ML20093N172
| ML20093N172 | |
| Person / Time | |
|---|---|
| Site: | Crystal River  |
| Issue date: | 09/30/1984 |
| From: | Birmingham D, Childerson M, Rush G BABCOCK & WILCOX CO. |
| To: | |
| Shared Package | |
| ML20093N159 | List: |
| References | |
| RDD:84:4091-24, NUDOCS 8410310437 | |
| Download: ML20093N172 (200) | |
Text
{{#Wiki_filter:_ .__ _ _ _ __ ._. - _ _ _ _ _ _ _ _ . . _ . _ . _ I. U l ex [ I I Once-Through Integral System Test Program OTIS Loop Functional Specification i < RDD:84:4091-24-01:01 ; ] Prepared By: 0 The Babcock & Wilcox Company Research and Development Division g Alliance Research Center 3 ICT r r L UNITED STATES NUCLEAR REGULATORY COMMISSION Office of Nuclear Regulatory Research 7915 Eastern Avenue LI O
- l. Silver Spring, Maryland 20910 September 1984 and h
. B&W OWNERS GROUP and ELECTRIC POWER RESEARCH INSTITUTE, INC.
P.O. Box 10412 3412 Hillview Avenue Palo Alto, California 94304 Principle Investigators: ARC DP Binningham MT Childerson GC Rush 8410310437 841022 ,/ PDR ADOCK 05000302 P PDR (% 0 l
1 QUALITY ASSURANCE STATEMENT r l To the best of my knowledge and belief, the material presented in this report was conducted in accordance with the following Quality Assurance Plan: Once-Through Integral Test Program (OTIS), 8/2/83 QA 83014 George W. Roberts Manager, Quality Assurance Alliance Research Center O I o
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i
SUMMARY
I
! This report contains documentation of the Once-Through Integral System (OTIS)
Tcst Facility built at the Alliance Research Center. This facility, known as OTIS, was a scaled simulation of a Babcock & Wilcox raised loop, 205 Fuel Assembly (FA) Pressurized Water Reactor. The test facility was originally built and tested for Brown-Boveri Reaktor (BBR) under contract to the Utility Power Generation Division (UPGD). The test program for BBR was called GERDA and is referenced throughout this report. Facility modifications were made at the completion of i GERDA and additional tests were performed as part of the Integral Systems Test Program sponsored by the Nuclear Regulatory Commission, EPRI, B&W Owners Group and B&W. f The test facility was designed to evaluatt the post - small break loss of coolant accident (SBLOCA) thermal-hydraulic events expected to occur in the B&W 205 FA plant. The facility was used to perfom separate effect and integral system tests at scaled power levels up to 3.7%. The objective of the program was g to obtain experimental data for the verification and/or refinement of the Vanalytical models used to predict plant perfomance during SBLOCA transients. The purpose of this report is to document the OTIS mechanical design features, instrumentation, data acquisition, loop controls, and results of the loop characterization tests (performed during the GERDA test program as well as during the OTIS test program). This report is divided into three volumes. The main text and its supporting documentation, Appendices A through E, are contained in Volume 1. The mechanical 1 and electrical drawings for the test facility are contained in Volumes 2 and 3, respectively. The main text includes an introductory section which describes the purpose of the loop, the loop components and instrumentation, and summarizes the scaling considerations. The key features of the test loop are described in Section 2. A 1 detailed description of each OTIS sub-system is included in Section 3. Results of I p the loop characterization tests are contained in Section 4 and include results l (_/ from the GERDA test program as well as the OTIS test program. I A-1
TABLE OF CONTENTS Section Page
1.0 INTRODUCTION
------------------------------------------ 1-1 2.0 KEY FEATURES OF TEST LOOP ----------------------------- 2-1 3.0 OTIS SUB-SYSTEMS -------------------------------------- 3-1 3.1 Reactor Yessel and Downcomer -------------------- 3-3 3.2 H o t L e g P i p i n g ---------------------------------- 3-14 3.3 Steam Generator --------------------------------- 3-19 3.4 Cold Leg Piping and Primary Forced Circulation Sy s t e m - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 29 3.5 P re s s u r i z e r - --- -- -- -- -- - - ------- -- - -- -- -- - - -- --- 3-36 3.6 High Pressure Injection and Facility Water S upply and Cl e a n-Up Sy stem ---------------------- 3-43 3.7 P rima ry Ye nti ng Sy stems ------------------------- 3-48 3.8 Secondary Forced Circulation System and Feed-Wa te r H e a te r s ------------------- ---- ------------ 3-55 3.9 Feedwater Piping -------------------------------- 3-60 3.10 Steam Piping ------------------------------------ 3-60 3.11 Secondary Low-Pressure Cleanup System (SLPCUS) -- 3-67 3.12 Noncondensibl e Gas Addi tion -------------------- 3-67 3.13 Data Acqui sition Sy stem (DAS) ------------------- 3-72 3.13.1 Initial Data File Processing ------------ 3-76 3.13.2 Post Processing of the Data File -------- 3-80 3.13.3 User Input for Definition of the OTIS YT ABL E D a ta b a s e ------------------------- 3-83 l @
TABLE OF CONTENTS (Cont'd) Section Page 4.0 LOOP CHARACTERIZATION TESTS --------------------------- 4-1 4.1 Hel i um L e ak Te s t -------------------------------- 4-1 4.2 Discharge Orifices - Vapor and Liquid Region ---- 4-3 4.3 Two-Phase Venting System - Checkout Test -------- 4-8 l-4.4 Irrecoverable Pressure Loss Characterization - Fo rwa rd and Reverse Fl ow ------------------------ 4-9 4.5 Heat Loss --------------------------------------- 4-10 4.6 Guard Heater Characterization ------------------- 4-17 4.7 Stored Metal E nergy Ef fec ts --------------------- 4-21 4.8 Calibration of Primary Flow Elements ------------ 4-29 4.9 Calibration of Feedwater and Steam Flowmeters --- 4-34 4.10 Filled Noncondensible Gas Test ----------------- 4-36 4.11 Temp e ra tu re C al i b ra ti o n s ------------------------ 4-39 4.12 Loop Volume Measurements Versus Elevation ------- 4-40 V i i l iU o l l l
. _ . ._.___ _ _ , _ _ _ . _ _ _ _ . _ . . . _ . . _ _ _ _ ______,_._____.,__m.__________.___._______ ..
i LIST OF APPENDICES Appendices Page O A OTIS FACILITY DRAWING $ L' W A-1 ,. B INSTRUMENTATION AND VALVE DESIGNATION B-1 C OTIS INSTRUMENT LIST C-1 D VTAB DATA CARDS-PARAMETERS AND FORMAT D-1 E L QT OF PHAS_E_0,ANS CHARACTERIZATION TESTS E-1 (GERDA AND OTIS) O I O
I l i 1 l LIST OF TABLES _ 7- ' V Page Table 3-1 Comparison of Key Elevations -- OTIS,vs - 3-2 Mulheim Karlich (MK) 3-2 GERDA Volume Checks 3-3 3-3 Reactor Vessel Vent . Valve Flow-AP Measurements 3-7 ( t 3-4 Reactor Vesse'l< Vent Valve Response Time 3-9 3-5 Manufacturers' Specified Flow Coefficients 3-14 for Valves in Reactor Vessel i 3-6 Elevation of Hot Leg Guard Heater 3-19 Zones and Control Thermocouples n 3-7 Elevation of Multi-Junction Thermocouple Junctions 3-26 3 '8 Manufacturers' Specified Flow Codfficients 3-39 for Valves in the Pressurizer
% 3-9 Feedwater Valve Position for 3' Feet Per Minute 3-58 ID Level, Increase V Feedwater Valve Positions for Simulating the 2-58 3-10 Davis-Bessee AFW Head-Flow
- Curve -
Steam Control Valves' Response Time 3-64 p 3-11 . 3-12 Gas Addition Reservoir Volumes 3-70 3-13 Accuracy and Resolution of the Analogic ANDS 5400 3-72 3-14 Comand Procedures for Enhineering Data Files 3-80 3-15 QA Documents for Source Codes and Comand Procedures 3-84 4-1 Loop Characterization Test Categorfes 4-2 a
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LIST OF TABLES (Cont'd) Table Page 4-2 Calibration Results for GERDA Leak Flow Orifices 4-(O' 4-3 Comparison of Gas Removed With Initial 4-8 Gas Volume In Loop 4-4 Comparison of GERDA Measured and SAVER 4-10 Predicted .1Ps j 4-5 Effect of Steaming Rate on Stored Energy 4-28 i Release
. 4-6 Superheat Produced by Stored Energy Release 4-28 l 4-7 Total Gas Content Prior To Voided Primary OTIS 4-39 Tests ' rte tc 'nc4uded-1+ter4--
O i f I O I
LIST OF ILLUSTRATIONS U Figure Page 1-1 OTIS Test Facility 1-3 1-2 Comparison of Full-Size 205 Fuel Assembly 1-5 Plant OTSG to 19-Tube OSTG in OTIS 1-3 Plant and Model HLUB 1-7 1-4 Comparison of Full-Size 205 Fuel Assembly Plant 1-8 l Reactor Yessti to OTIS Reactor Simulation i 1-5 Comparison of Full-Size 205 Fuel Assembly 1-10 Plant Cold Leg to OTIS Cold Leg 1-6 OTIS Instrumentation 1-13 1-7 OTIS Differential Pressure Measurements 1-14 2-1 OTIS General Arrangement 2-2 2-2 Leak Flow Control Orifice Assembly 2-3 O 2-3 Leak Flow Control Orifice 2-4 (d 2-4 Guard Heater Concept 2-6 3-1 Reactor Vessel and Downcomer General Arrangement 3-5 3-2 RVVV Arrangement and Flow Characteristics 3-8 3-3 Reactor Vessel Heater Response to a 60 KW Power Increase 3-11 3-4 Reactor Yessel and Downcomer Instrumentation -- 3-12 Thermocouples, RTDs and Conductivity Probes 3-5 Reactor Vessel and Downcomer Instrumentation 3-13
-- Pressure and Differential Pressure Measurements 3-6 Hot Leg Piping General Arrangement 3-15 3-7 Hot Leg Instrumentation - Thermocouples, RTDs, 3-17 Conductivity Probes and Viewports 3-8 Hot Leg Instrumentation -- Differential 3-18 Pressure Measurements j 3-9 19-Tube Once-Through Steam Generator 3-20 Oi v
4
LIST OF ILLUSTRATIONS (Cont'd) Figure Page O 3-10 Comparison of 19-Tube and Prototypical 3-21 OTSG Tube Support Plates 3-11 OTSG Temperature Measurements and Tube 3-23 Support Plate Elevations 3-12 OTSG Pressure and Differential 3-24 Pressure Measurements 3-13 Radial and Circumferential Location of Primary 3-25 Fluid and Primary Metal Thermocouples 3-14 Radial and Circumferential Location of 3-27 Secondary Fluid Thermocouples 3-15 Location of Multi-Junction Thermocouples, Pitot 3-28 Tubes and AFW Nozzles 3-16 Cold Leg Piping-General Arrangement 3-31 3-17 Cold Leg Piping-Temperature and Flow Measurements, 3-32 Location of High Pressure Injection and Cold Leg Leaks 3-18 Cold Leg Piping-Differential Pressure Measurements 3-34 3-19 Primary Forced Circulation Loop 3-35 l 3-20 Pressurizer-General Arrangement 3-37 3-21 Surge Line Layout 3-38 3-22 Pressurizer Guard Heater Bias for Adiabatic 3-41 Pressurizer for Tests Prior for April 3,1984 3-23 Pressurizer Instrumentation 3-42 3-24 High Pressure Injection System 3-44 3-25 GERDA 4 Pump HPI Head-Flow Curve 3-46 3-26 OTIS " Nominal" HPI/LPI Head-Flow Characteristic 3-47 3-27 Facility Water Supply and Cleanup System 3-49 O
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LIST OF ILLUSTRATIONS (Cont'd)
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j- Figure Page 3-28 Single-Phase Venting System-General 3-51 j Arrangement and Instrumentation 3-29 Two-Phase Venting System-General 3-52 Arrangement and Instrumentation 3-30 Two-Phase Venting System -- Differential 3-54 Pressure Measurements I, 3-31 Secondary Forced Circulation System-General 3-56 Arrangement and Test Instrumentation 3-32 Auxiliary Feedwater (AFW) Scaled 3-59 Head-Flow for Davis Bessee Plant [ 3-33 Feedwater Piping System-General 3-61 Arrangement and Instrumentation j 3-34 Steam Piping-General Arrangement 3-62 L ' Location of Steam Exit Pipe on OTSG 3-63 3-35 3-36 Steam Piping Instrumentation 3-65' 3-37 Secondary Low Pressure Clean-Up System General 3-68 Arrangement and Instrumentation l 3-38 Gas Addition System-General 3-69 Arrangement and Instrumentation 3-39 Gas Addition Locations 3-71 3-40 OTIS Data Acquisition System 3-73 3-41 Initial Processing of OTIS Raw Data File 3-77 3-42 Follow-Up Processing of OTIS Raw Data File 3-82 1 4-1 Measured and Predicted Critical Flows 4-6 1 2 4-2 Critical Water Flow for a Scaled 9.8 CM Leak 4-7
.4-3 - GERDA Loop Heat Loss 4-12 4-4 GERDA Steam Generator Heat Loss 4-13 ,
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LIST OF ILLUSTRATIONS (Cont'd) Figure Page 4-5 GERDA Reactor Vessel Heat Loss (No Guard Heaters) 4-14 4-6 .GERDA Cold Leg Heat Loss 4-15 4-7 GERDA Hot Leg Heat loss 4-16 4-8 GERDA Hot Leg Fluid Temperatures With and Without 4-19 Guard Heaters 4-9 Hot Leg Guard Heater Model 4-22 4-10 Predicted Fluid and Metal Temperatures In Vapor 4-24 I Region of Hot Leg Pipe During Depressurization -- 10 LB/Hr 4-11 Predicted Fluid and Metal Temperatures In Vapor 4-25 Region of Hot Leg Pipe During Depressurization -- 20 LB/Hr 4-12 Predicted Fluid and Metal Temperatures In Vapor 4-26 Region of F't Leg Pipe During Depressurization -- 100 LB/Hr 4-13 Predicted Fluid and Metal Temperatures In 4-27 Stored Heat Release Rate Versus Time In Vapor Region of Hot Leg 4-14 Flow Loop Arrangement for Venturi Calibration 4-30 4-15 Venturi Flow Coefficient 4-32 4-16 Cold Leg Orifice Flowmeter Calibration Data and 4-35 Curve Fit 4-17 Low Range Feedwater Orifice Calibration Data and 4-37 Curve Fit # 4-18 Low Range Steam Flow Orifice Calibration Data and 4-38 Curve Fit 4-19 Pressurizer Volume Versus Elevation 4-42 l O r
I l LIST OF ILLUSTRATIONS (Cont'd) Figure Page i l 4 Reactor Vessel Volume Versus Elevation 4-43 ) 1 4-21 Hot Leg Active Region Volume Versus Elevation 4-44
, 4-22 Cold Leg and Downcomer Active Region 4-45 Volume Versus Elevation 4-23 Steam Generator Primary, Hot Leg and Cold Leg In- 4-46 Active Region Volume Versus Elevation l
4-24 Steam Generator Secondary Volume Versus Elevation 4-47 l l r O I
TABLE OF ABBREVIATION Abbreviation Definition O f 177FA 177 Fuel Assembly 205FA 205 Fuel Assembly J AFW Auxiliary Feedwater i ARC Alliance Research Center B&W Babcock & Wilcox BBR Brown Boveri Reaktor CDC Control Data Corporation i CLD Cold Leg Discharge I CLS Cold Leg Suction
-DAS Data Acquisition System DB Davis-Bessee DC Direct Current DEC Digital Equipment Corporation DP Differential Pressure GERDA Geradrohr D_ampfergeuger A_nlage meaning straight-tube steam generator (test)
HLUB Hot Leg U-Bend HPI High Pressure Injection HPV High Point Vent ID Inside Diameter KW Kilowatt LPI Low Pressure Injection LTS Lower Tubesheet MK Mulheim Karlich MWT Mega-Watt Themal
i-t TABLE OF ABBREVIATION (Cont'd)
/ ,T. ,k) j- Abbreviation Definition NCG Noncondensible Gas OD Outside Diameter OTIS Once-Through Integral System (Test)
- 1
. OTSG Once-Through Steam Generator j PORY Power Operated Relief Valve QA Quality Assurance II QQLP Quick-Quick Look Plots RCP- Reactor Coolant Pump RTD_ Resistance Temperature Detector RVVV Reactor Vessel Vent Valve SBLOCA Small Break Loss of Coolant Accident
- SFLTS Secondary Face of the Steam Generator Lower Tubesheet TC Thermocouple TSP Tube Support Plate TVA Tennessee Valley Authority UPGD Utility Power Generator Division -
UTS Upper Tubesheet VTAB Variable Table Entry O
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1.0 INTRODUCTION
O Phase 1 of a contract between the NRC, owners of B&W nuclear steam supply systems, B&W, and EPRI, involved modifications to and testing of the GERDA l facility at B&W's Alliance Research Center. This experimental test facility was designed to evaluate the thermal / hydraulic conditions in the reactor coolant e system and steam generator of the Mulheim Karlich (MK) plant, a raised-loop B&W lI 205 fuel assembly, pressurized water reactor during the natural circulation phases Of a small break loss-of-coolant accident (SBLOCA). The test facility was a 1 x 1 l (one hot leg, one cold leg) electrically heated loop specifically simulating the important featuras of a raised loop plant. The facility was used to perfonn ,i l separate effect and integral system tests at simulated scale power levels of about I to 5%. Modifications were made to GERDA to support the subject Phase 1 workscope of the renamed facility, OTIS. Specifically, the OTIS facility modifications consisted of the following items: e Addition of a reactor vessel head vent and flow restrictor between the upper plenum and upper head of the reactor vessel e Addition of guard heaters to the upper plenum and upper head of the reactor vessel e Addition of a guard heater to the pressurizer surge line e Relocation of the cold leg flow measurement orifice by adding a flanged section in the cold leg near the steam generator outlet e Installation of a branched leak of the cold leg suction piping with a thermocouple for fluid temperature measurement e Installation of a string thermocouple in one of the steam generator tubes (a string thermocouple was added to a second tube but experienced early failure) and pitot tubes at the outlet of three steam generator tubes e Installation of control valve limit switches for the high and low i- flow feedwater and steam circuits to indicate valve closure e Relocation of the lower tap for the cold leg suction piping differential pressure measurement. O 1-1
The general arrangement of the major components and systems of the OTIS Test (j Facility is shown in Figure 1-1. The loop consisted of one 19-tube Once-Through j Steam Generator (OTSG), a simulated reactor, a pressurizer, a single hot leg, and a single cold leg. Reactor decay heat, following a scram, was simulated in the test loop by electrical heaters in the reactor vessel. No pump was included in the main primary loop, but a pump in an isolatable cold leg bypass line was
. available to provide forced primary flow. The test loop was full raised-loop ! plant elevation, approximately 95 feet high, and shortened in the horizontal plane (to approximately 6 feet) to maintain approximate volumetric scaling.
Other primary loop components included a reactor vessel vent valve (RVVV), pressurizer pilot-operated relief valve (PORV) or safeties, and a hot leg high l point vent (HPV). Auxiliary systems were available for scaled high pressu e injection (HPI), controlled primary leaks in both the two-phase and single-phase region, a secondary forced circulation system for providing auxiliary feedwater (AFW) to the OTSG, steam piping and pressure control, a cleanup system for the secondary loop, and gas addition for the primary loop, o 1 The configuration of the test loop was dictated by scaling considerations , The four scaling criteria used to configure OTIS, in order of priority, were: e Elevations e Post-SBLOCA Flow Phenonena e Volumes e Irrecoverable Pressure Loss Characteristics SBLOCA fluid behavior is typically buoyancy driven; therefore, full elevation modeling was assigned first priority. To obtain flow phenomena in the test loop l as close to plant-typical as possible, the governing phenomena were determined, I Details of scaling considerations are presented in Design Requirements Specifica-U tion for GERDA, b
- Document No. 12-1123163-01, July 1981, and in the OTIS Design
! Requirements, B&W Docu...ent No. 51-1149127-00, February 1984.
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fqcvaluated, and accommodated as second priority in the scaling criteria. VVolumetric scaling of the loop components was generally possible, but was assigned third priority. The last major scaling criterion was the loop irrecoverable pressure losses. When the other scaling considerations were accommodated, irrecoverable losses were adjusted to plant-typical by the inclusion of flow restrictors in expected single-phase water locations in the loop. t OTIS power and volume scaling originated with the size of the model OTSG
, shown in Figure 1-2. The model OTSG contained nineteen (19) full-length and i plant-typical tubes, which represented the 32,026 tubes in the two steam generators used in the 205-FA plants. Therefore, the dominant power and volume j scaling in the loop was:
Scaling Factor = 2 x 1 013 As indicated in Figure 1-2, the distance between secondary faces of the lower f and upper tubesheets in the 19-tube OTSG was full length. Auxiliary feedwater l nozzles were located in tne model steam generator at two elevations. The low AFW nozzles were located in an elevation approximately plant-typical of MK. The model also had high AFW nozzles located at an elevation typical of the 177 Fuel Assembly Plants. The tubesheet thicknesses in the model 0TSG were not plant-typical, and the inlet and outlet plenums were reducers. Therefore, the hot leg-L to-steam generator inlet and steam generator-to-cold leg elevations were atypical. Piping runs beyond the steam generator and plenums were used to retain plant-typical elevations. For example, Figure 1-2 indicates that the hot leg U-bend elevation of the plant was matched in OTIS. The hot leg inside diameter was scaled to preserve Froude number, and thus the ratio of inertial to buoyant forces. This criterion was considered to preserve two-phase flow regimes and flooding phenomenon according to correlations g of Dukler-Taitel and Wallis, respectively. Scaling with Froude number resulted in !c a hot leg diameter twice the diameter indicated by ideal volumetric scaling. Although this added approximately 20% to the ideal system volume (total loop 3 I (O 1-4
l l l l i ( 4 HOT LEG U BEND R ADIUS e 1.24' O SPILLOVER , RADIUS = S' l OTIS UPPER UPPER / HOT LEG TUDESMEET TUSESHEET f&G9&?&#?A?%& 'J I Q HIOM AUXIUARY d' . l LOWER FACE OF FEEDWATER NOZ2LE UPPER TUDESMEET
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peOTE: COMPONENTS ARE ORAWN TO SCALE IN ELEVATION. PIPE OIAMETERS ARE EXAGGERATED FOR CLARITY Figure 1-2 Comparison of Full-Size 205-FA Plant OTSG to 19-Tube OTSG in OTIS. f e A i l 1-5 l
i Ovolume), this choice of hot leg inside diameter was considered most likely to 2 avoid the whole-pipe slugging behavior observed in the SRI Reflux Boiler Tests , ( The hot leg U-bend in OTIS is shown overlayed on the plant hot leg U-bend in { Figure 1-3. As indicated in the figure, the plant spillover elevation is obtained in OTIS by matching the elevations of the bottom (inside) of the plant and OTIS hot leg U-bend pipes. The hot leg U-bend in OTIS is exactly volumetrically scaled j. 2 (1/1686). The inside diameter of the hot leg U-bend pipe was set by the phenomenological scaling of the hot leg. The radius of the U-bend was chosen to achieve exact volumetric scaling. The pressurizer in OTIS was volume and elevation scaled. With this scaling, the OTIS pressurizer was approximately 20 inches shorter than plant-typical. The olevation of the bottom of the pressurizer was plant typical as was the spillunder
) elevation of the pressurizer surge line. The centerline elevation of the hot leg-to-pressurizer surge connection matched the plant hot leg-to-surge centerline elevation.
O An electrically heated reactor vessel provided heat input to the primary fluid to simulate reactor decay heat levels to 3.7% scaled power. Based on a ptwer rating for the Tennessee Valley Authority (TVA) Plant (a domestic B&W 205 fuel assembly, raised loop plant) of 3600 MWt, 3.7% scaled power in OTIS ccrresponded to 79KW (3600/1686 x 0.037 x 1000). The OTIS reactor vessel heat input capacity was 180KW. The design of the OTIS reactor vessel compared to the 205-FA plant reactor vessel is shown in Figure 1-4. The annular downcomer of the reactor vessel was simulated by a single external downcomer in OTIS. The sp111under elevation in the h:rizontal run at the bottom of the downcomer corresponded to the elevation of the uppermost flow hole in the lower plenum cylinder. The OTIS reactor vessel con-
" Reflux Boiling Heat Removal in a Scaled TMI-2 System Test Facility," R.T.
i Fernandez, et. al., paper presented at Thermal Reactor Safety Meeting, Knoxville,
, (April,1980).
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_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ t x A .! Qllllllllllllll ! k . aa="co='_" '? =_a are *'uua'a P _ e move; ec-o==vs aar oma== to scate = stewarions; 88 ano non OTIS m acrose i to-ea - . **=====,e ruv snameisas,oa cua,,irouvat nooo.aano , osstaascee ang want Ptt ssuet ' t 206 f a Ptaarf ataCTodt vf 35ft figure 1-4 Comparison of Full-Size 205 Fuel Assembly Plant Reactor Vessel to OTIS Reactor Simulation
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sisted of three regions: a lower plenum, a heated section (core vessel), and an upper and top plenum. The center of the heated length of the core vessel corresponded to the center of the active fuel length in the plant core. The core vessel, portion of the reactor vessel contained excess volume due to construction { constraints; therefore, to maintain the total reactor vessel model scaled volume, the reactor vessel was shorter than plant-typical. Non-flow lengths were
. sacrificed to maintain reactor vessel scaled volume, that is, the lower plenum was
,1 shortened below the downcomer spillunder point, and the upper and top plenum was
. shortened above the reactor vessel vent valve spillover point.
k. Cold primary fluid entered the downcomer from the cold leg, and heated primary fluid exited the upper plenum to enter the hot leg. The center of the cold leg to downcomer connection in OTIS corresponded to the cold leg-to-reactor vessel nozzle centerline in the plant. Similarly, the center of the hot leg-to-upper and top plenum connection in OTIS corresponded to the reactor vessel-to-hot leg nozzle centerline in the plant. The cold leg in OTIS is compared to the 205-FA Plant cold leg in Figure 1-5. As indicated in the figure, the OTIS cold leg did not contain a pump, since OTIS was designed to simulate the natural circulation phases of a SBLOCA. A flange was provided in the OTIS cold leg just upstream of the reactor coolant pump spillover point so that a flow restrictor could be inserted to simulate the irrecoverable pressure loss characteristic of a stalled reactor coolant pump rotor. This flange l was not used in OTIS to provide simulated locked pump rotor resistance. Rather, the resistance was positioned at the flange assembly downstream from the OTSG cutlet for flow rate treasurement. i The OTIS cold leg originated at the lower plenum of the 19-tube OTSG and cxtended downward in order that the elevation of the horizontal run of the OTIS cold leg matched the spillunder elevation of the plant cold leg. The highest point in the cold leg, that is, the spillover into the sloping cold leg discharge line, matched the reactor coolant pump spillover elevation in the plant. Because lf horizontal distances were shortened in OTIS, the slope of the cold leg discharge i line was atypical in order that the cold leg to downcomer connection elevation was l plant typical. f 1-9 l
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! PtPE DeAnsETTRS AND HOnt20NTAL DISTANCES ARE 1 ExAcoEnAno eon CtAn TV i ! Figure 1-5 Comparison of Full-Size 205-FA Plant Cold Leg to OTIS Cold leg i i j
The diameters of the cold leg suction and cold leg discharge lines were chosen to preserve Froude number. Because of the she tened horizontal distances
- in OTIS, the cold leg volume was within 1% of the ideal volumetrically scaled volume.
Atypicalf ties in the OTIS test loop are summarized as follows: t e OTIS was predominantly a vertical system, due to the shortened horizontal distances and small cross sections of the various components such as steam generator and reactor vessel. There fore, ! OTIS was inherently a one-dimensional model. , e Because of the small size of the piping used in OTIS, the ratio of j loop wall surface to fluid volume was approximately 20 times that of the plant. Therefore, the fluid and wall-surface temperatures were much more closely coupled than those of a plant. e In high-pressure models, the ratio of metal volume to fluid volume increases as the model is made smaller. In OTIS, the ratio of metal volume to fluid volume was approximately twice that of the plant. Little can be done to eliminate the one-dimensionality and the excess metal volume atypicalities of scaled integral-system facilities unless the scale factor approaches one. However, data from scaled integral test facilities is important for benchmarking computer codes if the facility is shown to display the expected system phenomenon. Data obtained from a scaled facility can be used to benchmark the computer code which in turn, can be used to predict the performance of the pl ant. The pipe surface to fluid volume ratio atypicality of scaled facilities results in higher heat losses in the scaled facilities than in the plants. This atypicality can be minimized by using both active (guard heaters) and passive r insulation on the model piping in critical regions. Guard heaters were used for
! OTIS on the hot leg, pressurizer, reactor vessel upper and top plenums, and the pressurizer surge line.
l The secondary side of OTIS provided the steam generator secondary inventory I j and those fluid boundary conditions which impact SBLOCA phenomenon. This included O 1-11
1 i zmthe steam generator level and auxiliary feedwater control, auxiliary feedwater (m) inlet elevation, and the cooldown valves. These controls are discussed further in Section 2.0. q Figure 1-6 is a schematic of the test loop, indicating the types and loca-tions of instrumentation installed in OTIS. The OTIS instrumentation included
. pressure and differential-pressure measurements; thertnocouple (TC) and resistance .I' temperature detector (RTD) measurements of fluid, metal, and insulation tempera-tures; level and phase indications by optical-ports, heated RTD, and conductivity probes as well as by differential pressures; and pitot tubes and head flowmeters for measurements of flow rates in the loop. Figure 1-7 is provided to indicate the differential-pressure (DP) measurements in OTIS. In addition to these ceasurements, loop boundary conditions were metered; HPI, hot leg HPV, controlled leak (cold leg suction, cold leg discharge, RV lower plenum or RV upper head vent), PORY relief, and secondary steam and feed flow and energy transport were measured; noncondensible gas (NCG) injections are controlled and metered; NCG discharges with the two-phase primary effluent streams were measured; and the paggregate primary effluent were cooled and collected for integrated metering.
V In total, OTIS instrumentation consisted of approximately 250 channels of data which were acquired and stored by a high-speed data acquisition system. At the base of the data acquisition system was a dedicated Digital Equipment [ Corporation (DEC) PDP 11/34 minicomputer which converted raw voltages to cngineering values on-line to provide the operators with visual displays and printouts of the loop conditions as testing was proceeding. The acquisition rate could be event-actuated or adjusted by the loop operator to acquire and store a full set of data as often as every 5 seconds. f i
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I l .q 2.0 KEY FEATURES OF TEST LOOP O OTIS consisted of a closed primary loop, closed secondary loop, and several auxiliary systems. A general arrangement showing the relationship of the key 1( 1 components of these systems is shown in Figure 2-1. In this section the key I features of these systems will be discussed. The key features are: I e Multiple leak location, e Gas addition capability, e Guard heating, e Scaled high pressure injection (HPI), a Simulated reactor vessel vent valve (RVVV), ! e OTSG 1evel control, o Automatic cooldown, e High and low auxiliary feedwater addition. ' Multipli leak locations were present in OTIS to allow a controlled SBLOCA. Controlled leaks were located at the bottom of the lower plenum of the reactor
- vessel, at the top of the top plenum of the reactor vessel, in the cold leg upstream of the simulated reactor coolant pump (RCP) spillover, in the cold leg downstream of the RCP spillover, a high point vent (HPV) at the top of the hot leg I
U-bend (HLUB), and a simulated pilot operated relief valve (PORV) at the top of the pressurizer. Leak flow was controlled by an orifice located just downstream l of the leak site. The leak flow control orifice was located in a 5/8" diameter tube as shown in Figure 2-2, to fonn the leak flow control orifice assembly. The details of the orifice design are illustrated in Figure 2-3. During the GERDA 2 2 program, scaled leaks in the range of 5 cm to 40 cm were tested in the single 2 2 2 phase regions (cold leg and reactor vessel leaks), while 3 cm ,10 cm , and 77 cm scaled leaks were tested at the HPV and PORV. The actual diameter of the scaled leak was obtained from the ideal volume scaling factor of 1686. Thus a scaled 2 leak of 10 cm has a diameter of 0.034 inches in OTIS. Scaled leak control orifices of 3, 5, 10, 20, and 40 cm2 were characterized prior to installation in 2 GERDA. During GERDA, the 5, 10, 20, and 40 cm leaks were characterized in saturated water, while the 3 and 10 cm2 leaks were characterized in saturated steam. The characterization tests provided the critical flow rate for each orifice at pressures of 1000 and 2000 psia. These characterization tests are discussed further in Section 4.2. No additional orifice characterization tests were performed for OTIS. g 2-1
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t i i Batch addition of noncondensible gases (NCG) could be made to the primary loop to study the effect of NCGs on system performance. Tha NCGs could be added at four locations around the loop. These locations included: e lower plenum of reactor vessel
! e cold leg piping downstream of RCP spillover e top of steam generator e top of hot leg at HLUB To preclude leakage of NCGs from the loop, sealed stem valves were used, where possible, throughout the loop. Additionally, all instrument fittings in the reactor coolant system, above the top of the core heaters were seal welded. To characterize the leak tightness of the loop, a helium leak check was performed during the GERDA program. The results of this test are discussed in Section 4.1.
As a result of the large surface area to fluid volume ratio, heat loss in the OTIS loop was proportionally greater than that in the plant. To minimize this Gffect, guard heaters were used along the hot leg piping, pressurizer, pressurizer surge line, and the reactor vessel upper and top plenums. The objective of the guard heating system was to provide heat to the components in an amount equal to heat loss of that component to ambient. The concept used for guard heating is illustrated in Figure 2-4. A layer of control insulation, approximately 1/2" thick, enclosed by a thin shell of stainless steel lagging, was placed over the pipe sections to be guard heated. The heater tapes were spirally wrapped over the lagging material, covering nearly 100". of the pipe section. Two layers of passive l insulation then covered the guard heaters. The heaters were controlled based on thennocouples located on the pipe OD and at a point mid-way into the control insulation. Tests were performed to evaluate the heat loss from the OTIS loop and to characterize the operation of the guard heaters. The heat loss tests are ! described in Section 4.5 and the performance of the hot leg guard heaters is discussed in Section 4.6. Two high pressure injection (HPI) locations were provided on OTIS - one at the cold leg low point, upstream of the simulated RCP spillover, the other in the downward sloping cold leg, downstream of the simulated RCP spillover. A scaled O 2-5
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HPI flow was provided by a positive displacement pump. The flow into the loop was controlled to simulate the plant scaled head-flow curve. HPI flow could be directed to either one or both of the HPI injection locations. _l The reactor vessel vent valve (RVVV) was simulated in OTIS by a single pipe rixtending from the upper and top plenum of the reactor vessel to the external downcomer. The elevation at which the pipe was located matched the spillover elevation of the plant RVVV. This is illustrated in Figure 1-4. A pneumatically-cperated, automatically-controlled valve was located in the pipe. The valve was controlled to open and close when the differential pressure between the reactor vessel and downcomer reached preset values. An orifice in the pipe, downstream of the valve was used to control the flow through the simulated vent valve. The simulation was for the plant vent valves in the full open position. The secondary loop consisted of the 19-tube OTSG, steam piping, a water cooled condenser, hot well, feedwater pump, feedwater heater, and feedwater piping. The relationship between these components is shown in Figure 2-1. The secondary side simulation of the modeled plant was limited to the steam generator and the elevation of the auxiliary feedwater ( AFW) inlets. Additionally, several control functions were used to simulate plant performance. These included: e continuous level (inventory) control e band level control e steam pressure control e automatic cooldown Two modes of steam generator level control were available on OTIS, continuous level control and " band" level control. With continuous level control, the operator set the desired steam generator level from 0 to 100%. The controller maintained the collapsed water level at this set point by adjusting the feedwater flow rate. A second mode of steam generator level control was tenned band level control. With this mode of level control the steam generator collapsed water level was maintained between specified elevations relative to the secondary face l I of the lower tubesheet (SFLTS). When the collapsed level reached the upper level, the feedwater valve was cycled closed. When the collapsed level reached the lower level, the feedwater valve opened. The feedwater flow rate obtained during this mode of level control was determined by the position of several control valves in l 2-7
i l'D the feedwater piping. These valves could be positioned to supply the required AFW t flow rate for a single fixed steam generator pressure or adjusted to simulate the 3 AFW head-flow curve of interest. The signal for the collapsed level, for both modes of level control, was based on a differential pressure measurement. d l l The secondary loop could operate at steam pressures of approximately 100 to
, 1200 psia. Steam pressure was automatically controlled by a steam control valve, a
l based on a signal from the steam pressure transmitter. In addition to automatic steam pressure control, the steam pressure could be controlled to decrease at a pre-programmed rate. This feature allowed simulation of the plant operator initiated " automatic cooldown mode", where the steam generator is depressurized to l obtain a fixed cooldown rate. In OTIS, the desired cooldown rate was keyed into the controller as a series of linear segments of pressure and time. When activated, the steam pressure control valve modulated to maintain the set point pressure versus time. Auxiliary feedwater addition could be made at one of two locations in the steam generator - a high feed elevation, typical of the B&W domestic 177 FA plants, and a low feed elevation, typical of the MK plant. The configuration of the AFW nozzle at each elevation could be for maximum wetting or minimum wetting of the steam generator tubes. The two configurations, maximum or minimum wetting of the tubes, allows comparison of the effects of a spray pattern on heat transfer (typical of the outer rows of tubes near the AFW nozzles in the plant), with the effects of pool heat transfer (typical of the large majority of tubes that are
- away from the AFW nozzles in the plant).
i l l l lq v 2-8
3.0 OTIS SUB-SYSTEMS The major primary, secondary, and auxiliary components of the OTIS loop have O l been sub-divided into systems. Each of these systems will be discussed in detail r in the following sections. l The primary loop was fabricated from stainless steel and was designed for 2500 psi at 650*F. The secondary loop was fabricated from carbon steel and was designed for 1500 psi at 600"F. The test loop was hydro-static tested to 3750 and 2250 psi at ambient temperatures, on the primary and secondary respectively, in accordance with the pressure piping and boiler codes. Prior to discussing the details of each system, a reference comparison of the key elevations and volumes for OTIS and the MK plant will be made. Full elevation modeling was assigned first priority in the OTIS scaling criteria. OTIS piping generally models the MK spillover and spillunder elevations. Additionally, a number of other key elevations are preserved in the OTIS model. These key elevations for OTIS and MK are compared in Table 3-1. O i i O 3-1
I t
, Table 3-1 , -COMPARISON OF KEY ELEVATIONS -- OTIS VS MULHEIM KARLICH (MK) ,i -
Elevation-Inches Relative to the Secondary Face of the Steam Generator Lower Tubehseet OTIS MK (1) Bottom of Reactor Vessel -287-1/2 -336 Downcomer to Lower Plenum- -283-1/4 -283-1/4 Bottom of Heated Section -196-1/4 -230-1/2
-158-1/2 Center of Heated Section -157-1/2 Top of Heated Section -119 1/2 Hot Leg Nozzle-Reactor Vessel Centerline - 23 - 23 Reactor Vessel Vent Valve Spillover + 6-1/2 + 6-3/4 Top of Reactor Vessel Upper Plenum + 15-7/8 + 61 Top of Reactor Vessel + 91-1/4 +134-1/2 Hot Leg U-bend (HLUB) Spillover +807-1/2 +807-1/2 Primary Face of Upper Tubesheet (UTS) +628-3/8 +646-3/4 Secondary Face of UTS +625-3/8 +625-1/4 Secondary Face 'of Lower Tubesheet (UTS) 0 0 Primary Face of LTS - 24 1/2 Steam Generator Outlet / Cold Leg Interface 1/2 1/4
() Cold Leg Low Point (Top of Pipe ID) 7/8 3/4 i C/ Pump Spillover + 30 (2) + 30 Cold Leg to Downcomer Interface - 23 1/4
- g- Top of Downcomer + 25-1/4 43-1/4 Pressurizer Bottom + 79-1/4 + 79-1/4
- [ Pressurizer Top +566-1/2 +585-1/2 Hot Leg-To-Surge Line Connection (Centerline) +103-1/4 +103-1/4 Surge Line Sloping-to-Vertical Interface + 94-3/4 + 94-3/4 Surge Line Low Point, Top of Pipe + 30 + 30 Auxiliary Feedwater (AFW) Injection Elevation -- Low Injection Point + 71 + 77 Auxiliary Feedwater (AFW) Injection Elevation -- High Injection Point Used on Some 177FA Plants +610-3/8 +610-3/8 l
(1) MK elevations are rounded to nearest 1/4" (2) Simulated RCP spillover Volumetric. scaling of the loop components was generally adhered to. As part !- of the Phase 0 -- GERDA Loop Characterization Tests, the volume versus elevation
- was obtained for four (4) primary-side regions and for the secondary side of the steam generator. These primary regions included the pressurizer, the reactor j
()/ w 3-2 l
vessel (excluding the downcomer), the active region, and the inactive region. The active region included the volume in the cold leg piping between the cold leg spillover and the downcomer, the downcomer piping, reactor vessel, and the hot leg piping between the reactor vessel outlet and the HLUB spillover. The inactive region included the volume in the hot leg between the HLUB and the steam generator outlet, and the cold leg between the outlet of the steam generator and the cold leg spillover. The volume versus elevation results are presented in Section 4.12. In Table 3-2, the volume checks are summarized for these regions and compared with the ideal volume scaled loop. Table 3-2 GERDA VOLUME CHECKS Ideal Scaled GERDA 3 Loop Volume, f t3 Volumes, ft Primary Pressurizer 1.61 1.58 Reactor Vessel (excluding downcomer) 2.21 2.23 Active Region 4.06 5.74 Inactive Region 2.78 2.82 I TOTAL Primary Volume 8.48 10.14 Secondary Steam Generator 2.45 2.58 t l 3.1 REACTOR VESSEL AND DOWNCOMER An electrically heated reactor vessel provided the heat input to the primary fluid to simulate decay heat levels up to 3.7% simulated full power (neglecting heat losses). Based on the TVA plant power rating of 3600 MWt and on the ratio of the number of tubes in the model steam generator to the plant OTSG's (19/32,026), 3.7% simulated full power corresponds to 79 KW. The OTIS reactor vessel heat input capacity was 180 KW. 1 0 l 3-3
The stainless steel reactor vessel and downcomer design was similar to that shown in Figure 3-1. The reactor vessel was composed of three (3) regions; a i lower plenum, a heated section, and an upper and top plenum. The downcomer consisted of a single pipe external to the reactor vessel. The overall length of 3
- the reactor vessel was about 31 feet with a net fluid volume of about 3850 in (excluding the downcomer). A single line with a pneumatically operated control valve connected the upper and top plenum of the reactor vessel to the upper downcomer simulating the reactor vessel vent valve (RVVV).
f The cold leg pipe connected with the downcomer at elevation -23"3 The . external downcomer connected the lower plenum at elevation -283-1/4". The lower plenum consisted of a straight vertical section of 2" Schedule 160 pipe, and a six (6) pipe header arrangement consisting of four (4) 1" Schedule XXS pipes and two (2) 1-1/4" Schedule 160 pipes. This header supplied the heated section, which was enclosed in a 6" Schedule 160 pipe. The four (4) 1" Schedule XXS pipes were spaced 90* apart around the bottom flange while the 1-1/4" Schedule 160 pipes were 180* apart. All six (6) inlets were normal to the heater rods. The details , of the downcomer piping and lower plenum are shown on B&W drawings 9510E, 9542E, and 9560E. A complete list of the facility drawings is contained in Appendix A. The mechanical and electrical drawings are contained in Volumes 2 and 3 of this report, respectively. The heated section of the reactor vessel started at elevation -196-1/4". The four (4) 1" Schedule XXS inlets were approximately 2-1/2" below the start of the heated section, and the two (2) 1-1/4" Schedule 160 inlets were approximately 6-3/4" above the start of the heated section. The top of the heated section was at elevation -119", for a heated length of about 77-1/4". The upper and top plenums extended from the top of the heated section, elevation -119", to the top of the reactor vessel, elevation +91-1/4". An orifice plate (1/8" thick and having 7 holes of 0.469" diameter each) at elevation +15-7/8" separated the upper and top plenums. The pipe sections consisted of a short section of 6" Schedule 3 All dimensions are relative to the secondary face of the steam generator O lower tubesheet. The horizontal dimensions are from the centerline of the O pipe unless otherwise noted. 3-4
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i 3 160 pipe, a 6" x 4" concentric reducer, and about 200" of 4" Schedule 160 pipe. i (V At elevation -23", the fluid leaves the reactor vessel through a 4" x 4" x 3" tee, l where it entered the hot leg. A 1-1/2" Schedule 160 pipe, with the centerline located at elevation +7-1/4" connected the reactor vessel top plenum with the downcomer, through the RVVV simulation. A single-phase leak site was located at the bottom of the lower plenum of the reactor vessel. A nigh point vent (HPV), a scaled 3 square centimeter orifice for OTIS testing, was located at the top of the reactor vessel as shown on Figure 3-1. The details of the heated section, upper and top plenums, and RVVV connection are shown in B&W drawings 9505E, 9506E, and 95520. Reactor vessel decay heat was simulated using three (3) 60 KW Watlow rod heaters. The 1-1/4" OD heaters were spaced 120* apart on an ~3" bolt circle. The heaters were seal welded to the flanged head of the reactor vessel. There were three (3) flow distributor / rod spacer plates along the length of the heaters -- located at elevations -186-3/4", -159-3/4", and -123-1/4". Details of the reactor
- vessel heaters and plate design are shown on B&W drawings 9524C and 9512E. The reactor vessel power could be controlled to either a constant power or to a power ramp. Decay heat was controlled using a Leeds & Northrup 1300 Process Programmer.
- g This programmer allowed the operator to key-in the desired power level and time I intervals to approximate the decay heat curve.
The reactor vessel upper plenum and top plenum were guard heated. The guard heaters were divided into two (2) control zones, one each for the upper plenum and the top plenum. The upper plenum guard heater zone covered from -23" to +15-7/8" with the control AT, RVDT01, at -4". The top plenum guard heater zone covered the remainder of the top of the reactor vessel, extending from +15-7/8" up to 91-1/4". The control AT, RVDT02, was located at 58". The operation of the guard heaters is discussed in Section 4.6. The RVVV simulation consisted of a single 1-1/2" Schedule 160 pipe connecting the top and upper plenum with the downcomer, with a 1-1/2" Rockwell Edwards Hennavalve and an orifice (downstream of the valve) for RVVV flow control. This pneumatically actuated valve was controlled to open and close at specified O differential pressures betweer. the upper plenum and the downcomer. The opening and closing APs were adjustable, but typically the RVVV was set to full open at a 3-6
I AP greater than +.25 psid and to close at a AP less than +.125 psid. A (vertical) g, slotted orifice was located just downstream of the Hermavalve to control the W amount of flow through the RVVV. A test was performed during GERDA to determine l I the pressure drop -- flow characteristics of the RVVV. The RVVV flow rate was measured using three independent measurements -- weight-time, accumulating flowmeter, and a turbine meter. Pressure drop was measured using the AP transmitter across the vent valve, RVDP03, and a water over oil manometer. The results of this test are summarized in Table 3-3. Table 3-3 REACTOR VESSEL VENT VALVE FLOW-AP MEASUREMENTS Flow Measurement AP Measurement Accumulating Nominal Flow Weight / Time Flowmeter Turbine RVDP03 Manometer Ibm /hr lbm/hr lbm/hr lbm/hr i n. H 20_ i n. H20_ 500 419.2 387.7 433.6 .23 .11 750 745.5 750.7 778.9 .55 .45 1000 993.9 1047.0 1023.5 .83 .75 1250 1244.2 1259.3 1269.1 (2) 1.01 1500 1437.1 (1) (1) (2) 1.42 1800 1837.0 (1) (1) (2) 2.33 (1) Flowmeters out of range (2) Zero shift on transmitter -- unit taken out of service The predicted and measured pressure drop-flow characteristics are shown in Figure 3-2, as is the calculated loss coefficient versus Reynolds number. The loss coefficient approached a constant value of about 17.6 for Reynolds numbers above 10,000. The response time for the vent, valve (a Rockwell Edwards Herniavalve) was measured during the GERDA program. The data is recorded on Table 3-4. The delay time in going from close-to-open was the time from valve actuation to the first indication of valve movement (time required to vent air out of actuator). The ramp time was the total elapsed time from valve actuation to 100% or 50% travel. 3-7
4 O O O i i i 2.50 23 i f
/ - - +* - - )
VENT VALVE f DOUMcCOMER I
! RES TRICTION 2.25 -
%/ . 22 i
I 1
) [ 2.00 - - 21 A AI l /
- e s ,
,.25 - ,
j - = c
# \, i
/ M'
. 1.50 j + + ,300**
2
~
\ g f f
- 19 2 y y' D \ '/ Ew l
SECTION "A-A** w 1.25 - PREDICTED
%=m 18 . 9:
> / oL
{ { j ---- MEASURED / oa Y # 1.00 - --- CALCULATED # - 17 I m ;
/
/ SS" i w
> / 2
.75 -
/ -
1s - A /
/ p' ISOLATION .50 -
,/ DESIGN POINT -- 15 j VALVE /
.25 - -
14 i f' l s' 4
' ' ' ' ' ' ' l l / k 0 250 500 700 1000 1250 1500 1750 2000 2250 TOP PLENUte VENT FLOW, L8M/HR
\ l t i I l l 1 i i I i
- 23e8 are0 7:40 es20 f
- - 4. - - l l REYNOLDS NUMBER (BASED ON l.D. = 1.34")
i i Figure 3-2 RVVV Arrangement and Flow Characteristics l; 4 l 1
I
.i Table 3-4 REACTOR VESSEL VENT VALVE RESPONSE TIME Close Open Del ay Ramp to to Time Time Percent Temperature Pressure Open Close (Seconds) (Seconds) Travel *F osia j X 1.3 18.7 100 520 1951 X 1.2 19.3 100 520 1951 X 1.2 18.6 100 520 1951 X 0 13.2 100 520 1951 X 0 12.7 100 520 1951
- ! X 0 13.3 100 520 1951 X 1.1 4.9 50 512 2023 X 1.3 5.1 50 512 2023 X 0 4.0 50 512 2023 X 0 3.8 50 512 2023 X 0 13.5 100 512 2023 X 0 12.9 100 512 2023 O
NOTE: Instrument air pressure is 46.5 psi i i 3-9
l 1 g A GERDA test was run to determine the response time of the reactor vessel
!j heater sheath to a step change in power. The heater response to a 60 KW step j'
change in power is shown in Figure 3-3. The time constant of the heater sheath, l that is the time required for the normalized sheath temperature to reach 63% of l its maximum value, was found to be about 20 seconds. The instrumentation associated with the reactor vessel and downcomer are shown in Figures 3-4 and 3-5. The following measurements were recorded as test data: e fluid and metal temperatures at key elevations along the vessel e guard heater control differential temperature e static pressure e differential pressures e phase detection at key locations using conductivity probes e mass flow rate from a Venturi meter (throat diameter of 0.775 inches) e power input to reactor vessel heaters [
\ Calibration of the venturi meter will be discussed in Section 4.8.
The notation used on the figures is defined in Appendix B. The elevation at which each instrument was located is given in the Instrument List, included as Appendix C. Additional instrumentation was used for loop operation and protection. This instrumentation, which was not recorded as test data, provided protection to the reactor vessel heaters for the following conditions: e high fluid temperature e high metal temperature e high pressure e low water level Interlocks to the heaters were opened if any of these conditions occurred. O 3-10
O F 'l p# g 7 = 20 SEC. p
'u.
*" e N .s -
>R-e k"
i o .6 - E m e
.4 -
E. O N k.2 I E k I I I I I I I l 0 ( 0 20 40 SO SO 100 120 140 160 180 TIME, SEC l l Figure 3-3 Reactor Vessel Heater Response to a 60KW Power Increase l, t ( l O 3-11 l
l'
- l 7.
V iff -
.100 <
RVTC08 f 1 RVTC12. RVDT02 RVHRO1 -
+50 ,I Il' C
RVTC10 [ RVCP03 RVCPO4 E f. g
- O e RVTC11, RVDT01 g RVTC09 ; RVCP01 g RVCP02 o y, s- L ,_ _ _ _f a- -
DCTC01 50 $* VIEW "S B" N 5 RVTC07 u RvCP0s
**o DCTC02 RVTC06 E
O) ' - (V RvTCOs - 30m 2 en f U RVTC03 i Id. 4 200Ig i t w RVTC02 { DCRT01 - 260 l_: s RVTC01
~**
Figure 3-4 Reactor Vessel and Downcomer Instrumentation
- Thermocouples, RTDs, and Conductivity Probes.
n-
\_,)
f 3-12
O f RVPR01
}
- +50 RVDP03 -
- RVDP01 w
w
..S: tt) 0 E E
o e I s w RVDP05 50 $ RVDP02 s E 8 100 $ 2 5 w DCDP 02 RVDPO4 - 150 8 E E 1
~, , -
200 DCDP 01 * ' DCDN3 ;l g y' _o d L. e
- 250 4
l_; s
;p 300 w i Figure 3-5 Reactor Vessel and Downcomer Instrumentation - Pressure and Dif#erential Pressure Measurements 3-13 L
!! ) l I, A valve was located in the bottom of the downcomer to satisfy pressure vessel Q code requirements. The manufacturers' specified flow coefficient (Cv) for this 'q valve being fully opened and for a fully opened reactor vessel vent valve are shown in Table 3-5. Table 3-5 MANUFACTURERS' SPECIFIED FLOW COEFFICIENTS FOR VALVES IN REACTOR VESSEL Flow Coefficient, Cv Valve Full Open Valve RVHV01 (downcomer) 120 a RVCV01 (RVVV) 32 A safety relief valve and rupture disc assembly was located just above the heated section. 3.2 HOT LEG PIPING G This system consisted of the piping and associated hardware and instrumentation from the junction of the hot leg-reactor vessel outlet to the primary inlet at the upper head of the steam generator. The piping was comprised of sections of 3" Schedule 160 stainless steel and Inconel 600 pipe. A general arrangement of the hot leg piping is shown in Figure 3-6. From the hot leg-reactor vessel outlet at elevation -23", the hot leg extended horizontally about 17", then made a vertical upturn through a special pipe section with a radius of curvature of 14-7/8". The hot leg extended vertically to an elevation of about 794". The piping then started a bend to form the hot leg U-bend (HLUB), with a radius of curvature of 14-7/8". The HLUB spillover was located at 807-1/2". The HLUB radius of curvature was selected to scale the HLUB volume while maintaining the same hot leg pipe inside diameter of 2.626". From the HLUB the piping ran vertically downward to the steam generator. A high point vent (HPV) was located on the top of the HLUB. The details of the hot leg piping design are shown on B&W drawing 9553E. 3-14
} .I
- i HIGH POINT VENT I +507 1/2"
+79 4 ~
- 800
- 700
+428 :1 'i - .r5
- 600 STEAM p GENERATOR e i
- 600 o 5
E HOT LEGp - 400 g 5 E
- 300 i 4
9 l d c l
- 200
+103-1/4" ~ SURGE UNE
- 100 l -o
! q 23"
% ' m REACTOR VESSEL Ficare 3-6 Hot Leg Piping General Arrangement O
3-15
I 1 1 1 7 Hot leg instrumentation is identified on Figures 3-7 and 3-8. Resistance ( temperature detectors (RTDs) were located near each end of the hot leg piping. l Fluid temperatures from thennocouples were measured just above and below the surge line connection on the hot leg, and at approximately 10' intervals along the hot j leg. Conductivity probes, for phase detection, were located at approximately 4' intervals between the 444" elevation and the inlet to the steam generator. Below this elevation, the probes were placed further apart. There were three AP measurements along the hot leg -- from the hot leg-reactor vessel nozzle to the HLUB, from the HLUB to the steam generator inlet, and from the hot leg-reactor vessel nozzle to the steam generator inlet. These measurements are identified in Figure 3-8. There were two viewports located on the hot leg that allowed visual observation of the fluid inside the pipa. One viewport was located in the vertical hot leg, approximately at elevation +420", while the other was located at the HLUB. A video camera was located at each viewport. The cameras were connected to a video recorder through a special effects generator that allowed the flow visualization data at each viewport to be recorded simultaneously, n The hot leg was guard heated over its entire length. Guard heaters were U divided into eight (8) control zones, each approximately 132" long. In each zone there was a AT measurement used for controlling the guard heaters and a AT measurement that was recorded on the data base for monitoring the performance of the guard heaters. The two AT measurements were at the same axial location, 180* apart. The elevation of the hot leg guard heater zones and control thermocouples are given in Table 3-6. The operation of the guard heaters is discussed in Section 4.6. 3-16
- I 9
HLHR01 HLUB HLTC11 VIEWPORT HLCP12 HLTC08 - 800 HLCP13 - -HLCP11 HLDT07 HLCP14 - - HLCP10 HLTC09 HLTC07
~'
HLCP15 - - HLCP09 HLDT08 HLTC14HLDT06 HLTC17 HLCP16 - - HLCP08 r> rh
- HLCP07 HLTC06 -
6C0
- HLCP06 HLTC1%HLDT05 g A A 500 f
- HLCP05 g
HLTC05 m
?
- HLCPO4 g
- HLCP03 []% HOT LEO E E12T04 VIEWPORT _ 400 in HLTC04 i
G E
~
H 10 HLTC14.H1DID 3 d HLTC03
- 200 HLCP02 -
ELTC13,HLDT02 HLTCO2
% HLTC01 \ - 100 HLTC12, HLDT01 HLCP01- 4 HLCP17 HLRT01 ,
-0 L '
x A Figure 3-7 Hot Leg Instrumentation - Thermocouples, RTDs, Conductivity Probes and Viewports O 3-17
I J n ,,
- .00 HLDP03
- 700 o o r%
- 600 0
A d MLDP02
- 500 o >-
T' l 5 y HLDP01 - 400 m O I.
- 3o0 I t
t
- 200 l
o \ - 100 l l' m
-0 L o i
1e x l l Figure 3-8 Hot Leg Instrumentation - Differential Pressure Measurements l 3-18 1
f i Table 3-6 ELEVATION OF HOT LEG GUARD HEATER ZONES AND CONTROL THERM 0 COUPLES
! Elevation Covered Elevation of Zone by Zone Heater Control TCs Control TCs No, (Inches Relative to SFLTS) Designation for Zone (Inches Relative to SFLTS) 1 - 23 to + 86 HLDT01 + 26 2 + 86 to +218 HLDT02 +157-1/2 3 +218 to +350 HLDT03 +295 4 +350 to +482 HLDT04 +408 5 +482 to +612 HLDT05 +559 6 +612 to +746 HLDT06 +695 4 7 III +746 to +734 HLDT07 +786 8 +734 to +635 HLDT08 +692 (1) This zone crosses over HLUB (elevation +807-1/2) 3.3 STEAM GENERATOR An existing 19-tube Once-Through Steam Generator (OTSG) was used in OTIS.
The OTSG was a single pass, counterflow, tube and shell heat exchanger. It consists *of 19 Alloy 600 tubes with an outside diameter of 5/8 inch spaced on a triangular pitch of 7/8 inch on centers. The tube bundle was enclosed in a hexagonal shell 3.935 inches across flats and was held in place by 16 carbon steel tube support plates (TSPs) spaced at approximately 3 foot intervals. The distance between the secondary face of the lower and upper tubesheets was full length, approximately 52 '-1-3/8". The 19-tube OTSG is illustrated in Figure 3-9. The TSPs were 1-1/2" thick and were drilled in a manner to simulate the broached pattern of a full-size OTSG TSP. This is illustrated in Figure 3-10. ad ei In the OTSG primary flow entert at the top, flows' dopward through the tubes,andexit/gat the bottom. The main feedwater enterp the steam generator at the bottom, boils'on the outside of the tubes, and exitsdat the top. For OTIS. both a high and a low auxiliary feedwater (AFW) injection location were available. The high AFW injection location was selected so that the distance from the nozzle to the first TSP below the nozzle in the model was the same as in the Oconee III 3-19
. . _ . .. . . _ - . . _~ ... _._- . . _ _ _ . -. 4 PRIMARY INLET If O
ewy
+425 3/8" m NUPPER TUSE SHEET STEAM OUTLET
+410- 3 / 8 "-
HIGH AFW sq
' INJECTION NTUBE SUPPORT ass f "A"
A" 3.935" l 00 m
SECTION "A A" eas O
+71"-C::
LOW AFW INJECTION
===
l D o" 7-TOP OF LOWER LOWER TUBE SHEET TUSE SHEET If PRIMARY OUTLET Figure 3-9 19-Tube Once-Through Steam Generator O 3-20
- 18. TUBE OTSG TUBE SUPPORT PLATE (DRILLED) h 1 0, i
/""\
[ 0 3,3 p 1 1
,3 0 h2
--# Rg (IN 1 R2 (IN l R3 (IN ) ARE A (IN 1
\. , 0.32031 0 250 0 1907 0 051518 FULL SIZE OTSG TUBE SUPPORT PLATE (BROACHED) 11' "" 29 T 7 Ot I t f ths I, Og,[ "2 N I
2 Rg (IN ) R2 (IN ) ARE A (IN 1 0.323 0.430 0 051855 0.320 0.430 0 053075 0.320 0 427 0.051485 0.323 0.42/ 005C233 l 120' Figure 3-10 Comparison of 19-Tube and Prototypical OTSG Tube Support Plates i ! 3-21
g] type OTSGs. The low AFW injection location should have been located at 6'-5-1/16" C' (relative to the SFLTS) to exactly match the MK elevation, however, this elevation j was too close to the second TSP in the model OTSG to allow the shell penetrations ) to be made. The low AFW injection was located at 5'-11". These AFW injection locations are shown on Figure 3-9. The pressure boundary between the primary and secondary circuits was established by carbon steel tubesheets placed at the top and bottom of the generator with a distance of 52'-1-3/8" between the secondary faces of the tubesheets. Each tubesheet was clad with Inconel on the primary side. The tubes pass through the drilled tubesheet and were welded at the primary face. The upper and lower tubesheets were 3 and 24 inches thick, respectively. The details showing the assembly of the steam generator are presented on B&W drawing 10710E7. To measure the overall performance of the steam generator, RTDs were located in the inlet and outlet plenums. These are identified on Figure 3-11. Prima ry and secondary-side pressures and differential pressure measurements are shown in G Figure 3-12. O The OTSG was instrumented, during fabrication (in 1968), with internal thermocouples to provide primary fluid, secondary fluid, and tube metal l temperatures. However, due to time and use, many of the thermocouples have failed. Replacement of the primary fluid and tube metal thermocouples was not possible. The primary, secondary, and metal thermocouples used during the OTIS program are shown in Figure 3-11, along with their elevation relative to the SFLTS. The tubes in which the primary fluid thermocouples were located are identified in Figure 3-13. The primary fluid thermocouples were positioned at the center of the identified tube. Metal thermocouples were located on the tube OD at the position identified in Figure 3-13. The secondary fluid thermocouples were positioned in either of two locations: o between the shell and the first row of tubes (peripheral cell) e in the unit cell between the first and second row of tubes (bundle cell) O v 3-22
PRIM ARY INLET 1f SPAT 01. SPRT02 TUSE 'J puPPER TUSESHEET
,23 SUPPORT 4
\ 49'.9" - SSTC25
- #8'*I~ -
47'.0"- SSTC23. SSTC24 4 8 '.8" --- 44'.2"- SSTC21, SSTC22 42 '.0 " .-- 41 3"- SSTC19, SSTC20 8 ' ' ~ --- 3s'.2" - SPTC01, SSTC17, SSTC18. SMTCOS 38'.0" --- 36'.4"- SPTC02. SSTC16, $$TC16 33*.10" --- 32'.4 - SSTC13, SSTC14 0'.10" --- 29'.3"- SSTC11. SSTC12. SMTC03 27*.9" --- 28'.4"- SSTC09 SSTC10, SMTCO2 24'.10" -"- 23'.2" - SSTC00 21 '.8 " --- 20'.2" - SPTC03 SSTC07, SMTC01 18 *.8 * --- 17.4"- SPTC04. SSTCOS 18'.10" ~~* 14*.2" - $ $7C06 12 *.8" --* 11*.1" - 8 STC04 3'.7" ~~* s'.1" - SPTCOS SSTCO3 8 '.7 * --- 4*.11" - $$7C02 3 *.S " ,,, 1*.8" - S STC01 0.mEFERENQ1 DNE 747 TOP OF LOWER TUeESHEET LOWER !q[ ~:SPRT03.SPRT04 TUSESHEET SFTC16. SPTC17. SPTC18 m 1f PRIMARY OUTLET Figure 3-11 OTSG Temperature Measurements and Tube Support Plate Elevations O 3-23
i
%/
l PRIMARY jpINLET 4 SPPR01 - 836 3/4" i l _ k UPPER y W TUSFSHEET PSPRoi ,ggg,
- 423 3/4" SSDPO4 l - 387 3/4" SSDPOS SSDP03 - 360 1/2" SPDP01 ggg,P02
- 277 1'2' O
SSDP01 LOWER " TuSESHEET N === - 0"lREFERENCE)
) 5FFT01, 02, 03
- .331/4" m
Figure 3-12 OTSG Pressure and Differential Pressure Measurements b 3-24
O A N sMTC02 T j j s iou I l 0, 1
'"'c*'
1 lvl H l B A { E l P 1 v SMTC03 l nnlJ jj C l D ( N I A K j l L ( M sMTC04 V PRIMARY FLUID TUBE THERMOCOUPLES IDENTIFICATION SPTC01 E SPTCO2 B SPTC03 F SPTC04 R SPTC06 U Figure 3-13 Radial and Circumferential Location of Primary Fluid and Metal Thermocouples t l O 3-25
[ ; ( i y ,;
/
T n 73 A mS,p showing the circumfere6tial and radial location of the secondary fluid s (v ) thermocouples is given in Figure 3-14. s\ , A Additional instrumentatim was added to the steam generator for the GERDA and
,', OTIS program. A speciallycfabriceted piti-junction themocouple was installed W' b into one tube. This tube is idettified in Figure 3-15. The multi-junction )
thermocouple had ten (1Gi'th)rm'occuple junctionr. in a single 1/8" diameter sheath. i;,k The tharmocouples were positioned at an elevation to measure the effect of high 9, elevatfor. AFW injection on thd f tiest transfer process. These elevations, along
~
with the thermocouple designation are givcr.'in Table 3-7. Pitot tubes were
^ installed at the exit plane of the lower tubesheet in three selected tubes. The pitot tubes were used to provide a relative flow indication between the tube
'! \>, f r.strumented with the multi-junction,thermxouples and one uninstrumented tube.
, is s
,i Each pitot tube was equipped with a thermocouple for measuring temperature at the
same point as differential pressure in the fluid stream. The steam generator l' tubes instrumented with a pitot tube are identified in Figure 3-15. The details of the additional instrumentation e arrangement in the existing steam generator
[ W, is shown on B&W drawing 9527E. Table 3-7
. ELEVATION OF MULTI-JUNCTION THERMOCOUPLE JUNCTIONS VTAB Designation Elevation of TC Junctio- ~
SPTC** Relative to SFLTS 06 23 ' 3/8"
, 07 30' 3/8" k 08 35' 3/8" 09 39' 3/8"
> 10 43 ' 3/8"
[ L'
' 11 47 ' 3/8" m 12 49' 3/8" f 13 50' 3/8" 14 50' 3/8"
> ' 15 51 ' 3/8" o
w ./ , ( " 3-26 r .
,i b N N NUMBERS REFER TO SSTC". FOR EXAMPLE. 24 REFERS TO SSTC24 I U l l T } l S l L v ! G I l F l 4 R l 19 11 1s 2s I"l I H l ! B l { A I E l P zi l J \ C l D i N l Y ln Yl I K j 9 L j { 17 M l l Figure 3-14 Radial and Circumferential Location j of Secondary Fluid Thermocouples l l 9 3-27
]
Q n N AFW NOZZLE FOR MAXIMUM N / WETilNG t U T S V G F R H B A E P J C D N AFW NOZZLE K L M \ AFW NOZZLE FOR MAXIMUM & FOR MAXIMUM MINIMUM WETTING WETTING INSTRUMENT TUBE IDENTIFICATION I (VTAB DESIGNATION) MULTI-JUNCTION TC #1 (SPTCOS SPTC15) J ll J PITOT TUBE #1 (SPPT01) . TC SPTC16 PITOT TUBE #2 (SPPT02) . TC SPTC17 R f f- PITOT TURE #3 (SPPT03) . TC SPTC18 N l Figure 3-15 Location of Multi-Junction Thermocouples, Pitot Tubes, and AFW Nozzles l ll l lx 3,-28 L-
i i Conductivity probes were installed in the steam generator to measure the secondary level swell anticipated during some transients. The thirteen (13) active conductivity probes were concentrated between the 29' to 36' elevation in the generator (the normal GERDA test operating level in the steam generator was about 26'). These probes were spaced approximately 6" apart. and were staggered around the circumference of the generator. The steam generator reference probe was located at the 20' elevation. The details showing the location and installation of the steam generator conductivity probes are given on B&W drawing 9548E. Auxiliary feedwater injection in OTIS could simulate either a high or low elevation AFW injection plant. Additionally, nozzles for AFW were used that allowed either maximum or minimum wetting of the tubes in the model OTSG. These maximum and minimum wetting nozzles were used during the GERDA secondary heat transfer and natural circulation tests to evaluate the importance of spray pattern on the heat transfer process and natural circulation. The configuration of the AFW nozzles for maximum and minimum wetting was determined using a plastic model of the 19-tube OTSG4 ,5 The maximum wetting configuration consisted of a 0.187 inch ID tube with a 0.063 inch OD cross insert l located on three sides of the hexagonal shell. The minimum wetting configuration consisted of a single 0.430 inch ID tube located on one side of the hexagonal shell. The circumferential location where the maximum or minimum wetting nozzles were installed is identified on Figure 3-15. 3.4 COLD LEG PIPING AND PRIMARY FORCED CIRCULATION SYSTEM
. The cold leg piping was scaled based on phenomena and elevation.
Phenomenological#scgling set the pipe size to a 3" Schedule 160 pipe. The cold leg piping extend / from the 5" x 3" concentric reducer at the outlet of the steam / 4 Auxiliary Feedwater Benchscale Tests, LR:81:5168-05:01, D. P. Birmingham and A. L. Miller to Distribution, March 15, 1981. Auxiliary Feedwater Benchscale Tests-Effects of Tube Material on Wetting Characteristics, LR:81:5168-05:02, D. P. Birmingham and A. L. Miller to Distribution, April 15, 1981. 3-29
1
' 1 I
generator, through a flanged orifice assembly (bore diameter is 1.110 inches), to ( the cold leg low point (spillunder) at elevation 7/8". The pipe turned 90" to a short horizontal run prior to the upbend. The horizontal run was at a 45' angle to the reactor vessel / steam generator centerline. The cold leg then ran vertically for about 24", where it was reduced from 3" Schedule 160 pipe to 1-1/2" i Schedule 160 pipe. The 1-1/2" pipe then turned 90* to the horizontal, then 90* again to a vertical run. This vertical run of 1-1/2" Schedule 160 pipe, of approximately 39 inches, was included for the cold leg ultrasonic flowmeter. The ultrasonic flowmeter was found to be an unacceptable technique for measuring flow rates in GERDA and was not used for GERDA and 0 TIS test data. However, the associated piping did remain as part of the cold leg piping. After passing through this section of pipe, the cold leg returned to a 3" Schedule 160 pipe, ad continued vertically upward to the simulated reactor coolant pump (RCP) spillover - resistance. From the RCP spillover the cold leg sloped downward and connected with the downcomer at elevation -23". The routing of the cold leg piping and the key elevations are illustrated in Figure 3-16. Details of the cold leg piping are shown on B&W drawing 9542E. I v There were two high pressure injection (HPI) locations in the cold leg -- one at the cold leg low point on the upstream side of the cold leg spillover, and the other in the sloping section on the downstream side of the cold leg spillover. HPI fluid was injected on the bottom side of the pipe normal to the axis of the pipe. Thc HPI nozzle was sized to preserve the ratio of cold leg to HPI momentum for one HPI pump discharging to one injection location. Details showing the HPI connections to the loop are illustrated on B&W drawing 9572E. There were two simulated leak sites in the cold leg -- one at the cold leg low point on the upstream side of the cold leg spillover, and the other in the sloping section on the downstream side of the cold leg spillover. The leak sites were located on the bottom side of the pipe. These leak sites are shown in Figure 3-17. Effluent from the leaks was directed to the single-phase venting system / (discussed in Section 3.7). The instrumentation associated with the cold leg is elso shown in Figure 3-17. There were five (5) thennocouples located in the cold leg, three (3) on the V upstream side and two (2) on the downstream side of the cold leg spillover. An 3-30 i
\
O
+30"(BOTTOM ID OF PIPE)
-23" 9 STEAM GENERATOR DOWNCOMER 6630-1/2" FLANGED
-66" " ORIFICE ,
l 7/8"' (TOP ID OF PIPE) ) Figure 3-16 Cold Leg Piping - General Arrangement O' 3-31 w . _ . . . . . - - . . _ . . - . - - _ . . _ . - _ _ _ - . . - . - . .
l l I
+50 D
E
+25 g W CLTC04 e S
5 t 9 w HPl 5 CLD LEAK - O g g CLTCO3- C CLTC05 8
<n e
a
, 0 T
-25 5 5
5 5 o a 1 5 P
- 50 a
\r.., *
-CLTC01 -CLTCO2 I'
t CLOR02 CLOR04 ~
-75 I I l HPI CLS LEAK l
Figure 3-17 Cold Leg Piping - Temperature and Flow Measurements Location of High Pressure Injection and Cold Leg Leaks i i O 3-32 l l
9 orifice was located near the bottom of vertical run from the steam generator to the spillunder. A high range and low range AP transmitter was used to calculate the flow rate from this orifice. The calibration of this orifice is discussed in Section 4.8. The differential pressure measurements arcand the cold leg are shown in Figure 3-18. A Chempump Model GET was used in OTIS for providing forced circulation. The Chempump was a canned-rotor pump with a design head of 250 feet at a flow of 250 GPM. The pump was cooled using city water. The circulating pump was used during facility start-up. The pump was located in a loop parallel to the " natural circulation" flow path through the cold leg. Its location is illustrated in Figure 3-19. The Primary Forced Circulation Loop started at the tee connection in the cold leg low point just before the vertical upturn. A 2-1/2" isolation valve was downstream of the tee section and just upstream of a 4" Schedule 160 straight section to the suction side of the pump. The straight section contained a flanged strainer assembly. The pump discharged vertically upwards through a 3" pipe. After passing through a concentric reducer, the flow passed through an isolation valve located in a 2-1/2" pipe downstream of the pump. The Primary Circulation Loop connected back into the cold leg piping at approximately an elevation of 3/4". l The pump-by-pass valve, CLCV01, was full open during natural circulation l tests. During forced circulation operation, the isolation valves around the pump were opened and CLCV01 was throttled to give the desired flow rate. As CLCV01 was ! closed down, more flow was forced through the primary loop. With CLCV01 full open (flow coefficient, Cv, of 110) and the isolation valve on the discharge side of the pump, PCHV02, opened 3-1/2 turns, a flow rate of about 7500 lb/hr was obtained with cold water. This was the normal alignment during loop start-up. The pump l was interlocked so it could not be started unless the pump by-pass valve was full open. This was to prevent forcing a large amount of flow through the loop and possibly damaging instrumentation. Pressure gages and thermocouples were located upstream and downstream of the pump. This instrumentation was not recorded as test data, but used for loop operation. Details of the forced circulation system l' are shown on B&W drawing 9542E. l 3-33
t-1 .t jb W u E 9 u STEAM GENERATOR DOWNCOMER -- o o I EEa t CLDP02 CLDPO4 Figure 3-18 Cold Leg Piping - Differential Pressure Measurements yC v.)
'l 3-34 1
- 1
i e i l c o PCHV02 PCHV05 k b E cLCv01 STRAINER FELTMETAL FILTER H 01 CHEMPUMP PCHV06 i Figure 3-19 Primary Forced Circulation Loop l ~ O 3-35
,. The forced circulation pump in OTIS was not intended to match the head / flow V or coastdown performance of the plant RCP, but only to provide forced circulation.
The coastdown time for the OTIS forced circulation pump was determined during GERDA testing to be about 5 seconds based on flow measurements before and after pump trip. l During facility startup and when the suspended solids in the primary fluid exceeded the desired level, a portion of the primary fluid was directed through a 0.6 micron Feltmetal filter. The Feltmetal filter consisted of interlocked metal fibers which were sintered to produce metallic bonds at all points where the fibers touch each other. This porous structure enabled filtration to 0.6 microns. The filter was tubed into a by-pas- loop around the Chempump, and is shown in Figure 3-19. Instrumentation w s provided around the filter to measure the
! pressure drop across the filter, flew rate, and pressure. These measurements were used for loop operation and not for test data.
3.5 PRESSURIZER
- n k The pressurizer vessel was fabricated from a 3" Schedule 160 stainless steel pipe. The volume of the pressurizer was scaled to that of MK, as was the elevation of the bottom of the vessel. The length of the pressurizer was l
approximately 20" shorter than that of the MK plant to preserve the volume scaling. The surge line was fabricated from 1" Schedule 80 stainless steel pipe. Surge line volume was approximately scaled to MK as were the elevations of the hot leg-to-surge line connection the surge line sloping-to-vertical interface, and the surge line low point. These elevations and volumes for OTIS are compared to MK scaled parameters in Section 3.0. A schematic illustrating the pressurizer and surge line is shown in Figure 3-20. A layout of the surge line is shown in Figure 3-21. The pressurizer could be isolated from the hot leg by two (2) manually operated valves, PRHV01 and PRHV02. A simulated pilot operated relief valve (PORV) was located at the top of the pressurizer. A spray connection to the pressurizer (from the cold leg) was provided through a remotely operated valve, PRCV01. The facility water supply g system was connected to the pressurizer through PRCV02. Provisions for degassing (during heat-up operation) the pressurizer and for providing a gas blanket on the 3-36
. . - - - - , . - . - , , , - , _ , - - . - , . ,,.- ----.,m ,. - - , .,
I l 1 f O FACILITY WATER SUPPLY
, if
{~ PRHVO4 SIMULATED Q PORV M n y
- TOVENTING PRIMARY SYSTEM PRHVOS
, g ,,
PRCV02% SPRAY UNE + M FROM COLD LEG PRCV01 h i l PRSVO1 O PRESSURIZER % HOT LEG % PRHV01 PRHV02 i 9 +79 1/4" I I SURGE ' LINE PRHV03 l l Figure 3-20 Pressurizer - General Arrangement I I 1 3-37 t ee
l l
! = 32" :
PRESSURIZER a 30"
= 29 3/4" r 1
30' u STEAM HOT LEG GENERATOR (VERTICAL RUN) T i l N HOT LEG %
+103-1/4" A +94 3/4" lN PRESSURIZER # s;
( ,79,3f4-
+30" l (TOP OF PIPE)
Figure 3-21 Surge Line Layout 1 i
, O
!, 3-38 l
pressurizer (used during fill operation) were provided through PRHV04 and PRHV05. A drain valve, PRHV03, was located at the bottom of the surge line. A safety valve and rupture disc assembly was located near the middle of the vessel. The details of the pressurizer and surge line design are contained in B&W drawing 9518E and 9549D. All the valves on the pressurizer (except the code safety valve and drain valve) were sealed stem valves to preclude leakage of NCGs. The safety valve / rupture disk assembly and drain valve had a water trap upstream of the valve to isolate NCGs from the potential leak path. The flow coefficient, Cv, for the valves in the flow path are given in Table 3-8. Table 3-8 MANUFACTURERS' SPECIFIED FLOW COEFFICIENT l FOR VALVES IN THE PRESSURIZER Valve Flow Coefficient, Cv Designation Full Open Valve PRHV01 1.2 PRHV02 1.2 PRCV01 1.0 l The simulated PORY was located at the top of the pressurizer in a section of 3/8" tubing. This simulation consisted of two (2) sealed stem automatically actuated valves, and a flow control orifice upstream of these valves The flow control orifice was sized to provide the desired relieving capacity of the PORV. The valves in the PORY simulation were controlled to open at a set point pressure of 2300 psia and then to close at 2250 psia. These dual set point pressures were adjustable. The valves could also be opened manually. The operation of the PORV is discussed further in Section 3.7, Primary Venting Systems. The pressurizer was heated externally using band heaters. The main heaters had an installed capacity of about 1.4 KW (MK scaled power was 1.12 KW) and were located over the lower 18" of the vessel. Pressure was controlled with the main heaters during steady-state operation. The heaters were tripped at the start of the SBLOCA transient, and remained off during the entire test. In addition to the 3-39
l
,o main heaters, guard heaters were used over the remaining 40' length of the vessel . U and over the surge line. The guard heaters were used to minimize the heat loss d -from the pressurizer and surge line. The guard heater concept was described in Section 2.0.
The pressurizer guard heaters covered approximately 40' of pipe. A single controller was used to control guard heater output. For all tests before April 3, 1984, the control was based on the (arithmetic) average of three (3) sets of control thennocouples (AT measurements). The control thermocouples were located near the bottom (146-3/4"), middle (325-3/4"), and top (513") of the pressurizer
~~
i vessel. (A single guard heater wa's used for the surge 'line. After April 3, 1984,
~
control was based only on the thermocoupl'es near the pressurizer top (513").e A single controller was used to control guard heater output using one (1) set of control thermocouples. The control thermocouples were located on the vertical section between the surge line low point and the hot leg at an elevation of 37-1/4" above the SFLTS. As with the hot leg guard heaters, two sets of AT measurenents were made for each of the three pressurizer and the surge line
,o control zones, one for controlling the heater, and the other for test data. These two sets of measurements were at the same elevation, but 180' apart.
Much of the OTIS testing simulated a time during the SBLOCA transient where the pressurizer (in the plant) would already have drained and tripped its main heaters. To better simulate the nearly adiabatic plant pressurizer during this period, a series of tests were run in GERDA to detennine the pressurizer guard heater control settings that would maintain a constant pressure with the main heaters off. This control setting, or bias, was obtained for several pressures. For reference, the results of the GERDA tests are shown in Figure 3-22. This curve was used for tests performed before April 3,1984. After this date, a bias l setting of 0.07 to 0.08 was used. GERDA tests were also conducted that allowed the pressurizer heat loss to be calculated. These tests were completed with the pressurizer isolated from the hot leg. The results of these tests are discussed in Section 4.5. The instrumentation associated with the pressurizer and surge line is shown n in Figure 3-23. Fluid temperatures (PRTC01 - PRTC03) and metal temperatures j' U '(PRTC04 - PRTC06 and PRTC08 - PRTC10) were measured along the length of the a L 3-40
t 1 4 O 1 1
...e e.es .
l e.44 . s c' ll a e.4a . s l s e,4 . E ! T I I e.as . M
=
O l e.2 _ g g g g g g l 5 5 2ge des GBe 888 1988 1298 14ee tage 1880 2eSe 220e N PSTA Figure 3-22 Pressurizer Guard Heater Bias for Adiabatic Pressurizer for Tests Prior to April 3,1984. 1 l l O 3-41
I
? l l
.t F 'l l ,1 _f. l
- . 00 PRTC06 - - PRTCO3 PP.TC10 ,
-PR DT03 b l 4,PRPROI y e
h E I PRTC05- -
+400
- PR CO2 W
S I E
-PRDT02 $
PRESSURIZER PRTC09 2
\ -
8 w
+300 #
O w
'[d - PRTC01 PRDP01 g
w PRTC04- -PR HR01 m 1 r
+200g i
E
-PRDT01 BOT LEG N PRTCOB g
- +100 PRTC11
-PRDT04 o
I PRTC07
-0 Figure 3-23 Pressurizer Instrumentation I
u
\
3-42
pressurizer. Pressure, differential pressure, and guard heater AT measurements were also made and recorded as test data. The surge line metal temperature and l the guard heater AT measurement were made in the vertical leg of the surge line as shown by Figure 3-23. A second metal temperature (PRTC07) was positioned at the surge line low point. Additional instrumentation was included for loop operation but was not recorded as test data. These included high temperature and high pressure trips for the heaters, current meters for the main and guard heaters, a pressure gage, and an indication of pressurizer level. 3.6 HIGH PRESSURE INJECTION AND FACILITY WATER SUPPLY AND CLEAN-UP SYSTEM A high pressure injection (HPI) system was included in OTIS that provided the scaled head-flow characteristics of the plant HPI pumps. The system was capable of providing flows up to about 3 GPM. A John Bean pump, 4 MS B a three piston positive displacement pump, was - used to provide the scaled HPI flows. Output from this pump was controlled to simulate the desired head-flow characteristics. The system was capable of simulating either low (~1700 psi) or high (~ 2500 psi) shut-off head plant systems. Control of head-flow was through a Research Incorporated Model 5110 DATA-TRAX. The DATA-TRAK Programmer was an electro-mechanical instrument designed to position the shaft of a rotary output device in accordance with variations in a preplotted program attached to a rotating drum. The preplotted program was a X-Y plot of the head-flow characteristics to be simulated. Pressure was plotted as the X-coordinate and flow as the Y-coordinate. The pressure signal was from i RVPR01 (reactor vessel pressure) and the flow signal from HPTM01 (total HPI flow
- turbine meter). Each was plotted in terms of 0 to 100% of full range output. As the drum rotates to track the pressure variation, the sensor probe follows the etched line in accordance with the head-flow curve. , The output device signal was varied in an amount proportional to the prescribed fiow. As the demand for flow was changed, the position of the HPI by-pass valve, HPCV03 in Figure 3-24, was varied.
e 3-43 o ..
- - _ _ ___ - ,_. _ . _ m ._ ..
)
4 i i i i TO COLD LEO TO COLD LEO DISCHARGE SUCTION it A ynPHvas %HPNV45
- 3_3. 3_.0 li; R :
TO PRESSURIZER SPRAY HeHv4e w )(HPTM02 1
- . HPI PUMP l $ x X '
) _ rnoM rAcet Tv 1
HPTM03 HPTM01 ~ WATER SUPPLY HPTC01 l HPCv03 l 1 l i Figure 3-24 High Pressure Injection System i i
To verify the operation of the head-flow controller, a test was run during
, the GERDA program where the loop pressure was varied from about 200 psia to just above tne MK shut-off head of 1863 psia, and then back to 200 psia. The head-flow curve for 4 scaled MK HPI pumps was simulated. The results of this test, shown in Figure 3-25 verified the ability of the controller to match the HPI shut-off head and the head-flow curve.
In the OTIS test program a simulation of LPI was provided with the John Beam pump by including the LPI head-flow characteristic of interest on the HPI curve tracked by the DATA-TRAK. Figure 3-26 shows this concept for the OTIS " Nominal" HPI/LPI head-flow characteristic. The ability of the control system to track the i LPI portion tf the centrol syste- te track the LPI pertica of this characteristic - is shown by the inset for Test 2202BB. As indicated by comparison of the I l experimental data (a) to the expected characteristic (solid line) two observations are noted:
- 1) The pressure for LPI actuation (240 psia) is missed during actual operation by about 10 psia. The major source of this error results from the uncertainty in the pressure measurement, (about +/- 7 psia) and comparable error in aligning the DATA-TRAK sensing head.
- 2) A significant data scatter and hysteresis is present during LPI actuation that directly relates to the error (sensitivity and response characteristics) present in the HPI control system. The existing HPI system shown in Figure 3-24 and controls were not designed to track the LPI head-flow characteristic.
l HPI supply was from the facility water supply system (to be discussed later in this section). The desired head-flow could be delivered to eitherge,HPI ' location on the suction side or discharge side of the simulated RCPh Each line contained a manually adjustable flow control valve, HPHV45 and HPHV46 so that the HPI could be divided, as desired between the suction side and discharge side of the RCP spillov,er. Turbine meters were installed in each branch, in addition to the turbine meter upstream of the split. This is illustrated in Figure 3-24. Check valves were installed in each branch line to prevent backflow in the HPI l lines. O 3-45
- - m rw 0N %') U P (BAR) 13 48 100 128.5 I I I i 1400 SN N A----A MEASURED
---- SCALED MK 1200 -
*( ,
! 1000 - ! c k } S
. 800 - -
Y b A a .a w I gSa 400 - s i
- m -
1
! A I
0 I I l 1 I I l Y 1 i 0 250 500 750 1000 1250 1500 1750 2000 4 DISCHARGE PRESSURE (PSIA) ' i
) )'
Figure 3-25 GERDA 4 Pump HPI Head-Flow Curve
2282BS.0 NO ClMRD HEf.TERS TEST 18-APR-84 2w \ J \ e 1996 A e 3 8# _ , M A
/
H 888
- R g ,,
79$ A a s#A, 86 A 600 , s,- 500 A' a n 4g A g
* **, s'kl _ _ _ _ - -
b l_ L.__ _ _ _ . . , , a 228 225 230 235 244 245 250 ' ~ THEORETICAL HEAD-FLOW PSIA A'"A EXPERIMENTAL EAD-FLOW 1400 < - h (230 psia 1332 lbm/hr) 1200. . 1000 -- 0 4 3 e a00 . I e 600 **
"0 TIS Nominal"
' (Tull Capacity, high shetoff h.ad)
(240 p.ia. 443 lba/hr) gno . . 2400 psia. 176 lbm/hr) LP1 EFI e O ~ 560 1600 15'00 2000 2500
....r.. ....
Figure 3-26 OTIS " Nominal" HPI/LPI Head-Flow Characteristic 3-47 l 1
The HPI system was supplied by the Facility Water Supply and Clean-Up System. ) This system, illustrated in Figure 3-27, provided high-purity deaerated water for initial filling of the primary and secondary loops, for leakage makeup, for removal of NCGs from the loop, and for HPI supply. Demineralized water from the plant reverse osmosis system was passed through a Continental demineralizer, then to an Epicor vacuum deaerator. The deaerator was operated at a fluid temperature of 110*F and a pressure of 3 inches mercury to provide deaerated water (<10 ppb oxygen) at flows up to 3 GPM. Flow from the deaerator could be supplied directly to the loop, either through the HPI system or through a Sprague pump. The Sprague pump, which is a single piston air driven pump, was primarily used for making chemical additions to the loop and for small amounts of makeup water. Water from the deaerator could also be stored in a 1000 gallon storage tank. In this storage tank, the demineralized water was kept at ambient temperature with a small gas overpressure. The conductivity of the water in the tank was adjusted to that in the loop to minimize the (conductivity) dilution effect during high pressure injection. Also, the gas overpressure was g3 selected to be either nitrogen or helium depending on which species was being used in the loop. Water stored in this tank could be routed back to the deaerator so that degassed water could be supplied to the loop. Upon completing a NCG test, the water in the loop was routed back to the Facility Water Supply and Clean-Up System, where it was degassed, and then returned to the loop using the HPI system. 3.7 PRIMARY VENTING SYSTEMS The function of the primary venting system was to provide a controlled le.'k for the release of primary fluid, and to provide a means of measuring the rate and total mass of fluid exiting the loop through the leak site. In OTIS there were six (6) leak sites - four (4) defined as single-phase region leaks, and two (2) defined as two-phase region leaks. Independent systems were used to control and meter the fluid from the single-phase and two-phase leak regions. The single-phase venting system will be discussed first. There were four controlled leak sites in the single-phase region - two (2) in the cold leg, one on the suction side of the simulated RCP spillover and one on the discharge side of the RCP spillover, one controlled leak at the bottom of the 3-48
i e
.. ~ u-
...-. - I I W.T.. .ufMT t - ,3
-, H- " .
R ..
"'"~h 3-,
. . _ , 3-,. 3- M- =p 3 ,,,, , --- .
-- e .n -#F' , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ,
* *- u ():'"" . ,,
; 2_ l
.rWW2, 8 3
= ="~-A- ! l -ch- -
l
" " ~ ;
C88EM ="
,,,,,yg y 0 o l "a 2 @, ,o
= .
so.. l
, ___. ...l
~
L8CW. m. g.- To , _P. woe l M
'
- X+='
a,, ,,,'"."* -a l f
- : e :
-~-o-~e y ,,
l t.____________. ...r = . =uo.c rie,=- PWW.3 Figure 3-27 Facility Water Supply and Clean-Up System O 3-49
- 1
l-f _ lower plenum of the reactor vessel, and one controlled leak at the top of the top ( plenum of the reactor vessel. These four leak sites tied into a common point, I' after which they shared a heat exchanger and a leak measuring system. The cold leg suction leak site was branched into four lines, each having a leak orifice. This arrangement avoided loop cooldowns for cold leg suction (CLS) leak orifice ; changes. This system is illustrated in Figure 3-28. ' Remotely actuated leak control valves were located just downstream of the leak control orifice. (The orifice assembly was discussed in Section 2.0.) The f- cnntrol valves and control orifice were located in 3/8" tubing. The control valves were 3/8" NUPRO "U" series sealed stem valves, which have a flow coefficient, Cv, of 1.0. After passing through the control valve, the fluid was cooled using a single pass, tube-in-shell heat exchanger. The heat exchanger had sufficient cooling capacity to handle single-phase leaks up to a scaled 50 cm 2 break. Downstream of the cooler the effluent could be sampled to determine the amount of dissolved gas prior to being collected in a collection tank. An accumulating flowmeter, Y1AC01, was used to measure the mass of fluid exiting through the leak site. Leak rate was computed (by the data acquisition system) based on the accumulating flowm'eter reading and the time interval between data [ acquisition scans. Fluid temperature was measured downstream of the meter. The l collection tank was mounted on a weigh scale to allow cross checks on total inventory leaked from the loop. Details of the single-phase leak system are given on B&W drawings 9574E and 9539D. I There were two (2) leak sites in the two-phase region of the loop - a high point vent (HPV), located on top of the HLUB, and a simulated pilot operated l relief valve (PORV), located on the top of the pressurizer. The effluent from these leaks was cooled, stripped of NCGs (if present), then the liquid and NCG l l mass flows were measured. A schematic illustrating the two-phase venting system is shown in Figure 3-29. Details of the two-phase venting system are given on B&W drawings 9559D, 9562D, 9563D, 9564D, and 9565D. j The HPV leak control valves, which were two 3/8" NUPRO "U" series sealed stem valves, were located upstream of the leak control orifice assembly, After passing / [ k through the orifice the steam-water-NCG mixture was condensed, cooled, and the l gases were separated from the condensate. A centrifugal separator was used to 3-50
RV TOP PLENLH O LEAK SITE v1Cv12 em SACVOS SACVW 8 vitCD3 $ TEAM
# GENERATOR g
CLD
# v1 cn2 R E ACTOR SITE CLS LEAK SITE h.v1Cv03 . . .. .
4V1MV00 VICV04 VICVM g VICV05 VICV07
-so-V1HV07 OACVOS GACV07
~ ~
RV INER PLINLH LEAK SITE hv1Cv01 V1MV06 COOLER
~
V1MV01 TO DEAERATOR
}(e vinv0.
b"" V1HV03 V1HV04 7 TO COLLECTION TAhK Figure 3-28 Single-Phase Venting System - General Arrangement and Instrumentation O l 3-51
(~ 1 V2TC03 MO di WNVet V3CV02 OneFeCE ir l VENT l , WTCM f
$4PV 30 OALLON h gggg i SEPARATOR f 3V2HV07
% i V2HVOS SURCE TANK l
V3CV93 V2CVOS WITC01 d' "" "" WUTM NORTH TANE TANK v ACOi Q .__ch_dih_ _ . V3CVO3 V2CV04 PORvLEAK cop,o' ~
~ _ _ -
PORv sTsAm
*E'^a^Toa v3Cv10 yy vzCvii mu J
TO U ORAIN V2HV01 g PRessumiram To AIN WaCvosh Vawvor { I 1P V3MV04 TO Cousenow TANE V3MVes t vtTC02
o>0 l W-3
) v TO COLLECnow TANE Figure 3-29 Two-Phase Venting System - General Arrangement and Instrumentation O 3-52 l 1
separate the liquid and the gases. The liquid level in the separator was maintained at a nearly constant level using a flow control valve, V2CV05, and the separator differential pressure. The differential pressure measurements associated with this system are shown in Figure 3-30. An accumulating flowmeter, Y2AC01, was used to meter the mass of steam-water removed through the HPV. The NCGs flowed from the top of the separator to the two 250 gallon tanks. When the internal pressure of the separator was sufficient to raise the water level in an overflow leg to its discharge elevation, water from the 250 gallon tank would spill over into either the North or South accumulator tank (whichever one was selected by the operator). The level in the accumulator tank was calculated from the differential pressure measurement, V2DP03 or V20P04. The volume of gas released through the HPV was then computed from this level change. The PORY leak control valves were located downstream of the leak control orifice assembly. As with the HPV a double isolation valve was used. After the mixture from the PORY was cooled and the gases were separated from the condensate, the liquid mass and gas volume were measured in a manner similar to the HPV. A Surge tank was used in parallel with the two accumulator tanks (North and South tanks). The purpose of the Surge tank was to provide a means of pressure relief for the system as well as to measure water displaced from the tanks. In the event a large quantity of gas was released, the lines to the North and South tanks may not be able to handle the resulting water flow rate without building up a backpressure. The large line to the Surge tank would provide a path to relieve the pressure and a means to measure this large gas release. The instrumentation associated with the two-phase venting system are shown on Figures 3-29 and 3-30. Included are limit switches on the HPV and PORY flow control valves; accumulating flowmeters to measure steam-water removed through both the HPV and PORV; thermocouples located in each separator, on the water side of the 250 gallon tanks, and at the Surge tank, a pressure transmitter, and the differential pressure measurements shown in Figure 3 . All these measurements were recorded as test data. 30 A test to verify the ability of the two-phase venting system to accurately meter gas removed through the HPV and PORV was performed as part of the GERDA 3-53
;y gl
~
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.. 3
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i g s 3- . ,,. , > .. Og ') .
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-? *
-t Ow.
y ,_ o a o [j %) I ~ ,
~
4 o
'1 t
4
' V2DP01 V2DP02 -
) V2DP03 V2DPO4 V2DP05 o _ ;-
'( .
HPV , 'f
=s- SEPARATOM o PORY'
' U5 'I -
SEPAR ATOR ' 5
* .\ s ,
.., ! /
3., n a
'i lf 1I lE
, 8
. ~ , ee'
, SOUTH NORTH SURGE
* -A '
ACCUMULATOR ACCUMULATOR TANK 4' -
+ TANK TANK M. t d
V,.. , . Figure 3-30 Two-Phase Venting System-Differential
;;1 Pressure Measurements a 'M-g,4
- p -
'j .~ 9,ri 'jj i I?-(-... -t;, _
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f?
}-
l-
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=44
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9 3-54 s+ s
.( ) d' .*k
.r=. _ _ l!
.1 program. This will be discussed in Section 4.3. The response time for the HPV and PORY flow control valves, V2CV01 through V2CV04 on Figure 3-78, was measured. .
The total time required for the valve to move close-to-open or open-to-close was less than one second, i I 3.8 SECONDARY FORCED CIRCULATION SYSTEM AND FEEDWATER HEATERS The purpose of the secondary forced circulation system was to provide feed flow to the 19-tube OTSG at flow rates from approximately 0.2 to 2.5 gpm (represents plant scaled flow rate of 340 to 4210 gpm) and at supply pressures from approximately 100 to 1300 psia. To supply the desired flow rates and pressures, an existing Sundyne LMV-311 centrifugal pump was used. The Sundyne pump was rated at 27 gpm at a developed head of 1600 psia. The arrangement of the pump in the secondary forced circulation system is shown in Figure 3-31. This arrangement allowed proper operation of the pump by returning most of the flow back to the hot well while passing the desired flow to the steam generator. The flow split between the steam generator and the hot well was varied by positioning the pump discharge valve, SFCV01, the by-pass valve, SFCV02, and the flow control valve, SFCV03 or SFCV04. The hot well was used as an accumulator tank for the secondary side of the loop. The hot well was located to provide the required net positive suction head (NPSH) for the Sundyne pump and was used to collect condensate from the condenser. Since most of the pump flow was by-passed back to the hot well, a system was required to remove the pump heat from the fluid in the hot well. This system will be discussed in Section 3.11. Chemical additions to the secondary loop were made into the hot well. A slight nitrogen overpressure was maintained on the hot well at all times. i A feedwater heater was included in the OTIS loop. This vessel was constructed using six (6) parallel and interconnecting 4" diameter pipes. A 20 KW electrical heater, Chromalox Model MTS3180AXX, was located in each of the interconnecting pipes. With the installed capacity of 120 KW, it would be possible to heat the feedwater from 100* to 500*F for flows up to 1.5 gpm. In the O. 3-55
/"' '
x . ( e.een .,,a.s ir
.~
N.. n STLSO2 *
->, == -- --
* @ X Y . . . ..
.,3 .[ u
=
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= M . . .
m sei .co'h-m ..
.co.
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--,.M 8j W
- I78 - 5 E-9., W )(+"~
_gg_g. gg . , , g g' " E k--J g.. .. . , - , 2 Figure 3-31 Secondary Forced Circulation System
- General Arrangement and Test Instrumentation
l OTIS test matrix, feedwater temperature was specified as about 100 F for all tests; consequently, the feedwater heaters were not used. Hand isolation valves i were provided that allowed by-passing the feedwater heater. Parallel flow control and flow measurement circuits provided for a high feedwater flow path and a low feedwater flow path. Each path contained a flow l control valve and a flow orifice. The flow control valves were Annin Series 94 valves with flow coefficients, Cv, of 0.075 and 0.55 for the low and high flow path, respectively. These valves are identified in Figure 3-31 as SFCV03 and I SFCV04. Each of these control valves was instrumented with a limit switch (SFLS01 and SFLS02) for positive indication of a closed valve. The flow orifices, l manufactured by Fluidic Techniques Incorporated were installed downstream of the flow control valves in a flanged spool piece. The orifices had a bore diameter of 0.207 and 0.312 for the low and high flow orifices, respectively. The meters had corner taps for the differential pressure measurement. The calibration of these meters is discussed in Section 4.9. High and low range turbine meters were installed in parallel flow paths, upstream of the feedwater heaters. These turbine meters were used as the standard for calibrating the steam and feedwater flowmeters. The details of this system are shown on BaW drawings 9501E, 9502E, and 9503E. The test data instrumentation associated with the secondary forced circulation system included the APs across the flow orifices. A high (0 - 100" H2 0) and low (0 - 20" H 20) range AP was used on each orifice. The remaining instrumentation in this system was for loop operation and protection and was not recorded as test data. For the domestic raised loop plants considered, i.e., Davis-Bessee (DB) and Tennessee Valley Authority (TVA), AFW flow is injected at a rate such that the steam generator secondary water level increases at a rate of not more than 3 feet l per minute. In OTIS, the feedwater valve positions were determined so that the 3 feet per minute level increase was obtained at about 1000 psia. These valve positions are given in Table 3-9. O 3-57 1
i
! Table 3-9 FEEDWATER VALVE POSITION FOR 3 FEET PER MINUTE LEVEL INCREASE Valve Valve Position Designation (% Open)
-SFCV01 93 SFCV02 55 SFCV03 60.5 During some of the OTIS tests, it was necessary to approximate the head-flow characteristic of the DB plant AFW pumps. The OTIS scaled AFW head-flow curve for the mentioned plant is illustrated in Figure 3-32. The feedwater valve positions were found at various pressures to approximate this head-flow curve. The positions are giken in Table 3-10 for Db simulation.
l Table 3-10 FEEDWATER VALVE POSITIONS FOR SIMULATING THE DAVIS-BESSEE AFW HEAD-FLOW CURVE Pressure, psia 200 400~ 600 800 900 1000 1100 1200 1250 1300 Flowrate,lb/hr 900 900 900 893 803- 691 554 392 281 108
- 'l SFCV01,. % Open 93 93 93 93 93 93 93 93 93 93 SFCV02, % Open 55 55 55 55 55- 55 55 55 55 55 SFCV03, % Open 71 74 80 89.5 88 84.5 79 65.5 55 30.5 t I a'
l
' 3-58 i
._ ._ - _ . . __ _ , _ _ _ - , . _ . _ . . _ _ _ . _ . _ . . _ _ . ~ , - - - . -
~ . _ _ _ . _ _ _
t O
-4:
0.3 - 0.2 - 7 s 8 g - DB 3 0.1 - O I I I I I I q ,. 1 O 800 1000 1200 1400 STEAM GENERATOR PRESSURE (psia) Figure 3-32 Auxiliary Feedwater (AFW) Scaled Head-Flow for the Davis Bessee Plant. I I O 3-59 i k.
). y 3.9 FEEDWATER PIPING b)' i This system extended from just downstream of the feedwater flow measurements (in the secondary forced circulation system) to the feedwater injection locations on the steam generator. This is illustrated in Figure 3-33. There were three (3) feedwater injection locations on the 19-tube OTSG; a high AFW location typical of that used on some 177FA OTSGs a low AFW location typical of that used on 205FA OTSGs, and an injection location just above the lower tubesheet. The two locations that simulated AFW injection were discussed in Section 3.3. These locations were used for testing. The inlet just above the tubesheet was used periodically to flush out the " dead leg" below the low AFW site. This inlet also served as a drain point for the steam generator. The instrumentation associated with the feedwater piping included a Resistance Temperature Detector (RTD) in each line and a thermocouple upstream of the split (to the three locations). The feedwater lines were arranged so that one
. feed path could be selected while the other paths were isolated. A remotely actuated control valve, with a response time less than 1 second, and a manually operated valve were located in each line. The two lines simulating AFW injection supplied a header arrangement that allowed either maximum or minimum wetting of the steam generator tubes. This was discussed in Section 3.3. The details of the feedwater piping and this header are shown in B&W drawing 9550E.
3.10 STEAM PIPING The steam piping system extended from the outlet of the steam generator to the piping upstream of the hot well. A schematic illustrating this system is shown in Figure 3-34.
-Steam exited the steam generator at elevation 619-3/8" centered on a point on the hexagonal generator adjacent to tube "H". A cross-section of the generator at this elevation is illustrated in Figure 3-35. After leaving the steam generator, steam passed through either a low flow or high flow path for steam pressure control and flow measurement, through a water cooled condenser, through v
, 3-60 b
l 1 O n FPRT03 610 3/s" 6 _ FPCV03 FPHV03 1 1 O FPTC01 FPRT02 i t b-CIO 71" 6 .FPCV02 FPHV02 FPRT01 4&FPHV01 FPCV01 3/s-FPHVO4 Figure 3-33 Feedwater Piping System - General Arrangement and Instrumentation O 3-61 k
1
)
\,s PSCV01 PSSV01h k
PSHV01 q
.a PSHV04 PSCV03 i
1- STEAM GENERATOR CONDENSER O LJ PSHVO3 PSCV04 k HOT ELL PSHV02 PSCV05 Figure 3-34 Steam Piping - General Arrangement O
, 3-62
)
4 0 f u N K u l l T l { s j j STEAM EXIT i nnnn I I I l n I ml H lonon v u lv u lv B l A j l E l P l t , 1 A>ln ln ln J C 1 D l N l l { A K j {A} n L { M j l Figure 3-35 Location of Steam Exit Pipe on OTSG l l 9
- , 3-63 I
l either a low flow or high flow path condensate backpressure valve, and then to the f ( 7 ,, hot well. The piping from the outlet of the generator to the hot well was 1" s
" Schedule 80 carbon steel pipe.
j t Parallel steam pressure control and flow measurement was provided for a high { and low steam flow path. The circuits were capable of measuring steam flows in 7 the range of 100 to 1200 lb/hr (represents plant scaled flow rates of 0.17 to 2.02
! x 106 lb/hr) over a range of pressures from 100 to 1300 psia. The high flow path steam pressure control valve, PSCV01, was a Fisher 1" DBQ with a 3/8" microform i trim. The low flow path control valve, PSCV03, was an Annin Model 9460 with a 1.0 L (linear) trim. Each of these control valves was instrumented with a limit j switch (PSLS01, PSLS02) for positive indication of a closed valve. A fl ow orifice, manufactured by Fluidic Techniques, Incorporated, was installed in each flow path. The low flow path orifice had a bore diameter of 0.296" while the high flow path bore diameter was 0.441". The steam meters utilized corner taps for the differential pressure measurement. The calibration of the steam flowmeters will i be discussed in Section 4.9. The meters were installed in the steam pipe in a flanged spool piece section.
The response time of the steam pressure control valves to go close-to-open and open-to-close was measured during the GERDA program. The results are shown in Table 3-11. The delay time was the time from actuation until the stem began to move. Ramp time is the total time from actuation to full closed (or opened) position. l Table 3-11 STEAM CONTROL VALVES RESPONSE TIME Close Open Delay Ramp Valve to to Time Time Identification Open Close (Seconds _)__ (Seconds) PSCV03 X 1.2 5.5
# PSCV03 X 1.6 5.1 ll PSCV01 X 1.2 6.0 PSCV01 X 1.2 5.9 a
]' Note: Loop pressure was 25 psia, loop temperature was 90*F and instrument air
) pressure was 92 psi.
3-64 d-l
j i
! The steam condenser was a single pass, tube in shell, counterflow heat exchanger. Steam was on the tube side, inside a 1-1/2" Schedule 80 pipe, while i shell side coolant was enclosed in a 3" Schedule 40 pipe. The heat exchanger was about 78' long with about 30 ft 2of cooling surface available. The condenser was
[ capable of removing about 335 kw of heat input. Tower water from the plant's main tower provided cooling water for the condenser. Downstream of the condenser were j two Micropak 1" control valves (one for the high flow circuit and one for the low flow circuit). These valves were intended to backpressure the steam control valve and thereby extend the range for steam pressure control. The valves had a trim of 0.25 L and 0.04 L for the high and low flow circuits, respectively. Details of
, the steam piping system are shown on B&W drawings 9513E, 9514E, 9515E, and 951GE.
l The instrumentation associated with the steam piping is shown in Figure 3-36. The measurements recorded as test data included the thermocouple and RTD just outside the steam generator, and the thermocouple in each flow measuring branch, steam pressure, and the differential pressure across the steam flowmeter. Dual l range APs were used for each steam flowmeter, a low range (0 - 125" H20) and a high range (0 - 500" H20). The other instrumentation shown in Figure 3-36 was used for loop operation and not recorded as test data. Automatic control of steam pressure was available for either constant pressure control or pressure ramp control. For constant pressure control, the output from a pressure transmitter provided the signal to modulate the steam pressure control valve to the desired set point. The process line for steam pressure was located near the steam exit from the generator at elevation 619-3/8". During the course of a SBLOCA, the plant operator initiates loop cooldown by decreasing steam pressure at some rate. In OTIS, this steam pressure ramp control was simulated using a Leeds & Northrup 1300 Process Programmer. The cooldown rate was keyed into the programmer as a series of linear segments of pressure
, (saturation)andtime. A test was conducted during the GERDA program that verified the operation of this controller for a 50 F per hour ramp from 700 to 200 psia.
f O j 3-6[
I
- )
TO i i SDM1 PSLS01 PSDP02 PSPR1M 01 PSTC04 PSRT01 ' pstgo2 . O G k
^ .
PSDP03 PSPR101 PSTC01 PSTC05 PSDPO4 PSTC100 A O V PSTC101 h h m- Sc Figure 3-36 Steam Piping Instrumentation ! l lI li l l l O 3-65
\
S 3.11 SECONDARY LOW PRESSURE CLEAN-UP SYSTEM (SLPCUS) The purpose of the Secondary Low Pressure Clean-up System (SLPCUS) was two-fold. One was to remove heat added to the secondary-side fluid by the main secondary forced circulation pump and the second was to remove suspended and dissolved contaminants from the secondary-side fluid. This was accomplished using the hardware and instrumentation shown on Figure 3-37. The subsystem hardware was arranged so that a Worthington D512 pump takes suction from the hot well to provide a flow of approximately 20 gpm through a counterflow heat exchanger. The counterflow heat exchanger was sized to remove heat from the secondary fluid added by the secondary forced circulation pump. The heat exchanger was used to maintain the feedwater temperature less than or equal to 120*F. ?l Downstream of the heat exchanger the flow was split by valves SCHV04 and L SCHV05 and either returned to the hot well or passed through the clean-up system. Approximately 4 gpm was passed on to the clean-up system while the remaining flow was returned to the hot well. The 4 gpm flow was directed through a CUNO 5 CD1 filter with a 5 micron filter cartridge to remove suspended contaminants and through a CUB S-300 demineralizer with NH4 0H resin to remove soluble contaminants. Af ter passing through the demineralizer the flow was returned to the hot well. All of the instrumentation shown on Figure 3-37 was required for loop operation. As such, the output from these instruments was monitored to insure proper operation of the system but was not recorded as test data. 3.12 NONCONDENSIBLE GAS ADDITION L The function of the noncondensible gas (NCG) addition system was to add a known quantity of NCG into the primary loop. The NCG was added as a batch addition. Batch addition of a known quantity of NCG was performed by expanding the gas j
- at an initial pressure and temperature from a known volume into the primary loop.
A schematic of the NCG addition system is shown in Figure 3-38. The source of NCG 3-67
I h SCMV14 HEAT EXCMANGER I I l PSIA II FLOWMETER SCMV04
,~
I SCMV02 SCSV01 SCCV01 SCMV12 O m
- 1 FLOWMETER fROM hSCMVOS FLPCUS HOT 7 mu )
PSIA " D", ",va O -# #SCMV07
,,,,E , SCMVOS d PSIA P8'A SCMV01 SCMVII CUNO CIRCULATING F8LT.a OT otMia RAU2ER SCMVt3 s *
- l Figure 3-37 Secondary Low Pressure Clean-Up System General Arrangement and Instrumentation I
i 4
, O 4
3-68 c L
r O GATC02
- GACV02 HOT LEG GACV01 UBEND GATC03
. GACV04
- UPP R HEAD GATC04 L
ACV06 GACVO COLD LEG GATC01 GAPR01 i REGULATOR GAHV02 GATC06 GACV08 _ REACTOR GAHV01 _ GACV07 VESSEL t CYUNDER1 - () FILTER CYUNDER 2 _ l l CYUNDER 3 _ l FROM GAS l SUPPLY Figure 3-38 Gas Addition System - General Arrangement and Instrumentation
, e li 3-69
1 was a standard size 2500 psia gas bottle. Nitrogen (N )2was used during OTIS
, Q testing. There were three reservoirs available for gas addition. One or more h reservoirs were selected based on the quantity of gas to be added and the loop pressure. A computer program, GASADD, was used to select the appropriate reservoir (s) and/or tubing volumes and the initial pressure to which this volume f
should be pressurized to make the desired addition. The volume of the reservoirs and tubing is included in Table 3-12. Table 3-12 GAS ADDITION RESERV0IR VOLUMES Reservoir Volume. in 3 J Tubing (T) only 40.14 1 T + cylinder 1 107.81 T + cylinder 2 177.24 3 T + cylinders 1 and 2 244.91 T + cylinder 3 394.92 T + cylinders 1 and 3 462.59 T + cylinders 2 and 3 532.02 T + cylinders 1, 2, and 3 599.69 Prior to adding gas to the loop, the gas supply was isolated, the active volumes and gas pressure were checked, then the gas was added through the appropriate ' isolation valves. There were two isolation valves, NUPRO "U" Series sealed stem bellows valves, at each gas addition location. These valves were remotely operated from the control room. There were four locations in the primary loop where NCG could be added. They were: e Lower plenum of the reactor vessel e Cold leg piping, downstream of RCP spillover e Top of steam generator o Top of HLUB These locations are illustrated in Figure 3-39, , l' 3-70 l
i O i i 4 < I a
.S U
8 e l }- 2
* \'
C is m
, ;, -5 e ,u
- r h N =
E p' OK g 0XRN 4 + -X g4 3 rDG-Wh i, s [. r
'X j% F m
*X a tfg~j l@s .
4, E> n F- M_ 1 l l i e 3-7L l
i k-("% 3.13 DATA ACQUISITION SYSTEM (DAS) y The OTIS facility had a Digital Equipment Corporation (DEC) PDP6 11/34-Einicomputer and Analogic ANDS 5400 data acquisition system dedicated to the o facility for data acquisition and on-line data processing. A number of input / output devices were attached to the PDP 11/34 for user communication to the DAS and prompting of data display options. In addition, a DECnet7 link from the PDP 11/34 to the existing VAX6PDP 11/780 computer at the Alliance Research Center
~
was used for direct communications with this computer. The system architecture that make the OTIS DAS is shown in Figure 3-40. An Analogic ANDS 5400 was used to acquire analog voltage, digital, and frequency data from the test instrumentation. The architecture of the Analogic was such that analog voltages were input to one of three card types depending on the full scale range of the input. Analog inputs in the millivolt range to a maximum of 10.0 volts were digitized by the Analogic system. Sixteen bit, bipolar D (hence,15 bits plus sign) data acquisition rates of about 10,000 readings per second were obtained. Table 3-13 sumarizes the Analogic's resolution and accuracy for three full scale DC voltage inputs. Table 3-13 ACCURACY AND RESOLUTION OF THE ANALOGIC ANDS 5400 Full Scale Resolution Typical Input (yv) Accuracy Inputs
+/-40 av 1.2 0.05%/20 uv Thermocouple
+/-1.25 V 38 0.05%/625 uv RTD
+/-10.0 V 305 0.05%/5.0 my Pressure and differential pressure transmitters, watt transducer, con-ductivity probe (analog) q- 6 PDP and VAX are trade names for families of DEC minicomputers.
7DECnet is a hardware / software communication link for interconnecting compatible computers. 3-72 (
O
) .
NC R I T E YE. P D C S RO IR NH NT C
- EC T OS UI I
.E PM R l
QW T E S T R OV R Dass SJ M B M 5 M F T I DA 6 0 LM I H C 7 0 AL - 1 T {1 IG*S. Cw% 1C 7 l I DC P r (
- 4 t
)
T R C E E L T m N T E NE e C C0 I 0 R N t I P1 . t E G4 E A G s O5 C P PM LSNV -O .
,D "
r A y X D# t L S MH AD A , ' PI ADO C T V I NNC T t .N R n AA D A A . o
/ P C i A T
( t t , i s i u q c A a t a D S I T O O S 0 C I 8 1 9 L SL 4 HL R L 0 A R CA - PA E A 0N TOHII N 3 AN N I DLPM l R M I TI I RM 1M T I OA R e G OR WR V R E CR E r E CE T GT u R T T E T g i . E D F R X I NO R E _ OEI RDP TI O KV E C T O_ Yd I -
The filter on each of the Analogic voltage input channels attenuated the f amplitude of an analog voltage input such that an additional 0.05% full-scale input error was present at a frequency of 0.12 Hz. For analog voltage inputs with l { frequency contents greater than 0.12 Hz, the error caused by the filter increased ! j to approximately 30% at 5 Hz. i Raw signal data from a thermoc]uple (NLTC08), a differential pressure transmitter (HLDP01), and a pressure transmitter (RVPR01) were recorded on magnetic tape as well as by the OTIS DAS for the first 1.5 hours of an OTIS test. ; The magnetic tape data was analyzed to: ; e determine frequency content from OTIS instrumentation raw signal l data, e estimate the effect of the Analogic input filters on data acquisition, and , evaluate the ability of the OTIS DAS sampling method to record
}] e SBLOCA phenomena of interest.
The dctatied .e-Wt h givd. The analysis
- showed that the transient data was f tracked well by the OTIS DAS. Spectral analysis of the raw signal fluctuations showed that fluctuations were less than 5 to 10 Hz, and typically of low magnitude. Errors introduced through the filter characteristics of the Analogic l
- and by sampling at OTIS DAS rates (0.2 Hz) were found to be negligibly small in most cases. It .W$ncluded that the application o the acquired OTIS data for code benchmarking exercises on a macro scale does^r${ot warre l
frequency to more accurately acquire the data on a micro scale. j Measurement accuracy of a frequency input (such as from a turbine meter) was conservatively set at +/-0.1 Hz for frequency inputs from 1 to 100 Hz and +/-0.1% l f of the reading for inputs of 100 to 5000 Hz. No error was associated with the input and handling of a digital input. Digital inputs resulted from limit f switches and from the conductivity probes when first processed by the Creare i t I 1 8"0 TIS Signal Analysis," ROD:84:4091-30-01:01, H.R. Carter to Distribution, September,1984. 3-74
i electronics and microprocessor Similarly, no error was associated with measuring the counts obtained from the output of the accumulating flogmeters at their output frequency during ,peration. Calibration checks of the Analogic ANDS 5400 were achieved by substituting a specf ally configured MAC patch panel in place of the panel used during test data acquisition. This panel wired all analog voltage input cards of the same full scale input in parallel so that a single connection of a calibration standard allowed the whole series of channels to be simultaneously checked. The calibration check was performed periodically, depending upon past history and stability of the Analogic. Control of the Analogic DAS and data processing was through the PDP 11/34 minicomputer controlled under a real time (RSX-11M, Version 4) operating system. User software was written in Fortran IV Plus with software instructions stored in the 11/34 memory (256 K bytes) and/or on disk. Data in raw and/or engineering units was transferred to one of the two 10 mega-byte disks for temporary storage during data acquisition. Between tests when data acquisition was not required. the PDP 11/34 disk records were transferred over the DECnet to much larger disk drives (176 mega-bytes) on the VAX 11/780 computer for conversion to engineering unit data and permanent archival on tape. In addition, the VAX computer was connected to the computer center at UPGD via a telephone link and thereby provided a data transfer means to UPGD. The flow of data from the PDP 11/34 to UPGD will be discussed later in this section. A MAC patch panel was used to provide a flexible interface between transducer inputs to the DAS and the Analogic and PDP 11/34. The MAC panel could interface up to 1088 3-wire connections. Because of the desired flexibility when routing input channels to the Analogic and the parallel capability to route any input i channel to a secondary data acquisition device (such as a magnetic tape recorder, I pen-type strip chart recorder, digital voltmeter, etc.), the actual capacity of the MAC panel was reduced to about 350 input channels.
, 9 3-75 2
i User communications with the PDP 11/34 and 11/780 computers were through the O Q four terminal devices as shown on Figure 3-40. A DECWRITER III terminal was j available for hardcopy listings of data, source listings, or system error messages from either the PDP 11/34 or the VAX 11/780. A VT-100 DEC terminal with the RETR 0 GRAPHIC option was connected to the PDP.11/34 and VAX 11/780 computers and was used for software development and display of test data in graphical format during data acquisition. A second VT-100 DEC tenninal was used to display test data and/or loop operating parameters. An Industrial Data Terminals (IDT) Model 2000 color graphics tenninal was available for color graphic display of the OTIS test loop and selected test parameters during the test program. Color graphical displays of loop parameters such as the water level . temperatures, pressures, flow rates, etc., provided important real-time visual feedback of the loop behavior during transient tests. The graphical displays of the RETR 0 GRAPHICS terminal could be recorded in black and white hardcopy form using a TEKTRONIX Model 4632 video copier with enhanced grey scale.
'l Data acquired on the OTIS data acquisition system resided on the PDP 11/34 disk until the test engineer down-loaded the file to the VAX 11/780 computer for
!l data processing and long term archival. Once on the VAX, additional manual operations were required to ultimately transfer the converted engineering data file to UPGD, Lynchburg, and to archive the data to magnetic tape. In Section 3.13.1 the commands necessary to trace the path of data processing from the PDP
! 11/34 to the VAX 11/780 with u'Itimate data transfer to UPGD and data archival to tape will be described. In addition, the routines available for data file revisions or updates and subsequent data processing are defined.
3.13.1 Initial Data File Processirig The initial flow of the data file strictly involved its acquisition and processing to transmit a condensed part of the engineering data file to UPG0 for issuance of the Initial Report plots. Once processed at Alliance, the raw and converted engineering data files were archived to magnetic tape for long term f storage.
- I A flowchart illustrating the processing steps for a raw data file is shown on o
C Figure 3-41. A discussion of this flowchart and the routines available at ARC are ~ { 3-76 L
b PDP 11/34
- O Data File (ASC2! or II"**WI Convert Raw no to m gr III Engineering Data File?
VAX Data File (ASCII or 31 nary) es (5) ir Engineering Ves , ASCII Data File I'7 .E00 no (2)
"8
> y
.HDR File ,
.5CN File ges (6) ir (3) if Tape Files
,' g g ASCII Raw
.CMD
; Data File
.R00 CD m no
@O ."O
..t. "
Tap /et rans Wes (7) ir yes (4) if Mail Tape to UPCD, Engineering Lynchburg Data File
.E00 gr q,
Condensed r x E00 File for Plots
> > CDC
( STOP f (#1 0 entleseJ in parentheses refers to VAX command procedures that are discussed in the accompanying test. 7 Figure 3-41 Initial Processing of OTIS Raw Data Fike
\
O 3-77
r defined below. Numbers enclosed by parentheses on the flowchart correspond to VAX command procedure data processing routines and are referenced in the following text using the same nomenclature, i.e., the number enclosed in parentheses. (1) The data acquired on the PDP 11/34 was transferred to the VAX 11/780 using a Digital Equipment Corporation (DEC) file transfer routine called DECnet. The PDP user manually installed the DECnet transfer routines on the PDP by issuing the command 0[1,2]NETSTART. Once loaded, the data file could either be sent to VAX while logged on the VAX or logged on the PDP. If logged on the VAX the following command resulted in transfer of the data file: COPY SBLOCA" SYSTEM SYSTEM"::DL1:[PDP ACC'NT] PDP EXT VAX. EXT If the user was logged on the PDP and wished to perform the transfer to the VAX from the PDP, the following command was required: NFT>VAX/USERNAME/ PASSWORD //::VAX. EXT =PDP. EXT O V The transferred raw data file could be either in binary or ASCII format (2) at this time. depending upon how data save took place as defined by the test engineer. If the file was saved in binary, then two operations must have taken place to convert it to an ASCII format. First, the file was operated on using either the VAX command procedure DAYASC or NITASC j depending upon whether day batch or night batch processing, respect-I ively, was required. These routiaes translated the binary file to ASCII and " split" the r n data file into two parts -- a header section consisting of the legend and VTAB list, and the data portion for each time scan. In so doing, any additional comments to the legend that need to be included to document the completed test prior to its distribution to UPGD could be included at this time. The header section was small l enough that the VAX editor can easily be used to add any comments. This was important because with large files it was not possible to edit the header without first separating the header from the remaining data 1 (3) scans. The second step combined the ASCII header and data scan parts into a single file. Execution of either the command procedure DAYCOP or 3 3-78 (
i \ ! NITCOP (depending upon whether day or night batch processing was desired) merged the two files,into the single ASCII raw data file. As { indicated on the Figure 3-46' flowchart, this raw data file was denoted -
".R00", the "R" denoting the " raw" data file and the "00" indicating revision 0 of the file.
(4) To begin the process of making plots for the Initial Reports, the user manually invoked the execution of the command procedure, DATRNS or NITRNS, once again depending upon whether day or night batch data processing was required. This command procedure caused the conversion of selected raw data file scans to their corresponding engineering data file (denoted ".E00" on the flowchart) scans. Raw data scans to be converted to engineering unit scans were selected based upon a user predefined list of significant events during the test transient and corresponding data conversion time steps for each event. If this sorted engineering data file contained more than 250 time scans (the maximum
, allowed for UPGD plots). then an additional sort took place prior to data transnission to UPGD that limited the data file to 260 scans, In addition, this data file contained only those VTABs previously defined by UPGD as needed for the Initial Report data analysis and presentation.
Hence, the data file contained only a portion of the data base VTABs and a maximum of 260 time scans. I In the event that electronic data transfer to UPGD was not desired but the converted engineering data file was still required at ARC, a (5) number of conversion routines were available at ARC to create the engineering data file and provided additional listings of the legend part of the data file and/or a listing of the entire header (legend plus VTAB listing). This conversion was accomplished by executing a VAX command procedure depending upon the information desired and the mode of data processing -- real time, day batch, or night batch. In Table 3-14 these command procedures and their options are summarized. O 3-79
\
l ( Table 3-14 O. O COMMAND PROCEDURES FOR ENGINEERING DATA FILES Command Legend and Data to Procedure Batch Chrono Files UPGD CNVRE no - real time no no CNVRT no - real time yes no BCNVRT yes - day batch yes no NCNYRT yes - night batch yes no DATRNS yes - day batch yes yes NITRNS yes - night batch yes yes At this time, two data files were resident on the VAX computer, a raw data file, ".R00", and an engineering data file, ".E00". These files were stored to tape using command procedures on the VAX. The original (6) raw data file, ".R00", was saved to tape by executing the command procedure ORIGIN. A backup copy of the raw data file was created by running procedure BACKUP. Finally, the raw data file and engineering
' data file were saved as pairs on a tape by executing the command procedure COMBIN. These three steps created the data tapes ".0RG",
".BCK", and ".CMB", respectively, as shown on the flowchart. As c
indicated, three copies existed of the original version of the raw data file, ".R00". In the follow-up to the electronic data transfer for the Initial Report (7) the complete engineering data file created at ARC was copied to a CDC compatible tape at ARC and mailed to UPGD, Lynchburg. This tape was created using the VAX command procedure ENGR. 3.13.2 Post Processing of the Data File f
- ! After processing and transmitting the data file for the Initial Report, modifications to the data base were needed to remove or correct deficiencies to q the data base files. Additional comments to the data file legend and corrections jO to the data file VTAB listing were required. After implementing these corrections v
3-80 ?- (-
l the revised raw data file was converted to engineering units and the engineering data tape mailed to UPGD. The flowchart shown by Figure 3-42 traces the steps I required for file handling and the VAX command procedures needed to implement each. The original raw data file (or most recent revision) was migrated from tape back to the VAX disk. If the raw data file was too large for use of the VAX editor and available user disk space, the user executed the (1) command procedure DSPLIT or NSPLIT (day or night batch, respectively). These routines operated on the ASCII raw data file and split it into a header portion and a data scan portion. The user could then easily i operate on the header portion with the VAX editor -- making the needed additions to the legend and corrections to the VTAB parameters. After (2) completing the revision to the header file the two were combined to a single revised raw data file by executing the command procedure DAYCOP or NITCOP, described previously. The resulting raw data file is denoted on the flowchart as ".RO#", where the # symbol refers to the raw data file revision number. With the revised row data file complete, conversion to the corresponding O (3) engineering data file, ".E0#", was achieved using one of the command procedures previously defined -- CNVRE, CNVRT, BCNVRT, or NCNVRT. Note that neither DATRNS nor NITRNS were used since electronic transfer of data to UPGD was not performed for the revised data files. (4) The revised raw and engineering data files were archived to tape using j the command procedure COMBIN. Backup of the revised data files were periodically performad using VAX system commands to duplicate the magnetic tape. (5) The complete engineering data file could then be copied to a CDC compatible tape at ARC and mailed to UPGD, Lynchburg, Virginia. Thi s tape was created using the VAX command procedure ENGR. G 3-81 1 I
/ I j
; <[
t ( lt 7 I
\~ J .
onvert Raw no
} Engineering 3, , Data File?
f s y arge no I Raw Date sle* ges (3)
} 1r j .; ,
,t iges (1) Engineering Data File ir E0t*
.HDR File g
.SCN File i Tape no
, Storage * ?
gr i . ' ges (4) Perform I Editing 37 Functions - Tape Files J ;
'I23
- CMD
gr
- [D Raw Data no
' ,8 ,, CD0 m
'" Y
- ges (5) ir
'e '
.[:, , Mail Tape to UPGD, ] Lynchburg
>t
- ,-t b*f
<('
gr STOP 7 e e denotes the revision number of the file. (#) G enclosed in parentheses refers to VAX command procedures that are discussed in the accompanying test
- i ri ' .
'i ^ Figure 3-42 Follow-Up Processing of OTIS Raw Data File 1
+
3-82
~
e
- . . _ ~ _ _ . _ _ _ , . . , _ _ _ . _ _ . . . _ _ _ _ _ _ _ _ _ . _ _ . _ _ _ _ _ _ . _ _ _ , . _ . _ _ , _. _ _ , . ,, ,
l
- Additional infomation and listings of the command procedures and Fortran source code defining the routines referenced in this document can be found in the I
$ QA documents listed in Table 3-15. 3.13.3 User Input For Definition of the OTIS VTABLE Database The database for the OTIS data acquisition system was designed so the user could define all parameters needed to couple each of the user defined table entries (VTABs) to the available options in the data acquisition software. This information was stored on disk in account DLO: [201,10] with the file name, VTABLE.DAT. The VTAB generally corresponded to an instrument such as a thermocouple pressure transmitter, conductivity probe, etc. However, the VTAB may have referred to a "non-instrument entry" desired t" the user to more appropriately define the output of the inst dment. For examp an orifice used for flow measurement was monitored by a differential pressure transmitter that measures the pressure differential across the orifice. It was necessary for the data acquisition system to measure and record this differential pressure but it was also convenient for the operator to have an on-line indication of the flow rate based on this measured differential pressure. The OTIS data acquisition sof tware allowed the user to define a second VTAB which contained the necessary conversion constants and reference VTABs (or instruments) to compute the flow rate through the orifice. This flow rate remained in memory until the next data acquisition cycle. Hence, any on-line calculation for the current data acquisition cycle would have this flow rate available without the need to recompute the flow. This flow rate was also present in the off-line data base for distribution to users outside of ARC. l 9
, O 1
3-83
^ " " '=="'E - a -,a A :.m. a _ m _ __ _
e !. s Table 3-15
, QA DOCUMENTS FOR SOURCE CODES AND COMMAND PROCEDURES 2
QA Routine Document l-{. DAYASC QA0102.000 f NITASC DAYCOP NITCOP lll ~ [ DSPLIT QA0103.000 NI NSPLIT l W (. CNVRE QA0100.000 CNVRT BCNVRT NCNVRT
.(~' DATRNS l NITRNS Details Defining the Conversion. QA0097.001 from Raw to Engineering Units l
l ORIGIN QA0101.000 l BACKUP l- COMBIN ENGR b- ? Il. 3-84
--%-w-,- -,r,-,.m.,,,.e -w---.-,--,y-,---,+..---,--e,,--- re-- - - - - - .-- -----,,=,--,-.-..-----.7 - . . ,,
l i i' With this introduction, the following options required user input for each VTAB and are summarized below. I e Global definition to the data acquisition software regarding the status of a VTAB, i.e., in or out of service, use for loop alann indications to the operator, or use for control of the time interval between data acquisition scans. e Identification of a VTAB for alarm monitiring and the parameters required to define the low and high alurm values, and alarm deadband. e Identification of a VTAB for rate control of the data acquisition hardware, i.e., based on the rate of change of a VTAB raw data signal or engineering value, the time interval between data acquisition scans is either increased or decreased. e Definition of the ANALOGIC ANDS 5400 " card" (analog, counter-timer, or digital input) and ANALOGIC channel associated with the VTAB. e Conversion of the raw data signal (voltage, frequency, digital input, count, etc.) to the appropriate value in engineering format or units. This operation requires the following user defined information:
- Calibration constants and material or test loop geometry constants needed to perform the raw data signal to engineering format conversion.
- Reference VTABs (or instrument readings in this case) needed to perfonn the raw data signal to engineering format conversion.
e Definition of the " units descriptor" tex., DEG F, PSI, LBM/HR) associated with th: converted engineering value for each VTAB. e Definition of the number of significant decimal places that will be associated with the converted raw data signal to engineering value. e Descriptor associated with each VTAB for user ease in identification of the VTAB. I I The parameter order and fonnat for each of the VTAB data cards is contained in Appendix D. O l 3-85
i 4.0 LOOP CHARACTERIZATION TESTS The purpose of the loop characterization tests was to debug the mechanical and f electrical components, to characterize the operation of important loop systems (such as high pressure injection, guard heaters, etc.) and to calibrate in-place selected instrumentation. For reference, the results of the GERDA Phase O tests are documented here as well as in the final revision of the GERDA Loop Functional Specification (RDD:84:5168-01-01:01). The six (6) major test categories, along with the section of this report in which the results are contained, are identified in Table 4-1. A list of the test runs recorded during GERDA and OTIS Phase 0 is included as Appendix E. . 4.1 HELIUM LEAK TEST Tests were completed during the GERDA program to determine the extent of noncondensible gas (NCG) leakage from the primary natural circulation loop. The
- loop was drained under a helium blanket until the water level was about 72" above l
the secondary face of the lower tubesheet (SFLTS). This is approximately the
- elevation of the top of the reactor vessel. The helium pressure was increased to about 1000 psia. Based on the pressure decay with time, a leak rate of about 10-2 cc/sec was calculated.
A Matheson gas detector was used to " sniff" around the gas region of the loop to identify where the leakage was occurring. Leakage that produced a full scale 3 deflection of the gas detector, 8 x 10-4 cc/sec (~1 x 10-4FT /HR) or greater, was
- ' noted at the following locations
e hot leg U-bend (HLUB) view port windows both on the north and south side e conductivity probes, HLCP12 and HLCPO4, at the Conax fitting 9
- i. e hot leg isolation valve, RVHV02 I This valve was not present for OTIS testing.
O V
, 4-1
k Table 4-1 LOOP CHARACTERIZATION TEST CATEGORIES REPORT SECTION CONTAINING CATEGORY RESULTS
- 1. DEBUG AND CHECK 0UT I.1 Component, Instrument, and Control Operation Not applicable II. COMPONENT TESTS II.1 Feedwater and Steam Flowmeter Calibration 4.9 11.2 Steam Generator Volume 3.0, 4.12 II.3.A Discharge Orifices - Vapor and Liquid Region 4.2 II.3.B Venting with Noncondensible Gas (NCG) - 4.3 Pilot-Operated Relief Valve (PORV) Site III. COLD LOOP III.1 Leakage 4.1 III.2 Primary Volume 3.0, 4.12 III.3. A Filled NCG 4.10 III.3.B Yalve Response - Colo 3.1,3.9,3.10 III.4 Primary Flow - Cold 4.8 IV. HEATED LOOP IV.2.A Primary Flow - Hot, Low Flow 4.8 IV.2.B Heat Loss, Guard Heating, Stored Energy 4.5, 4.6, 4.7 IV.3 Temperatures 4.11 V. STEAMING (FORCED FLOW)
V.1 Cooldown 3.10 VI. ABNORMAL CONFIGURATIONS VI.1.B HPI Head-Flow Curve, LPI Simulation 3.6 VI.2 Reactor Vessel Vent Valve (RVVV) Head-Flow Curve 3.1 VI.3 Reversed Primary Flow 4.4 VI.4.A Level Indication with Condensation and 4.7 Guard Heating in a Vapor Region VI.4.B Venting with NCG - High Point Vent (HPV) 4.3 p i J O 4-2 'l
e reactor vessel vent valve, RVCV01 To get a feel how leak tight the loop was, consider how long it would take I l for helium to escape assuming that: e The measured leakage all occurred in the hot leg U-bend (HLUB) and the hot leg stub 3 (Volume = .65 FT ) c The HLUB and hot leg stub was filled with a 4% volumetric l concentration. single tube test {hote, a 4%the to elevate concentration was to primary pressure required in the greater than 2000 psia from an injttal pressure of about 900 psia.) (Volume He .026 FT = 736.32 cc) The time required for the helium to escape would be 66,938 seconds (18.6 hours) at 1000 psi system pressure. Based on these results it was concluded that the loop was leak tight enough to allow testing with NCG's, including helium. 4.2 DISCHARGE ORIFICES - VAPOR AND LIQUID REGION Scaled leaks up to 77 cm2 were tested in GERDA. Leaks of 5,10, 20 and 40 cm were tested in the liquid region (cold leg suction, cold leg discharge, bottom of reactor vessel), and 3,10, and 77 cm 2were tested in the vapor region (Hot Leg HPV and PORV). 2 To characterize the flow for each orifice size up to 40 cm , the critical flow rate was measured at pressures of approximately 1000 and 2000 psia for both 2 the liquid and vapor region orifices. Two 5,10, 20, and 40 cm orifices were 2 calibrated at these pressures in saturated water, and two 3, and 10 cm orifices were calibrated at the same pressures in saturated vapor. These calibrations [ 3 10 Condensation Heat Transfer Inside An Alloy 600 Once-Through Steam Generator (OTSG) Tube, LR:81:2987-07:01, G. C. Rush to J. R. Gloudemans, November 9,1983. b a 4-3
s l i were perfonned in the Steam Generator Test Facility (SGTF) pressurizer.t The-detailed-test-dete-4or-these 1:alibrat%ns is -containedM. The calibration test results are summarized on Figure 4-1 and Table 4-2. As shown by Figure 4-1, the steam phase critical flows compared well with the predictions of Fauske, Moody, and HEM. For the liquid phase orifices, the measured critical flows were approximately 1-3*. greater than predicted by Fauske. Figure 4-2 illustrates that as subcooling is reduced the critical flow is reduced until the fluid temperature reaches saturation. The flow measured at this plateau was taken as the saturated water critical flow and presented on Figure 4-1 and Table 4-2. The remaining data on Figure 4-2 was generated by increasing the pressure loss upstream of the leak orifice. The increased pressure drop caused the fluid at the orifice inlet to become two-phase. This resulted in a step-change reduction in the measured flow. The flow change (as noted during several orifice tests) was reversible and repeatable. i The critical flow rate for a 77 cm2steam phase orifice installed at the -
$ 1.
GERDA PORV site was also measured. The PORY was opened for about 15 seconds at pressures of 1900,1700, and 1550 psia, and the vented vapor was measured. The critical flow rate measured compared well with Moody predictions. The-detaHed- - resuits vi 44+-test-are_tacTuded 184 2 For the OTIS testing, a scaled 15 cm leak control orifice was also used. No characterization tests were performed for this orifice. Interpolation of GERDA leak orifice data was sufficient to characterize this orifice. 11 Letter from H.R. Carter to J.R. Gloudemans, Calibration of Leak Flow Orifices, SBLOCA-794, September 27, 1982. Letter from G.C. Rush to H.R. Carter and J.R. Gloudemans, Test 009910, Venting Through the Pressurizer Relief Valve Without Noncondensibles, SBLOCA-810, October 14, 1982. 4-5 t
O O O Table 4-2 CALIBRATION RESULTS FOR GERDA LEAK FLOW ORIFICES Orifice Test Normalized Test Normalized
, Orifice Diameter Arga Pressure Leak Rate Leak Rate 2
Pressure Leak Rate Leak Rate (in.) (psia) 2 Serial No. (cm ) (1bm/he) (1bm/hr-cm )_ (psia) (1bm/hr) (1bm/hr-cm )
- 52 0.0237 4.80 1060 155.3 32.4 2050 162.1 33.8 53 0.0241 4.96 1060 163.6 33.0 2020 173.1 34.9 12 0.0338 9.76 1055 294.7 30.2 2055 302.5 31.0 l 13 0.0339 8.82 1070 292.5 29.8 2050 300.8 30.6
! 56 0.u47 18.87 1045 580.6 30.8 1995 634.6 33.6 57 0.041 18.95 1050 572.3 30.2 2010 656.9 34.7 ! 58 0.0667 39.16 1000 1145 29.2 2060 1232 31.5 ) ? 59 0.0675 38.92 1005 1090 2R.0 2036 1115 28.7 i { SATURATED STEAM ! 4 0.0178 2.71 1050 14.2 5.2 1980 27.8 10.3 5 0.0180 2.77 1055 14.1 5.1 1990 27.8 10.3 ! 54 0.0319 8.69 1095 45.9 5.3 1985 87.5 10.1 55 0.0338 9.76 1000 42.0 4.3 1980 88.8 9.1- -l i i 1 i I I J
I O P(BAR) 79 100 150 48 I I 1 I s
- - - 30 g 4.1 -
I[A I , a 104- 4.0 - a I I g 20 l
\ il 3.9 <
MOODY
\ - 15 W"#
3.8 SATURATED LIQUID 3 FAUSKE "g
- ~t 3.7 -
^
"[ 5 x 10 CE 3.6 HEM #
{ - 10 o a g 3.5 -
\
SATURATED VAPOR
~ '
h n 6 < b 3.4 - z g oA ~ s
" 2 x 103 -
3.3 -
- d 3.2 -
e 3 CM 2 5 CM
- 3 g 3.1 A 10 CM 8 10 3- 3.0 - $ 20 CM 2 )
m 40 rM2 - 2 g
- l. o l 1 I I I I I i 1 l
' 800 1000 1200 1400 1600 1800 2000 2200 2400 P (PSIA) FAUSKE, MOODY, AND HEM (HOMOGENLDUS EQUILIBRIUM MODEL) CRITICAL FLOW 2 AT SATURATED CONDITIONS. GERDA CRITICAL FLOW is FOR A SCALED 1 CM LEAK. Figure 4-1 Measured and Predicted Critical Flows O 4-6
l i i i 1 L()x g340 E 320 eN O
!a 300 -
*N. e 9 g % ..e e 9 e--e e e4 E
= 2so 3
26o TIME INTERVAL 4o 0 o A-A.g d % g 20 -
\
l3, 10 I s. ti
, _ A -. A...A A A
- A-A A.A.A. A.A.4-4 4- A
-10 TIME INTERVAL Figure 4-2 Critical Water Flow for a Scaled 9.8 CM2 Leak 4-7 L .._ . . __ _. __ . . . . _ , . . , - . . . . . . . - . . , . _ , - _ . _ _ _ .
l
- t'
\
l 4.3 TWO-PHASE VENTING SYSTEM - CHECK 0UT TEST t j A GERDA test was completed to verify the ability of the two-phase venting system to effectively separate and meter the NCG's removed through the HPV and f PORY. This test was performed at the conclusion of GERDA Test 100145. 1 During GERDA Test 100145, a total of 37.19 SCF of nitrogen was added to l GERDA. Upon completing this test, the two-phase venting system checkout test was performed. The HPV was opened, allowing the NCGs to be vented out as the loop was slowly refilled. Periodically the PORY was cycled to vent any gases present in the pressurizer. The HPV remained open until the loop was refilled and the accumulator tanks indicated no more NCGs were being removed. The primary circulation pump was run after the loop was refilled to help release any trapped gases. After the free gas was removed, several grab samples were taken from the cold leg suction leak site for total gas analysis. The amount of gas removed from the loop was compared with the initial amount of gas in the loop. This is shown below in Table 4-3. Table 4-3 COMPARISON OF GAS REMOVED WITH INITI AL GAS VOLUME IN LOOP Initial Gas Volume Removed, Volume, SCF SCF NCG Added 37.19 --- NCG Vented --- 35.36 NCG Dissolved 0.045 2.86 Total 37.24 38.22 The amount of NCGs removed from the loop compare well with the initial gas content'.' its "+= d = "1 + e =nd-cakulations- for-this -test are included 4 l 13 Letter from J.E. Blake to H.R. Carter, Two Phase Vent Exercise, Run #009981, l SBLOCA-1009, March 11, 1983.
' 4-8 i
\ 4.4 IRRECOVERABLE PRESSURE LOSS CHARACTERIZATION - FORWARD AND REVERSE FLOW v The GERDA loop irrecoverable pressure drop characteristics must approximate l those of the MK plant to obtain similar natural circulation performance. SAVER Code calculations indicated that the GERDA primary loop piping was less restrictive than that of MK. To better match the irrecoverable pressure drop characteristics, orifice plates were added in GERDA. An orifice plate was added f near the reactor coolan'c pump (RCP) site to model the missing stalled RCP, and a venturi for flow measurement in the lower downcomer to match the loss coefficient in the RVVV loop. During OTIS testing the orifice at the pump spillover elevation f (used for flow rate measurement) was relocated in the cold leg to the steam generator outlet as shown by Figure 3-16. GERDA tests were conducted that allow calculation of the irrecoverable
- . pressure drop (Euler number) around the primary loop. These Euler numbers were then compared with the predicted values from the SAVER Code. Since natural I circulation pressure drops were too small for comparing measured and predicted s
Euler numbers, the tests were run with (nearly) isothermal, forced forward flow ( ) conditions. GERDA Test 0401CC, with a primary flow rate of about 20,000 lb/hr was ' used for comparison with the SAVER calculations # The measured APs are given in Table 4-4. Note that CLDP03, from the outlet of the steam generator to the RCP spillover, (including the cold leg orifice) was not recorded. The calibrated range of this transmitter precluded its use while in forced circulation. The fractional differences between the SAVER predicted and the adjusted measured APs ranged from -64% to +14%. The differences decrease with increasing AP. The sum around the loop of measured APs obtains a fractional difference of only -0.5%. h t:!'e af tha cat eu1 =+ 4ea- :.d the Len re d t: are 4acluded-ttth;-
.+
d 14 GERDA Forced Flow AP Prediction," B&W Document No. 32-1127192-00, 2/2/83. a 4-9 m . _ __ _ _ _ __ _ _ _ _ _ . _ _ _ _ . _ _ _ _ _
i A test was also perfonned to obtain loss coefficients for reverse flow in the primary piping loop. With a reverse flow of about 1600 lb/hr (~1.67% of full flow) the measured differential pressures were nearly identical (within transmitter accuracy) to the no-flow condition. The conclusion from this test was that for the expected reverse flows, irrecoverable loss was negligible in comparison with the gravity head. Table 4-4 COMPARISON OF GERDA MEASURED AND SAVER PREDICTED APs GERDA SAVER l " Corrected" Measured Predicted AP Transmitted AP, psi AP, psi HLDP01 0.762 0.426 HLDP02 0.785 0.482 HLDP03 0.156 0.056 SPDP01 1.572 1.682 CLDP01 0.260 0.143 CLDP03 -- 10.556 DCDP 02 2.092 2.390 f RVDP02 0.090 0.038 RVDP04 0.205 0.243 Total 5.004 4.978 j (excludingCLDP03) i 4.5 HEAT LOSS To determine the heat loss characteristics of the GERDA loop, a series of heat loss tests were conducted during GERDA Phase O Characterization Testing. l
' From these tests the total loop heat loss and the heat loss from the major components (reactor vessel, hot leg, steam generator, and cold leg) was determined. The heat loss was measured during steady-state conditions under natural circulation flow rates. To assure steady-state conditions, the loop was f allowed to soak at least 24 hours prior to taking the heat loss data. Data were taken both with and without the hot leg guard heaters activated (no surgeline or l
e
\
b 4-10
t k reactor vessel guard heaters were available during these GERDA heat loss tests). Pressurizer heat loss was determined during a separate test in which it was isolated from the loop. The overall loop heat loss (excluding the pressurizer) equals the core power 3 I required to sustain the loop temperature. Thus, loop heat loss was measured direc*ly by the core wattmeter. Heat loss for the major components was calculated based on the fluid enthalpy change between the inlet and outlet of each component. Enthalpy change was based on Resistance Temperature Detector (RTD) measurements located at the inlet and outlet of each component, and on the mass flow rate as indicated by the Venturi meter in the downcomer. The reactor vessel vent valve (RVVV) wae closed during all the heat loss tests. During these tests the secondary side of the steam generator was isolated. The water level in the steam generator varied from 0 to 67% during these tests. The overall loop heat loss, in terms of percent (%) full power versus steam generator inlet temperature, is shown in Figure 4-3. At 500*F with the hot leg guard heaters activated and with a wet steam generator, loop heat loss was about 0.55% of full power (1% of full power equals 22.4KW for GERDA tests). The component heat losses are shown in Figures 4-4 through 4-7 for the steam generator, reactor vessel, cold leg, and hot leg respectively. Steam generator heat loss, shown in Figure 4-4, was insensitive to the secondary-side water level,
]
as long as a level was present. The one data point taken for a dry steam t generator shows a lower heat loss than for a wet steam generator at the same temperature. l Hot leg heat loss, shown in Figure 4-7, was taken both with and without guard I
~ heaters activated. With the guard heaters activated (bias setting at 0.1), the hot leg was nearly adiabatic up to about 500*F. Above this temperature, the data indicates a net heat loss along the hot leg. At 535'F, the heat loss was about 0.045%.
Pressurizer heat loss was determined while the pressurizer was isolated from the loop. Initially, the pressurizer was at a steady-state condition with the M 4-11
F f i e ? l [d i 1 I l e.8
- o G ...
u . L a go P O W D ' e.4 E R D
- a 8.2 I
B--G SG ET - WITH GUNG EATERS *
*--+ SG DFU - WITH GDHD WATIRS
- l
+-+ SG uct - NO CUED HAERS see ase 4ee 4se see sse see SG IM.ET TDMRATURE DEG F I
- Hot leg guard heaters only, bias setting +0.1.
l f Figure 4-3 GERDA Loop Heat Loss I i
, G i
4-12
q O NJ i( )
< 0.3 0.25 0
*/. %D e.2 m F o o U
L L 6.15 g O W - E 81 [ R u
.95 l
f-e 550 600
= -
300 m 400 450 500 i e-- e SG IET 17-67% LEVEL M SG TDf9EATURE DEG F
*--* sG Im I!
Figure 4-4 GERDA Steam Generator Heat Loss
- 1 LO 4-13 I [
l L
r-- i l\ l G e.2
- e. is a
U D e.15
- v. O D UD
[L e.12s L e.1 w o P 0
$ .es R
.es
.e25 e
m ase 400 4se see sse m AVENE RV TDPERATtK DEG F Figure 4-5 GERDA Reactor Vessel Heat Loss (No Guard Heaters) i, f 4-14 '[ J
)'
b I
,gs
'd l, ..
I i a f e.2 e.17s ao e.is o % J 1 [L e.12s D a e.1 L P O y .e75 - t TN R U .es
.eas e
ase 4ee 4se see ese 600 see m c. TDPERATURE DEG F i Figure 4-6 GERDA Cold Leg Heat Loss i i LO 4-15 1* L ..
O e.2 e.15 u x 0 F u e,1 L L P O w .es
- E R
G o e ,
.05
* *
- e see 550 cee t
M EF
~* W ATERS ias Set ,}
Figure 4-7 GERDA Hot Leg Heat loss i 9 4-16
l
' I ! main heaters controlling to a set pressure (~2000 psia) and the guard heaters Q making up for heat loss. The main and guard heaters were tripped and the vessel was allowed to depressurize (due to heat loss). Based on the temperature,
{ pressure, and collapsed water level data, the heat loss was calculated as the vessel depressurized from 2000 to 1650 psia, and again from 1250 to 500 psia. The heat loss during these tests was 0.047 and 0.042% of full power at 622' and 530*F, respectively. For,0 TIS testing, guard h, eaters were added at the,p'tssuriz line
/
anf at the reactor fessel upper'and top plenums. ' Guard
- i ol bias heater settings contr/er were determined to minimize heat loss from these regions. ,4haracteriza' tion test
/
L results for these OTIS components will be added to this fext when test results are available. L L c' - 4.6 GUARD HEATER CHARACTERI6HOS EATie43 A Pressurized Water Reactor (PWR) at operating temperature typically loses 15 OTIS, with its larger surface area to g less than 0.1% of full power to ambient . volume ratio, will lose a larger percentage of the heat being generated to the surroundings. To minimize the undesirable effects of heat loss in the hot leg,p s, h pressurizer surge line, and reactor vessel upper and top plenums, a guard heating system was used on these components. The guard heating system (discussed in Section 2.0) was designed to provide heat to the components in an amount equal to that components heat loss to ambient. During the GERDA Phase 0 Loop Characterization Tests, the performance of the hot leg guard heaters was characterized. The hot leg guard heaters are divided j into eight (8) control zones, each zone covering about eleven feet of pipe. Heat .i input to the zone was controlled based on a AT measurement between the pipe OD and .I 6 p 15" Scaling Criteria and an Assessment of Semiscale Mod-3 Scaling for Small Break s Loss of Coolant Transients", T. K. Larson, J. L. Anderson, and D. J. Shimeck, EGG-SEMI-ST21, March, 1980. l *) 4-17' l
l l l a point approximately mid-way into the 1/2" layer of control insulation. The guard heater concept is illustrated on Figure 2-4. The proposed method to minimize the heat loss was to control the guard heater so that the AT between the pipe OD and the control insulation was zero. With the AT being zero, an adiabatic condition would exist at the pipe wall, thus the heat loss would be zero. During the heat loss tests it was found that with the guard heaters maintaining a zero AT, there was a net heat loss along the hot leg. The temperature at the steam generator inlet was about 2*F less than the reactor vessel outlet temperature. This represented a heat loss along the hot leg of about 0.045% (at 500*F). This net heat loss was due to a higher heat loss through instrument penetrations (thennocouples, conductivity probes, viewports, etc.) than through the insulated sections of the pipe where the control signal was located. To minimize the overall heat loss from the hot leg, that is making the steam generator inlet temperature equal to the reactor vessel outlet temperature, the heater control setpoint was increased (biased to +0.1). With the higher control setpoint there was a net heat addition over the insulated section of the control zone to l compensate for the higher heat loss through the instrument penetrations in that zone. The result is illustrated in Figure 4-8. Between the reactor vessel outlet and steam generator inlet, the net heat loss was approximately zero with the guard h heaters on (and biased to +0.10). The fluid temperatures along the hot leg varied by +1* F. This guard heater control setpoint (bias +0.10) was used for all GERDA Phase 1 tests. The fluid temperature profile with the guard heaters off is also illustrated on Figure 4-8. There was about a 5'F temperature difference from the outlet of the reactor vessel to the steam generator inlet with the hot leg guard heaters off. l ! As part of the OTIS characterization testing, a run was perfomed to i determine the control settings for the eight hot leg guard heaters for a steam environment at 500*F. The effects of slightly overpowered guard heaters are most 1, apparent in a steam environment due to the relatively small volumetric heat capacity of the fluid. This guard heater characterization test showed that the control settings for the eight hot leg zones, established during the GERDA program, were too high. An estimate of the excess heat addition to the hot leg I 4-18
l \ N i l l I LOCATIONS 2 l ! 1 yMOT LEG
. l WITH HEATERS l l
,i. . g a._a_6._6._o A _. __
2il "g
^'% %g
*Og
~ 5'F STEAM GENERATOR #
l r" 3* 5
- 6%g n-i s .e8 l WITHOUT HEATERS l s
3
- i O
; b coLo
. [' LEO \
L;
.98
,(
GRTD 6TC j I RE ACTOR VEssE L
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e 40 80 120 0 DISTANCE, FT L Figure 4-8 GERDA Hot Leg Fluid Temperatures With and Without Guard Heaters 1 . O 4-19 L
16 was made and totalled 324 watts . The control settings were reduced to +0.09 I for zone 4 (see Table 3-6 for zone elevations), +0.08 for zones 1 and 5, +0.07 for zones 2, 6, 7 and 8, and +0.06 for zone 3. Finally, the loop was refilled and the g l adequacy of the reduced hot leg guard heater control settings was verified under I natural circulation conditions. The natural circulation hot leg fluid j temperatures were within 1.5*F of those in a steam environment. The control settings for the reactor vessel upper and top plenum guard heater 5 were also detarmined in a steam environment at 500*F. A control setting of
+0.23 the upper plenum and +0.135 for the top plenum (see Section 3.1 for -
zone elevations) were required so that the top plenum fluid temperature (RVTC08) was within l'F of the core outlet fluid temperature (RVTC07). The heat loss from the reactor vessel was reduced from 3.36 KW to 2.26 KW at 500*F using these guard heaters. The total loop heat loss was decreased from 12.1 KW (or 0.57% of full power where 1% of full power equals 21.4 KW for OTIS) to 11.0 KW (0.51% of full power). These same reactor vessel guard heater control settings resulted in a
! 14*F temperature gradient between the core outlet and the top plenum for a water filled reactor vessel and natural circulation conditions in the loop. The heat loss from the reactor vessel upper and top plenums under these conditions was only 29W.
The pressurizer surge line guard heater control setting was set at +0.0 for ( OTIS testing. A larger bias setting was not required due to the absence of local heat sinks (instrument stand-offs, pipe supports, viewports, etc.) in the surge line piping. As mentioned in Section 3.5, the pressurizer guard heater control was based on the arithmetic average of three sets of control thermocouples for all tests perfonned before April 3,1984. On that date, one of the three sets of control I l thermocouples failed and control was switched to a single set of control i l Letter from D.P. Binningham to H.R. Carter, "0 TIS Guard Heater Characterization Test Results,0 TIS-158", April 17,1984. 4-20
themocouples. New characterization of the guard heaters was required. The characterizations were performed at pressures of 500 psia and 1600 psia with a half-full pressurizer. The new controller bias was determined to be 0.07 to 0.08 and was used for. the remainder of the OTIS testing. 4.7 STORED METAL ENERGY EFFECTS f During a depressurization transient, the water gives up its energy by flashing to steam. The metal, which was initi. illy at the fluid temperature, dissipates its stored energy by convecting hear to the fluid. During this depressurization the guard heater will shut off, only when the temperature of the pipe OD begins decreasing.(to follow the temperature of the depressurizing fluid). During the GERDA refill and composite tests (Tests 14 and 16), the hot leg fluid temperature in the steam region of the hot leg remained hot (became superheated) r as _the loop depressurized. An analyses was conducted to determine if this superheating was a. result of an overpowering guard heater or from stored energy. The effects of stored energy was determined using a computer code (TRUMP) q V model of the hot leg. The fluid, pipe wall, control insulation, heater, and passive insulation were modeled. One axial layer of the model represented the water region, and the other layer represented the steam region. Each region was of unit (1 foot) length. Axial conduction in the pipe was not included. The model is illustrated in Figure 4-9. The temperature of the water region was prescribed to follow the primary saturation temperature during the first 50 minutes of GERDA Run 140301. During this depressurization, the fluid temperature decreased from 518'F (initially) to 392*F (at 50 minutes into the transient test). The rate at which the fluid temperature changed was varied according to the saturation temperature for this run. The initial steady-state temperature distribution for the hot leg model was
. determined based on a fluid temperature of 518'F. All thermal properties in the j model were temperature dependent. The water was assumed to make perfect contact
'i with the pipe (infinite heat transfer coefficient), while the steam heat transfer L i 4-21
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WATER __ REGION l 9. l Figure 4-9 Hot Leg Guard Heater Model i Ii, I I I O 4.42 l 1
17 to the pipe was based on the Dittus and Boelter equation . Heat transfer from the passive insulation to the ambient was based on a natural convection heat transfer coefficient. The guard heater was off during this depressurization. Saturated steam, at the temperature of the water control volume, enters the steam control volume. The temperature of the steam control volume was calculated based on the heat convected to the steam region from the pipe wall. The steaming f- rate up the hot leg was varied. The minimum steaming rate considered was the high point vent (HPV) capacity of 10 lb/hr. This is approximately the HPV capacity at 900 psia. The steaming rate could be greater than the HPV capacity since steam may be condensing in the steam generator. To investigate this, steaming rates of f' 10, 20,100, and 500 lb/hr were considered. Using the initial temperature distribution calculated for GERDA Test 140301, the transient calculation was initiated to follow the depressurization rate from this run. The steam temperature, metal temperature (at inside diameter of pipe), l l and fluid temperature (saturation) are presented for hot leg steaming rates of 10, 20, and 100 lb/hr in Figures 4-10 to 4-12, respectively. The stored energy release rate, heat flow from the pipe to the steam control volume, for hot leg steaming rates of 20,100, and 500 lb/hr are shown in Figure 4-13. The analysis shows that even at 50 minutes into the test, stored energy was still being released from the pipe. At a steaming rate of 20 lb/hr, the heat release rate was about 25 watt / foot (of hot leg) at 50 minutes. Based or a stored energy capacity of 220 BTU / foot for a 3" Schedule 160 pipe, which cools from 518'F to 392*F, the pipe only released about 26". of its stored energy during the first ( 0 0 17 Dittus-Boelter equation is: Nu = 0.023 Re .8 Pr .3 where: Nu = Nusselt Number Re = Reynolds Number f . (q- Pr = Prandtl Number l 4-23
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t' 50 minutes of the transient (with 20 lb/hr steaming rate). The percent of stored energy released at 50 minutes, and the average heat release rate for 20,100, and 500 lb/hr steaming rate is shown in Table 4-5.
]
Table 4-5 EFFECT OF STEAMING RATE ON STORED ENERGY RELEASE lI
' Average Release Steam Stored Heat Flowrate Removed 0 Rate i lb/hr 50 min. (%) watt / foot 20 26.3 20.4 5 100 65.5 50.6 1 500 90.9 70.3 Based on these average release rates, the amount of superheat produced in a 10 foot section of pipe is shown in Table 4-6. These temperatures are based on the inlet fluid being saturated vapor at 900 psia.
Table 4-6 SUPERHEAT PRODUCED BY STORED ENERGY RELEASE O Flowrate Average Release Amount of Rate Superheat Produced lb/hr watt / foot *F 20 20.4 35 100 50.6 16 500 70.3 2 As a result, it is concluded that stored energy release from the pipe to the fluid, can add heat at a rate to produce the superheated steam temperatures observed during the first hour of some of the refill tests. A GERDA test was performed to determine if'significant condensation occur,ed l in the voided hot leg with and without guard heaters on. To void the hot leg, the reactor vessel leak was opened allowing the primary to saturate at approximately lt 1000 psia. The leak remained opened until the hot leg level was below the hot leg l O I i 4-28
viewport at the 35' elevation. A video camera at this viewport recorded the V events following the opening of the leak. The recordings revealed that vapor bubbles passed up the hot leg to replace energy removed by the steam generator and by heat loss after the hot leg voided and natural circulation stopped. Also, there was no detectable condensation film on the pipe ID with or without the hot leg guard heaters in service. ; 1 4.8 CALIBRATION OF PRIMARY FLOW ELEMENTS There were two flow elements in the GERDA primary loop - an orifice located just upstream of the cold leg spillover, and a Herschel venturi meter located in the downcomer. The venturi was calibrated in the 1000 GPM flow loop test facility using a certified weigh scale measurement as the standard. The cold leg orifice was calibrated in the GERDA loop using the venturi as the standard. For OTIS testing, the cold leg orifice (orifice diameter of 1.110 inches) was relocated to the vertical pipe just downstream of the SG outlet. The cold leg orifice was recalibrated in the OTIS loop, again using the venturi as the calibration k standard. U A schematic diagram illustrating the arrangement for the venturi calibration is shown in Figure 4-14. Flow to the meter was provided either by,a gravity feed from a constant head reservoir, or by pumping from the reservoir. A low range
'(0-5" H 20) and/or a high range (0-150" H2 0) differential pressure transmitter was used to measure the AP across the throat of the venturi, and to measure the irrecoverable pressure . loss. An integrating digital voltmeter (DVM) was used to average the signals from the AP transmitters. Downstream of the meter, the water was collected on a weigh scale. Weigh scales with capacities of 100, 1000, and 20,000 pounds were available and were selected based on the flow rate being tested.
The calibration range was established by matching the calibration Reynolds number range to the operating Reynolds number range. An operating Reynolds number range (based on throat diameter) of 5000 to 370,000 was selected based on expected GERDA flow rates. 4-29 L
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l t l O 4-30 t 4
The expression for mass flow rate through a venturi is:
\
'(G . 2g ep AP, m = Ca 1-8 4 Defining a flow coefficient, K, as:
C K= 1-8 4 and solving for K in terms of the measurable parameters yields: K= 2g c p APm a where , m = mass flow rate, lb /sec m 3 j (3 p = fluid density, 1b,/ft 2 '. V a = throat area, ft 2 AP, = differential pressure across throat, lbf /ft 2 g c
= gravitational constant, 32.174 lb,-ft/sec -lbf C = coefficient of discharge a = throat to pipe diameter ratio, d_
f D t The flow coefficient, K, was computed using the above expression, and j correlated with the parameter 1000/gRe D where Reynolds number is based on the 1 2-1/2" Schedule 160 pipe diameter. A plot showing this correlation is shown in , i Figure 4-15. l The data were curve fitted (using a linear fit) for use in the GERDA and OTIS data bases, i p,-] ' 4-31 t
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During the venturi (throat diameter of 0.775 inches) calibration, data were V also taken to determine the Euler number for the assembly to be installed in th; loop. An Euler number, based on a 3" Schedule 160 pipe, of 14.2 was experi-mentally determined for the assembly to be installed in the downcomer. This value I agreed well with the predicted Euler number of 16.7.b The ;cntri caldbration-data
-e=d the suppyti g aq"aHaas develep=ent is includepN.
The cold leg orifice (1.110 inch bore diameter) just downstream of the SG outlet was calibrated in the OTIS loop because of the non-standard installation required by the loop piping. The downcomer venturi was used as the standard for this calibration. Calibration data were recorded using the OTIS data acquisition system. The AP across the orifice was recorded using a low range (0-7" H 20) and a high range (0-25" H 2
- 0) differential pressure transmitter. Calibration data were taken under natural circulation conditions. The flow coefficient, K, was calculated from the measured parameters using:
K= 0.525 d 2 3p (v~} where lh = mass flow rate indicated by downcomer venturi, lbm/sec d = orifice bore diameter, inches 3 p = fluid density, 1b /ft m AP = orifice differential pressure, psid This flow coefficient was correlated with the parameter 1000/gReD, where Reynolds number is based on the 3" Schedule 160 pipe diameter. These calibration l I t i i i lm 18 Letter from J.E. Blake to H.R. Carter, "GERDA Downcomer Venturi Calibration", SBLOCA-932, January 11, 1983. 4-33
r-if data are plotted in Figure 4-16. The data were curve fitted (using a linear fit) for use in the OTIS database. ht4ondata-and-suppor-ting celttdathns
.ere incl aoa @i 4.9 CALIBRATION OF FEE 0 WATER AND STEAM FLOWMETERS The feedwater and steam orifices were calibrated in the GERDA loop. The feedwater orifices and the high range steam orifice were calibrated using the j
turb.ine meters upstream of the feedwater heaters as the standard. The low range i steam orifice was calibrated using the low range feedwater orifice as the standard. The flow coefficient, K, for each feedwater and steam orifice was calculated from: K= , 0.525 d 2 3p where di = mass flow rate from the flow standard, lb /sec m d = orifice bore diameter, inches 3 p = fluid density, lb,/ft AP = differential pressure, psid Fcr each flowmeter the flow coefficient was correlated with the parameter 1000/ YRe D , where the Reynolds number was based on the pipe diameter (1" Schedule 80 for steam and 3/4" Schedule 80 for feedwater). A curve fit of flow coefficient versus the Reynolds number parameter was developed for each meter for use in the GERDA and OTIS data bases. 19 Letter from J.E. Paxson to D.P. Birmingham, " Cold Leg Spillover Orifice Calibration", OTIS-103, February 21, 1984. l 4-34
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The flow coefficient versus the Reynolds numbers parameter is shown in Figure 4-17 for the low range feedwater orifice. For the low range steam flow orifice one flow coefficient was computed for each of the temperatures from PSRT01, PSTC01, and SSTC25 used to compute the density term. The flow coefficient calculated with SSTC25 was about 2% higher than that using SPRT01 and PSTC01. Since the earlier steam flow data from GERDA Tests 1 through 4 showed the low range steam flow rate to be approximately 3-5% less than the low range feedwater flow rate, the flow coefficient based on SSTC25 was used. This flow coefficient z-versus the Reynolds number parameter is shown in Figure 4-18. The-date-for-the--
-k.; reiige steam-ordf4ce-calkratioTr15-inciuded48'.
4.10 FILLED NONCONDENSIBLE GAS TEST A GERDA Phase O test was identified to determine the noncondensible gas (NCG) concentration in the primary loop using the normal fill procedure. The objective of this test was to determine if degassing was required prior to selected GERDA Phase 1 tests. The initial total gas content for each test with a voided primary was specified to be less than 60 cc/Kg 2H O prior to voiding. To verify the total gas content was less than 60 cc/Kg H2 0, a total gas sample was taken from the primary loop prior to each voided primary test. The sample was taken just prior to each test after the inventory had been circulated for at least I hour. The sample was drawn from the cold leg suction leak location, through a heat exchanger, and into a high pressure sample bomb. The sample bomb was flushed with at least 10 sample bomb volumes prior to collecting the sample. After the sample was collected, it was analyzed at the Chemistry Lab for total gas content. If the gas content was greater than 60 cc/Kg H20, the gases were further reduced by feeding and bleeding, 0 Letter from D.P. Binningham to H.R. Carter, " Low Range Steam Orifice Calibration". December 28, 1982. 4-36
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e.ss is is ze 22 a IN(8CrNOLIE PO) Figure 4-17 Low Range feedwater Orf fice Calibration Data and Curve Fit l l t l t 4-37
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l U 3 D a a C e g b o e.se .. u U o u. O 9.EE l < 3.2 3.4 3.6 3.3 4 4.2 4.4 4.6 4.8 f 19N(ED) l i Figure 4-18 Low Range Steam Flow Orifice Calibration l Data and Curve Fit i i l ll 1 O P. i 4-38 l i
passing through the vacuum deaerator, until the content was less than 60cc/Kg H20.
, A compilation of the initial gas contents prior to each OTIS test is included in Table 4-7. ]'
4.11 TEMPERATURE CALIBRATIONS
- The objective of these GERDA tests was to calibrate the thermocouples (TCs) !! in the primary natural circulation loop, the pressurizer, and tne secondary side of the steam generator. The pressurizer TCs were calibrated by isolating the 1 pressurizer from the loop, and then establishing a saturated condition in the pressurizer. Nine (9) pressure plateaus, ranging from 200 to 1900 psia were established for the temperature calibration points. The TCs were calibrated to the saturation temperature corresponding to the measured pressure. The measured saturation pressure was corrected to correspond to the saturation pressure at the elevation of the TC.
Table 4-7 i TOTAL GAS CONTENT PRIOR TO VOIDEO PRIMARY OTIS TESTS Total Gas Content Test cc/Kg H,,0 210100 2.7 220100 11.0 220201 17.9 f 2202AA 2202BB 15.5 15.5 220304 18.3 220402 17.9
- 220503 3.5 220604 11.0 220756 11.7 i 220899 7.4 220999 16.4 l 221099 15.7 230199 13.4 230299 14.0 O
h 4-39
t The primary-side TCs in the hot leg, steam generator, colo leg, and downcomer, and the secondary-side TCs in the steam generator were calibrated with forced circulation conditions in the primary loop, with the steam generator f isolated. Heater power was adjusted to establish the desired steam generator ( inlet temperature. Using four (4) Resistance Temperature Detectors (RTDs) around l the primary loop as standards, most of the primary-side TCs were calibrated to a temperature based on a linear interpolation between the RTDs. A total of thirteen (13) temperature plateaus, ranging from 350* to 575*F were established. I The calibration data (voltage and temperature standard) for each TC was recorded on a file. The data was then curve fit to a second-order polynomial equation using the POLYAA Comupter program. The coefficients for the polynomial equations were then entered into the database for each TC. The reactor vessel thermocouples (except RVTC01) were not calibrated due to their close proximity to the heat source and/or due to their being located in a non-flow region. The thennocouple voltage versus temperature data used for the non-calibrated thermocouples were traceable to the National Bureau of Standards (NBS) Monograph 125. This is discussed further in the uncertainty analysis 20 report . 4.12 LOOP VOLUME MEASUREMENTS VERSUS ELEVATION The volume versus elevation for the four (4) primary regions - pressurizer, reactor vessel, active region, and in-active region, and for the secondary side of J I the steam generator was determined during GERDA Phase 0 testing. These volumes
, were obtained by filling the loop, isolating the component to be measured, then draining the cold water from the component into a weigh tank, periodically A
stopping the drain to record the weight drained and the differential pressure. t f. l 20 Uncertainties for OTIS Instrumentation and Derived Calculations, & 1 RDD:85:4091-30:01:01, R.P. Ferron, August,1984. W t 4-40
water level was calculated from the differential pressure and fluid temperature measurements. The detailed procedure and valve alignments for these volume checks are contained in the technical procedures ARC-TP-500 and ARC-TP-502. The volume versus elevation for the pressurizer and reactor vessel are shown in Figures 4-19 and 4-20, respectively. Volume versus elevation for the active regions of the hot leg and the cold leg and downcomer are shown in Figures 4-21 and 4-22, respectively. The in-active regions of the hot leg, cold leg and the steam generator (primary) are shown in Figure 4-23. The OTSG secondary-side volume versus elevation is shown in Figure 4-24. N[' I I I i l O 4-41
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e . i e les ase see e see m ( ELEVATION FROM SFLTS - INCM:S Figure 4-19 Pressurizer Volume Versus Elevation O 4-42
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I Figure 4-20 Reactor Vessel Volume Versus Elevation
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seee e i e 100 20e 300 W W E1EVATION FROM SFLTS - IMS Figure 4-21 Hot Leg Active Region Volume Versus Elevation i I l l l i 4, '
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-ase -zee -sse -tee _se e 5, NTION N SFLTS - INGES Figure 4-22 Cold Leg and Downcomer Active Region Volume Versus Elevation
't t av , I 4-45 l s-. - _. . - _ - - . . . - _ - - - - _ _ _ . -__ . - . - . _ . _ _ . . - . . . . - .
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L .- U ,- u ' E ..- 3000 .. 3 2000 ,-,~ seee . a-e -
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- E11VATION FROM SFLTS - IHOES Figure 4-23 Steam Generator Primary, Hot Leg and Cold Leg In-Active Region Volume Versus Elevation l
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e, *' e see aos see 5,, , MTION N SFLTS - INGES Figure 4-24 Steam Generator Secondary Volume Versus Elevation li l O 4-47 I i
, - - - . - - , , - - . - , . . . , - . . , - - - - , - . . _ - - . - - , ,,an...----n.- , , - - - , . . - - - - - ~ ,,-,_nn ,.---,----,--,,n--, - - - -
( - Appendix A OTIS Facility Drawings List O 4 l l L l O l i 1
- _+e,. .w, _ _ _ , _ ,..__ _ , , , _ __
/ MIS DRMING LIST C
MECHANICAL DRAWINGS NOTE: The complete list of GERDA drawings is being used as a reference for the 071S project! M -Indicates Revision to Listing 3RMING IGMBER TITLE
*** AUKILIARY FEEDMTER INJECT 191 BENCHSCALE TESTS ***
9303 D-1 Auxiliary Fee &ater Injection (AFWI) Benchscale Test for kall tred Less of Coolant Accident Tests - Model Side Panel MCS B-0 Auxiliary Fee &ater injection (AFWI) Benthscale Test for hall Dreak Loss of Coolant Accident Tests - Test Loop M10 B-0 Auxiliary Fee &ater injection (AFWI) Benthscale Test for kall Break Loss of Coolant Accident Tests - Model General Assstly i v
*** SOLOCA FACILITY ***
9500 E-2 Details of E-12 Hot Well, $8LOCA Facility 9501 E-3 Deta!!s and Assembly of E-13, Fee &ater Heater, COLOCA Facility 9502 E-3 Sundyne Pop Piping Modifications for $8LOCA Test 9503 E-3 Fee &ater Heater Piping Arrangements 9504 E-0 Secondary Law Pressure Clean up Systen Piping and Instrumentation Arrangement - SSLOCA Test 9505E-6 M UTIS Test - Reactor Vessel Botten Section 9506 E-6 M UTIS Test - Reactor Vessel Top Section 9507 > 1 SOLOCA Test - Reactor Vessel Settes Flange O A-1 l
9508 D-1 $8LOCA Test - Reactor Vessel Bottom Head 9509 D-1 Ste m Condensing Reservoir 9510 E-2 SJLOCA Test - Lower Plenum 9511 C-0 Special Nuts for Botton Head 9512 E-1 $8LOCA Test - Reactor Vessel Heater Support 9513 E-0 Ste m condenser - S8LOCA 9514 E-0 Installation Assembly of Secondary Stem Condenser and LPCUS Heat Exchanger in Bay 919, Building 'A' 9515 E-0 Arrangement of Condenser and Stem Piping Systee - SBLOCA 9516E-4 M Arrangement of Condenser and Stem Piping System - OT!S Facility 9517 E-1 Tower Water Hook-Up Stem Condenser - 58LOCA 9518 E-2 S8LOCA Test - Pressurizer Vessel 9523E-0 $8LOCA Reactor Vessel Connection Box 9524 C-1 S8LOCA Test - Reactor Vessel Heater MK-2-A-13 9526 D-0 HK-47 Stem Mixer Detail - SBLOCA <ter Piping 9527 E-4 M 'A' 6enerator Modifications - OTIS 9528 E-1 Installation Assembly of 19-Tube 'A' 6enerator - SBLOCA 9529 D-2 Generator Vessel Support Stand - SBLOCA 9530 D-1 'A' 6enerator Modification Details - SBLOCA 9531 E-0 Arrangement and Details of Wireways S8LOCA Centrol Room - Bay 19 Extension Building 'A' High Bay 9533 E-0 Arrangement 8 Details of Censole Writing 8 Work Top - SBLOCA Control Room - Bay 19 Extension, Building 'A', High Bay l ! 9534 E-1 Arrangement and Details of Control Panel Equipment Support - SBLOCA Control Room - Bay 19 Extension - Building 'A' - High Bay 9535E-0 $8LOCA Test - Rea: tor Vessel Support 9536E-0 $8LOCA Test - Reactor Vessel Suppert 9539 D-0 Primary Venting (Single-Phase) Heat Exchanger - SBLOCA A-2 l t v
9541 0-1 90 Degree Pipe Bends for Hot Leg Piping - S8LOCA 2 E-5 M UTIS Test - Primary Forced Circulation Loop and Primary Cold Les Piping 9543 D-2 M 0715 Test - Primary Cold Leg Piping Penetration Details 9544 D-2 S8LOCA Test - Primary Cold Leg Piping Penetration Details 9545 D-0 Hot Leg View Port Section WHigh Point Vent 9546 E-1 Building 'A' Bay 19 Extension Wireway Installation - $8LOCA Test 9547E-1 Pressurizer Vessel Installation Arrangement - SBLOCA M4B E-4 'A' 6enerator Penetrations for Conductivity Probes i 9549 D-4 M OTIS Test - Surge Line 9550 E-0 Fre&ater Piping System - 6eneral Arrangment 9552 D-1 SBLOCA Test - RVW Piping 9553E-4 Primary Hot Leg Piping - SBLOCA ' ,_ 9554 D-9 Primary Hot Leg Piping - Details - SBLOCA ( v 9555 D-0 Support Stand for Hot Leg and Cold Leg Paping - SBLOCA 9556E-0 SBLOCA Test - Primary Forced Circulation Loop and Cold Leg Piping Supports 9557 D-0 S8LOCA Test - Primary Forced Circulation Locp and Cold Leg Piping Supports 9558 D-0 SBLOCA Test - Downcomer Support Detail 9559 D-0 2 Phase Primary Venting and Sepling System Scheeatic - SBLOCA 9560 E-0 $8LOCA Test - Lower Plenum Bypass Lines 9561 0-0 High Point Vent - Separator - SBLOCA 9562 D-0 P.O.R.V. - Separator 2 Phase Primary Venting and Sampling System - SBLOCA 95630-0 Dverflow Stack Detail - SBLOCA - 2 Phase Primary Venting and Sepling Systee 9564D-0 WV - Separatter Installation and Piping - 58LOCA 9565 D-3 Displacement Tanks and P.O.RN. Installation Assembly - SBLOCA - Primary Venting a*.d $mpling Systee 9566 E-2 SBLOCA Test - Ultrsonic Flometer O GI A-3
9567 D-0 $8LOCA Test - Strainer Plate Detail O
$569 C-1 58LOCA Test - Dwncomer Drifice Plate 9570 D-0 SBLOCA Test - Pressurizer Relief Valve Installation 9571 0-1 $8LOCA Test - Reactor Vessel Relief Valve Installation 9572 E-0 $8LOCA Test - High Pressure Injection and Spray Line Tubing Layout 9573 D-0 8' Overf1w Pipe Installation and Tank Discharge Piping - SBLOCA - 2 Phase Primary Venting end C ocling System 9574 E-2 M OTIS Test - Single-Phase Leak Location 9575D-4 M OTIS Test - Single-Phase Leak F1w Control Orifice 9576 C-0 SBLOCA Test - Vent Valve Installatien 9578 B-0 SBLOCA Facility H.P.I. System Scheratic l 9579 D-0 Het Leg Piping Supperts - SBLOCA 9582 D-0 $8LOCA Test - Gas Supling - Typ. for 2 Lccationi on Hot Leg Paping 9523 D-0 SBLOCA Test - 6as Addition Inlet Manifold 9584 D-0 $8LOCA Test - Gas Supling - To 8e Located in Tc; V w Port Bloc 6 on Hot Leg 9585 D-0 SBLOCA Test - Gas S upling - Top of Reactor Vessel 9566 E-0 S8LOCA Test - Gas Addition HCG Supply Manifold 9567 C-0 Multi-Junction Thermoccuple Suppert Locations - SBLOCA 9588 E-2 $8LOCA Test - Ground Floor DP and Pressure Transmitter Panel Board Arrangepnt 9589 E-0 SBLOCA Test - 67cund Floor DP and Pressure Tranmitter Panel Boatd Detail 9590 C-0 F1w Distribution Plate Detail, 'A' Generater - $8LOCA 9591 8-0 Stud and Spacer for Viw Port - SBLOCA 9592 D-3 M Conductivity Probe Details - OTIS 9593 0-0 $8LOCA Test - Second Deck DP and Pressure Transmitter Panel Board Detail 9594 E-1 SOLOCA Test - Second Deck DP and Pressure Transmitter Panel Board Arrangement O
A-4
Ste m Orifice Plate - SBLOCA p )f595 0-1
\
' " 9596 B-0 1' - 60004 Threadolet for SBLOCA Steam Generator i :
9597B-0 1-1/4' - 60004 Sockolet and Plug for S8LOCA Stem Generator 9599D-0 $8LOCA Test - Bulkhead Fitting Support Panel Detail 10009 D-1 SOLOCA Test - Pit DP and Pressure Transitter Panel Board Arrangement 10010 D-0 $8LOCA Test - Pit DP and Pressure Transmitter Panel Board Detail 10012E-0 SBLOCA Test - Gas Addition Tube Routing Diagra 10051 B-1 Instrument Air Sy' stem - S8LOCA
, 20052 B-0 Bau 19, Building 'A' City Water Supply System - SBLOCA Sheet 16.2 16053 B-0 Bay 19, Building 'A' Filtered and Unfiltered Tower Water Supply and Return System Sheet 16.1
';,10185C-0 S8LOCA Test - Orifice Plate 10237 C-0 S8LOCA Test - Orifice Plate
/ 10297 li-? Downeocer Venturi Flom eter Asseebly - set 0CA V
t 10298D-0 Downcomer Venturi Flcmeter Details - i4LOCA 10299 D-0 Downeomer Venturi Flometer Details - S8LOCA 10300 D-0 Dcwncomer Venturi Flometer Details - $8LOCA
., 10313 C-1 M UTIS Cold Les Orifice Plate 10314 C-0 $8LOCA Test - Downconer Orifice Plate 1
19697 C-0 M OTIS Test - /Witional Cold Leg Drifice Flange Detail l1 19706 6- 0 W UTIS Preject - Cold Leg Drifice Location 10710 E-7 M Assembly 6 Details of 19 Tube 'A' Gen. 10857 D-6 # OTIS Test - Branch Leak Connection 19968 C-6 M OTIS Tes: 7 Reactor Vessel Vent Valve f SK 1996~ Neater, Pressurizer for Babcock & Wilcox Co. - Watlow Electric Mfg. Co. 501-070-04 High Temperature Ultrasonic Flometer I. A-5
4-5236-1 H Proposed Hot Leg Probe Assembly 4-5236-5 C-0 Conductivity Probe Holders C-SK-2200-611 Special Multipak Assembly 706125, Rev. 6 Ass'y: Level Sensor, Miniature B & W Simulated Reactor Test Systee - Single Switch Point Sheet 1 of 3 706125, Rev. 6 Level Sensor Miniature B 4 W Simulated Reactor Test Systee - Dual and Single Switch Point Sheet 2 of 3 706125 Rev. 6 Ass'y Level Sensor, Miniature B & W Simulated Reactor Test System - Single Switch Point Sheet 3 of 3 0-489190 Rockwell E6ards Forged Steel Univalve Globe Stop Valve - Class 1690 e i ELECTRICAL DRAWINGS 9519 B-10 M OTIS Test General Panel Layout Looking North - Panel ( Sheet 1 9519 B-6 M OTIS Test General Panel Layout Looking West - Panel Sheet 2 9519 B-3 M OTIS Tes'. Power Distribution Center Layout - Panel Sheet 3 O l A-6 [ . _ _ _ _ _ _ _ _ _ _ _
f 9519B-3 M OTIS Test - Motor Control Center Arrangement - Panel et 4 9519B-1 SBLOCA Test - Power Distribution Center Panel Door Layout - Panel ilheet 5 l 9519B-2 M OTIS Test - Power Dicributien Ceter Panel Door Layout - Panel Sheet 6 9519 B 1 S8LOCA Test Lead Control Center Panel - Feekater Heater SCR's - Panel Sheet 7 9519 B-1 SBLOCA Test Lead Control Center Panel - Reactor Vessel & Pressurizer - Panel SheetB 9519B-2 H OTIS Test Lead Center Panel - Hot Leg - Panel Sheet 9 9519B-2 S8LOCA - Fee &ater Heater Connection Box - Panel Sheet 10 9519 B-0 SBl.CCA - FeeSater Heater Connection Box Cover Drwing - Panel Sheet 11 9519 B-0 SILOCA Test - First and Second Pit Levels Down - Floor Plari - Panel Sheet 12 19B-1 M UTIS Test - Ground Fleer - Floor Plan - Fanel Sheet 13
~
9519B-0 SBLOCA Test - First Deck Elevation - Floor Plan - Panel Sheet 14
~
9519 B-0 S$t0CA Test - Sacend Deck Elevation - Floor Plan - Panel Sheet 15 9519B-0 $8LOCA Test - Third Deck Clevation - Floor Plen - Panel Sheet 16 9519 B-0 SBLOCA Test - Penthouse Level 41 - Floor Plan - Panel Sheet 17 l 9519 B-O SBLOCA Test - Penthouse Levels 42 and 43 - Floor Plan - Panel Sheet 1B 9519 B-1 SBLOCA Test - Multipoint Temperature Recorder - Panel Sheet 19 (. 1' 9519B-3 M 071S Test - Steam Ramp Prograseer - Panel Sheet 20 o r U L
9519 B-1 $8LOCA Test - Secondary Piping Controls - Panel Sheet 21 9519 B-2 $8LOCA Test - Secondary Loop Temperature Limits - Panel Sheet 22 9519 B-1 $8LOCA Test - Secondary Circulation Pump and FeeSater Heater Controls- Panel Sheet 23 9519 B-2 SBLOCA Test - Secondary Low Pressure Clean-Up System (SLPCUS) - Panel Sheet 24 9519 B-1 $8LOCA Test - Reactor Vessel Temperature Limit - Panel Sheet 25 9519 B-2 $8LOCA Test - Pressurizer and Reactor Vessel Level Recorder - Panel Sheet 26 9519 B-1 SBLOCA Test - Reactor Vessel Controls - Panel Sheet 27 9519 B-2 SBLOCA Test - Pressuriter Temperature Limit - Panel Sheet 2B 9519 B-1 58LOCA Test - Pressurizer Heater Controls - Panel Sheet 29 9519 B-1 SBLOCA Test - Pressurizer Vent Valve and Fee @ater Puep Controls - Panel Sheet 30 9519 B-3 58LOCA Test - High Pressure injectio,. (HPI) Controls - Panel Sheet 31 9519 B-2 SB'.00A Test - Primary Circulation Pur+ - Panel l Sheet 32 l l 9519 B-1 S8LOCA Test - Dissolved Oxygen Analyzer - Panel Sheet 33 f519 B-2 S8LOCA Test - Conductivity Monitor and High Pressure Alarm - Puel l Sheet 34 1 9519 B-1 S8LOCA Test - Hot Leg Zone Heater Controls - Panel l Sheet 35 l l 9519 B-1 $8LOCA Test - Patch Panel Cutout - Panel Sheet 36 1 9519 B-1 SBLOCA Test - Patch Panel Layout Upper Case - Panel Sheet 37 'I I O A-8
s f M19 B-5 SBLOCA Test - Patch Panel Layout - Lower Case - Panel et 3B k 9519 B-0 58LOCA Test - Installation of Bailey Controls Module Racks - Panel i Sheet 39 9519 B-1 S8LOCA Test - Bailey Conditioner Rack 41 Layout - Panel Sheet 40 9519 B-2 $8LOCA Test - Bailey Conditioner Rack 42 Layout - Panel
)
Sheet 41 l
$8LOCA Test - Bailey Conditioner Rack 43 Layeut - Panel l M19 8-2 Sheet 42 t
9519 B-1 SBLOCA Test - Utility Outlet Panel - Panel Sheet 43 9519 B-2 $8LOCA Test - Relay Panel il - Fanel Sheet 44 9519 B-1 SBLOCA Test - Relay Panel 42 - Panel Sheet 45 9519 B-1 $8LOCA Test - Relay Panel 43 - Panel
; Sheet 46 9 B4 SBLOCA Test - Assembly for Color Monitor Keytcard Storage - Panel 9519 B-2 SBLOCA Test - Bailey Rack 41 Equipment Location - Panel Sheet 48 9519 E-2 SBLOCA Test - Bailey Rack 42 Equipment Location - Panel Sheet 49 9519 B-0 . S8LOCA Test - Reference Junction Enclosure SBLOCA Panel Board - Pant!
Sheet 50 9519 B-1 SBLOCA Test - Hot Les Temperature Controller Zones 1 Thru 4 - Panel Sheet 51 9519 B-1 S8LOCA Test - Hot Leg Temperature Controller Zones 5 Thru 8 - Panel Sheet 52 9519 B-1 SBLOCA Test - Annunciator Centrols and Room Temperature Monitor Panel - Panel Sheet 53 9519 B-0 S8LOCA Test - Ground Floor Layout - South Side - Panel Sheet 54
,s w
A-9
i 9519 B-0 S8LOCA Test - Protective Cover for Analogic DAS - Patel Sheet 55 9519 B-3 $8LOCA Test - Annunciator - Panel 1 Sheet 56 9519 B-0 $8LOCA Test - 6as Sample - Panel Sheet 57 9519 B-1 SBLOCA Test Phase Vent - Panel Sheet 50 9519 B-0 SBLOCA Test - Relay Panel 6 - Panel Sheet 59 9519 B-1 S8LOCA Test - Primary and Hot Well Pressure 64uge Layout - Panel l Sheet 60 9519 B-1 SBLOCA Test - Secondary Pressure Gwge Layout - Panel Sheet 61 9519 B-1 SBLOCA Test - Differential Pressure 6auge Layout - Panel Sheet 62 9519 B-1 S8LOCA Test - Differential Pressure 6nge Layout - Panel Sheet 63 9519 B-1 M OTIS Test - Pananetries Ultrasonic Flomete' Conditioner Mounting Panel Sheet 64 9519 B-1 M OTIS Test - Guard Heater Centrols Sheet 65 I M OTIS Test Phase Vent Systee 9519 B-2 Sheet 66 9519 B-0 SBLOCA Test - 6as Addition Sy5 tem - Panel l
'. Sheet 67 9519 B-1 $8LOCA Test - Vent and Spray Valves - Panel Sheet 68 9519 B-0 S8LOCA Test - Turbine Flometer Layout - Panel Sheet 69 9519 B-0 $8LOCA Test - Terminal Strip Layout - Panel Sheet 70
. 9519 B-0 $8LOCA Test - Digital Input Power Supply - Panel Sheet 71 O A-10 [
19 B-0 S8LOCA Test - Digital input Terminal Strip - Panel t 72 9519 B-1 SBLOCA Test - Heated RTD Electronics - Panel Sheet 73 9519 B-0 $8LOCA Test - Power Supply - A*alog Device Mounting - Panel Sheet 74 9520 b-4 N UTIS Test - 480 V Power Circuits Reactor Vessel Heaters - Electrical Sheet A 9520 B-1 SBLOCA Test - 480 V Power Secondary FeeSater Heaters - Electrical Sheet B 9520 B-2 $8LOCA Test - 480 V Power Secondary FetSater Heaters, Primary Circulation Pump, Sheet C Deserator - Electrical 9520 B-2 M UTIS Test 480 V Power SLPCUP System - Electrical Sheet D 9520 B-3 M OTIS Test - 480/240 V Power Hot Leg and Pressurizer Heaters - Electrical Sheet E 9520 B-3 M OTIS Test - Heater Power Control Pressurizer and Hot Leg - Electrical , Sheet F 20 B-1 SBLOCA Test - Heater Power Control Pressurizer and Hot Leg - Electrical Sheet G 9520 B-1 SBLOCA Yest - Heater Power Control Pressurizer and Hot Leg - Electrical Sheet H 9520 B-0 $8LOCA Test - 120 V AC Power - Electrical Sheet ! 9520 B-0 S8LOCA Test - Reactor Vessel Controls - Electrical Sheet J l S8LOCA Test - Reactor Vessel Controls - Electrical 9520 B-1 Sheet K l 9520 B-2 SBLOCA Test - Reactor Vessel and Pressurizer Level - Electrical Sheet L 9520 B-4 M OTIS Test - Reactor Vessel Controls - Electrical Sheet M 9520 B-3 SSLOCA Test - Reactor Vessel Controls - Electrical Sheet N O G A-ll b
i l 9520 B-3 M OTIS Test - Pressurizer Controls - Electrical Sheet 0 9520 B-2 SBLOCA Test - Pressurizer Controls - Electrical Sheet P 9520 B-2 SBLOCA Test - Pressurizer Level Conditioner - Electrical SheetQ I M OTIS Test - Pressurizer Controls - Electrical 9520B-4 l Sheet R 9520 B-2 SBLOCA Test - Pressurizer and Hot Leg Controls - Electrical Sheet S 9520 B-3 M UTIS Test - Hot Leg Controls and Primary Circulation Pump Controls - Electrical SheetT 9520 B-0 SBLOCA Test - Facility Low Pressure Clean-Up System Controls - Ele:trical Sheet U , M20 B-1 SBLOCA Test - Facility Low Preesure Clean-Up System and Deaerater Controls - Electrical Sheet V M20 B-3 SBLOCA Test - Hol Controls - Electrical Sheet H M20 B-2 SBLOCA Test - HDI Controls - Electrical Sheet X l i M20 B-1 SBLOCA Test - HPI Make-L5 Pump Controls - Electrical Sheet Y 9520 B-0 $8LDCA Test - Hot Les Controls 1 Electrical l Sheet 2 9520 B Z. M OTIS Test - Hot Les Controls 5-B - Electrical l ' Sheet AA 9520 B-2 M OTIS Test - Steam Generator Level Controls - Electrical l Sheet AB i 9520 B-3 SBLOCA Test - Steam Generator Level Controls - Electrical ( Sheet AC f 9520 B-1 $8LOCA Test - Steam Generator Level Controls - Electrical l Sheet AD 9520 B-2 $8LOCA Test - Secondary Fee @ater Injection Controls - Electrical SheetAE O A-12
20 B-3 M OTIS Test - Secondary Stem Pressure Controls - Electrical f et AF 9520 B-1 SBLOCA Test - Stem Generator Secondary Pressure Controls - Electrical SheetAG l 9520 B-3 58LOCA Test - Secondary Circulation Pop Centrols - Dectrical SheetAH 9520 B-2 $8LOCA Test - Secondary Circulation Pump Controls and Hot Well Controls - Dectrical SheetAl 9520 B-2 S8LOCA Test - SLPCUS and Fee &ater Controls - Dectrical Sheet AJ 9520 B-0 $8LOCA Test - Fee &ater Temperature Controls - Electrical SheetAK 9520 B-2 $8LOCA Test - Secondary Circulation Controls - Dectrical SheetAL 9520 B-3 S8LOCA Test - Feewater Pop Speed Control and GA'RDI - Electrical Sheet M 9520 B-2 SBLOCA Test - 6eneral Instrumentation Power Connections - Dectrical g Sheet M 0 B-3 SBLOCA Test - 6eneral Instrumentation Powr Connections - Dectrical Sheet A0 952C B-2 SBLOCA Test - Reference Junction P,wer Connections - Dectrical Sheet AP 9520 B-2 $8LOCA Test - Flometers - Electrical Sheet AQ 9520 B-5 S8LOCA Test - 6eneral Instrumentation - Dectrical SheetAR 9520 B-3 S8LOCA Test - Heated RTD Connections - Dectrical SheetAS 9520 B-1 SBLOCA Test - 120 V AC Outlets - Dectrical Sheet AT 9520 B-1 SBLOCA Test - Annunciator - Electrical Sheet (U 9520 B-2 SBLOCA Test - Annunciator - Dectrical SheetAV (p A-13
t 9520 B-1 SBLOCA Test - Annunciator - Electrical Sheet #1 9520 B-5 M OTIS Test - Transmitter Connections - BGl Model 7601 Power Supply - Dectrical Sheet AX 9520 B-2 SBLOCA Test - Transmitter Connections - BGi Model 7601 Power Supply - Electrical SheetAY 9520 B-3 SBLOCA Test - Transmitter Connections - Bei Model 7601 Power Supply - Dectrical Sheet AZ 9520 B-2 SBLOCA Test - Electrical Sheet BA 9520 B-2 SBLOCA Test - Multi-Point Recorder Signal Connections - Dectrical Sheet BB 9520 B-2 SBLOCA Test - RTD Connection Box - Electrical Sheet BC 9520B.T M OTIS Test - Reference Junction Thermocouple Signal Channels - Electrical Sheet BD 9520 B-1 SBLOCA Test - Computer Interf ace Cable Layout - Dectrical Sheet BE 9520 B-D SBLOCA Test - Analogic Master Chassis - 0 Configuration - Electrical Sheet BF 9520 B-0 SBLOCA Test - Analogic Chassis - 1 C:rfiguration - Dectrical Sheet BG 9520 B-1 SBLOCA Test - Analogic Chassis - 2 Configuration - Dectrical Sheet BH 9520 B-2 SBLOCA Test - Analogic Chassis - 3 Configuration - Dectrical SheetBI 9520 B-1 SBLOCA Test - Analogic Chassis - 4 Configuration - Dectrical Sheet BJ 9520 B-0 SBLOCA Test - Analogic DAS - Local and Program Channel Addresses - Dectrical Sheet BK
$520 B-0 SBLOCA Test - Analogie DAS - Local and Program Channel Addresses - Dectrical Sheet BL 9520 B-0 SBLOCA Test - Analogic DAS - Local and Progra Channel Addresses - Electrical Sheet Ri O
A-14
9520 B-0 SBLOCA Test - Analogic DAS - Local and Progra channel Addresses - Electrical et 94 9520 B-0 SBLOCA Test - Analogic DAS - Local and Progra Channel Addresses - Electrical Sheet 90 9520 B-0 SBLOCA Test - Analogic DAS - Local and Prosta Channel Addresses (Future) - Electrical Sheet BP
$520 B-0 SBLOCA Test - Analogic DAS - Local and Progra Channel Adcresses (Future) - Electrical Sheet 90 9520 B-0 SBLOCA Test - Patch Panel Connections - Electrical Sheet BR 9520 B-0 SBLOCA Test - Patch Panel Connections - Electrical Sheet BS 9520 B-1 SBLOCA Test - Patch Panel Connections - Electrical Sheet BT 9520 B-1 SBLOCA Test - Patch Panel Connections - Electrical Sheet BU 9520 B-1 SBLOCA Test - Patch Panel Connections - Electrical Sheet BV B SBLOCA Test - Patch Panel Connections - Electrical 9520 B-1 SBLOCA Test - Patch Panel Connections - Eltetrical l Sheet BX 9520 B-1 SBLCCA Test - Patch Panel Connections - Electrical Sheet BY 9520 B-2 SBLOCA Test - Patch Panel Connections - Electrical Sheet BZ 9520 B-4 SBLOCA Test - Patch Panel Connections - Electrical Sheet CA 9520 B-1 SBLOCA Test - Patch Panel Connections - Electrical Sheet CB 9520 B-2 SBLOCA Test - Patch Panel Connections - Electrical Sheet CC 9520 B-1 SBLOCA Test - Patch Panel Connections - Electrical Sheet CD m
v i i A-15 i
)
I
\
9520 B-3 SBLOCA Test - Patch Panel Connections - Electrical ! SheetCE l 1 9520 B-1 S8LOCA Test - Patch Panel Connections - Electrical l SheetCF l 1 9520 B-2 SBLOCA Test - Patch Panel Cennections - Electrical Sheet C6 9520 B-1 S8LOCA Test - Patch Panel Connections - Electrical i SheetCH 9520 0 2 SBLOCA Test - Patch Panel Connections - Electrical l Sheet Cl 9520 B-1 SBLOCA Test - Patch Panel Connections - Electrical Sheet CJ 9520 B-0 $8LOCA Test - Patch Panel Connections - Electrical Sheet CK 9520 B-1 $8t0CA Test - Gas S uple: Hot Leg (U-Bend) Controls - Electrical Sheet CL 9520 B-2 M OTIS Test - 6as Saple: Het Leg (Main) Controls - Electrical SheetCM 9520 B-1 SBLOCA Test - 6as Seple: Stem 6en. Prir.. Outlet Controls - Electrical Sheet (H 9520 B-2 M OTIS Test - 6as Seple: Reactor Vessel Controls - Electrical Sheet C0 9520 B-3 M OTIS Test Phase Vent System Centrols - Electrical SheetCP 9520 B-4 $8LOCA Test Phase Vent System Controls - Electrical Sheet CQ l 9520 B-4 S8LOCA Test Phase Vent System Controls - Electrical Sheet CR 9520 B-3 S8LOCA Test Phase Vent System Sheet CS 9520 B-2 SBLOCA Test - 6as Addition Systee - Electrical Sheet CT 9520 B-2 $8LOCA Test - Bas Addition System Valve Switch Connections - Electrical Sheet CU O A-16 i -.
l M20 B-4 M OTIS Test Phase Vent Systee - Electrical tCV 9520B-(- M OTIS Test Phase Vent System Valve Switch Connections - Electrical Sheet 04 1 9520B-3 M UTIS Test - Vent and Spray valves - Electrical l SheetCX 9520 B-2 M OTIS Test - Digital input Chart - Electrical l SheetCY 9520 B-6 M OTIS Test - Digital input Chart - Electrical Sheet CZ 9520 B 3 M UTIS Test - Wire Number Listing - Electrical Sheet DA 9520 B-7 M OTIS lest - Wire Number Listing - Electrical Sheet DB 9520 B-0 Number List'ing - S8LOCA - Electrical Sheet DC 9520 B-1 Cable Number Listing - SBLOCA - Electrical Sheet DD 20 B-4 M Cable Number Listing - OTIS - Electrical Sheet DE (1 of 2) 9520 B-1 M OTIS Test - Cable Number Listing - Dietrical Sheet DE (2of2) 9520 B-0 S8LOCA Test - Conductivity Probe Connections F SheetDF 9520 B-0 S8LOCA Test - Conductivity Probe Connections Sheet DG 9520 B-0 SBLOCA Test - Conductivity Level Probe Connections - Electrical Sheet DH ! 9520 B-0 M OTIS Test - Reactor Vessel Guard Heater Controllers - Electrical ! Sheet 01 9520B-1 M OTIS Test - Heater Power Control Reactor Vessel & Surge Line - Electrical SheetDJ l 9520 B-0 # OTIS Test - Reactor Vessel & Surge Line Guard Heater Controls - Electrical 9520Bl M OTIS Test - 1 Phase Vent Systen Valve Switch Connections - Electrical Sheet DL A-17
, ~ - , - _ _ _ _ _ _ _ - - _ - - __ _ _ _ _ - - _ _ ._ _.
l 9' I l
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Appendix B Instrumentation and Valve Designation
- 0 1
I
- l. ,
/
O i
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The instrumentation and valves in OTIS are identified by a six or seven
,r]
- (./ character string. The first two letters identify the system of which the j instrument or valve is a part, the second two letters identify the instrument or valve type, and the last two or three numbers are a unique number for the particular instrument or valve. Numbert. between 01 and 99 are used to identify
" test data instruments". Three digit numbers,100 or greater, are used to identify " loop operation instruments". For example, SSDP02 stands for Steam Generator S_econdary (SS), Differential Pressure (DP), instrument 02. RVCV03 stands for Reactor Vessel (RV) Control Valve (CV), number 03. A complete listing of the abbreviations used are contained in Tables B-1 and B-2.
[ G I O l? l l ! o l B-1
I Table B-1 ABBREVIATIONS FOR LOOP COMPONENTS Loop Component Abbreviation Steam Generator - Primary SP Steam Generator - Secondary SS l Steam Generator - Metal SM Reactor Vessel RV
- Downcomer DC Pressurizer PR Facility Water Supply and HP Clean-Up System 5 Secondary Low Pressure SC Clean-Up System Primary Venting 1-0 V1 Primary Venting 2-0 V2 Primary Forced Circulation PC Cold Leg CL Hot Leg HL High Pressure Injection HP Secondary Forced Circulation SF Feedwater Heater SF Steam Piping PS Feedwater Piping FP Gas Addition GA Gas Sampling GS O
B-2 e m.
Table B-2 ABBREVIATION FOR INSTRUMENTS AND YALVES Instrument or Hardware Abbreviation Themocouple TC Resistance Temperature Detector RT t Differential Temperature DT ? Themometer TH Pressure PR Differential Pressure DP Flow Rator FR Turbine Heter TM Orifice OR Conductivity Probe CP Watt Meter WM Control Valve CV Hand Yalve HV Safety Valve SV Limit Switch LS Accumulating F1ow Meter AC 0xygen Monitor OX O B-3
O l 6 Appendix C OTIS Instruraent List O O
*** INSTDUMENT LIST ***
TODAYS DATE: 16-JULY-94 COMPONENT: STEAM GENERATOR REFEREh CE D R AWINGS: 9 52 7 E 4,9 5 4B E4,9 553 E4,9 587 CO INSTRUMFNT IDENT ELEV ATION REL ATIVE TO SF LTS CO W.U E N T (RVSD) (NEW) PROP 0 FED (1) DE SI GhE D INSTALLED S FP901 5 3 '-1 -1/ 2" 53*-1 3/4" 9553E4
- S FRT 01 53'-1" 53'-2 1/2" 53*-1 3/4" 9 553 E 4 S PRT02 53'-1" 53'-1 1/2" 53'-3/4" 9 553E4 SSTC25 49'-10" 4 9 *-9 " 49*-9 1/2" 03/23/83 SPTC01 47'-1/4" THE INSTALLED ELEVATI]N S STC23 47'-o" 47'-0" 47'-1/4" F0F ALL SMTC & SFTC'S S STC24 4 7 '-0 " 47*-0" 47'-1/4" WAS DETEE"INED FFOM , SSTC21 44'-2" 44'-2" 44'-2 1/4" PEh?Th ATION "E ASURE"ENTS 23/83 SSTC22 44' 7" 44'-2" 44'-2 " MI5US 3" BASED ON DR AWTNG SMTC06 44'-2" 44*-2" 44'-2 1/2" r.L-13 6 6 4 9-6 S STC19 41*-2" 41 '-3 " 41'-3" SSTC20 41'-2" 41 '-3 " 41'-3" SFTCO2 38'-2" S STC17 38'-?" 3 9 '-2 " 38'-2" S STC19 38"-2" 38'-2" 38'-2" S MICOS 3 8 '- 2 " 38*-2" 38'-2" SPTCO3 35'-3 3/4" S STC15 3 5 '- 5 " 3 5 '-4 " 35'-4" S STC16 35' E" 35'-4" 35'-4" S STC11 29*-?" 2 9 *-3 " 29'-2 3/4" S STC12 29'-2" 29'-3" 29'-2 3/4" SFTC03 2 9 '- 2 " 2 9 '-3 " 29'-3" l
SSTC09 25'-4" 26'-4" 26'-3 1/2" S SIC 10 - 25'-4" 2 6 '-4 " -- 26*-3 1/2" - SMTCO2 25'-4" 26'-4" 26'-3 1/2" ll 23'-2" 23'-1 1/2" ,i SSTCOB 23'-2" l S STC07 20'-2" 20'-2" 20'-1 1/2" - SNTC01 20'-2" 20'-2" 20'-1 1/2" S PTC04 17 '-4 " 17'-3 1/2"
-S STC06 17'-4" 17 '-4 " - - 17 '-3 1/2" --
S STC05 14'-2" 14'-2" 14'-1 1/2" 73 SSTC04 11'-1" 11'-1" 11'-3/4"
'( i S PTCOS 8'-1" 8 '- 7 / 8 " ---
l kJ S STCO3 8 '- 1 " 8'-1" 9 '- 7 / 8 " l S STCO2 4 '-11" 4 '-11 " 4'-10 7/8" S STC01 l'-6" 1*-6" l'-6" S FRT03 -2'-1" - 2 '-9 1/ 4" -2'-9 3/4" 9542E5 C-1
SPRT04 -2*=2" -2 *-11 1/ 4" -2 *-11 1/4" 9542E5 SPPT01 -24" 9527E4 PTe3 (DN N0Z) 01/30/84 SPTC16 - - - - - -- - 0 . 5 " - -- 9 527 E4 (ON NOZ TC) SPPT02 -24" 9527E4 PT#1 (OFF NOZ) 01/30/84 SPTC18 -0.5" 9 527 E 4 (OFF NOZ TC) SPPT03 -24" 9 527 E4 PT#2 (OPP N32) 01/30/84 S PTC17 -0.5" 9 527E 4 (OPP NO2 TC)
. SPTC06 23'-1-3/8" 9 587 C O ,9 527 E 4 SPTC07 30'-1-3/8" SPTC06 TO SPTC15 SPTCOB 35'-1-3/8" IN "NW" TUPE(PLANT "SW")
SPTC09 39'-1-3/8" M.1 TC "0N N0ZZLE" S PTC10 43'-1-3/6" C5 GORCON TCf 3 SPTC11 4 7 '-1 -3 / 8" . SPTC12 49'-1-3/8" - SPTC13 5 0 '-1 -3 / 8" SPTC14 5 0 '-7 -3 / 8" SPTC15 51'-1-3/8" S SCP14 21'-1" 21'-1/2" 9548E4 REF P:0FE S SCP01 35'-5" 3 5 '-7 " 35'-6 1/2" 9549E4 SSCP02 34*-6" 3 4 '-6 " 34'-5 1/2" SSCP03 3 4 '- 0 " 34'-0" 33'-11 1/2" SSCPO4 33'-6" 33'-6" 33'-5 1/2" S SCP05 3 3 '- 0 " 3 3 '-0 " 32*-11 1/2" SSCP06 32'-8" 32 * -7 " 32'-6 1/2" S SCP07 32*-0" 32*-0" 31'-11 1/2" S SCP08 31' '" 31*-6" 31'-5 1/2" S SCP09 31 '- 0 " 31'-0" 30'-11 3/4" S SCP10 30*-6" 30 '-6 " 30*-5 1/2" SSCP11 30'-0" 30'-0" 29'-11 1/2" S SCP12 29'-6" 2 9 '-6 " 29'-5 3/4" S SCP13 2 9 '- 0 " 29'-0" 28'-11 1/2" S SDP01 32'-0" 32*-3 3/4" P.EF0VEC SSTC14 SSDP01 00*-0" 0*-0" SFLTS S SDP02 51 '-7 -1/ 4" 51'-4" STEAM LINE S SDP02 00'-0" 0'-0" SFLTS S SDP03 35'-4" 35'-3 3/4" S SDP03 2 3 '-2 " 23'-1 1/2" 9548E4 S SDPO4 3 5 '-4 " 35'-3 3/4" S SDPO4 32'-0" 32'-3 3/4" SSDP05 32'-0" 32'-3 3/4" S SDP05 2 9 '-3 " 29'-2 1/2" 9548E4 S PDP01 53'-1-1/2" 52*-11 3/4" 9553E4 SG INLET 03/23/83 S PDP01 -2 '-9 -1/ 4" -2'-9 1/4" 9542E3 SG OUTLET S SDP100 SG LEVEL IN-CONTROL R009 '03/31/03 S S D P 0 2 -- --- - - -- -- - --- -- 51 '-3 " HOT DIRENSION ETkN TAPS
@ SSTC01:501.4F SSTC25=508.9F 03/31/83 S PDP01 --- -- ---- - ---
55'-10 1/2" HOT DIFENSION ETFN TAPS S SPRT01:510.5F SPPT03:500.2F m .emw6m - O C-2
C MPONENT: REACTOR VESSEL N ERENCE DRAKINGS: 950 5 E6,95 06 E6,9 510 E2 IN STRUMEN T IDENT ELEV ATION REL ATIVE TO SF LTS COM u EN T (RVSD) (NEW) P ROP OS ED DESIGNED INSTALLED RVTC01 -23'-8" -23 '- 9 3 /4" -23 *-8 3 / 4" FLUID, BOTTOM PIPE RVTCO2 -19'-2" -19'-1" -19 *-1 1/2" FLUID R Vkv01 RVTC03 -15'-6" -16'- 3/8" -16'-1/2" SFIh 04/05/83 RVTC100 - 14 '- 6" HE ATEF TC RVTC103 -14'-4" -13 '-11 5/ 8"-13 '-11 3/ 4"H I SF I A TEMF (K A S RVT C0 4) 04/05/83 RVTC101 - 12 '- 2" HEATER TC RVTC05 -12*-10" -11'-10 7/8"-11'-11" SKIN RVTC06 -11'-2" -9 '-10 1/3 " -9 *-10 1/4" S KIN RVTC102 - 8 ' -7 1/2" -8'-8" HI FLUID TEu? RVTC07 -8'-10" -8*-3 1/2" -d'-3 7/6" FLUID RVTC10 0'-8" 0*-7 1/2" 9552D1 RVVV LINE,0C SInF R VTC09 0 *-10 " O'-7 1/2" 9552D1 RVVV LINE,RV SIDE RVTC104 HEATEP TC R VTC105 HE ATER TC RVTC106 HEATER TC RVTC107 HEATEh TC R VTC108 -23 '-5-1/4" FLUID,TCP CRCSF0VEF PIPE (~' R VPP01 7 '- 2 " 7'-1 3/8" 7'-5/8" (s,$ / RVTCOB 7'-2" 6'-10 3/8" 6'-9 3/4" FLUID RVCP02 -2' 4" - 2 '-5 " -2'-5" RV-EL R VCP01 -l'-6" -1 '-4 e / 8" -1'-5" PV-HL RVCPO4 0'-6 19/32" O'-6 5/8" RVVV RVCP03 0*-7 29/32" O'-8" RVVV RVCP05 -9 '-1 1/ 2" -8'-11" 9506E6 REF P9095 R VDP01 7 '- 5 /6" 7'-5/8" RV TOP R VDP01 - l '-1 1" -1'-11" RV-HL RVDP02 -1'-11" -l'-11" RV-HL RVDP02 -8*-1/2" -8'-3/4" COFE TCP RVDP03 0*-7 1/4" 0*-7 1/2" RVVV RVDP03 0'-7 1/4" O'-7 1/2" RVVV R VDPO4 -8 '-1/2 " -8'-3/4" COPE TCP RVDPO4 -16"-1/2" -16 '- 3 / 4" C OPE PCTTou. RVDPOS 7'-5/8" 7' 5/8" RV TDF RVDP05 -16'-1/2" -16'-3/4" CORE BOTTOM RVLS01 RVVV LIMIT SKITCF RVRF01 3'-11 3/4" 3*-11 1/2" SVID HTP VOLTAGE R VRT01 3'-11 3/4" 3'-11 1/2" SWID PEF FTD RVLS02 3'-11 3/4" 3'-11 1/2" SWID S/W IND RVLS03 3'-11 3/4" 3'-11 1/2" SWID F AILURE IND
-RVHR01 --
3'-11 3/4" 3'-11 1/2" H RTD -DT- -- R VHR02 -17 '-5 1/2" STD HRTD DT RVRF02 - 17 '- 5 1/2" STD HTR VOLTAGE r3 RVRT02 -17'-5 1/2" STD REF PTD
! ! RVLSO4 -17'-5 1/2" STD S/h IND R VLS05 -17 '-5 1/2" STD F AILURE IND c-3
( I R VRT03 -17'-5 1/2" STD SAT TEMP R VPR100 RV PRESSURE-CONTFDL E00" 03/23/83 R VLS06 -- ----- ---- RVVV CLOSED INDICATIO4 03/31/83 R VDP05 23'-2 7/16" HOT DIPENSION ETVN T AF
@ DCRT01:497.6F R VT C07 : 515. 2F RVTC09=479.IF 04/13/84 R VD701 -4.0" D AT A 04/13/84 -R VDT101 -4.0" LOGP-04/13/84 RVDT02 4*-103 DATA 04/13/84 R VDT102 4'-10" L OCP 04/13/84 R VTC11 -4.0" METAL (9506E6) 04/13/84 RVTC12 4'-10" METAL (9506E6)
COMPONENT: PRESSURIZER ANJ SURGE LINE REFERENCE D R AWINGS: 9 518 E2,95 49D 4 INSTRUMENT TDENT ELFVATION REL ATIVE TO SF LTS COMMENT (RVSD) (NEW) P 90POS ED DESIGNED INSTALLED PFTC101 7'-11 1/2" 7'-11 1/2" SYIN PFTC100 9'-7 1/4" 9 '-7 1/ 4" HI FLUID TEMP PFDT01 12'-2 3/4" DATA PRDT101 12'-3 3/4" LOCP PPTC01 11'-0" 21*-10 3/4" 21'-10 1/2" FLUID PPTC04 11'-0" 17'-5 1/2" 17 '-11 1/2" SKIN PRDT02 27'-1 3/4" DATA P RDT102 27'-1 3/4" LOCP P RTCO2 23'-6" 34'-2 1/4" 34*-2" FLUID PRTC05 23'-6" 36'-5 1/2" 36'-9 1/2" SFIN PETC102 26'-11 1/2" 27'-1 3/4" SKIN (FECORDER) PRDT03 42*-9" DATA (EEFORE 4/3/64 ONLY) PRDT103 42'-9" LOOP PPTC03 42'-10" 46'-5 3/4" 46'-5 3/4" FLUID PETC06 42'-10" 45'-11 1/2" 46'-5 3/4" SKIN PRPR01 46'-10" 40'-5 3/4" 40'-5 3/4" PRDP01 46'-10" 40'-5 3/4" 40'-5 3/4" TOP OF PP PRDP01 2'-5 1/2" 2'-5 3/4" 9549D4 SUPGE LINE P RHP 01 21'-4 3/4" 21'-5 1/2" SWID DT P P RF01 - - - -- - - --
-- 21'-5 1/2" SWID HTR VOLTAGE l , PRRT01 21'-5 1/2" SWID REF PTD P RLS01 21'-5 1/2" SWID S/h IND PRLS02 -- - - - - - - --
21*-5 1/2" SWID F AILURE IND PRPR100 PRESSURIZER FRES. CONTFDL 01/30/84 PFDT04 3'-1 1/4" SUFGE LINE DT (DATA) 01/30/84 - P RDT104 - - - -
- - - -- 3 '- 1 1/ 4" SUFGE -LINE D T (LCOP) 04/05/83 PPTC07 2'-6 3/8" S KIN, D AT A 03/31/83 PRDP01 38'-1 1/8" HOT DIPENSION PTVN TAPS
- 0 PRTC01:58E.7F PRTCO3:586.0F h 04/13/84 PRTC08 12'-2 3/4" METAL 04/13/84 PPTC09 - --
27'-1 3/4" METAL 04/13/84 PFTC10 42'-9" METAL 04/13/84 PFTC11 3'-1" METAL (SURGE LINE)
P~70NENT: HPI AND FLPCUS -- - - -
- (.)
INSTRUMENT IDENT ELEVATION RELATIVE TO SF LTS COM W.EN T -- (RVSD) (NEW) PROPOSED DESIGNED INSTALLED RPPR101 - - - - - - - - - - HPPR100 HPTH100
- - - - - H PCP100 H FCP101 HPPS100 HPPR105 HPPR105 H PPR107 HPPR108 - -- - --
H PTM01 HPTC01 FLUID TEMP HPTC101 - - - - ELLIOT TANK HPTC102 DEAERATOR HPTM02 HPTM03 H PTH101 H PPP102 H PPR103 r
,c3 - HPTC100 H P AC100 H PPP134 1( HPAC01 TOTALING FLOF COMPONENT: PRIMARY CIRCUL ATION LGOP REFERENC3 D R AWING: 9542E5 INSTRUMENT IDENT ELEV ATI ON REL ATIVE TO SF LTS COMVENT (RVSD) (NEh) PROPOSFD DESIGNED INSTALLED P CTC100 -78" UPSTRM PUMP i PCTC101 -58 3/4" DWNSTPP. PUMP P CTC10 2 -- - -- - - - - - - - - - - - - - - - - - - -
-COCLING h ATER OUTLET P CDP 100 P CGR100 P CPR10 2 - - -- -- - - - - - - --
P CDP 101 PCPS100
- P CP R 10 0 - - -- -78" -
UPSTRM PUMP - ! PCPR100 PCPR101 -98 3/4" DWNSTRP. PUMP ( C) l
COMPONENT: COLD LEG PIPING REFERENCE DR AWING: 95 42 E 5,954 3D 2,95 443 2,10697 CO ,10706D 0 INSTRUMENT IDENT ELEV ATION REL ATIVE TO SF LTS COM M EN T --
'(RVSD) (NEh) P ROP OS ED DESIGNED INSTALLED 6/8/84 CLTC01 -4'-10" - 4 '-9 " -4'-8 5/8" FLUID CLTCO2 -4'-10" -4*-E" -4'-6" FLUID CLUS01 -1'-10" - 4 '-3 /4" CLTC03 -0*-10" -O'-3 1/2" -O'-1 3/4" FLUID CLTC04 1 '- 10 ' l'-9" l'-9" FLUID C LTC05 -O'-6" -O'-6" -
-O'-5 3/4" FLUID CLDP01 2'-7 5/16" 2 '-7 3 / 4" CL-50 I CLDP01 - 8 '-3 " -8'-3" DC
- l. 6/ 8/84 CLDP02 -5'-4 1/2" -5'-4 1/2" CLC LO RANGE (UPPEF TAD) 6/ 8/84 CLDP02 -5'-7 1/16" -5'-7 1/16" CLC LO FANGE (LOkER TAP)
CLDP03 2'-7 5/16" 2'-7 3/4" CL-SO 6/ 8/84 C LDP03 --
-4 '-5 3 / 8" -4*-5 3/8" CL US LOWER DRAIN 04/05/83 CLDPO4 -5'-4 1/2" -5'-4 1/2" CLC HI RANGE (UPFER TAP) 04/05/83 CLDPO4 -5'-7 1/16" -5'-7 1/16" CLG HI R ANGE (L0kER T AP)
CLLS101 - CLCV01 OPEN CLLS102 CLCV01 MAX D CTC01 -3'-7" - 3 '-3 " -3'-3" FLUID D CTCO2 -10*-0" - 9 '- 9 " -10*-0" FLUID D CRT01 -20'- 1/4" -2 0 *- 0 "
-2 0 *- 91/ 2" -12*-8" RV DC VENTURI LO RANGr 05/09/83 D CDP 01 RV DC VENTURT LO FENG:
05/09/83 D CDP 01 -2 0 '- 11 1/ 2"-13 '-2" D CDP 02 3" -8'-3" DC DCDP 02 -16*-5" -16'-3/4" 9505E6 CORE EDTTCM 05/09/83 DCDP 03 -12 *- 8 " RV DC VENTUDI HI RANGE 05/09/83 D CDP 03 -13'-2" RV DC VENTURI HI RANGE COMPONENT: SECONDARY LOW P9 ESSURE CLEAN-UP SYSTEM REFEREN CE D R AWING: 9504E0 ELEVATION REL ATIVE TO SF LTS COMuENT INSTRUMENT IDENT (RVSD) (NEW) PPOPOSED DESIGNED INSTALLED S CPP104 S CPR105 S CFR102 S CTS 100 S CTC100 -- - - S CTH102 S CFS100 S CPR102 S CPR103 - - S CFR101 i S CTH100 l S CTH101 - - -- S CFR100 i S CPR100 S CPP101 - C-6
COMPONENT: SINGLE-PHASE VENTING SYSTEM REN CE D R AWING: 9574 E2,108 57 D O,1066 8C O INSTRUMENT IDENT ELEVATION REL ATIVE TO SF LTS COMuENT - (RVSD) (NEW) PROPOSED DESIGNED INSTALLED VITC01 FLUID TEMP DbNSTFu CO3LER 01/30/84 VITCO2 CLS LEAK TEv.PEFATUFE 01/30/84 VITCO3 CLD LE AK TEMFEF LTUDE VILS01 RV LOWEP PLENUU LEAK 03/23/83 V1LS03 CLD LE AT 01/30/84 V1LSO4 10 CM2 CLS LEAK SITE 01/30/84 VILS05 10 CF2 CLS LEAF SITE 01/30/84 V1LS06 15 CM2 CLS LEAF SITE 01/30/84 VILS07 -- 15 C42 CLS LEAK SITE 01/30/84 VILS08 RV TOP PLENUY LE AK SITE VIAC01 _. COMPONENT: TWO-PHASE VENTING SY ST EM REFERENCE D F AWING: 9559D o,956 503 ELEVATION RELATIVE TO SF LTS COPMENT g "3NSTRUMENT IDENT
' ,jV SD ) (NEn') PRODOSED DESIGNED INST ALLED V 2TC01 HPV SEFARATOF V 2TCO2 PDFV SEPARATCP V2TC03 NCG TEMP (250 G AL T ANK)
V2TC04 SUEGE hATEP TEMP V2DP01 HPV SEFAFATOF 1 V2DP02 PDFV SEP AR ATCR 2 03/23/83 V2DP03 19'-11 11/16"0VEFFLOW T ANK 1( SOUTH) 03/23/83 V 2DPO4 19'-10 7/16" OVEPFLCW TAN 8 2(f.0?TE) 03/23/83 V 2DP05 19'-11 11/16"0VER FLCW T ANK 3( SUPGE) V 2LS01 HPV V 2LS02 HPV V2LS03 PDFV V2LSO4 -- - - - - POPV V 2PR01 TWO PHASE VENT SYSTEF PRE V2AC01 HPV ACCUM FLOk V2ACO2 PDFV ACCUp FLOW l t j' I N.,) c-7
COMPONENT: HOT. LEG PIPING REFERENCE D P AWING: 9553E4 INSTRUMEN T IDENT ELEV ATION REL ATIVE TO SF LTS COMWENT (RVSD) (NEW) PROPOSED DESIGNED INSTALLED HLRT01 0 '- 0 " 0'-0" O'-0" HLCP01 1*-0" l'-0" 1 "- 0"
..- - - -fi L D T 01 4'-0" 2 '- 9" D AT A H LDT101 2'-9" CONTPOL H LTC01 8 '- 0 " 8'-0" 8'-1" PELO) SURGE HLTCO2 9'-0" 9'-0" 9 '- 1 3 / 4" ABCVE SURGE HLDT02 15'-0" 12'-9" D AT A H LDT102 12*-9" CONTROL HLCP02 15'-0" 15 '-0 " 15'-0" HLTCO3 20'-0" 20'-0" 19'-11 3/4" FLUID HLDT03 25'-0" 23*-9" D AT A HLDTIO3 --
23'-9" COhTROL H LTC04 30'-0" 30'-0" 29'-11 3/4" FLUID HLCP03 35'-0" 35'-0" 34'-11 1/2" HLDT04 35'-0" 34'-6" SATA HLDT104 34*-6" CONTPOL HLCPO4 37*-0" 37'-0" 36'-11 3/4" HLCP05 41'-0" 41'-0" 41'-0" HLTC05 40*-0" 40'-0" 39'-11 3/4" FLUID HLCP06 45'-0" 45'-0" 44'-11 1/2" HLDTOS 45'-0" 46'-3" D AT A HLDT105 46*-?" C0hTROL HLCP07 49'-0" 4 9 '-0 " 49'-11 1/2" HLCP08 5 3 '-0 " 53'-0" 52'-11 1/2" HLDT06 55'-0" 57 '-3 " DATA HLDT106 57*-3" CONTROL HLCP09 57'-0" 57'-0" 56'-11 1/2" H LCP10 61'-0" 61'-0" 60'-11 1/2" H LTC07 60'-0" 60'-0" 59'-11 1/2" FLUID l HLDT07 65'-o" 65'-0" 65'-11" DATA HLDT107 65'-11" CONTROL HLCP11 65'-0" 6 5 '-0 " 64'-11 1/2" 03/23/83 HLCP12. 67'-R" 67'-6 1/8" 9545DO 9545DO, FLUID 03/23/83 HLTC08 67'-3 1/2" HLCP13 65'-0" 65'-0" 64'-11 1/4" ! H LCP14 61 '- 0 " -61*-0" 60'-11 3/8" HLTC09 60'-0" 60'-0" 59 '-11 1/4" FLUID HLDT08 60'-0" 57'-2" D AT A ilLDT108 - - 57'-2" CONTROL H LCP15 57'-0" 57'-0" 56'-11 1/4" l 03/23/83 HLCP16 53'-1" 53'-2 1/2" 53'-0 3/ 4" li LCP 17 - --- - - - O '- 6 " - - O '-6 1/ 4" R E F- P R GB E -- HLVP01 35'-0" 35'-0" 9545D0 H LVP02 67'-6" 954500 HLDP01 -1 '-11" -1'-11" 9506E6,PV-HL 03/31/83 HLDP01 67 '-4-3 / 4" 67 '-5 5 /16 " 9 5 45D O,P.LUp (DSTNC PTi TAPS ADDED TO LWP ELV) i e C-8
HLDP02 - --- -
- 1 *-1 1" - - -l'-11" 9 506 E 6,R V-HL , f""73/83 HLDP02 53'-1-1/2" 53'-1 3/4" SC INLET -l ,31/83 HLDP03. 67'-4-3/4" 67*-5 5/16" 9545DO,HLUB (SAVE AS HLDP01-HLUB)
HLDP03 53 '-1-1/ 2" 52'-11 3/4" SG INLET 03/23/83 H LHP01 66'-11 3/4" SWID DT
" SWID HTR VOLTAGE
-- -" HLRF01 "
H LRT02 SWID REF RTD
" SWID S/W IND HLLS01 HLLS02
" SWID F AILURE IND HLPR100 HL PPESSURE(!!LDP01-HIGH)
-CONTFCL ROOM 03/31/83 HLDP01 69'-9 3/4" HOT DINENSION ETkN T APS
@ HLTC08:513.0F HLPT01:512.3F 03/31/83 HLDP03 14*-5 15/16" HOT DIkENSION BTkN T AFF
@ SFPT01:510.5F 04/13/84- HLTC10 34'-6" METAL (DATA) 04/13/84 HLTC11 65'-11" METAL (DATA) 04/13/E4 HLTC12 2*-8 1/2" METAL (D AT A) 04/13/84 H LTC13 12'-8 1/2" METAL (DATA) 04/13/84 H LTC14 23'-8 1/2" METAL (DATA) 04/13/84 HLTC15 46'-2 3/8" METAL (D AT A) 04/13/84 HLTC16 57'-2 3/E" METAL (DATA) 04/13/84 H LTC17 57'-2 3/8" METAL (D ATA)
I l l
-h C-9 f
COMPONENT: SECOND ARY FORCED CIRCULATION AND FEEDk ATER HE ATERS REFERENCE D P AWINGs: 9500 F 2,95 02 E3,9 503 E3 INSTRI5 MENT IDENT ELEVATION REL ATIVE TO SF LTS COMMENT (RVSD) (NEW) P ROP OS ED DESIG NED INSTALLED SFOR01 LO FL0k
-SFDP01 LO,LO FLCW SFDP02 HI,LO FLOW
'~SFOR02 HI FLOk S FDP03 LO,HI FLOk SFDPO4 HI,HI FLOW SFTM01 LO FLOk SFTu02 HI FLOk 01/30/84 SFLS01 FEED LC FLOF CV 01/30/84 SFLS02 FEED HI FLOW CV S F AM100 SUNDYNE STARTER S F AV101 FW HTR 1 SFAM102 FW HTR 2 S F AM103 FW HTF 3 S F AV104 FW HTR 4 SFAM105 Ek HTP 5 S FAM106 FW HTR 6 SFTC100 S UNDY N E ,
S FTC101 FW HTR(LIMIT) SFTC102 FW HEATER (?ECCFDER SFTC103 FW HTR(CONTPCL) S FTC104 FLUID, HOT WELL SFPR101 DWhSTRF FISHER PY-PAS 3, CONTROL P00v SFPR102 FEEDWATER HTR-CONTROL ROCM SFPR103 HOT WELL-CONTFDL ROOV SFDP101 LEVEL GAGE & CONTE 0L, HOT WELL-CCNTROL ROO" SFFS100 SUNDYNE CO3 LING kATEF SFHM100 S FFD.100 DWNSTRM'SUNDYNF.-CONTFDL RODY SFOR100 DWhSTRM SUNDYNE SFDP100 - - - DWNSTRM SUNDYNE-CONTPOL ROOM SFPS100 FW HTR PERMISSIVE f hw-see,. g..,s. O C-10
~ . _
C3MPONENT: STEAM PIPING RENCE DRAWINGS: 9 515 F0,9516 E4,9 517 El ,. NSTRUMEN T IDENT ELEVATION RELATIVE TO SF LTS COMMENT-(RVSD) (NFW) PROPOSED DESIGNED INST ALLED P SPP100 STM OUTLET-CONTRCL ROOM P SPR01 STM OUTLET (DATA) P STC01 FLUID,UPSTRV 0F PIXER P SRT01 FLUID,0WNSTRV 0F PSTC01 P SOR01 LO FLOk P SDP01 LO,LG FLOW P SDP02 HI,LO FLOk P SOP 02 HI FLOk P SDP03 -- --- --- - LO,HI FLOW PSDPO4 HI,HI FLOW P STC04 FLUID,LO FLOk SITE P SPR101 - DWNSTRP STM CV CCNT. ROGV P STC101 FLUID,UFSTRM CONDENSER P STC102 FLUID,0WNSTRP CONDEhSEF P STC05 FLUID,HI FLOk SIDE P STC100 STEAV CUTLET (TO FECOPDER) 01/30/84 P SLS01 STEAM LO FLOW CV 01/30/64 P SLS02 STEAP HI FLOk CV rs C3MPONENT: FEEDWATER PIPING REFEPENCE D R AWING: 9550E0 INSTRUMEN T IDENT ELEVATION REL ATIVE TO SF LTS COMMEN1 (RVSD) (NEW) PROPOSFD DES IG NED INSTALLED F PRT03 50'-10 3/8" 177FA AFhI FFRT02 5'-11" 205FA AFWI F PRT01 0'-3/8" AFWI AT SFLTS h FFTC01 DkNSTPP FW HEATEF5 FPPR100 } . . . _ . . _ _ p W e' -e
- 4 e M1 m
C-ll
COMPONENI: GAS ADDITION SYSTEM INSTRUMENT IDENT ELEV ATION REL ATIVE TO SF LTS COMMENT h (RVSD) -- (NEW) PROPOSED DESIGNED INSTALLED -- REFERENCE DRAWING: 9583D0 G ATC01 GAPR01
-GALS 01 -
HLUB G ATCO2 HLUB G ALS02 UPSTRM OTSG GATCO3 - UPSTRM OTSG GALS 03 COLD LEG G ATC04 COLD LEG GALSO4 RV-LP GATC05 RV-LP C3MPONENT: MISCELLANEOUS MSRF01 - RTD REFERENCE VOLTAGE M SRF02 STD CELL VOLT AGE-D AS 40h. MSTC01 REFENENCE OVEN TEMP M STCO2 REFEREhCE OVEN TEMP i M STCO3 ANALOG 1C DAS TEMP (1) ELEVATIONS TO THE NE AREST INCH ocoo************************************************************************** The following instruments were used for dimensional inspections during f acility construction and testing, and are included in this list to complete the scone of instrumentation used during the project. REVISED B&W ID DESCRIPTION 20-JUN-83 -780363 - - -- - - Micrometer, Cutside 20-JUN-93 780364 Micrometer, Cutside 20-JUN-83 610062 Conparator, Cptical JUN-83 750160 Caliper, Verrier 20-JUN-83 780355 Caliper, Vernier A O C-12
O Appendix D VTAB Data Cards - Parameters and Format 4 O l !~ 1 O
VTABLE Structure The data base for the SBLOCA data acouisition swstem is designed so the user can define all parameters needed to couple each of the user defined table entries (VTAB's) to the availabic options in the data acouisition software. This information is stored on disk in account E201,103 with the file ncoe, VTABLE.DAT. The VTAB senerailw corresponds to an instrun.ent such as c thermocouple, Pressure transmitter, Conductivitw Probe, etc. However, the VTAB maw refer to a 'non-instrument entrw' desired bwFor theexample, user to more areropriatelv define the output of the instrument. an orifice used for flow me a su r e merit is monitored bw a differentici Pressure transa.itter that measures the Pressure differential cetoss the orifice. It is necessarv for the data acovisition tuttera to measute and record this differential Pressure but it is also convenient for the osoiator to have an on-line indication of the flow rate bcsed ori this measured dif f erential Presture. The SBLOCA data accuisitiori software allows the user to define a second VTAB which contains the necessarv conversion conttants and reference VTAP's (or instruments) to compute the flow rate through the orifice. This flow rate t e ra s i n s in men. ors uritil the ne;:t data accuisition cycle. Hence, any on-line calculation for the current data scoussition cucle would haveThis thisfio flow rate available without the neEd to recomPate the flow. rate is also present in the off-line data base for distribution to users outside of ARC. With this intoduction, the followins ortions reouire user input for each VTAB and are summarized below. Globel definition to the datainacouisition software recardins or out of service, use for the status of a VTAB, ie., loop alarm indications to the operator, or use for control of the time interval between dets scouisition scans. Identification of a VTAB for alarm monitoring and the Parameters ruouired to define the low and high alarm values, arid alarm desdband. Identification of a VTAB for rate control of the data ie., based on the rate of chance of acouisition hardware, a VTAB raw data signal or engineering value, the time 'nterval between data acouisition scans is either increased or decreased. Definition of the ANALOGIC ANDS 5400 'cerd' (analos, counter-timer, or diditol input) and ANALOGIC channel essociated with the VTAB. O D-1
l'hi i
\_/
Conversion of the raw data signal (voltase, frecuenev, digital input, count, etc.) to the aFFroFriate value in engineerins format or units. Thi: operation teovires the followins user defined information* Calibration constants and material or test loor geometrv constants needed to perform the raw data signal to engineerins format conversion. Reference VTAB's (or instrunient readings in this case) needed to Perform the raw data sisnal to ensineerior format conversion. Definition of the ' units descriptor' ( e:: . , DEG F, PSIA, LEM/HR) associated with the converted ensineerin vclue for each VTAB. Definition of the number of sisnificant decimc1 Fisce that will be associated with the converted r:w data signc1 to engineerins value. Descrietor associated with each VTAB for user ecse in identificction of the UTAB. n t 4 (_/ The followins discussion defines the parameter order and formtt for each of the VTAB date cards. All VTAB's reouire the same F aramEter
. entries on cards 41 and 42. Cards 43 and 44 a re or-tional de r-E ndiris on the data reduction twFe needed to convert from the raw input sicnal to
-the engineerins formatted value.
i
- l. -
D-2 l l l t.
r- - c000000000000o00000000000000000oooooooooooooooooooooooooooooooooooo*******o***++ Card 01 definan the percmater list for global alctming and rate specifications, set up of the data acquisition system prior to a date . scan, definition of the data reduction routine, and VTAB units and descriptor. ; 000e*..**........*........*.....................*..**.*...*..................... coo CARD #1 *** FORMAT (2X,3A2,1X,913,4X,40A1) ;
*********** CARD COLUMN AND ENTRIES ********** !
1 2 3 4 5 6 7 8 j 12345678901234567890123456789012345678901234567890123456789012345678901234567890 A1A2A3 BBBCCCDDDEEEFFFGGGHHHIIIJJJ KKKKKKKKKKKKKKKKKKKKKKKKKKKKKKKKKKKKKKKKk ; CARD SOFTWARE ENTRY PARAMETER DESCRIPTOR VALUE(S) FORMAT
******* ********* ************************ **************** ***++***
A1A2A3 VTAB Name of VTABLE.DAT entry A1 - Subsystem A2 (Instrument or " dummy" A2 - Instrument A2 name) A3 - Number A2 BBB KEYS Read, Rate, Alarm, and 13 Ref Channel Code Wcrd VALUE PARAM O/1 1 VREAD Read /No Read 1 2 AWORD Alarm Out/In 4 RWORD Rate Out/In ! 8 VREF None/Ref VTAB BBB = Summation of CVALUE*(O or 1)] ' CCC ALARMW Alarm Code Word 13 VALUE PARAM O/1 1 AVTAB No Alarm /Yes 2 ADEAD Delta /%Deadband 4 ALSTAT No/Yes Alarm State (User Should Set This tc O Initially -- System i ' Will Then Modify) 8 ALVTAB Lo/Hi Alarm l l State CCC = Summation of CVALUE*(O or 1)] l DDD RATEW Rate Option Code I3 Word VALUE PARAM O/1 1 RVTAB No/Yes Rate Change 2 RDUM **Not Used** 4 RVOLTS Not Used/Eng Units 8 RLIMIT Limit / Rate of Change l DDD = Summation of CVALUE*(O or 1)3 l l EEE REDUC Reduction Equation I TYPE DESCRIPTION 1 Engineering Value = Raw
*1"'
! D-3 l 1
Pcge 4 2 RTD 3 C1+C2a(V-VV)+C3e(V-VV)**2 l 4 C1+C2*V+...+C5*V**4 5 Type J TC Not Used [\-') 6-8 9 Uncalibtsted 100 chm Platinum RTD 10-20 Not Used 21 Turbine Flow Meter 22 DP Transmitter (W/O H2O Correction) 23 Orifice Flow Meter With Flange or Corner Taps 24 DP From TYPE 22 to Actual (H2O & Thermal Expansion Corrected) And Vertical Orifice DP in Upflow and Downflow 25 Correct Pressure Trans-mitter Reading to Upper Tap 26 Not Used 27 Volume of Gas Discharged into the Two-Phase Venting System 28 Composite Steam Flow Rate in GERDA Steam Circuit 29 Composite Feed Flow Rate in GERDA Feed Circuit 30 Pressurizer Collapsed f'"N Water Level 'j- OTSG Primary Collapsed I-31 Water Level 32 OTSG Secondary Collapsed Water Level l I 33 Hot Leg Collapsed Water Level 34 Hot Leg Stub Collapsed Water Level 35 Reactor Vessel Collapsed Water Level 36 OTSG Secondary Wetted CP 37 Hot Leg Stub Wetted CP 38 Hot Leg Wetted CP 39 Reactor Vessel Wetted CP 40 Feedwater Temperature 41 RVVV Mass Flow Rate 42 HPV & PORV Composite Mass Flow Rate 43 Single Phase Leak Mass Flow Rate 44 Pitot Tube Mass Flow Rate 45 RV Downcomer Composite Venturi Mass Flow Rate 46 Cold Leg Orifice Composite O 47 48 Mass Flow Rate Not Used Integrate Turbine Meter Flow Rate with Time to Get Accumulated Total D-4 49 RVVV Limit Switch (Open,
7 Pege 5 Naither, Closed) 50 Cold Log Co11cpsed Water Level 51 RV Downtomer Collapsed Water Level 52 Cold Leg Orifice Mass F > Rate w/ Level t-: Sat Checks
** Called from Type 23 **
53 RV Downtomer Venturi Mass e Flow Rate
** Called from Type 23 ** } 54 Saturation temperature from pressure 55 Auctioneered cold leg suction leak for OTIS FFF DEC # of Significant 13 Digits After the Decimal Places in the Converted ENG Value GGG UNIT CODE FOR UNITS CODd UNITS 13 1 Volts 2 Deg F 3 PSIA 4 PSIG 5 GPM 6 LBM/HR 7 PSI 8 KWATT 9 BTU /HR 10 DRY / WET 11 OPN/CL 12 LBM 13 FT 14 SCF 15 GAL Analogic Channel I3 HHH CHAN Gain Code Word 13 III GAIN For ANALOGIC Cards GAIN DESCRIPTION I O " DUMMY" Channel--Not Instrument VTAB l
l Or Accumulating Flow Meter 1 Gain of 1 for" ADTYPE's 1-3 2 Gain of 2 " 4 Gain of 4 " " 8 Gain of 8
# # = Bit for Digital Input Card (1-16, 16 bit)
## ## = Gate Time for Frequencs Input
## GATE TIME (SEC) 4 600 5 3600 6 60 7 100 E 10 9 1 10 0. 1 D-5
- A . . . . .
I Page 6 11 0.01 i 12 0.001 l 13 0.0001 )
~ /~' 14 0.00001 bg l 15 O.000001 l JJJ ADTYPE ANALOGIC Card Type 13 CODE CARD 0 " DUMMY" Channel 1 Analog +/- 40 mv 2 Analog +/- 1.25 v 3 Analog +/- 10.0 v 4 Digital Input 5 Counter 6 Frequency KKK..KKK -
DESCR VTAB Descriptor 40A1 000 END CARD #1 *** ooooo*************************************************************************++ 0o0o0*******************************************##*#***##*********************** i (_\/ O D-6
Page 7 Data input to card #2 is specific to the data reduction type code, REDUC, defined above. The input parameters for each reduction type are defined below. coco **************************************************************************
- oooo****************************************************************************
coo CARD #2 *** FORMAT (10X,5(E13.7,1X)) FORMAT (10X,4(E13.7,1X),2(13,2X),4X) <--- TYPE 23 ONLY
*********** CARD COLUMN AND ENTRIES **********
1 2 3 4 5 6 7 8 12345678901234567890123456789012345678901234567890123456789012345678901234567890 AAAAAAAAAAAAA BBBBDDDDDBBBB CCCCCCCCCCCCC DDDDDDDDDDDDD EEEEEEEEEEEEE AAAAAAAAAAAAA BBBBBBBBBBDDB CCCCCCCCCCCCC DDDDDDDDDDDDD EEE eee !'!
!!! Type 23 only l
CARD REDUCTION VALUE ENTRY FORMAT TYPE DESCRIPTOR (IF CONSTANT) oo***** AAAAAAA E13.7 1 Engineering = Raw Input 0.00 2 RTD Resistance (OHM) e 0. 0 (C) 3 C1 of C1+C2*(V-VV)+C3*(V-VV)**3 4 C1 of C1+C2*V+C3*V**2+.. +CS*V**4 5 TYPE J TC (Coefficients Hardwired) 0.00 6-8 Not Used 0.00 9 RTD Resistance (OHM) at O (C) 10-20 Not Used 0.00 21 C1 of C1 + C2*K + C3*K*K + C4*K**3 22 C1 of (C1+C2*EE+C3*DE**2)(1-C4* PRES) 23 Pipe Inside Dia. (inches) 24 Distance (FT) Between DP Taps 25 Elevation (FT) of Pressure Tap Above Transmitter 26 Reduction Type Not Used 27 Not Used 0.00 28 Not Used 0.00 29 Not Used 0.00 30-43 Not Used 0.00 l 44 Flow Cross Sectional Area (FT**2) 45 Minimum Transmitter Voltage 46 Minimum Transmitter Voltage 47 Reduction Type Not Used Not Used 0.00 48-55 Engineering = Raw Input 1.00 BBBBBBB E13.7 1 2 RTD Temp Coeff e 0.0 (C) -- Alpha 3 C2 OF C1+C2*(V-VV)+C3*(V-VV)**3 4 C2 OF C1+C2*V+C3*V**2+....+C5*V**4 TYPE J TC (Coefficients Hardwired) 0.00 5 Not Used 0.00 6-8 9 Temperature Coefficient at O (C) 0. 0 10-20 Not Used l 21 C2 of C1 + C2*K + C3*K*K + C4*K**3 22 C2 of (C1+C2*DE+C3*DE**2)(1-C4* PRES) , 23 Orifice Dia (FT) Coefficient of Thermal Expansion (1/F) 24 0.00 25 Not Used D-7
Page 8 26 Reducticn Typo Not Usod 27 Not Used 0.00 28 Max Voltage for Over-Range
-- 29 Max Voltage for Over-Range
( 30-44 Not Used 0.00
\- ' 45 Max Voltage for Over-Range 46 Max Voltage for Over-Range 47 Reduction Type Not Used '
48-55 Not Used 0.00 i
-CCCCCCC E13.7 1 Engineering = Raw Input 0.00 2 RTD Constant -- DELTA 3 C3 OF C1+C2*(V-VV)+C3*(V-VV)**3 4 C3 OF C1+C2*V+C3*V**2+....+C5*V**4 5 TYPE J TC (Coefficients Hardwired) 0.00 6-8 Not Used 0.00 9 RTD Constant -- Typically About 1.49 10-20 Not Used 0.00 21 C3 of C1 + C2*K + C3*K*K + C4*K**3 22 C3 of (C1+C2*DE+C3*DE**2)(1-C4* PRES) 23 C3 +C3 ==> K=C3(1+C4/ red) Flange
-C3 ==> K=-C3+C4*1000/SGRT(RE) Corner 24 C 1=0. 0 ==> Invert DP with Ref Leg C1=1.0 ==> Orifice DP for Downflow C1=2.0 ==> Orifice DP for Upflow 25 Not Used 26 Reduction Type Not Used 27-46 Not Used 0.00 47 Reduction Type Not Used
/~'\ 48-55 Not Used 0.00 V
.DDDDDDD E13.7 1 Engineering = Raw Input 0.00 2 Resistance (OHM) of Precision Resister 3 C4 of C1+C2*(V-VV)+C3*(V-VV)**3
, 4 C4 of C1+C2*V+C3*V**2+....+C5*V**4 5 TYPE J TC (Coefficients Hardwired) 0.00 6-8 Not Used 0.00 [ 9 Current (AMPS) Through RTD !, 10-20 Not Used 0.00 21 C4 of C1 + C2*K + C3*K*K + C4*K**3 22 C4 of (C1+C2*DE+C3*DE**2)(1-C4* PRES) Static Pressure Span Error (Typically L 1% per 1000 PSI or +1.E-05) 23 C4 of K=C3(1+C4/ red) Flange L -or K=-C3+C4*1000/SGRT(RE) Corner l 24 Not Used 0.00 l 25 Not Used
- 26 Reduction Type Not Used l 27-46 Not Used 0. 00 l 47 Reduction Type Not Used l 48-55 Not Used 0.00 r E13.7 1 Engineering = Raw Input 0.00 (s)3EEEEEE13.7 E13.7 2
3 Not Used VV of C1+C2*(V-VV)+C3*(V-VV)**3 0.00
- E13.7 4 C5 of C1+C2*V+C3*V**2+....+C5*V**4 l E13.7 5 TYPE J TC (Coefficients Hardwired) 0.00 6-20 Not Used 0.00 E13.7 21 Not Used 0.00 l
l D-8
Pago 9 E13.7 22 'Zoro' Voltego EEE 13 23 Pipo Mat'l O=Steinless, 1=Cerbon ooe 13 Orifice Mat'l O= Stainless. 1= Carbon E13.7 24 Not Used 0.00 E13.7 25 Not Used 0.00 26 Reduction Type Not Used E13.7 27-46 Not Used 0. 0C 47 Reduction Type Not Used E13.7 48-55 Not Used 0.00 000 END CARD #2 *** ocooe*************************************************************************** 0000C*************************************************************************te O 9 i i l O i D-9 l
Wage B@ Cerd C3 centcins the reforonco VTAD's (when used) for converting the input of the VTAB to engineering format. For example, an RTD requires the voltage drop across a precision resistor to determine the current flow in the circuit. Hence, the reference s_/ voltage drop across this resistor appears as a reference VTAB for the 8 RTD.in location A1A2A3. I Note that unused reference VTAB entries must be set to blanks by the user since the read is for 4 entries. ooooce**************************************************************************. ooooce************************************************************************** Coo CARD #3 *** FORMAT (8X,4(2X,3A2),40X)
*********** CARD COLUMN AND ENTRICS **********
1 2 3 4 5 6 7 E 12345678901234567890123456789012345678901 EJ456789012345678901234567890123456789 ; A1A2A3 B192B3 C1C2C3 D1D2D3 Where, A1A2A3, B1B2B3, C1C2C3, D1D2D3 are the reference VTAD's REDUCTION -------------------- CARD E N T R Y ------------------------ TYPE A1A2A3 B1B2B3 C1C2C3 D1D2D3 oooo***** ()1 Card Not Required Voltage Drop Across '6 Blanks' '6 Blanks' '6 Blank s ' 2 Precision Resistor 3 Card Not Required 4 Card Not Required 5 Card Not Required 6-8 Not Used 9 Card Not Required 10-20 Not Used Fluid Pressure Fluid Temperature '6 Blanks' '6 Blanks' 21
'6 Blanks' '6 Blanks' '6 Blanks' 22 Fluid Pressure Fluid Pressure Fluid Temperature Orifice Diff '6 Blanks' 23 Pressure Ref Leg Temp Diff Pressure Fluid Temp 24 Fluid Pressure O 25 Fluid Pressure Ref Leg Temp '6 Blanks' '6 Blanks' 26 Not Used 27 Vent Sys Press Vent Sys Temp '6 Blanks' '6 Blank s ' ,
D-10
-. - _ . . .. .~ -_ _ - . - - - . - _ . , - - . _ . _ . - - - _ - . - - - . - . - . . - --
Page 11
'22-30 Ccrd Not Roquirod 31 '6 Blanks' '6 Blanks' '6 Blanks' Flow Rate 32 Card Not Required 33-35 '6 Blanks' '6 Blanks' '6 Blanks' Flow Rete 36-40 Card Not Required 41 Cold Leg Flow Rate RV DC Flow Rate '6 Blanks' '6 Blenis-42' Two-Phase Vent Two-Phase Vent HPV Acc Flow PORV Acc System Pressure System Temp Meter Flow Meter 43 Primary Pressure Temp at Single- Single-Phase '6 Blanks' Phase Acc Meter Ace Flow Meter 44 Fluid Pressure Fluid Temp Pitot DP '6 Blants' 45-46 Card Not Required 47 Not Used 48 Flow Rate '6 Blanks' '6 Blanks' '6 Dlanks' 49 Card Not Required 50-51 '6 Blanks' '6 Blanks' '6 Blanks' Flow Ra 52-53 Called From Type 23 54 Fluid Pressure '6 Blanks' '6 Blanks' '6 Blanks 55 Card Not Required 000 END CARD #3 ***
l ocoo****************************************e*********************************< 0000**************************************************************************** l i l l D-11
f Card #4 definoe the porcmaters ossocieted with clorm messages cnd rato control stim 2 betw2Gn dato acquisition scons) of the data acquisition system. This card is therefore used only when the VTAB is selected for alarming or rate control. In all other instances this e card should not be part of the VTAB identity. The ' KEYS' parcmeter on fg card #1 should be switched to include the presence of rate and/or
')
e alarm control for the subject VTAB. ocooo*************************************************************************** ocooo************************************************************************s<. ooo CARD #4 *** FORMAT (10X,4(E13.7,1X))
*********** CARD COLUMN AND ENTRIES **********
1 2 3 4 5 6 7 E 123456789012345o7890123456789012345678901234567890123456789012345678901234567E;; AAAAAAAAAAAAA BBBBBBBBBBBBB CCCCCCCCCCCCC DDDDDDDDDDDDD EEEEEEEEEEEEE CARD SOFTWARE ENTRY PARAMETER DESCR IPT ION FORMAT
******* ********* ****************************************** ******++
AAAAAAA ALARMH Hi Alarm Value E13.7 BBBBBBB ALARML Low Alarm Value E13.7 CCCCCCC ALARMD Alarm Deadband E13.7 DDDDDDD RVALUE Maximum Change of VTAB Engineering Value E13.7 Between Successive Data Acquisitions or Maximum Engineering Value Allowed Before
'Pe gging ' DAS Sp eed O EEEEEEE RATOLD Previously Calculated Value for Rate E13.7 000 END CARD #4 ***
occoo**************************************************************************> ooooo***********************************************************************<-**u This concludes the definition of the VTABLE.DAT file. The in-formation in VTABLE.DAT is used to define swstem cocmon dcta for each of the VTAB's. This information is then available to all othet SBLOCA DAS routines. The ne::t section lists and desc ribes all of these SBLOCA DAS routines. O D-12
O Appendix E List of GERDA and OTIS Phase O Characterization Tests O ( i O 1
GERDA PHASE O TESTS I Run Number Description 000100 TC Calibration - Pressurizer at 382*F 000200 TC Calibration - Pressurizer at 432*F 000300 TC Calibration - Pressurizer at 486*F 000400 TC Calibration - Pressurizer at 532*F 000500 TC Calibration - Steam Generator at 350*F
~000600 TC Calibration - Steam Generator at 375'F 000700 TC Calibration - Steam Generator at 400'T 000800 TC Calibration - Steam Generator at 425'F 000900 TC Calibration - Steam Generator at 450*F 001000 TC Calibration - Steam Generator at 450*F 001100 TC Calibration - Steam Generator at 475'F 001200 TC Calibration - Steam Generator at 475'T 001300 TC Calibration - Steam Generator at 500*F 001400 TC Calibration - Steam Generator at 500*F 001500 TC Calibration - Pressurizer at 587'F 001600 TC Calibration - Steam Generator at 525'F 001700 TC Calibration - Steam Generator at 525*F 001800 TC Calibration - Steam Generator at 550'F 001900 TC Calibration - Steam Generator at 550*F 002000 TC Calibration - Steam Generator at 575'F 002100 TC Calibration - Steam Generator at 575*F
, 002200 TC Calibration - Pressurizer at 629'F
.(T 002300 TC Calibration - Steam Generator at 500*F
(_ / 002400 TC Calibration - Steam Generator at 500*F 002500 TC Calibration - Pressurizer at 587'F 002600 TC Calibration - Steam Generator at 425'F
-002700 TC Calibration - Steam Generator at 425'F
- 002800 Steam Ramp Cooldown
. 002900 Steam Ramp Cooldown 003000 Steam Ramp Cooldown I) 'j- 003100 VOID l 003200 TC Calibration - Steam Generator at 350'F
- 003300' TC Calibration - Steam Generator at 350*F l 003400 TC Calibration - Pressurizer at 486*F l 003500 TC Calibration - Pressurizer at 382*F
! 003600 TC Calibration - Reactor Vessel at 382*F 003700 TC Calibration - Reactor Vessel at 432*F ! 003800 TC Calibration - Reactor Vessel at 488'F l 003900 TC Calibration - Reactor vessel at 531'F l 004000 TC Calibration - Reactor vessel at 587'F 004100 void 004200 TC Calibration - Reactor Vessel at 629'F 004300 TC Catteration - Reactor Vessel at 587'F TC Cal 1Lca61on - Reactor Vessel at 527'F l 004400 004500 TC Calibration - Reactor Vessel at 486'F l 004600 TC Calibration - Reactor Vessel at 382*F l 004700 VOID 004800 VOID (} l i l- E-1 .I'
PHASE O TESTS (cont'd.) Run Number Description 004900 Steam /Feedwater Orifice Calibration - 200 lb/hr 005000 Steam /Feedwater Orifice Calibration - 250 lb/hr 005100 Steam /Feedwater Orifice Calibration - 300 lb/hr 005200 Steam /Feedwater Orifice Calibration - 350 lb/hr 005300 Steam /Feedwater Orifice Calibration - 200 lb/hr 005400 Steam /Feedwater Orifice Calibration - 300 lb/hr 005500 Steam /Feedwater Orifice Calibration - 400 lb/hr 005600 VOID 005700 Steam /Feedwater Orifice Calibration - 250 lb/hr 005800 Steam /Feedwater Orifice Calibration - 300 lb/hr 005900 Steam /Feedwater Orifice Calibration - 350 lb/hr 006000 Steam /Feedwater Orifice Calibration - 200 lb/hr 006100 Steam 7Feedwater Orifice Calibration - 120 lb/hr 006200 Steam /Feedwater Orifice Calibration - 200 lb/hr 006300 Steam /Feedwater Orifice Calibration - 250 lb/hr 006400 Steam /Feedwater Orifice Calibration - 300 lb/hr 006500 Steam /Feedwater Orifice Calibration - 200 lb/hr 006600 Steam /Feedwater Orifice Calibration - 250 lb/hr 006700 Steam /Feedwater Orifice Calibration - 285 lb/hr l 006800 Steam /Feedwater Orifice Calibration - 100 lb/hr i 006900 4 HPI Pump Head-Flow Control 007000 4 HPI Pump Head-Flow Control 007100 2 HPI Pump Head-Flow Control 007200 2 HPI Pump Head-Flow Control 007300 Primary Flow Calibration at 9450 lb/hr 007400 Primary Flow Calibration at 12000 lb/hr 007500 Primary Flow Calibration at 2300 lb/hr 007600 Primary Flow Calibration at 2300 lb/hr 007700 Primary Flow Calibration at 1600 lb/hr 007800 Primary Flow Calibration at 2000 lb/hr 007900 Primary Flow Calibration at 2400 lb/hr 00S000 Primary Flow Calibration at 2900 lb/hr 008100 Primary Flow Calibration at 3350 lb/hr 008200 Primary Flow Calibration at 3600 lb/hr l 008300 Primary Flow Calibration at 1100 lb/hr 008400 Heat Loss - No Guard Heaters - 505'F ! 008500 Heat Loss - Zone / On - 505'F 008600 Heat Loss - Zone 1 and 2 On - 512*F 008700 Heat Loss - Zones 1-6 On - 553*F 008800 Heat Loss - Guard Heaters On - 561*F 008900 Surge Line Special Test I 009000 Heat Loss - No Guard Heaters - 566*F l 009100 Heat loss - Zones 2-6 On - 536*F i 009200 Heat Loss - Guard Heaters on - 502*F 009300 Heat loss - Bias + 0.1 009400 Heat Loss - Bias 0.0 l 009500 Heat loss - Zones 2-6 on - 492*F 009600 Condensation and Guard Heating Vapor Region 009700 Heat Loss - No Guard Heaters - 490*F E-2 v
F l PHASE O TESTS (cont 'd.)
~
'Run Number Deseription 009800 Heat Loss - No Guard Heaters - 490'F l 009900 Heat - Loss - No Guard Heaters - 490*F )
009901 63-Bar Interception 009902 Conductivity Probe Checkout 009903 NPV w/o NCG 009904 RPV w/o NCG 009905 HPV w/o NCG C09906 HPV w/o NCG 009907 Gas Sample HLUB 009908 Gas Sample with NCG 009909 Gas Sample HLUB with NCG 009910 PORV w/o NCG 009911 PORV with NCG 009912 PORV with NCG 009913 Heat Loss - No Guard Heaters - 497'F 00991l. Heat Loss - No Guard Heaters - 451*F 009915 Heat Loss - Guard Heaters on - 494*F 009916 Ultrasonics - No Flow 009917 Ultrasonics - Intermodulations 009918 Ultrasonics - Pulse Echo w/o NCG 009919 Ultrasonics - Pressure = 1266 psia 009920 Ultrasonics - Pressure = 1541 psia 009921 Ultrasonics - Pressure = 1908 psia Ultrasonics - Pressure = 2100 psia ("')S s, 009922 Ultrasonics - Pressure = 928 psia 009923 009924 Ultrasonics - Pressure = 790 psia 009925 Ultrasonics - Water Injected at CLS
- 009926 Ultrasonics - Pressure = 840 psia with NCG 009927 Ultrasonics - Pressure = 1425 psia 009928 Heat Loss - SG Level 32%, 554*F 009929 Ultrasonics - Spectrum Analysis 009930 Heat Loss - SG Dry, 550*F 009931 Ultrasonics - Pressure = 1200 psia 009932 Ultrasonics - Density Layering 009933 Ultrasonics - Pressure = 1200 psia
, 009934 Conductivity Probes 009935 Steam /Feedwater Orifice Calibration - 120 lb/hr Steam /Feedwater Orifice Calibration - 200 lb/hr 009936 l 009937 Steam /Feedwater Orifice Calibration - 250 lb/hr 009938 Steam /Feedwater Orifice Calibration - 300 lb/hr
- 009939 Steam /Feedwater Orifice Calibration - 250 lb/hr
! 009940 Steam /Feedwater Orifice Calibration - 200 lb/hr 009941- Steam /Feedvater Orifice Calibration - 150 lb/hr 009942 Steam /Feedwater Orifice Calibration - 110 lb/hr 009943 DCUS, Pressure = 1200 psi (no disk file) 009944 DCUS, with Guard Heaters, 460*F 009945 DCUS, with Guard Heaters, 513*F l C
\
009946 009947 VOID Energy Balance at 520'F l l E-3
PHASE O TESTS (cont'd.) Run Number Description 009948 Pitot Tubes (Renamed 010302) 009949 Heat Loss at 515'F 009950 Cold Leg Orifice Calibration 0 1% Power 009951 Cold Leg Orifice Calibration 01.5% Power 009952 Cold Leg Or.ifice Calibration 0 2% Power 009953 Cold Leg or.fice Calibration @ 2.5% Power 009954 Cold Leg Orifice Calibration 0 3.0% Power 009955 Cold Leg Orifice Calibration 0 3.5% Power 009956 Cold Leg C-ifice Calibration 0 4.0% Power 009957 Cold Leg Orifice Calibration 0 4.5% Power 009958 Cold Leg Orifice Calibration 0 5.0% Power 009959 Cold }.eg Orifice Calibration @ 5.5% Power 009960 Cold Leg Orifice Calibration 0 0.3% Power
- 009961 Cold Leg Orifice Calibration 0 0.54% Power 009962 Euler Number Test - Stalled Flow 009963 Euler Number Test - Minimum Forced Flow 009964 Euler Number Test - Repeat of 9963 009965 Cold Leg Calibration 0 8.6 KW 009966 Euler Number Test - 15000 lb/hr 009967 Euler Number Test - Stalled Flow 009968 Euler Number Test - 20,000 lb/hr 009969 Euler Number Test - Stalled Flow 009970 Data Storage Qieck 009971 Heat Loss at 465'T 009972 Heat Loss, Guard Heaters on, 519'F 009973 Heat Loss, Guard Her.ters on, 526*F 009974 Heat Loss, Guard Heaters On, 420*F 009975 Heat loss, Guard Heaters on, 330*F 009976 Conductivity Probe Check at 30 pmho/cm ; 009977 Conductivity Probe Check at 24.5 teho/cm 009978 Conductivity Probe Check at 44.5 vmho/cm 009979 Leak - HPI Equilibrium for 070602 009980 Heat Loss at 537'F, SC Dry 009981 Two-Phase Vent Exercise l 009982 Heat Loss, SG Level 30%, G.H. On 009983 Heat loss, SG Level 67%, No G.H.
009984 Equilibrium Pressure for 10 cm 2CLS and 3 cm2 HPV - 2 HPI Pumps , 009985 Equilibrium Pressure for 10 cm 2CLS and 3 cm2 HPV - 4 HPI Pumps 2 ! 009986 Equilibrium Pressure for 10 cm CLS - 2 and 4 HPI Pumps 009987 Heat Loss, SG IAvel 35%, No G.H. 009988 Equilibrium Pressure for 070301 009989 Equilibrium Pressure for 071112 i 009990 Equilibrium Pressure for 070801 009991 HK(2) AFW Head-Flow, Part 2 009992 NK(2) AFW Head-Flow, Part 1 009993 Equilibrium Pressure for 070401 1 009994 Heat Loss, 433*F 009995 Equilibrium Pressure for 070201 009996 Equilibrium Pressure for 071224 E-4
y 1 OTIS PHASE O TESTS G l Run Number Description _200001- RVUP and SL Guard Heater Characterization, w/HL heaters only, 2/2/84 1 - 200002 Same as 200001,2/2/84 200003 Same as 200001,2/3/84 200004 RVUP and SL Guard Heater Characterization, BI AS = 0 2/3/84 200005 GH Test, HL BIAS = 0.1, RV = 0.05, SL = 0.00, , 2/4/84 200006 CL Orifice Calibration 0 2.5% Power, 2/6/84 200007 CL Orifice Calibration 9 2.0% Power, 2/9/84 200008 CL Orifice Calibration 01.5% Power, 2/10/84 200009 CL Orifice Calibration 91.0% Power, 2/10/84 200010 CL Orifice Calibration 9 3.0% Power, 2/10/84 4 200011 CL Orifice Calibration 9 3.5% Power, 2/10/84 200012 CL Orifice Calibration 9 4.0% Power, 2/10/84 200013 Deleted 200014 Heat Loss, HL BI AS
- 0.1, PR = 0.35, RV Upper =
O.2, RV top = 0.15, PR SL = 0.10, 2/13/84 i 200015 CL Orifice Calibration 9 3.0% Power, 2/13/84 200016 CL Orifice Calibration 9 4.5% Power, 2/13/84 200017 CL Orifice Calibration 9 5.0% Power, 2/13/84 O' 200018 CL Orifice Calibration 9 5.5% Power, 2/13/84
' U 200019 CL Orifice Calibration 9 5.0% Power (Report), '
2/13/84 o
- 200020 CL Orifice Calibration 91.0% Power (Report), '
2/13/84 200021 CL Orifice Calibration w/ dry SG, 2/14/84 i 200022 Heat Loss, all GH on, 2/17/84
-200023 Heat Loss, all GH on, 2/17/84 200024 Heat Loss, all GH on except SL, 2/17/84 200025 Heat Loss, continuation of 200024, 2/17/84 200026 Heat loss, all GH on except SL, 2/20/84 200027 RV, HL Guard Heater Test for Steam, Drain Phase, ,
2'/22/84 200028 RV, HL Guard Heater Test for Steam, 2/23/d4 200029 Continuation of 200028,2/23/84 200030 Continuation of 200028,2/24/84 4 200031 Continuation of 200028,2/24/84 200032 Continuation of 200028,2/28/84 200033 GH Settings for Steam, Final Run, 3/1/84 200034 Steam GH ' Settings with Water-Solid Loop, 3/2/84 200035 Continuation of 200034,3/3/84 200036 Continuation of 200034, 3/4/84 200037 Continuation of 200034,3/5/84 200038 Continuation of 200034,3/6/84 ; O E-5
OTIS PHASE O TESTS (Continued) Run Number Description 200039 Pressurizer GH Re Characterization, BIAS = 0.07, 4/3/84 200040 Continuation of 200039,4/4/84 200041 Continuation of 200039,4/4/84 l O .I [ t , i l O E-6
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