 0.804 DP-00lP DP - Transa PC tuimlar DC llONEYwT11 STD120 TMD 057 0 : 10G kPa 2.555 -25.05 0.025 -50.05 0.10$ DP-002P DP - Trnasm PC estelar DC IlONEY%T11 STD120 BID 068 0 : 100 kPa 2.7I -26376 0 025 -51.576 0.105 DP-003P DP - Traran DC lalet/PC LP 110NEYWE11 SID120 TMD 053 0 : 70 kPa 0.242 -2.373 0.0175 -15.127 0.10 5 DP404P DP - Transa PC LP IIONEY%TiL STD120 TMD 114 -30 : 30 kPa 0.932 9 14 -0.015 54.14 0.10% DP-005P DP Transa PC riser llONEY%T11 STD120 TMDIL -20 : 20 kPa 0.741 7N -0.01 37.27 0.101 DP4tlP DP - Transa PC riner flONEY%T11 STD120 ntD 121 -15 : 35 kPa 1.48 14 514 0.0125 -12.986 0 10 % DP-012P DP - Transa PC riser llONEYWTIL SID120 TMD 118 -15 : 35 kPa I 11 to 885 0.0125 -16.615 0.105 DP-013P DP - Transa PC riser flONEY%T11 STD120 TMD 189 -15 : 35 kPa 1.11 10 885 0.0125 -16.615 0 10% DP-014P DP - Transa IC riser flONTYWELL STDI20 TMD 127 -10 : 10 kPa 0865 8.679 0.005 4 321 0.109 DP-017P DP - Transa IC lli ilONEY%T11 STD120 TMD 122 0 : 50 -*a 1 889 -18 525 0 0125 -31.025 0 10 % DP-018P DP - Transa IG<A/SL llONEY%T11 SID120 n1D 129 -10: 10 kPa 0.899 8.816 0 005 4.184 0.101 DP-019P DP - Transa SL llONEY%T11 51D120 TMD 140 -25 : 25 kPa 0.741 7.267 4 0125 44 767 0.101 <E55 O 9 e

\\ fh: -() J 9# TABLE C-1 } SPES-2 INSTRUMENT LIST (O)nt.) 2 klANt!. 7 PLANT SIET b K ' %I Q A(TI'RA(T ON)E INSTRt' MENT LOCAllON & LAM TACTt'RER MODEL G)l)E SPAN htU. On) (kPa) (MlunW) BLLL) 3 4 DP-020P DP - Transm SL IIONEYWHL S1D120 BlD 085 -50 : 50 kPa 3.426 33.598 4 025 IJ8.598 0.10% 8:s DP-021P DP - Transa PR HONEY %111 S11)l20 BlD 047 -20 : 20 kPa 1.444 14 161 4 01 4 161 0 10 % k DP-022P DP - Transa PR HONEYWELL SID120 TMD 076 -20 : 20 kPa 1.44 14 161 4 01 4.161 0.10 % g DP-023P DP - Tranam PR HONEY %1LL SIU120 1M) 073 -20 : 20 kPa 1.444 14 161 4 01 4 161 C 10% DP-024P DP - Transa PR IlONEYWE11 STD120 BlD 074 -20 : 20 kPa 1.444 14 16l 4 01 4.161 0.10 % DP425P DP - Transa PR llONEY%HL SID120 BlD 141 -10 : to kPa 0 43 4.217 -0005 19217 0.10's. DP-026P DP - Transa PR HONEYWELL SID120 1M)OM 10:10 kPa 0.32 3.138 -0005 18 138 0.10 % DP-027P DP - Transn. PR flONEY%I1L SID120 TMD 036 -10: 10 kPa 0.235 2.305 4 005 17 305 0.10% DP-MIP DP - Tramd. CleAl/B t SENS(TIEC Z/1901-12 TSD 040 -M : 34 kPa 0 0 L7443 05084 0.25 % DP-N2P DP - Trand CleA2/B2 SENSO11C Z/1901-12 TSD N1 -34 : 34 kPa 0 0 1.734 0.2765 0.25%. DP-N3P DP - Transd CleBI/B2 SENSO11iC A-5/1901-12 TSD M2 -34 : 34 kPa 0 0 1.7667 0.0737 0.25 % O DP-044P DP - Transd CleAllA2 SINSO11C Z/1901 12 TSD 039 -34 : 34 kPa 0 0 1.7359 4140 0.25 % DP-An0lP DP - Transa CleAl llONEY%111 STD120 IM) 124 0 : 50 kPa 1.051 -10.297 0 0125 -22.797 0.10 % DP-An02P DP - Transm CleA2 IlONEY%B 1 STD120 BR) 126 0 : 50 kPa 1.051 -10.297 0.0125 -22.797 0101 DP-A00P DP - Transa PCP-A IlONEYWH1 STD130 TMD 132 0 : 700 kPa 0 339 -3 325 4 175 171.675 0 los DP-A005 DP - Tseasm SG-A baffle GOt!LD PD3000-030 TMD 029 -2.5 : 2.5 kPa 0 0 0.0n125 3.75 0.25% DP-A0l t P DP - Transa GeAl llONEYWE11 SID120 TMD 046 -25 : 25 kPa 0 0 0.0125 -37.5 0 10% DP-A012P DP - Transa CleA2 HONEY %111 STD120 BID 043 -25 : 25 kPa 0 0 0.0125 -37.5 'O.101 DP-A01S DP - Transm SG-A nser GOUlJ) PD3000 200 1MD1% 0 : 50 kPa 3.98 39 03 4 0125 51.53 0 25 % DP-A02 t P DP - Transa CleAl/PC DC HONEYWEli SID120 TMD 138 0 : 70 kPa 1.245 12.209 0 0175 -29 709 0 10 % DP-A022P DP - Transa CleA2/PC DC llONEY%111 STD120 B1D 039 0 : 70 kPa 1.245 -12.209 0.0175 -29.709 0.10 % DP A025 DP - Transa SG-A riser HONEY %B1 S~IU120 B1D 054 0 : 70 kPa 6.5 63.743 -00175-81.243

0. IO%

DP-A03P DP - Trmesm SG-A ia/out HONEYWH1 STD130 BtD 055 -100 : 400 kPa 0 0 0.125 -225 0.10 % DP-A03S DP - Traum SG-A separator HONEYWELL SID120 TMD 087 -50 : 50 kPa 3.2 31.381 4 025 106.381 0.10 % DP-AGSP DP - Transa HI A ilONEYWEli STD120 TMD 115 -40 : 60 kPa 3.603 35.3M 0.025 -29.666 0 los Di5? i e-s

9g l TABLE C-1 l SPES-2 INSTRUMENT LIST (Cont.) 1 _3 { MANU-a PLANT SIET b K M Q AC(TRACY CODE INSTRLMENT IA DCATION MANETACTt'RER MODEL CtM)E SPAN hlU. tml (kPa) 01 UJmV) (M.U-l g 9 IF Anas DP - Tramm SG-A separanor SGILL'MBERGER BD5GA-3 ThiD 013 -10 : 10 kPa 0675 6 619 -0.005 21.619 0.25 % 8 .R DP-A05 P DP - Trenam U-nee SG-A IIONEY%T11 STD130 nG1037 -60 : 120 kPa 5 125 50.2575 0.N5 54.741 010% DP. A05$ DP Transe SG-A dryers IIONEYWE11 SH)l20 ThE) 056 0:10 kPa 0.69 6.7M 4)0025 9.266 0 10 % U ! IFAmP DP - Transm U-ahe SG-A IlONEYWT11 517 % 0 BE) 113 -40 : 60 kPa 3.75 % 775 0.025 -28.225 0.10 % 3 IFA065 DP - Transm SG-A rea GOUID PD3000-400 bel lW 0 : 30 kPa 2 15 21.084 -0.0075 28.584 0,25 % LP A07P DP - Transm U-mee SG-A IlONEYDT11 SH)120 n 0 081 -M : 70 kPa 175 4 6.775 0.025 -91.775 0.10% IEA08P DP - Tramm U-ahe SG-A IlONEY%Til 511)IM 3 0 105 40 : lon kPa 5125 -50 259 0M 150.26 0.10% IPAwP DP - Tramm PS-A IlONEY%T11 SH)l20 nG) ll6 0 : 100 kPa 1.768 -17.338 0 025 -42.338 0.10% W A15P DP - Transa ir UlYlil, A IK)NEYWE11 STD120 3 0 048 -15 : 15 kPa 1.014 9 M4 0.0n75 -12.556 0.10 % ISA16P DP - Transa lit A/PC UP llONEYWE11 51DI20 B51049 0 : 20 kPa 0.666 -6.531 0 005 -11.551 0.10 % DP. A20E DP - Transa A(UA ini hae llONEYWE11 STDl30 ntD 104 -50: 200 kPa 3M 32.754 0.0625 -79.746 0.10 4 O DP. A28P DP. Tramm GU-A PR toi. fine IIONEY%Ill STDI30 B1D 107 0 : 100 kPa 4 637 -45.47 0.025 -70.47 0 10 % 1* A40E DP - Tramm Ofr. A inj hae IIONEYWE11 STT)l30 ThE) 093 -15 : 105 kPa 2.615 -25.644 0.0325 -si 144 0.10 % DP A41E DP - Transa ChfT A IBONEYWELL SH)120 n1D l39 0 : 18 LPa I.555 15 249 -0.on45 19 749 0.10 % DP.A42E DP - Transa oft-A IlONEYWT11 STD120 TMD 040 0 : 18 kPa 1.555 15.249 -0.0045 19.749 010% DP-A41E DP - Trama Chfr-A flONEY%Ill STD120 U O O32 0 : 18 LPa 1.555 15.249 00045 19.749 0.10% DP A44E DP - Transa Gir A IlONEY%T11 STI)l20 TMD 062 0 : 18 kPa I555 15 249 4 0645 19.749 0.10 % DP. A45E DP - Trenan Off-A CIAal hoe llONEY%B1 STI)l20 TMD 063 -20 : 80 kPa 7.225 70 853 -0.025 'I5 853 0.10 % DP-A61E DP - Tramm IRWST inj line A IlONEYWELL STD120 31D il7 0 : 100 kPa 1.015 -9 954 0.025 34 954 0.10 % DP A81 AE DP - Transa PRilR Supply line llONEY%TIL STD120 TMD 032 -20 : 80 kPa 2.629 25 782 0.025 49.218 0 10 % DP A81BE DP - Traum PRilR Supply Line HONEYWE11 STD130 Tht) 099 -50 : 50 kPa 2.t 29 -25 782 0.025 -Inc.78 0, tir% DP-A81E DP - Transa PRilR supply line llONEY%T11 STD120 3 0 188 20 : 80 kPa 8 006 78.512 0.025 3.512 0.10 % DP-A82E DP - Transa PRilR sup/ ret. IIONEY%Til SH)120 n o 066 -50 : 50 kPa 5.38 -52.76 0.025 127.76 e 10% DP-A83E DP - Transa PRilR retura hae llONEYHT1L STD120 BG) 041 0 : 50 kPa 1 13 -11.082 0.0125 -23.582 0 10 % DP itooIP DP - Tranam a B1 IIONEYWELL STD120 B1D 080 0 : 50 kPa 1.051 -10.297 0.0125 -22.797 0.10 % <E 5? O O O

Eg TABLE C-1 g SITS-2 INSTRUMENT LIST (Cont.) MANt!. ~ g g PLANT SIET h K M Q ACITRA(T O MIE INSTRt?MWT t OCAT10N MANLTACIURER MODEL O M)E SPAN hl.tk qad {LPal (M.UJmVI tM.tu + 6 DP B002P DF - Transa Co,B2 IloNTY%TIL S1T)120 TMD 069 0 : 50 kPa 1 051 -10.297 0 0125 -22 797 0.10% R .N.- DP Blu f DP - Tran6m ' PCP-B llONEY%B L STD130 TMD 133 0 : 700 kPa 0 339 -3 325 0.175 171 675 0.10 4 f DP IMn3 DP - Treasm SGB baffle GOLU) PD3000 0%12 TMD 225 -2.5 : 2.5 kPa 0 0 0 00125 -375 0 25 % 8 } DP B0llP DP - Trnaam (LBI HONEY %TIL STD120 I M )071 -25: 25 kPa 0 0 00125 37.5 0.10 % DP Bol2P DP - Transa C1 B2 IlONTY4TIL STD120 BH) 072 -25 : 25 kPa 0 0 0 0125 -37.5 0.10 % DP Bois DP - Transa SGB neer YOKOGAWA EJ110 TMD 205 0 : 50 kPa 3.98 39 03 00125 51.53 0.25 % DP B021P DP - Transa (LB1/PC DC IK)NEY%T11 STD120 TMD 051 0 : 70 LPa 1245 -12209 00175 29.709 0,10 % DP B022P DP - Tranam CL-B2/PC DC llONEY%Tl1 STD120 TMD 061 0 : 70 kPa i245 12.209 0.0175 29 700 0 tot DP B02S DP - Trassa SGB riser IlONEY%TIL STDl20 TMD 060 0 : 70 kPa 65 63.743 -00175 81.243 0 10 % IS B0W DP - Transa SG-B insuus llONEY%U L STDl30 BR) l09 -100 : 400 kPa 0 0 0.125 -225 0.10 % DP B035 DP - Transa SGB separasor llONEY%TIL S11)l20 TMD 086 -50 : 50 kPa 1.2 31.381 4.025 106.381 0109 DP B04P DP - Trnasm in A IK)NEY%TIL STD120 TMD 050 40 : 60 kPa 3603 35.334 0.025 -29.666 0 tot 9 DP-lWktS DP Transa SGB separator-IlONEY%111 S1T)120 nG) 088 -10 : 10 kPa 0 675 6.619 -0005 21.619 0 10 % ) IW B05P DP - Transa U-tube SG B llONEY%TIL STDl30 BG) l31 -60 : 120 LPa 5 825 50.258 ON5 -54 741 0.10% DP Bois DP - Transa SGB dryen GOLU) PD300(k200 TMD 144 0 : 10 LPa 0.69 6.766 -0.0025 9 266 0259 i DP Bo6P DP - Transm U-tube SG B flONEY%TIL STD120 TMD 089 -40 : 60 kPa 175 % 775 0.025 -28.225 0104 DP INMS DP - Transa SGB riser Gotu) PD3(M200 1MD 154 0 : 30 LPs 2.15 21.0M 4 0075 - 28.584 0 25 % l DP B07P DP - Transa U4uhe SG-B llONEY%UL STT)120 TMD o&4 30 : 70 LPs 175 -36.775 0.025 -91.775 0.10 4-telW8P DP - Transa U-tube SG B IK)NEY%TIL STD130 BG) 106 4 0 : 100 kPa 5 125 -50.259 0.4 -150.26 0.101 DP B09P DP - Transa PS B llONEY%T11 STD120 TMD 119 0 : 100 kPa 1.76 8 -17.338 0.025 -42.338 0.101 DP Ill5P DP - Tranam IR B!IC l'P HONEY %TIL STD120 TMD 075 15: 15 kPa 1.014 9 944 0 0075 -12.556 0109 DP-B16P DP - Transa lit B/ICUP IlONEY%TLL STD120 TMD 137 0 : 20 kPa 0.666 4.531 0 005 -11.531 0 10 % DP B20E DP - Transa A(C-B ini line BK)NEY%UL STDl30 ntD 097 -50 : 200 LPa 3.34 32.754 0.0625 -79 746 0.10 % DP B28P DP - Transa CMI' B Pit bal. line llONEY%Tl1 STD120 BID 143 0 : 100 kPa 4 637 4547 0.025 -70.47 0.101 DP B40E DP - Transa oft-B ini. line llONEY%U L STD130 BR) 098 25 : 105 kPa 2.615 -25 644 0.0325 -83.144 0.1og M m< DI5 E

ay TAHl.E C-1 SPES-2 INSTRUMENT 1.lST (Cont.) 2 h 510 0-g PLANT SIET h K M Q ArtTRatT OX)E INSTRI' MENT LOCA110N MANITA(TURER MODEL CODE SPAN blU-tal (kPat 61 UJn V) 61.UJ g P DP B41E DP - Transa Off-B IRWEY%E l STD120 ntD 090 0:18 kPa 1 555 15.249 -0 0ius 19 749 0.1o% 8u DP B42E DP-1ranam oft-B lH)NEY%El STDI20 nID I30 0:18 kPa 1.555 15.249 4 0045 19 749 0109 E DP B43E Of* - Transa CMT-B IK)NEYuul SU)120 TMD 091 0: 18 kPa 1.555 15.249 -0 0lu5 19.749 0.105 g DP B44E DP Tranam Ofr-B llONTY%U1 STD120 TMD 038 0: 18 kPa 1.555 15.249 4 0145 19.749 0109 DP fuse DP Transa CMT-B CL-bal. line IIONEY%Tl1 511/120 nG) 042 - 20 : 80 kPa 7 225 70.853 4.025 115 853 0 10 % DP B6IE DP - Tranam IRWST ini hae B SCIILUMBERGER BTBF3GA3 TMD 016 0 : 100 kPa 1.015 -9.954 0.025 -14 954 0.25 % F-001BP Veerun/DP-Transm. IlONEY%UL STT)120 B1D 142 0:40 kPa 0 0 0.01 -10 0.10 9-F-001BS Venewvt)P.Transm. IR)NEY%U1 SU M24 B1D 230 0 : 20 kPa 0 0 0 005 -5 0.10 % F-001 A DP-Transa CVS BALEY BC2521515 TMDIM 0 : 30 kPa' O O O0075 -7.5 4.101 F-002P Twhee PC iubular DC ENG 4' N/A dm% 0 007 0.00667 0.15 F-CO3P Ventwi/DP-Transm. PC tubular DC IN)NEY%U1 51T)l20 B1D 082 0 : 80 kPa 0.161 -1.578 0 02 -21.574 0104 h F-On'LP VentwVDP.Transm FC subular DC IK)NEY%UL STD120 BG) 082 0:6 kPa 0.161 -1.578 0.0015 -3103 0.10 % F405P Turtnae Break hae CENG 2* N/A dm3/s 0 0n66 4Wm6 0.1 % F-014P VenrwdDP-Transm DC-G' bypass llONEY%El STD120 TMD il2 0 : 100 kPa 0.057 0.559 0.025 24.441 0.10% F-015P Twhee SL CENG 1.5* N/A dmM 0On038 -0.3725 01% F-030P Twtwee ADS-I.-2.-3 header M t. 3' N/A dmM 0.14 F4uoP Twhee ADS 4 header GNG 3' N/A dm3/s t 0 0.1 % F A00E On6ce/DP-Transa NRIIR A IlONEY%U1 SH)l30 TMD 035 0 : 700 kPa 0 0 0.175 -175 0105 F-A0I P Ventwi/DP-Transa CLAI IlONEY%T.11 SH)120 ntD 077 0 : 60 kPa 0 0 0 015 -15 0101 F. AOIP VentwdDP-Transm. CLAI IIONEY%El SU)120 B1D 077 0:5 kPa 0 0 0.00125 -1 2588 0 a0% F. A015 Orince/DP-Transa MlW-A IIONEYwn1 SH)l30 TMD 095 0 : 200 kPa 0 0 0.05 -50 0.105 F.A02P VentwdDP Transm (LA2 IlONEY%T1L STT)120 TMD 078 0:5 kPa 0 0 0,00125 -1.248 0 10 % F-A02P Ventwi/DP-Transm (L A2 IR)NEYHT11 STD120 TMD 078 0 : 60 kPa 0 0 0 015 -15 0101 F A025 VeneuvDP-Transm. SG-ADC SCllLUMBERGER BlBF5GA-3 B1D 202 0 : 100 kPa 0 085 -0 8 M 0.025 -25.8 M 02511 W F-A035 Ventun/DP-Transm. SG. ADC YOKOGAWA Ell 10 ntD 200 0 : 10!) kPa 0.085 -0.8 M 0.025 -25.8 M 0.25 4 tT1b 5e0 t O e

w y J ) ~ f,:,; .,;r:: e - m >l;i ( .xy =

O AreENDix r SPES 2, AP600 INTEGRAL SYSTEMS TEST DELTA.P INSTRUMENTATION DATA REDUCTION

O

, - s... ss e.i aevisios:Li

,q V' F1 Introduction in order to use the data from the SPES dP instrumentation, it is necessary to understand the arrangement of the dP cells, to account for the tap-to-tap elevation differences, and to compensate for fluid densities. With this understanding, the dP cell data can be used to obtain the dP due to friction losses and to measure water level at low or no-flow conditions when the component friction loss due to flow is approximately O. The following sections provide a description of each dP cell installation configuration used at SPES-2, a description of how the engineering unit data should be processed, a list of the dP instruments, and the appropriate temperature instrument (s) that should be used in determining the density of fluid (s). See Appendix F-7 for a summary of results, and reference Appendix E-1 and E-3 of this report. O O m \\apMul615=nossapp-f.noo:I b-072795 F-3 REVISION: I

h F-2 Configuration i dP Cells F-2.1 Installation and Offsets The installation / characteristics of configuration i dP cells are as follows: The normal direction of flow is in the UP vertical direction, and the negative (low-pressure) side of the dP cell is the upper tap. l This causes flow losses to increase the measured dP since flow is from the positive (lower) tap to the negative (upper) tap. j l J The data acquisition system (DAS) adds the tap-to tap elevation difference to the dP at the I = instrument taps, converting this height to force (psi) using the following equation: p.,gh/144 g, l l 1 where: p., = density of cold water at ambient conditions (62.2 lbs/ft.') g = acceleration due to gravity (32.2 ft./sec.2) h = tap-to-tap elevation difference (ft.) g, = mass to force conversion (32.2 ft. - Ib/sec.2 Ib,) F 2.2 Friction Loss Determination When the component is full of flowing water, the friction loss portion of the measured dP is calculated as follows: Recorded dP data (psid) = dP at instrument + p,cgh/144 g, where the dP at the instrument equals the (positive tap pressure) minus (negative tap pressure). That is, l dP at instrument = (friction loss + p,ngh/144 g ) - (p,gh/144 g ) where: pon is the density of the hot process water in the component which must be determined based on the existing system pressure and the temperature of the water. m%;WKAt 625 woonQf.noo:1b-072795 F.4 REVISION: 1

I o -l l, ~. -()- Since the DAS adds p.,gh/144 g,, then . Recorded dP data (psid) = friction loss (psid) + p.,gW14 g, and Friction loss (psid) = recorded dP data (psid) - p.,sh/144 g, F-2.3 Component Water Level Determination 'The water level that exists between the dP cell taps can be calculated from the recorded dP data when the friction loss is negligible or when the flow is 0. This is done as follows: Il Recorded dP data (psid) = p.3Lg/144 & + p (h - L) g/144 g, where: L = water level of water (ft.) - p, = density of steam Btis numerically reduces to the following: L=[ ] / (p., - p,) Riis level can be converted to percent level using the following: % level = (Ilh)

• 100%

'the density of steam (p,) can be ignored (assumed 0) in the above equation, with less than 1% error introduced, when system pressure is less than 500 psia. Table F-1, provides a listing of dP instruments that operate as described above Also listed are the-pressure and temperature insuument(s) that should be used to determine p., and p, in the above equations. J0 mAap600\\l625woon\\ar5>f non:Ib-o72795 F-5 REVISION: - 1 '-

s' F-3 Configuration 2 dP Cells h ~ F 3.1 Installation and Offsets The installation / characteristics of configuration 2 cells are as follows: 'the normal direction of flow is in the DOWN vertical direction, and the negative (low-pressure) side of the dP cell is the bottom tap. This causes flow losses to increase the measured dP since flow is from the positive (upper) tap to the negative Gower) tap. i: The DAS adds the tap-to-tap elevation difference to the dP at the instrument taps, converting i this height to force (psi) using the following equation: p.,gN144 g, l l i The DAS reverses the signs c'the taps. F 3.2 Friction Loss Determination O, I The friction loss portion of the measured dP when the component is full of flowing water is calculated { 1 as follows: Recorded dP data (psid) = dP at instrument - p.gM144 g, -) I where the dP at instrument equals (negative tap pressure) minus (positive tap pressure). That is, dP at instrument = (p.gN144 g ) - (friction loss + p.,gM144 g )- Since the DAS adds p.,gM144 g, then I Recorded dP data (psid) = p.gN144 g, - friction loss (psid). f, and Friction loss (psid) = p.gM144 g, - recorded dP data (psid) I -i l ] ~m:WKA1625wnonWf.non:1b-072795 F-6 . REVISION: 1

,~.() F 3.3 Component Water Level Determination The water level the exists between the dP cell taps can be calculated from the recorded dP cell data when flow is approximately 0 (friction losses are 0 or negligible). This is done as follows: Recorded dP data (psid) = paU144 g, + pg (h - L)/144 g, This numerically reduces to the following: L=[ ] / (p 3 - p ) As stated above, p, can be assumed to be 0 when system pressure is less' than 500 psia. This level can be converted to percent level using the following: % level = (Uh)

• 100%

Table F-2 lists the dP instruments that operate as described above. Also listed are the pressure and temperature instrument (s) that should be used to determine p., and p,in solving above equations. O i 1 a 1 I ( m:waai615.ao wr.non:ib-072795 F-7 REVISION: 1

F-4 Configuration 3 dP Cells i 4 F-4.1 Installation and Offsets \\ l Be instrumentadon/ characteristics of conDguration 3 UP tells are as follows: The normal direction of flow is in the DOWN direction. 1 . He positive (high-pressure) side of the dP cell is connected to the upper tap. The DAS subtracts the tap-to-tap elevation difference, converting this height of water to force (psi) using the following equation: P.Jh/144 g, F-4.2 Friction Loss Determination When the component is full of flowing water, the friction loss portion of the measured dP is calculated - as follows: Recorded dP data (psid) = dP at instrument - p.gh/144 g, Where the dP at the instrument equals the' positive tap pressure minus the negative tap pressure. Dat is, dP at instrument = (friction loss + p.,gh/144 g,) - p,4W144 g, Since the DAS subtracts p.,gh/144 g,, then Recorded dP data (psid) = friction loss (psid) - pah/144 g, and: Friction loss (psid) = recorded dP data (psid) + p.gh/144 g, F 4.3 Component Water Level Determination he water level that exists between the dP cell taps can be calculated from the recorded dP data when i the friction loss is negligible (when flow is approximately 0). This is done as follows: Recorded dP data = - (p JUl44 g, + p,(h - L) g/144 g,) mAa(WdXA1625wnonWf.oon:lt>o72795 - F-8 REVislON: 1

Ppi e< ~ ) . 'Ihis ' numerically reduces to the following: l L=[. ] / (p, 'p.J l As stated above, p, can be assumed to be 0 when system pressure is less than 500 psia. Also, this-level can be converted to percent level using the following: i % level = (11h)

• 100%

i Table F-3, lists dP instruments that operate as described above. Also listed are the pressure and temperature instruments that should be used to determine p;3 aM p, used in the above equations. +l 1 ~l =J i 5 D j . m:W1625woonwt.no : tdem 95 F REVISION:.1 ,,,i

f F-5 Configuration 4 dP Cells F 5.1 Installation and Offsets The installation / characteristics of the configuration 4 dP cells are as follows: De normal direction of flow is assumed to be DOWN. The positive (high-pressure) side of the dP cell is connected to the lower tap.. . - The DAS subtracts the tap-to-tap elevation difference, converting this height of water to force (psi) using the following equation: p.,gh /144 g, L The DAS reverses the signs of the taps. F 5.2 Friction Loss Detennination The friction loss portion of the measured dP when the component is full of flowing water is calculated as follows: 1 Recorded dP data (psid) = dP at instrument - p cgh /144 g, where the dP at instnament equals the (negative tap pressure) minus the (positive tap pressure). That is, dP at instrument = (friction loss + p.,hg /144 g.) - p,Ag /144 g, and Recorded dP data (psid) = friction loss - p.Ag /144 g. and l I l Friction loss (psid) = recorded dP data (psid) + p.Ag /144 g,. e l 1 mwi625.onwr.no.:ib.onns F.10. REVISION: I l l- __________________________j

j i ./ ~ F 5.3 - Component Water Level Determination The water level that exists between the dP cell taps can be calculated from the measured dP data when j the friction loss is negligible (for example, in large components such as tanks where level changes are relatively slow). 1 Recorded dP data = - (p,yU144 g, + p,(h - L)g/144 g,) This numerically reduces to the following: L=l 1/ (p. - p.n) A stated above, p, can be assumed to be 0 when system pressure is less than 500 psia. Also, level can be converted to percent level using the following: % level = (Uh)

• 100%

Table F-4 lists the dP instruments that operate as described above. Also listed are the pressure and temperature instruments that should be used to determine p., and p, used in the above equations. O 1 l \\ l w ) LO. l m:\\a;WXA1625 w oon\\ app-f.noe : l b-072795-F-11 REVISION: 1 i l

L l F 6 Conclusion / Summary hl The following equations have been derived for calculating the friction loss (in psi) from the dP data measured for the SPES-2 tests.' These equations (numerically reduced) are as follows: Configuration i dP cells : friction loss = dP data - p.3h/144 Configuration 2 dP cells : friction loss = p,nh/144 a dP data i Configuration 3 dP cells : friction loss = dP data + p,nM4 e Configuration 4 dP cells : friction loss = dP data + p,nh /144 The following equations have been derived for calculating the water level (in ft. H O) from the dP 2 data (in psi) measured for the SPES-2 tests. These equations (numerically reduced) are as follows: Configuration i dP cells : water level = [ ] / (p., - p,) Configuration 2 dP cells : water level = [ ] / (p,, - p,) - Configuration 3 dP cells : water level = [ ] / (p, - p,J Configuration 4 dP cells : water level = [ ] / (p, - p,J O O m:\\ap601A1625woonbpp f.noo:lb-072795 F-12 REVISION: I

P TABLE F-1 y SPES-2, Al'600 FULI.-IIEIGilT FULL-POWER INTEGRAI. SYSTEMS TEST t: SPES-2 CONFIGURATION 1 Di'-TRANSMITI'ERS 3 L-evel Reference g L'pper Tap Elev. Imtrument dP hicas. Range Nicas. Reference Ternp. Pressure Tag No. Imation Tap (+/-) IMfTer. (ft.) Range (psi) (psi) Range (ft.) Imtrument(s) (Note 1) j DP-000P Power channel nser 17.41 -8.70 to +8.70 -2.39 to +15.01 0 to 17.41 1001P + ToliP (overall) 2 7g DP-01 IP Power channel nser 4.86 -2.I8 to +5.08 -0.7 to +7.18 0 no 4.86 1U03P g Oxmorn) DP-012P Power channel nser 3.M -2.18 to +5.08 -0.6 to +6.65 0 to 3.64 TwP + Tol5P (bouom middle) 2 DP-013P Power channel nser (sop 3.M -2.18 to +5.08 -0.6 to + 6.65 0 to 3.64 TV01 + TUISP middle) 2 DP-014P Power channel nser (top) 2.84 -1.45 to +1.45 -0.19 to +2.71 0 to 2.84 TDl5P DP-018P lla leg A/ surge hoe 2.95 -1.45 to +1.45 -0.17 to +2.73 0 to 2.95 1 DISP DP-A04P llot leg-A 11.82 5.80 to +8.70 -0.68 to +13.82 0 to 11.82 TA03PO DP-BO4P lia leg-B 11.82 -5.80 to +8.70 -0.68 to +13.82 0 to I1.82 11103PO

• TI i

DP-A05P U-tube steam generator-A 16.82 -8.70 to +17.40 -1.41 to +24 69 0 to 16.82 TA06P + TA05P PA04P W (hot-leg side) 2 DP-B05P U-it.be steam generata-B 16.82 -8.70 to +17.40 -l.41 to +24.69 0 to 16.82 TB05P + T1106P PBG4P (hot les side) 2 DP-A06P U-Tube steam generator-A 12.30 -5.80 to +8.70 -0.47 to +14.03 0 to 12.30 TA06P + TAOMP PA04P Olet-les side toim) 2 DP-B06P U-tube steam generator.B 12.30 -5 80 to +8.70 -0.47 to +14.03 0 to 12.30 B06P + TBORP PB48P OIL Side to tm) 2 DP-A15P Power chmanet upper 3.33 -2.18 to +2.18 -0.73 to +3.62 0 to 3.33 TOISP plenunAct leg-A DP-BI5P Power channel iapper 3.33 -2.18 to +2.18 -0.73 to +3.62 0 to 3.33 TV15P plenum / hot leg B DP-A20E Accumulator-A lajection 10 96 -7.25 to +29.0 -2.5 to +33.75 0 to 1096 TA23P PA20E hae DP-B20E Accumulator-B Injection 10.96 -7.25 to +29.0 -2.5 to +33.75 0 to 1096 TB23P PB20E hae DP-A81 AE PRilR supply bae 8.63 -7.25 to +7.25 -3.51 to +10.99 0 to S.63 TAR 2E + TASIE y m 2 G 3 1. hessure channel P027P (Fessunzer gressure) shall be used as the reference pressure instrument, unless otherwise acaed. .4 k ____._____.3

M TABLE F-2 ~ SPES-2, AP600 FUL1 HEIGHT FULL-POWER INTEGRAL SYSTEMS TEST g e SPES-2 CONFIGURATION 2 DP-TRANSMrlTERS 8s Reference Upper Tap Dev. Imtrument Range dP Meas. Range level Meas. Reference Presore Tag No. Location Tap (+/-) Defeer. (ft.) (ps4 (ps4 Range (ft-) Tesaperneure (% e1) .~ DP4MMP Power channel lower p!enum + 3.06 -435 to 435 +1.33 to +5.68 0 to 3.06 IUntP b ti DP.005P Power channel riser + 2.43 -2.90 to 2.90 -1.85 to +3.95 0 to 2.43 TUO3P DP419P Swge hoe + 2.43 -3.63 to 3.63 -2.57 to 4M 0 to 2.43 'IDI8P DP420P Surge hoe + 11.24 -7.25 to 7.25 -238 to 12.12 0 to 11.24 T020P DP-02 tP Presswuer + 4.74 -2.90 to 2.90 -0.85 to 4.95 0 to 4 74 T021P DP-022P hessunm + 4.74 -2.90 to 2.90 -0.85 to 4.95 0 to 4.74 1D22P DP-023P Pressunm + 4.74 -2.90 to 2.90 -0.85 to 4.95 0 to 4.74 TV23P [ DP424P Pressunm + 4.74 -2.90 to 2.90 -0.85 to 4.95 0 to 4.74 TU24P DP.025P Presswim + l.41 -1.45 to I.45 -0.84 to 2.06 0 to 1.41 TD25P DP-026P Pressunm + 1.05 -1.45 to 1.45 -0.99 to 1.91 0to1.05 T026P DP-027P Pressunm + 0.77 -1.45 to I.45 -1.12 to 1.78 0 to 0.77 TV26P DP.AGIS Steam generata-A nser + +13.06 0 to 7.25 -1.59 to 5.66 0 to 13.06 TA05S PA04S DP.BOIS Steam generata.B tiser + + 13.06 0 to 7.25 -159 to 5.66 0 to 13.06 IB05S PBass DP.A02S Steam generator-A nser + +2133 0 to 10.15 -0.91 to 9.24 0 to 2133 TAGES PA04S DP-B02S Steam generator-A nser + +2133 0 so 10.15 -0.91 to 9.24 0 to 21.33 1308S PBG4S + 10.50 7.25 to 7.25 -2.70 to 11.80 0 to 10.50 TA03S PA04S DP-A03S Steam generator-A separator + 10.50 -7.25 to 7.25 -2.70 to 11.80 0 to 10.50 TB035 PBn4S DP.B03S Steam generator-B separator + 2.21 -1.45 to 1.45 -0.49 to 2.41 0 to 2.21 TA03S PA04S DP-A04S Steam generator-A separator h DP-Bo4S Steam generator-B separator + 2.21 -1.45 to I.45 -0.49 to 2.41 0 to 2.21 TB03S PBG4S El I. Presswe dianael P027P (gessurim Fesswe) shall be used as the reference pressure instrument, unless otherwise noted. O O e

(- u_j q) v ilc3g TABLE F-2 (Cont.) SPES-2, AP600 FULL-ilEIGitT FULL-POWER INTEGRAL SYSTEMS TEST y SPES-2 CONFIGURATION 2 DP-TRANSMITTERS (Cont.) l'pper Reference Referviuv g Tap Tap Elev. Instrument Range dP Meas. Level Meas. Temperature Pressure Tag No. location ( +/-) Differ. (ft.) (psu Range (psh Range (ft-) Instrumenus) INote 1) 7 k DP-A05S Steam generator-A dryer + +2.26 0 to 1.45 -0.47 to 0.98 0 to 2.26 TA04S N/A T + +2.26 0to 1.45 -0.47 to 0.98 0 to 2.26 TTIMS N/A g DP-8055 Steam generator-B dryer 3 DP-A06S Steam generator-A nser + + 7.05 0 to 4.35 -l.29 to 3.06 0 to 7.05 TA075 PAMS DP.B06S Steam generator-B riser + + 7.05 0 to 4.35 -1.29 to 3.06 0 to 7.05 11107S PB04S DP-A4 t E GlT-A (bottom) + + 5.10 0 to 2.61 -0.40 to 2.21 0 to 5.10 TA4ISE to TA420E PA40E 6 DP-A42E CMT-A dow middle) + + 5.10 0 to 2.61 -0.40 to 2.21 0 to 5.10 TA41IE to TA415E PA40E 5 DP-A43E CMT-A dugh nuddle) + + 5.10 0 to 2.61 -0.40 to 2.21 0 to 5.10 TA407E to TA411E PA40E 7 ~.n DP A44E GlT-A (tm) e + + 5.10 0 to 2.61 -0.40 to 2.21 0 to 5.10 TA401E in TA407E PA40E 7 DP-B4t E GlT-B (bottom) + + 5.10 0 to 2.61 -0.40 to 2.21 0 to 5.10 114415F. 417E. 420E PB40E 3 DP-B42E CMT-B (Iow nuddle) + + 5.10 0 to 2.61 -0.40 to 2.21 0 to 5.10 1B411E + TB411E PB40E 2 + 5.10 0 to 2.61 -0.40 to 2.21 0 to 5.10 TB1407E + TB409E PB40E DP-B43E CMT-B Ough nuddle) 2 + 5.10 e to 2.61 -0.40 to 2.21 0 to 5.10 1B401E. 401E. 405E PB40E DP-B44E GlT-B trop) 3 DP-A45E CMT-A cold leg balance line + 23.71 -2.90 to 11.60 -1.33 to o to 23.71 TA14IP + TAI 41P PA40E 13.17 2 + 23.71 -2.90 to 11.60 -1.33 to O to 23.11 11tl41P + TAl4tP Pil40E DP-B45E CMT-B cold leg tulance line I3.17 2 y DP A8!E PRilR supply hne + 26.27 -2.90 to 11.60 -0.22 to O to 26.27 TA8IE + TAR 2E 14.28 2 5 1. Pressure channel P027P (gessuriier pessure) shall be used as the reference pressure instrun... unless otherwise noted.

il TABLE F-3 SPES-2, AP600 FULL-IIEIGIIT ITJI.L POWER INTEGRAL SYSTEMS TEST ti SPFS-2 CONFIGURATION 3 DP-TRANSMrlTERS 3 g Level ( l'pper Meas. Reference Reference Tap Tap Des. Instrurnent dP Meas. Range Range Temperature Pressisre Tag Na taration (+/-) thfrer. (fL) Range (pd) (psil (ft) lastnseent(s) (%4e il o 2 DPMilP Ponte channel astelar downuwaer (topt + 8 34 0 to 14 50 -3 63 to +10 87 1 to 8 34 T00lP Tg DP402P Power chmael asbular downcomer (tantosa) + 8 89 0 to 14.50 -3 85 to +10 65 3 to 8 89 T003P DP403P DC to PC D + 0 79 0 to 10.15 -0 34 to 9 81 ) to 0.79 TtotP + TUMP 2 DP417P Po=cr channel upper lead + 6.20 0 to 7.25 -2 69 to +4.56 3 to 6.20 11)l6P DP-A00lP Cold leg-Al + 3 45 0 to 7.25 -1.49 to +5 76 ) to 3 45 TA3 tit DP-B00lP Cold les-BI + 3 45 0 to 7.25 -149 to +5.76 > to 3 45 TB3tPl. DP-A002P Cold Icg. A2 + 345 0 to 7.25 -1.49 to +5 76 1 to 3 45 TA32It DP-B002P Cold leg-82 + 3.45 0 to 7.25 -1.49 to +5.76 3 to 3 45 TB32PL + 4 08 0 to 10.15 -1.77 to +8.38 ) to 4 08 TA021Po + 1m1P DP-ACCIP Cold leg-Allpower channel downconner ? + 4 08 0 :o 10.15 -l.77 to +8 38 3:o 4 08 TB021rO + Tim!P g DP-802iP Cold leg-Bl/pomer channel downconner 2 DP-A022P Cold leg-A2/ power channel dowacommer + 4 08 0 to 1015 -1.77 to +8 38 ) to 4 08 TA002M) + Tt41P 2 + 4 08 0 so 10.15 -1.776 +8.38 ) to 4 08 TBa22Po + TUDIP IVl7P DP-B022P Cold leg-B2/poucr channel domsw 2 DP-A07P U-asbe steara geacrator-A + 12.30 -4.35 to 10.15 -9 68 to +4 82 t to 12.30 TA06P + TA08P 2 ( 9 to cold-leg side) DP-B07P U-ambe steam generasus B + 11.30 -4.35 to 1015 -9.68 to +4 82 t: to 12.30 TB06P + ITIORP 2 tag to cold-leg sade) DP-A08P U-ashe steam geacrakr-A (cold leg sede) + 16 82 -8.70 to 14.5 -15.99 to +7.21 ( to 16.82 TA09P + 16 82 -8.70 to 14.5 -15 99 to +7.21 ( to 16 82 TB09P DP-B08P U-ashe sacarn gecerakr-B (col & leg side) DP-A09P Steam generamr-A to RCP A + 5.80 0 to 14.5 -2.51 to +11.99 3 to 5.80 TAIOP DP B09P Sacaen generskr-B to RCP B + 5 80 0 to 14.5 -2.51 to 11.99 1 to 5 80 TBIOP DP-A16P llot leg-A/ power channel upper plenum + 119 0 to 19 -0 95 to +1.95 3 to 2.19 1U15P 73 DP-Bl6P llot leg-R/ power channel upper plenum + 119 0 to 2.9 -0 95 to +1.95

) to 219 TUl5P tr7$

DP-A28P CMT-A pressuruer hal-are ime + 15.21 0 to 14.5 -6 59 to +7.9I ( to 15.21 TA28P d 1 Preswre diannel P027P (Pressunter lYessure) shaB be used as the reference pressure utstrument. imless otherwise noted O e

.._........m p ',s* D 9 TABLE F-3 (Cont.) SPES-2, AP600 FUI.L-HEIGHT FULL. POWER IN1TGRAL SYSTEMS TFST y SPES-2 CONFIGURATION 3 DP-TRANSMITTERS (Cont.) h Reference Reference 'f Upper Tap Eles. Indrusment Range dP Nicas. Rante 1.evel Meas. Tesaperature Pressere 7 Tag No. Le,.aw Tap (+/-) Differ. (ft.) tydn (psi) Range (fL) Insensaments (Nede 1) k DP-B28P CMT.B pressurim + 15.21 0 to 14.5 -6.59 to 7.91 0 to 15.21 1B28P y talance Isee b DP-A40E CMT-A injection lane + 8.58 -3.63 to 15.25 -7.34 to 11.51 0to 8.58 TA421E PA40E 2 DP-B40E ChfT-B iajectioa tine + 8.58 -3.63 :o 15.25 -7.34 to ll.51 0:o 8.58 IB421E PB40E DP-A6tE IRWSTinjection line A + 3.33 0 to 14.5 -1.44 to 13.06 0 to 3.33 TD6SE 12.5 psig DP-86t E IRWST injection line B + 3.33 0 to 14.5 -1.44 to 13.06 0 to 3.33 TD65E 12.5 psig DP-A8 t BE PRIIR segply line + 8.63 -7.25 to 7.25 -10.99 to 3.51 0 to 8.63

TA82f, DP-A82E PRilR heat exchanger

+ 17.65 -5.80 to 8.70 13.45 to 1.05 0 to 17.65 TA82E + TARW 2 DP-A83E PRiiR return line + 3.71 0 to 7.5 -1.6ItoS M 0 to 3.71 TA83E 7 G l. Pressure diassel P027P Quessuruer gressure) shall be used as the reference pressure instrument. unless otherwise noted.

• C rn Eo?

4 --a P TABLE F-4 2 SPES-2 Al%49 INTEGRAL SYSTEMS TEST f SPES-2 CONFIGURATION 4 DP-TRANSMITTERS E Tap Level f Upper Elev. Meas-Reference Reference { Tap INffer. Instrument dP Meas. Range Temperature IYessure Tag No. Location (+/-) (ft.) ~ Range (psi) Range (psi) (ft.) Instruments (Note 1) u ' vS-DP-A00P RCP-A 1.11 0 to 101.5 -101.98 to O to 1.11 TAllP P027P 4 y -0.48 DP-BOOP RCP-B ' 1.11 0 to 101.5 -101.98 to O to 1.11 TBilP P027P 4).48 ? E E &s .3 ~ O e e

%J. 1 1 APPENDIX G j SPES-2, AP600 FHFP INTEGRAL SYSTEMS TEST DATA FILES l i l l l l s j 1 m;ug m i6:5*k m c non s o72795 G-1 REVISION: 1

n. G1 SPES 2 Data Files g Table G-1 provides a listing of the SPES-2 test data files. Note that this file listing has been ulxiated - to include the hiind tests (S00908, S01211, and S01512), and the file for DP-000P has been corrected to reflect the proper reference leg height. ' The table also identifies the' size of each~ file and the file preparation time and date identifier. O l i lc I-e mvvis25.wa amib.072795 G-2 REVISION: I

) 1 (].. TABLE G 1 SPES 2 TFST DATA FILES Matrix File Identifier File Size Test No. File Name Date/ rime (bytes) S00303 s00303. Master. Data June 17 - 17:02 41923628 S01703 s01703. Master. Data June 17 20:09 47923478 S00504 s00504. Master. Data June 17 17:29 56158568 S00401 s00401. Master. Data June 17 - 17:16 88209248 S01613 s01613. Master. Data June 17 20:11 87350076 S00605 s00605. Master. Data June 17.17:40 44507665 S00706 s00706. Master. Data June 17 17:41 39469411 ^ S01007 s01007. Master. Data June 17-17:48 48774386 S00908 s00908. Master. Data June 17 17:44 37443 % 8 S01309 s01309. Master. Data June 17 20:01 80791853 ] S0ll10 s01110. Master. Data June 17.17:55 94652474 S01211 s01211. Master. Data June 17 19:08 114729517 S01512 s01512. Master. Data June 17e 19:57 39897456 m:\\aptaA1625whG.noo:lbo72795 G-3 REVISION: 1 i ..}}