ML19312A213
| ML19312A213 | |
| Person / Time | |
|---|---|
| Site: | 05000495 |
| Issue date: | 11/29/1978 |
| From: | NEW YORK STATE ELECTRIC & GAS CORP., STONE & WEBSTER, INC. |
| To: | |
| References | |
| NUDOCS 7909050538 | |
| Download: ML19312A213 (206) | |
Text
{{#Wiki_filter:SWESSAR-P1 CHAPTER 10 STEAM AND POWER CONVERSION SYSTEM LIST OF EFFECTIVE PAGES Page , Table (T) , Amendment Page, Table (T) , Amendment or Figure (F) No. or Figure (F) No. 10 -afb 39 F10.3-1B (BSW) 30 10 -i 8 F10.3-1 (C-E) 30 10-ii 9 F10.3-1A (C-E) 30 10-iii/iv 17 F10.3-1B (C-E) 30 10 -v/vi 9 F10.3-1C 19 10-vii 6 10.4-1 19 10.1-1 8 10.4-2, 3 12 10 .1 -2 , 2 A 9 10.4-4 thru 8A 9 T10.1-1 (sheets 162) 6 10.4-9 thru 10B 17 T10.1-1 (sheets 364) 12 10.4-11 13 T10.1-2 pi) (3 sheets) 21 10.4-12, 12A, 12B 21 T10.1-2 (W-3S) 28 10 .4 -13 12 (3 sheets) 10.4-14 19 T10.1-2 (B&W) (2 sheets) 37 10.4-14A 9 T10.1-2 (C-E) (2 sheets) 23 10.4-15/16 s F10.1-1 Orig 10.4 -17/18 12 F10.1-2 6 3 (W) 7 10.4-19 1 F10.1-26 3 (W-3S) 17 10.4-20 3 F10.1-2 (B&W) 19 10.4-21 13 F10.1-3 (BSW) 19 10.4-22 19 F10.1-2 63 (C-E) 3 10.4-22A/22B 15 10.2-1 8 10 .4 -23 13 10.2-2 12 10 .4 -24 9 10.2-3 thru 7 8 10.4-24A 8 10.2-8 thru 11 1 10 .4 - 2 5 Orig 10.2-12 9 10.4-26, 26A 9 10.2-13 5 10.4-27/28 12 10.2-14 8 10.4-29 thru 31 3 10 .2 -15 9 T10.4.7-1 8 10.2-16, 17 23 T10.4.8-1 7 T10.2-1 8 T10.4.8-2 20 T10.2-2 thru 6 17 T10.4.8-3 7 F10.2-1 12 T10.4.10-1 35 F10.2-2 thru 4 5 T10.4.10-263 (W) 9 10 .3-1 33 T10.4.10-2 [W-3S) 17 10.3-2,2A 19 T10.4.10-2 (BSW) 1 10.3-3 thru 6 30 T10.4.10-2 (C-E) 6 T10.3-1 (sheet 1) 35 F10.4.1-1 12 T10.3-1 (sheet 2) 28 F10.4.2-1 12 F10.3-1DO 30 F10.4.4-1 12 F I C . 3-TA (W: 30 F10.4.6-IA 17 F10.3-1B(W) 30 F10.4.6-1B 12 F10. 3-1 (W-3S) 30 F10.4.7-1 12 F10. 3 -1 ASB (W-3S) 30 F10.4.7-2A (W) 12 F 10. 3-1 (B&W) 30 F 10. 4.7-2A (W-3S) 17 F10. 3-1A (B SW) 30 F10. 4 .7 -2A (BSW) 19 10-a - d,-[) Amendment 39 h)) 7/14/78
SWESSAR-P1 LIST OF EFFECTIVE PAGES (CONT) Page, Table (T) , Amendment Page, Table (T) , Amendment or Figure (F) No. or Figure (F) No. F 10.4.7-2A (C-Z) 30 F10.4.7-2B 19 F 10. 4. 8 - 1 A (W) 13 F 10. 4.8 - 1 A (W-3S) 20 F10. 4. 8 - 1A (C-E) 13 F10.4.8-1B 20 F10.4.9-1 Orig F 10. 4 .10 -1 A (W) 11 F10. 4.10-1 A (W-3S) 17 F 10 . 4 .10- 1 A (B &W) 23 F 10. 4 .10- 1 (C-E) 23 F10.4.10-1B 19 F10.4.11-1 12 F10.4.12-1 12 0
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SWESSAR-P1 CHAPTER 10 STEAM AND POWER CONVERSION SYSTEM TABLE OF CONTENTS Section Page 10.1
SUMMARY
DESCRIPTION 10.1-1 10.1.1 Materials Considerations 10.1-2 10.1.2 Interface Requirements 10.1-2 10.2 TURBINE-GENERATOR AND TURBINE STEAM SYSTEM 10.2-1 10.2.1 Design Bases 10.2-1 10.2.2 Description 10.2-2 10.2.2.1 Turbine Steam System 10.2 -2 10.2.2.2 Turbine Control System 10.2-2 10.2.2.2A Turbine Control System for General Electric Turbine 10.2-4E B 10.2.2.2B Turbine Control System for Westinghouse Turbine 10.2-7 10.2.2.3 Lubricating Oil System 10.2-11 10.2.2.4 Turbine Gland Scaling System 10.2-11 10.2.2.5 Generator 10.2-11 10.2.2.6 Generator Hydrogen 10.2-11 10.2.3 Turbine Missiles 10.2-12 10.2.4 Design Evaluation 10.2-16 10.2.5 Testing and Inspections 10.2-17 References for Section 10.2 10.2-17 10.3 MAIN STEAM SYSTEM 10.3-1 10.3.1 Design Bases 10.3 -1 10.3.2 Description 10.3-2 10-i Amendment 8 3/28/75 (n n ~' ' (J U U Us i
SWESSAR-P1 TABLE OF CONTENTS (CONT) Section Pace 10.3.3 Safety Evaluation 10.3-3 10.3.4 Inspection and Testing Requirements 10.3-5 10.3.5 Water Chemistry 10.3-5 9 10.3.6 Instrumentation Applications 10.3-S 10.3.7 Interface Requirements 10.3-6 References for Section 10.3 10.3-6 10.4 OTHER FEATURES OF STEAM AND POWER cot! VERSION SYSTEM 10.4-1 10.4.1 Main Condenser 10.4-1 10.4.1.1 Design Bases 10.4-1 10.4.1.2 System Design 10.4-1 10.4.1.3 Safety Evaluation 10.4-2 10.4.1.4 Testing and Inspections 10.4-2 10.4.1.5 Instrumentation Applications 10.4-2 10.4.2 Condenser Evacuation System 10.4-2 10.4.2.1 Design Bases 10.4-2 10.4.2.2 System Design 10.4-3 10.4.2.3 Safety Evaluation 10.4-3 10.4.2.4 Testing and Inspection Requirements 10.4-3 10.4.2.5 Instrumentation Applications 10.4-3 9 10.4.2.6 Interface Requirements 10.4-4 10.4.3 Turbine Gland Sealing System 10.4-4 10.4.3.1 Design Bases 10.4-4 10.4.3.2A System Description with General Electric Turbine 10.4-4 (, { , . <- 10-ii Amendment 9 4/30/75
SWESSAR-P1 TABLE OF CONTENTS (CONT) Section Page 10.4.3.2B Sptem Description with Westinghouse Turbine 10.4-5 10.4.3.3 Safety Evaluation 10.4 -S 10.4.3.4 Testing and Inspections 10.4-5 10.4.3.5 Instrumentation Applications 10.4-6 10.4J Turbine Bypass System 10.4-6 10.4.4.1 Design Bases 10.4-7 10.4.4.2 System Design 10.4-7 10.4.4.3 Safety Evaluation 10.4-8 10.4.4.4 Inspection and Testing 10.4-8 10.4.4.5 Inst unentation Applications 10.4-8 10.4.4.6 Interface Requirements 10.4-8 10.4.5 Circulating Water System 10.4-8A 10.4.6 Condensate Polishing System 10.4-8A 10.4.6.'n Design Bases 10.4-8A 10.4.6.2 System Description 10.4-9 10.4.6.3 Safety Evaluation 10.4-10 10.4.6.4 Testing and Inspections 10.4-10A 10.4.6.5 Instrumentation Applications 10.4-10A 10.4.6.6 Interface Requirements 10.4-10A 10.4.7 Condensate and Feedwater Systems 10.4-10B 10.4.7.1 Design Bases 10.4-11 10.4.7.2 System Description 10.4-11 10.4.7.3 Safety Evaluation 10.4-12A 37 10.4.7.4 Testing and inspections 10.4-12A l 10-iii Amendment 17 9/30/75 f / (; p - (i,<u U;j
SWESSAR-P1 TABLE OF CONTE? PTS (COtTr) 10.4.7.5 Instrumentation Applications 10.4-13 10.4.7.6 Interface Requirements 10.4-14 10.4.8 Stema Generator Blowdown System 10.4-14 10.4.8.1 Design bases 10.4-14 10.4.8.2 Syatan Description 10.4-14A 10.4.8.3 Design Evaluation 10.4-15 10.4.8.4 Testing and Inspectionn 10.4-15 10.4.8.5 Instrumentation Applications 10.4-15 10.4.8.6 Interface Requirements 10.4-15 10.4.8.6.1 Westinghouse 10.4-15 10.4.8.6.2 Canbustion Enginearing 10.4-15 10.4.8.6.3 Babcock & Wilcox 10.4-16 10.4.9 Turbine Plant Component Cooling System 10.4-17 10.4.9.1 Design Bases 10.4-17 10.4.9.2 System Description 10.4-17 10.4.9.3 Safety Evaluation 10.4-19 10.4.9.4 Testing und Inspections 10.4-19 10.4.9.5 T..strumentation Applications 10.4-19 10.4.10 Auxiliary Feedwater System 10.4-20 10.4.10.1 Design Bases 10.4-20 10.4.10.2 System Description 10.4-20 10.4.10.3 Safety Evaluation 10.4 -22 l 10.4.10.4 Testing and Inspection Requirements 10.4-22A n-10.4.10.5 Instrumentation Applications 10.4-22B 10.4.10.6 Interf ace Requirements 10.4-23 10-iv Amendment 17 9/30/75 i c. {} C U UJ
SWESSAR-P1 TABLE OF CONTENTS (C017T) Sl ction Page 10.4.11 Turbine Plant Service Water System 10.4-23 10.4.11.1 Design Bases 10.4-24 10.4.11.2 oystem Description 10.4-24 10.4.11.3 Safety Evaluation 10.4-24 10.4.11.4 Testing and Inspections 10.4-?3 10.4.11.5 Instrumentation Applications tu A-25 10.4.11.6 Interface Requirements 10.4-26 9 10.4.12 Auxiliary Steam and Condensate System 10.4-26 10.4.12.1 Design Baces 10.4-26 10.4.12.2 System Description 10.4-26 10.4.12.3 Safety Evaluation 10.4-28 10.,'4.12.4 Testing and Inspections 10.4-29 10.4.12.5 Instrumentation Application: 10.4-29 10.4.13 Lubricating Oil System 10.4-24 10.4.13.1 Design Bases 10.4-29 10.4.13.2 System Description 10.4-30 10.4.13.3 Safety Evaluation 10.4-31 10.4.13.4 Tests and Inspections 10.4-31 10.4.13.5 Instrumentation Applications 10.4-31 10-v Amen dn.ent 9 4/30/75
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SWESSAR-P1 LIST OF TABLES Table 10.1-1 Steam and Power Conversion Systems, Princinal Design and Performance Characteristics 10.1-2 Steam and Power Conversion Systens Interface Information 10.2-1 Vendor Provided Turbine Information 10.2-2 Strike Probability (P2) for a Single Unit 10.2 ' Overall Probability (P4) for a Single Unit 10.2-4 Strike Probability (P2) for a Two-Unit Site 10.2-5 Overall Probability (P4) for a Two-Unit Site 10.2-6 Turbine - Tarcet Distances and Lnpact Areas for a Two-Unit Site - 10.3-1 Main Steam Svstem, Principal Design and Perf or-mance Characteristics 10.4.7-1 Deleted 10.4.8-1 Steam Generator blowdown System, Component Design and Perf ormance Characteristics 10.4.8-2 NSSS Design und Operating Interf ace Parameters 10.4.8-3 Consequences of Component Failures, Steam Gener-ator Blowdown System 10.4.1C -1 Auxiliary Feedwater System, Component Desion anc Perf ormance Characteristics 10.4.10-2 Consequence of Component Failures , Auxilia ry Feedwater System SI 9 10-vi Amendment 9 n/30/75 e c r-() b u VsO
SWESSAR-P1 LIST OF FIGURES Figure 10.1-1 Steam Plant Fundamental Diagram 10.1-2 Typical Heat Balance at Rated Power 10.1-3 Typical Heat Balance at Turbine Mdximum Capability 10.2-1 Turbine Steam System 10.2-2 Turbine Missile Reference System 10.2-3 Top View of Idealized Target 10.2-4 Side View of Idealized Target 10.3-1 Main Steam System 10.3-1A Main Steam System 10.3-1B Main Steam System 10.3-1C Main Steam System 10.4.1-1 Condenser 10.4.2-1 Condenser Evacuation System 10.4.4-1 Turbine Bypass System f% 10.4.6-1A Condensate Polishing System 10.4.6-1B Condensate Polishing System 10.4.7-1 Condensate System 10.4.7-2A Feedwater System 10.4.7-2B Feedwater System 10.4.8-1A Stedm Generator Blowdown Q..*em 10.4.8-1B Steam Generator Blowdown System 10.4.9-1 Turbine Plant Component Cooling System
- 10. 't .10 - 1 A Auxiliary Feedwater System 10.4.10-1B Auxiliary Feedwater System 10.4.11-1 Turbine Plant Service Water System 10.4.12-1 Auxiliary Steam und Condensate System 10-vii Amendment 6 1/17/75
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SWESSAR-P1 CHAPTER 10 STEAFi AND POWER CONVERSION SYSTEM 10.1
SUMMARY
DESCRIPTION The steam and power conversion system is shown in Fig. 10.1-1. Typical heat balances at rated power and at turbine maximum capability are shown in Fig. 10.1-2 and 10.1-3, respectively.
'he steam and power conversion system includes a six flow, tandem campound, 1,800 rpm turbine, coupled to a single, hydrocen inner-cooled cenerator and rotating rectifier exciter. Steam to drive the turbine is produced in steam generators taking heat from the reactor coolant system. Moisture separation and steam reheat are provided between the high and low pressure turbines. Steam is condensed in three surface-type sinole pass condensers of divided water box design, and condensate is collected in the hotwell which has storage capacity equivalent to approximately 5 min full load operation.
The steam and power conversion systems shown and discussed in SWEFSAR-P1 are based on a turbine cycle consisting of turbine driven f eedwater numps, six stages of feedwater heating and a single stage of steam reheat. Because of variations in site er"ironmental conditions and economic evaluations, the turbine
, buildino design has the flexibility to allow Utility Applicants to optimiz e the turbine cycle. The turbine building design can a ccommodate motor-driven feedwater pumps, seven stages of feedwater heating, and two stages of steam reheat. The extra f eedwater heater and second stage of reheat are indicated by dashed lin es on Fig. 1.2-7. The electrical systens can accommodate motor-driven feedwater pumps by increasing the transformer's capacities.
The steam and power conversion systems are based on detailed desian information for General Electric and Westinghouse turbine generators compatible with the reference plant cower level. Turbine-generators provided by other manufacturers may result in changes to the steam and power conversion systems related to the t urbine-generator. The turbine building arrhngement drawings may 8 change with respect to the width and height of the turbine building and the location and dimensions of related equipment. However, the orientation of the turbine-oenerator and the turbine buildino will remain the same with respect to the remainder of the plant. It is anticipated that such a chunge vould have a very minimal ef f ect on the remainder of the plant design. 10.1-1 Amendment 8 e, n ,' ~i 3/28/75 OOu GJl
SWESSAR-P1 The cond ensate and feedwater systems return feedwater to the steam generators through six stages of extraction heating arranged in three parallel strings. The system provides load following capability in accordance with the NSSS Ven0or's specified capability and within the turbine manuf acturer 's recommended limitations. Turbine bypass and atmospheric steam dump capacity accommodates more severe load rejections without reactor or turbine trip, as specified by the nuclear steam supply system (NSSS) Vendor. The principal design and performance characteristics of the steam and power conversion system are summarized in Table 10.1-1. Interf ace Recuirements Interface information of general applicability to the steam and power conversicn systems, as presented ir Section 10.1 of the respective NSSS Vendor's SARs is discussed in this section. Westinghouse it.terface information given in RESAR-41 is addressed in Table 10.1-2. 10.1.1 Materials Considerations Materials for Safety Class 2 and 3 portions of the steam and f eedwater systems comply with ASME III Code Classes 2 and 3, respectively, and are selected for adequate corrosion resistance and fracture toughness characteristics. Fabrication specifications invoke the requirements of Regulatory Guide 1.71 as described in Section 3A.1-1. 71. In addition, the use of ferritic ma terials for ASME III Code Classes 2 and 3 components invokes the fracture toughness requirements of NC 2300 and ND 2300 of the ASME III code. The use of austenitic stainless steel complies with Regulatory Guide 1.44 as discussed in Section 3A.1-1.44 and the requirements for cleaning comply with Regulatory Guide 1.37, as discussed in S ection 3 A.1-1. 37. Where non-metallic insulation is emp'_oyed , requirements of Regulatory Guide 1.36, as discussed in Section 3A.1-1.36, are invoked. The fabrication of low alloy steels invoke requirements of Regulatory Guide 1.50 as described in Section 3A.1-1.50. 10.1.2 Interface Recuirements Interface information applicable to the steam and power g conversion systems, cs presented in the respective NSSS Vendor's SAR 's , is discussed in Table 10.1-2. 10.1-2 Amendment 9 4/30/75
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SWESSAR-P1 Table 10.1-2 does not address all items listed as interface reauirements because many items so listed interf ace requirements only if the NSSS Vendor supplies the described system. 9 Table 10.1--2 addresses as a minimum items which are, in fact, interface requirements imposed on the systems within the SSW scope of design responsibility.
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SWESSAR-P1 TABLE 10.1-1 STEAM AND POWER CONVERSION SYSTEMS PRINCIPAL DESIGN AND PERFORMANCE CHARACTERISTICS Item Design and nerformance Characteristics Turbine-Generator (Section 10.2) Turbine 1,800 rpm tandem compound, 6-flow, 43 or 44 in. last row blades, single stage reheat Generator 1,800 rpm, direct coupled, hydrogen cooled Exciter 1.0 response ratio Overspeed a. Normal and transient speed Protection control system
- b. Mechanical overspeed system
- c. Backup overspeed protection system Turbine Gland Operated with main steam or auxiliary 9 Sealing steam. Offgas discharged to radioactive gaseous waste system.
Turbine Steam System (Section 10.2) Turbine Steam a. Piping provided by the turbine manu-Piping facturer: in accordance with the tur-bine manufacturer's standards, wher-ever industry codes and standards do not apply
- b. Balance of turbine steam piping:
ANSI B31.1.0b-1971 Moisture-Separator / ASME VIII Reheaters Main Steam System (Section 10.3) Main Steam Piping *a. Frcm each steam generator up to and including the main steam isolation valves: ASME III, Code Class 2: Seismic Category I (v,. o,O ;; , -]
- Safety related (QA Category I) 1 of 4 Amendment 6 1/17/75
SWESSAR-P1 TABLE 10.1-1 (CONT) Item Design and Performance Characteristics
*b. From main steam piping up to and including auxiliary feedwater pump turbine: ASME III, Code Class 3; Seismic Category I
- c. Balance of the main steam piping:
ANSI B31.1.0b-1971 Main Steam Maximum closing time as specified by the Isolation NSSS Vendor (see Table 10.3-1 for specified Valves
- time) : ASME III, Code Class 2; Seismic Category I Main Steam Flow capacity as specified by the NSSS Safety Valves Vendor (see Table 10.3-1) ASME III, Code and Main Steam Class 2; Seismic Category I Atmospheric Dump Valves
- Turbine Eypass System Capacity equal to 40 percent of the (Section 10.4.4) maximum calculated steam generator mass flow at full load pressure.
Piping: ANSI B31.1.0b-1971 Condenser Conventional tubular design, deaerating type (Section 10.4.1) steam surface condenser, single pass with divided water box. Steam and condensate crossover ducts to equalize pressure, impingement baffles to protect the tubes, and means in the hotwell for detection of circulating water leakage are included in the design. Condenser Condenser air removal pumps are provided Evacuation System for initial condenser shell side air (Section 10.4.2) reuoval. Steam jet air ejectors main-tuin vacuum while removing noncondensable gases from the shells. A radiation moni-tor is installed in air ejector discharge line to the radioactive gaseous waste system (Section 11.3). Circulating hater Provided by Utility-Applicant. System (Section 10.4.5)
- Safety related (OA Category I) 2 of 4 Amendment 6 1/17/75
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SWESSAR-P1 TABLE 10.1-1 (CONT) Item Design and Performance Characteristics Steam Generator a. See Section 10.4.8 for details of Blowdown System system. (Section 10.4.8)
*b. Piping un'l valves insiaa the containment structure up t, and including the containment isolation valves: ASME Section III, Code Class 2
- c. All other piping: ANSI B31.1.0b y Auxiliary Steat Piping designed in accordance with System ANSI P31.1.0b {g (Section 10.4.42)
Condensate and a. Three one-half capacity motor-driven Feedwater Rystems condensate pumps, six stages of re-(Section 10.4.7) generative feedwater heating , three one-third capacity turbine-driven feedwater pun as
*b. Piping from and including the feed-water isolation valves outside the containment structure to steam generator inlets: ASME III, Code Class 2; Seismic Category I
- c. Piping from condenser up to, but not n' including, feedwater isolation valvesoutside the containment structure: ANSI B31.1.0b Auxiliary Feedwater a. See Section 10.4.10 for details of System * (Section 10.4.10) system.
- b. All piping up to but excluding t he auxiliary feedwater containment iso-lation valve: ASME III, Code Class 3:
Seismic Category I 3 of 4 Amendment 12 6/16/75
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SWESSAR-P1 TABLE 10.1-1 (CONT) Item Design and Ferformance Characteristics
- c. Pining from and including the auxiliary feedtater containment iso-lation valve to the feedwater system steam generator connection: ASMT III, \t2 Code Class 2; Seismic Category I
- Safety related (QA Category I) 4 of 4 Amendment 12 6/16/75
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e SWESSAR-P1 TABLE 10.1-2 [ STEAM AND POWER CONVERSION SYSTEMS C3 INTERFACE INFORMATION Responses are given, whenever possible, to the SWESSAR section in which ', cunpliance with the interf ace item is discussed. ,j) L RESAR-41 Interf ace Iten SWESSAR-P1 Desian Steam and Power Conversion Systems, RESAR-41, Table 10.1-1 IIeat balance data The values given are typical values calculated using a specific turbine cycle and heat balance. Values calculated for a different cycle will vary slightly, as seen on Fig. 10.1-2. The choice of turbine cycle is the responsibility of the Utility-Applicant / Architect-Engineer. Instrumentation Refer to Secticm 7.8. Electrical Refer to Section 8.4. Main steam and feedwater Sections 10.3.3 5 10.4.7.1, Tab 10 10.3-1 isolation valve closure time Water chemistry Sections 10.4.6, 10.4.7, 8 10.4.8 Prevention of uncontrolled Section 10.3.3 blowdown of more than one steam generator a Maximum flow to turbine Fig. 10.2-3 Single failure Section 3.1.65 Instrument mir 'lhere are no steam and power conversion system valves within the NSSS Vendor's scope of design responsibility. Uniform feedwater Section 10.4.7.2. temperature and contintmus fcedwater flow Feedwater storage capacity Section 10.4.7.2 Main steam design pressure Table 10.3-1 W 1 of 3 Amendment 21 2/20/76
SWESSAR-P1 I'] C_D TABLE 10.1-2 (COffr) U RESAR-41 Interface Item SWESSAR-P1 Design
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Prevention of consequential Section 3.6.2 w-da:nage f rom pipe breaks Main steam valves
- ability Section 10.3.3 to stop flow in either 21 direction Main steam safety valve Table 10.3-1 capacity Main steam atmospheric Table 10.3-1 dunp valve capacity Auxi18ary Peedwater System, RESAR-41, Section 6.6 When system is required Sections 10.4.10.2, 7.3.3.8 Multitrain power sources Sections 10.4.10.3, 7.8 and three train actuation logic Minimum deliverm! flow Section 10.4.10.3, Table 10.4.10-1. Auxiliary feedwater flow 2t and pressure based on a steam pressure of 1,339 psia.
Maximum total delivered Basis for sizing the AFST is a 2 tour hot flow standby followed by a 50 F per hour cooldown. Containment pressure considerations are within Sf,W scope of design responsibility. Maximum allowable time Section 10.4.1('.3, Table 10.4.10-1 for flow delivery Maximum tenperature The maximum annult's building cubicle testgerature of 120 F y; will give a maximum APVST temperature of 120 F. Actuation logic and Sections 7.8, 7.4.3.1 operation f rcun control room or local control station t Single failure Section 3.1.65 21 AFST minimtun solume Table 10.4.10-1 W 2 of 3 Amendment 2i 2/20/76
SWESSAR-P1 C_ D TABLE 10.1-2 (W NT) c -) J 'J P_ESAR-41 Interf ace Item SWESSAR-P1 Design 'S-- Isolation of steam Section 7.8 21 generator blowdown systera Fee
- water nozzle Table 3.2.5-1, Sections 5.2, 10.1.1 mater iala ,
W 3 of I Arnend mnt 21 2f20/16
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SWESSAR-P1 ' [ LJ TABLE 10.1-2 CJ STEAM AND POWER COtWERSION SYSTEMS INTERFACE INFORMATION x.)- s., Respor.ses are given, whenever possible, to the SFESSAR section in which compliance with the interf ace itan is discusse6. Rt.SAR-3S Interface Item SWESSAR-P1 Design Steam and Power Conversion Systems, RESAR-3S, Table 10.1-1
- Heat balance data The values given are typical values calculated using a specific turbine cycle and heat balance.
Values calculated for a different cycle will vary slightly, as seen on Fig. 10.1-2. 'the choice of turbine cycle is the responsibility o1 the Utility-Applicant / Architect-Engineer. Instnnaentation Section 7.8 Electrical Section 8.4 Instrument air There are no steam and power conversion system valves within the NSSS Vendor's scope of design respcrisibility. Main steam and feedwater Section 10.3.3, Tatle 10.3-1, Section 10.4.7.1 isolation valve closure f25 time Feedwater isolation Section 15.1.14.3 Ma ri tm na flow to turbine Fig. 10.2-3 Single failure Section 3.1.65 Prevention of uncontrolled Section 10.3.3 blowdown of more than one 28 steam generator Main steam saiety valve Table 10.3-1 capacity Main steam atmospheric dump Table 10.3-1 valve capacity Unif oca feedwater temperature Section 10.4.7.2 and cDntinMus teedwater tiow W-3S 1 of 3 Amendment 28 8/6/76
0 SWESSAR-P1 L l O TABLE 10.1-2 (COffr) c0 RESAR-3S Interf ace Item SWESSAR-P1 Design w Feedwater storage capacity Section 10.4.7.2 Main stea:n design pressure Table 10.3-1 Prevention of consequential Section 3.6.2 re damage from pipe breaks Main stease valves' ability to Section 10.3.3 stop ilow in either direction Water chemistry Sections 10.4.6, 10.4.7, 10.4.8 Auxiliary Peedwater Systesa, RESAR-3S, Section 6.5, Appendix 6A When system is required Sections 10.4.10.2, 7.3.3.8 Multitrain power sources Sections 10.4.10.3, 7.8 and two train actuation logic Flow rate and pressure Section 10.4.10. 3, T@le 10.4.10-1 delivered to steam generators Maximtan flow to any one steam generator assumed by Westinghouse in its calculation of mass and 3 energy releases for the main steam line break is 1,380 gpa. These releases have been used in the analyses of Section 6.2.1.1.2.2. Therefore, the systen layout during the detail design will assure that this value is not exceeded. Maximum total delivered Basis for sizing the AFST is a 2 hour hot flow standby followed by a 50 F per hour cooldown. Containment pressure considerations are within St.W scope of design responsibility. Maximum allowable time Section 10.4.10.3, Table 1J.4.10-1 for flow delivery Max i nr n= temperature Table 10.4.10-1 Actuation logic and operation Sections 7.8, 7.4.3.1 from control room or local control station Sources of auxiliary feedwater Section 10 .4 .10.2 Feedwater nozzle materials Table 3.2.5-1, Sections 5.2, 10.1.1 W-3S 2 ot 3 Aciendment 28 8/6/7o
SWESSAR-P1 Ll CD TABLE 10.1-2 (CONT) c3 SWESSAR-P1 Design <J RESAR-3S Interf ace Item x _, Condensate Storage Facilities, RESAR-3S, Section 9.2.6 AFST minintza volume Table 10.4.10-1. Usable volume is based 3 on 60 gal per MWt of the reactor rating, which is the Westingtxmase sizing criterion. W-3S 3 of 3 Amendrent 28 8/6/76
SWESSAR-P1 e a t 1 TABLE 10.1-2 O STEAM AND POWER CONVERSION SYSTEJ4S ItrrERFACE REQUIREMENTS -
<2 SWESSAR Reference b' Requirement B SAR-205 Reference Section 10.5.1 (Note 1) Sections 8.4, 10.4.10.3 Power Sections 10.5.2 (1,2,3), Sections 3.3, 3.4, 3.5 Protection against wind, tornado, floods, ami missiles 10.5.4 Sections 10.5.2 (4, 5, Sections 10.3.1, 10 . 4 . 7 .,1, Seismic criteria and ASME Code 10.4.10.1 Class 6, 7)
Sections 10.5.3, 10.5.5, Section 3.6 Pipe separation, rupture, and whip 10.5.6, 10.5.7 (2) Mass and energy release data Sections 10.5.5.1, 10.5.5.2 Section 15.1.14 Section 10.5.7 (1, 3, 4) Section 7.8 Independence of controls Section 10.5.9 (1, 2, 4) See Note 2. Auxiliary feedwater system Sectjon 10.5.9 (5, 6) Section 10.2 Turbine-generator Section 10.5.9 (7, 8, 9, Section 10.4.4 Turbine bypass system 11, 12) Modulating atmospheric dusp valve Sections 10.5.9 (10, 18), Fee Note 4. 10.5.17(3) Feedwater system Section 10.5.9 (13, 14, 15, See Note 3. 16, 17) Section 10.5.10 Fig. 10.3-1, 10.4.7-1 Monitoring section 10.5.11 Section 7.8, Table 10.4.10-1 Operational cxmtrols (See Note 5) II Sections 10.3.4, 10.4.7.4 Inspections and tests Section 10.5.12 Section 10.5.13 Sections 10.4.6, 10.4.7.2 Chemistry and sampling Section 10.5.eo Sections 10 .1.1 Materials Sections 10.3, 10.4.7 Syst W component arrangement Section 10 .5. 15 Section 10.5.1b Chapter 11 Radiological waste Sections 10.5.17 (1, 2) Section 10.3 Overpressure protection Amend:nent 37 B&W 1 of 2 5/22/78
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TAB'? 10.1-2 (CONT) 2 Nozzle loadings Section 10.5.18 Section 3.6 -s NCyrES: 1. Where a B-SAR-205 ref erence section is list ed without an atmoanving iters number in parentheses, it is intended that all item n. tabers within that section are ref erenced.
- 2. The SWESSAR-P1 design meets these requirements (reference Seccion 10.4.10) , with the exception of the 90 F auxiliary feedwater temi.erature given in item 4. The auxiliary feedwater storage tank (AFST) , located inside 3he annulus building, is subjected to the ambient temperature in the annulus building. Aa described in Section 9.4.2, the annulus building ventilation system maintains the temperature in the taak cubicle below 104 F.
- 3. The SWESSAR-P1 design meets these requirements (ref u ence Section 10.4.7). Fbilowing a turbine trip without a reactor trip, the reactor is rin back in pow r. As reactor power decreases, feedwater flow decreases. n e storage capacity of the condenser hotwell (Section 10.4.1) is more than adequate to accourmodate the f eedwater/ steam n: ass lost via release through the atmospheric dump valves during reactor runback.
- 4. The SWESSAR-P1 design meets these requirements (ref erence Section 10.3) with the follow-ing clarification. Manually operated isolation valves are provided between the steam generators and the modulating atmospheric dump valves in the SWLSSAR-P1 design. These valves are normally open and are provided for maintenance of the atmospheric dump valves.
The SWESSAR-P1 design includes f our atmospheric dump valves, one per main steam line (i.e. , two per steam generator) in lieu of B&W's requirement of one per steam generator. This design f eature increases the plant's capability to accommodate main steam pressure rises during normal operating transients, particularly during valve maintenance. Should one atmospheric dump valve be isolated for maintenance, the related stearn generator remains protected by the atmospheric dump valve locatM on the steam generator's other main uteam line.
- 5. B-SAR-205 Section 10.5.11, paragraph 6, to be addressed in Applicant's PSAR. 31 B&W 2 of 2 Amendment 37 5/22/79
SWESSAR-P1 T TABLE 10.1-2 , STEAM AND POWER COtN%SION SYSTEMS C 1FfEPFACE RIQUIREMENTS CO Requirement CESSAR Reference SWESSAR Faf erenq
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Missile, pipe whip, jet Sections 3.5, 3.6, 5.1.4.C.5, sections 3.5 and 3.6 impingement protection 5.1.4.D.4, 5.1.4.G.2, 5.1. 4 . L .7 Electric power Refer to SWESSnR-P1 Section 8.4 Control circuitry Refer to SWEOSAR-P1 Section 7.8 Feedwater isolation Sections 5.1.4 (G.9.) Section 10.4.7 5.1. 4 (G .12. ) 5.1.4 (G.15.) Main Steam design conditions Section 5.1.4 (I .1) Section 10.3.1 Main steam header arrangement Section 5.1.4. (I.3) Fig. 10.3-1 Main steam isolation Sections 5.1.4 (I.4) Section 10.3.3 5.1.4 (I.5) Maximum turbine power Section 5.1.4 (I .6) Fig. 10.1-3, 23 Section 10.3.1 (7) Sections 5.1.4 (I.7) Table 10.3-1, Atmospheric dump valves 5.1.3 (I.8) 5.1.4 (K . 2 ) Section 10.3.3 Sect ions 5.1.4 (I .11) Sections 7.8, 10.4.10 Emergency feedwater 5.1.4 (I.12) Sections 7.8, 10.4.10
- 5. *e . 4 (I .13) Fig. 10.4.10-1, 10. 4. 7 -2A 5.1.4 (I .14 ) Tabic 10.4.10-1 5.1.4 (I .15) Table 10.4.10-1 5.1.4 (I .16) Maximum temperature, Table 10.4.10-1.
Minimum temperature is building t emperature, Sect ion 9.4.7.1 (2) . 5.1.4 (I.17) Table 10.4.10-1 5.1.4 (K .12 ) Fig. 10.4.10-1 5.1.4 (0.9) Fig. 10.4.7-2A 5.1.4 (0.10) Inop seal will be provided to prevent drainage of feedwater piping. Main steam isolation bypass va. . Section 5.1.4 (I.20) Sect ion 10.3.1 (11) Isolation of steam paths Section 5.1.4 (I .21) See Note 1. Sections 3.1.65, 10.4.10.3 Single f ailure Section 5.1.4 (L.7) 1 of 2 Amendment 21 C-E 3/31/76
ENESSAR-P1 TABLE 10.1-2 (COffr) i.7 t ) Requirement CESSAR Feference SWESSAP Feference Secondary chemistry control Section 5.1.4 (M . 2) Sections 10.4.6, 10.4.8, 10.4.10 5.1.4 (M.9) , Blowdown processing Saction 5.1.4 (P.1) Sections, 10.4.8, 10.4.6 " 5.1. 4 ( R .17) Main steam safety valves Section 5.1.4 (Q.3) Table 10.3-1 5.1.4 (Q. 5) 5.1.4 (Q.6) nirbine bypass section 5.1.4 (0.8) Section 10.4.4 23 Note 1: Following a main steam line break, either all steam paths downstream ( f the main steam 8.s>1ation valves (MSIV) will be isolated by their respective control systems fo: lowing an MSIV clos are signal, or the results of a blowdown through a non-isolated path will be shown to be acceptable. An acceptable maximum steam flow f rom a non-isolated steam path will be provided in the C-E application f or Final Design Approval. Blowdown f rm any non-isolated path will not exct ed this value. The SWESSAR-P1 design isolates all steam paths downstream of the MSIVs by their respective control ystems f ollowing an MSIV closure signal . (Peterence Fig. 7.8.1-3, 10.2-1, and Section 10.2.4.)
'.hese controls are redundant, physically independent, and separated and designed to withstand a single f ailure.
C-E 2 of 2 Amendment 23 3/31/76
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J SWESSAR-P1 A heat balance at rated power for B-SAR-205 is not provided because of the different power levels the BSW NSSS is capable of providing. BSW offers NSSS thermal outputs of either 3,620 MWt or 3,820 MWt. The 3,820 MNt heat balance is provided as Fig. 10.1-3 because this is the power level used for the design of the steam and power conversion systems. 19 FIG. 10.1-2 TYPICAL HEAT BALANCE AT RATED POWER PWR REFERENCE PLANT SAFETY ANALYSIS REPORT SWESSAR-P1 7.. g c 0 BSW Amendment 19 12/12/75
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SWESSAR-P1 10.2 TURBINE-GENERATOR AND TURBINE STEAM SYSTEM The function of the turbine-generator and the turbine steam system is to receive steam from the main steam system (Section 10.3) and to transform the thermal energy in the steam to electrical energy. Detailed design information and analyses of specific applicability to General Electric and Westinghouse turbine-generators are provided in the following Sections: 10.2.2.2 Turbine Control System 10.2.3 Turbine Missiles 10.4.3 Turbine Gland Sealing System 15.1.35A and Malfunction of Turbine Gland 15.1.35B Sealing System. Should a Utility-Applicant referencing SNESSAR specify a different turbine-generator manufacturer, the design information and analyses applicable to that manufacturer will be provided at the time of the Utility-Applicant's submittal. In addition, revised turbine building arrangement drawings will be submitted, if necessary. A typical turbine steam system is shown in Fig. 10.2-1. 10.2.1 Design Bases The design bases of the turbine generator and the turbine steam system are:
- 1. 'Ihe turbine shall be designed for normal operation based on steam conditions as determined by the U tility-Applicant 's choice of NSSS Vendor and the main steam piping configuration. The conditions at the steam generator outlet are specified in Table 10.3-1.
- 2. The turbine generator shall be designed for load following operation.
- 3. The turbine-generator design shall allow safe continuous operation at the maximum capability of the turbine (valves wide open condition) .
- 4. The turbine generator and associated steam and power conversion systems shall be capable of a 50 percent load reduction without producing a reactor trip by dumping steam into the condenser through the turbine bypass system (Section 10.4.4) .
- 5. The turbine-generator shall be capable of increasing or decreasing electrical load at a rate consistent with the 10.2-1 Amendment 8 3/28/75
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SWESSAR-P1 requirements which the NSSS Vendor imposes on the turbine (Section 7.7) .
- 6. The turbine-generator shall be built in accordance with the turbine manufacturer's standards and the industry codes that most closely approximate the conditions of turbine-generator applications.
- 7. The moisture separator / reheaters shall be designed and fabricated in accordance with Section VIII of the ASME Boiler and Pressure Vessel Code.
- 8. Generator rating, temperature rise, and insulation class shall be in accordance with the latest ANSI Standards.
10.2.2 Description 10.2.2.1 Turbine Steam System The turbine is an 1,800 rpm, tandem compound, 6-flow, steam reheat machine with 43 in. (General Electric) or 44 in. (Westinghouse) last stage blades. The turbine consists of one double-flow high pressure cylinder and three double-flow low pressure cylinders. Steam from the main steam system, flowing through four main steam lines, passes through the turbine stop and control valves and into the high pressure turbine. Steam leaving the high pressure turbine passes through the moisture separator reheaters to the inlets of the low pressure turbines. Each of the steam lines between the reheater outlets and low pressure turbine inlets is provided with combined intercept and stop valves. The moisture separator / reheaters are located on the operating floor on both sides of the turbine. Steam from the main steam manifold heats the exhaust steam from the high pressure turbine, while chevron type baffles remove moisture from the exhaust steam. Each moisture separator / reheater has a single stage of reheat. The moisture separators are provided with relief valves u which discharge to the atmosphere. The exhaust from the three low pressure turbines passes to the condenser where it is condensed by the circulating water system (Section 10.4.5) . Turbine extra ction steam, used for feedwater heating, is taken f rom six extraction points (see Fig . 10.1-1) : one on the high pressure turbine casing, one from the exhaust of the high pressure turbine, and four from the low pressure turbine casing. Six stages of closed feedwater heaters are provided (Scction 10. 4. 7) . Motor operated block valves and power assisted nonreturn valves in the extraction piping protect against the possibility of turbine water induction or overspeed due to energy stored in the extraction steam system. 10.2-2 Amend ment 12 6/16/75
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SWESSAR-P1 10.2.2.2 Turbine Control System The turbine control system is capable of remote manual or automatic starting and loading of the unit at a preset rate, and holding speed and load at a preset level. The system contains valve positioning, operating, and tripping devices with provisions for testing valve operation. Typical turbine control systems provided by the turbine manuf acturers are discussed in the following sections. 8 10 9 2.2A Turbine Control System for Genera.1 Electric Turbine The turbine control system is of the electr ohydraulic control (EHC) type and is organized into three major units to minimize interactions. A speed control unit compares actual turbine speed with the speed reference, or actual acceleration with the acceleration reference, and provides one speed error signal for the load control unit. The load control unit combines the speed e rror signal with the load reference signal, and provides limits and biases to determine desired steam flow signals for the turbine stop valves, turbine control valves, and intercept valves. Finally, the valve flow control units accurately position the appropriate valves to obtain the desired steam flc vs to the turbine. Turbine-Generator Overspeed Protection Control System Modern EHC controls incorporate the experience gained over a period of 10 years on 140 turbines using EHC control. It is a highly reliable system, employing three electrical and one mechanical speed inputs. Logic signals are redundantly processed in both electronic and hydraulic channels. Valve opening actuation is provided by a 1,600 psig hydraulic system which is totally independent of the bearing lubrication system. Valve closing actuation is provided by springs and aided by steam forces upon the reduction or relief of fluid pressure. The system is designed so that loss of hydraulic fluid pressure for any reason leads to valve closing and consequent shutdown (f ail safe). The main steam valves are provided in series arrangements: a group of stop valves actuated by either of two overspeed trip signals, followed by a group of controlling valves modulated by the speed governing system, and tripped by either overspeed trip signal. The intermediate valves are arranged in serie s-pairs , an intermediate stop valve and intercept valve in one casing. The closure of either one of the two valves closes off the corresponding steam line. 9 10,2-3 Imendment 8
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g 3/28/75 b< v o o
SWESSAR-P1 A single failure of any component will not lead to destructive overspeed. A multiple failure, involving combinations of undetected electronic faults and/or mechanically stuck valves and/or hydraulic fluid contamination at the instant of load loss, would be required. The probability of such joint occurrences is extremely low, due to both the inherently high reliability of the design of the components and frecuent inservice testing. A. Speed Seny_ing The EHC system provides three independent levels of speed sensing. All three are normally in operation. A minimum of two are in operation during the short period used to test the overspeed trip devices.
- 1. The operating speed signal is obtained from two magnetic pickups on a toothed wheel at the high pressure turbine shaft. Increase of either of the speed signals tends to close control and intercept valves. Loss of one of the speed signals transfers control to the other speed signal. Loss of both speed signals trips the emergency trip system through two redundant trip signals. The operation of both speed signals is continuously monitored by the alarm system.
- 2. The mechanical overspeed trip uses an unbalanced rotating ring and a stationary trip finger operating a trip valve to dump the emergency trip fluid system pressure directly upon reaching its set speed, typically 110 to 111 percent of rated speed. All stop and control valves and intermediate valves are tripped.
The operation of the overspeed trip mechanism and the mechanical trip valve can be tested during normal operation. A test interval of once per week is recommended.
- 3. The electrical backup overspeed trip trips the emergency trip fluid system pressure, through two redundant trip signals, upon reaching its trip speed.
The operation of the backup overspeed trip and the electrically operated master trip solenoid valves can be tested during normal operation. A test interval of once per week is recommended. B. Steam Flow Controllina Valves The Genera 2 Electric turbine control system provides two independent valve groups for defense against overspeed in each admission line to the turbine. The normal speed control system closes one on moderate overspeed, and the emergency trip system closes both upon a higher overspeed or other trip signals. O 10.2-4 Amendment 8 3/28/75
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SWESSAR-P1 All valves are testable during operation. The fast closing feature of any valve is fully operative while the valves are being tested. Main Steam Inlets Steam from the turbine steam system is admitted to the high pressure turbine through four main stop valves, followed by a manifold, followed by four main control valves. followed by four un-manifolded main steam inlets. The manifold ahead of the control valves permits inservice testing of the stop valves with little effect on load. Daily testing of each stop valve is recommended. The control valves can be individually tested in service at the expense of shedding up to about 15 percent of maximum load. A testing interval not exceeding one week is recommended. The control valves are normally controlled by the redundant speed control system. In their emergency operating mode, the valves are rapidly tripped closed when fluid pressure is dumped by the fast acting solenoid valves upon power / load imbalance actuation or by either of two redundant trip valves. Both the normal operating and fast closing devices are tested while under load. The main stop valves are normally held open by pressure in the emergency trip system (ETS). They are rapidly tripped closed by dumping the ETS pressure. Stop valves of the stem sealed design have been used on large General Electric steam turbines since 1948. There have been over 700 turbines shipped and put in service during this period, and there has been no report of the stop valves failing to close when required to protect the turbine. Impending sticking has been disclosed by means of the daily full closed test, so that a shutdown can be made to make the necessary correction. Such incipient problems have been found only on high temperature fossil fueled units and have been due to the accumulation of an oxide layer in the stem and bushing. Oxidation is not expected at the relatively low temperatures of water cooled nuclear reactor applications. General Electric has 12eard of two f ailures of nuclear turbine stop valves to close. Both were repc d to have occurred on a unit not of General Electric manuf acture, and were reputed to have been due to silica buildup betwe'n the stems and bushings. General Electric believes that their stop valves are not subject to such failure, because the stem sealed design precludes the transport of steam carried hupurities back along the stem. At the present writing General Electric has accumulated about 300 valve-years of service on nuclear turbine stop valves and knows of no failure to close. Calculated failure rates are based on these statistics. Nuclear turbine control valves are similar in construction to the highly developed designs used in fossil fuel anplications. 10.2-5 Amendment 8 7 ,g , ~ , 3/28/75 Uvv v- V
PWESSAR-P1 Because the operating temperature is lower, they should be significantly freer of temperature related problems, such as sticking caused by stem thermal distortion or oxidation. At the present writing General Electric has accumulated over 450 valve years of r.aclear turbine control valve service. One failure to completely close has been reported. That valve, of a design no longer used, employed a bolted down removable seat. A small piece of seat locking hardware came loose and lodged between the seat and disc, preventing closure by about 1/8 inch. The calculated failure rates used in the present study consider this failure, treating it as a complete failure in the open position. Combined Intermediate Stop and Intercept Valves Modern nuclear turbine cycles employ either moisture separators or moisture separator-reheaters, at 150 to 250 psia, between the high and low pressure turbine sections. The energy storage in these devices and the associated piping are sufficient to accelerate a nuclear turbine generator to higher than normal, but not catastrophic overspeed on loss of full load. Two combined intermediate valves are provided at the inlet of each low pressure casing to prevent such overspeed. Each valve contains two independently operated valve discs in series, one called an intercept valve, and the other called an intermediate stop valve. The intercept valves are normally wide open but are closed by the speed control system upon a moderate speed increase. Th ey are tripped closed rapidly upon removal of the ETS pressure. The intermediate stop valves are normally open but are tripped closed rapidly upon removal of the ETS pressure. Both valves are of the stem sealed design with its attendant reliability advantage. Loth valves, including their rapid closure devices, can be tested during normal operation with minor load perturbation. Daily testing is recommended. Special field tests are made of new components, both to obtain design information and to confirm proper operation. Such special tests include the confirmation of the capability of controls to prevent excessive overspeed on loss of load. Design procedures take into account the effect of extra overspeed potentici reulting from water in contact with hot metal flashing into steam. The described design, inspection, and testing features substantially reduce the probability of destructive overspeed as a possible cause of failure in modern design units. The regular testing of all testable devices and circuits during operation in 10.2-6 Amendment 8 3/28/75 '
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SWESSAR-F1 accordance with instruction book recommendations increases the reliability of the protection system by several orders of magnitude. 10.2.2.2B Turbine Control System for Westinghouse Turbine a The turbine control system is a digital electrohydraulic CNLH) control system and includes a digital computer, an analog backu1-system, electronic servo hardware, and hydraulic valve actuators. During automatic operation, the computer sends output signals to the servo system to position the valve actuators, which, in turn, admit steam to the turbine and thus control turbine speed and/or load. During computer maintenance, an analoa backup system maintains valve position and provides simple raise and lower a ction . The computer and analog systems continuously track each other, allowing smooth transfer from one mode to the other. Emergency Trip System and Overspeed Protection A. Emergency Trip System I The emergency trip system provides a means of protection against B various contingencies which micht cause damage to the unit were it not immediately taken out of service. Electrohydraulic in design, the system offers: p* Complete redundancy of all trip functions Complete on-line testability without causing or preventing a trip Provisions for detection and diagnosis of failed device Provisions for inservice maintenance Fail safe design Pertinent turbine parameters arc continuously monitored. If they exceed the limits of safe turbine operation, the unit shuts down. All steam valves close upon the occurrence of the following: Turbine overspeed Excessive thrust bearing wear Low bearing oil pressure low condenser vacuam Low EH fluid pressure A remote trip is also provided. The system consists of an emergency trip block and three test blocks mounted on the governor pedestal, a cabinet containing all electrical and electronic hardware, and a remote mounted trip test panel. 10.2-7 Amendment 8 3/28/75 t/o ri bVO Uva
SWESSAR-P1 I Trip Block The emergency trip block contains four normally energized solenoid valves divided into two channels. When a contingency occurs, both channels are deenergized causing the turbine to trip. Only one valve per channel is necessary to trip. When testing, only one channel is deenergized at a time. This will not cause or prevent a trip since the other channel is still functional. Two additional solenoid valves associated with the overspeed protection controller circuitry are also contained in this block. Test Blocks The test blocks, similar in nature, provide the means of monitoring bearing oil pressure, Ell fluid pressure, and condenser vacuum. Low bearing oil pressure is discussed in detail. Four pressure switches monitor bearing oil pressure with two associated with each trip channel. If at least one from each channel functions on low bearing oil pressure, contacts open dropping out relay trains in the trip cabinet which deenergize the trip solenoid valves and therefore trip the turbine. Test valves and gages for locally and remotely testing each function are included in these blocks. I Trip Cabinet The trip cabinet contains all power supplies, relays, and additional hardware associated with the trip system. It also contains the electronics for the electrical overspeed trip channel. All purchaser connections are made to terminal strips in this cabinet. Test Panel The test panel cantains all the lights, pushbuttons, and selector switches to tes c both channels of each trip function remotely. Testing is accomplished by actually changing the pressure read by each channel of the pressure trip function, by moving the position of the pickups used in sensing thrust bearing wear, or by injecting an overspeed signal into the electrical overspeed channel. Interlocks are provided to prevent testing one channel when the other channel is down. Lights on the panels indicate when a channel has tripped. Additional lights are available for monitoring all pressure switches, power supplies as well as the trip channels. Summary of Trip Punctions Low bearing oil, low vacuum, low EH fluid are monitored by pressure switches in test blocks on the governor pedestal. Two pickup coils monitor the position of the thrust bearing collar. 10.2-8 Amendment 1
,/30/74 7 -
L d L V I
/
SWESSAR-P1 Excessive movement in either the governor end or generator end trips the unit. Overspeed protection is provided by independent mechanical and electrical channels. If the turbine speed reaches the trip setpoint (standardly 111 percent) , a spring loaded bolt located in a transverse hole in the turbine shaft flys out, dumping the autostop oil which unseats a diaphragm valve, dumping the EH fluid. The electrical overspeed channel picks up a relay which deenergizes all solenoid valves in the trip block. The occurrence of either closes all steam valves, tripping the turbine well before design speed is reached. Purchaser remote trip can be provided with an option for on-line testing. B. Overspeed Protection Overspeed protection redundancy is provided in the design of the < steam valves and sensing circuitry. l Valve Design Main Inlet ! l1 Redundancy is accomplished by providing separate throttle and j governor valves. i Reheat Inlet Separate reheat stop and interceptor valves provide redundancy in the valving between the moisture separator reheater and the low pressure turbine. Speed Sensing Three electromagnetic speed sensors are located in the governor pedestal and one is located in the turning gear pedestal. The following sensors are provided: Mechanical Overspeed Trip Weight i This is a spring loaded bolt located in a radial drilling of ! the turbine stub shaft (governor pedestal) . The center of ' gravity of the bolt is outside of the shaft center. Electromagnetic Speed Pickups One pickup is provided as a feedback for the main speed control channel. A speed reference (setpoint) is compared against the feedback. The governor valves are closed if the feedback has a higher value than the reference. 10.2-9 0bu uv' Amendment 1 7/30/74
SWESSAR-P1 1 A second pickup feeds the overspeed protection controller (OPC) . The OPC speed channel can be substituted for the main speed channel if a digital electrohydraulic (DEH) system is furnished. A third speed pickup is used by the turbine supervisory instruments (TSI) for speed indi ating and recording. The TSI speed signal is used for speed signal comparison on DEII systems. A fourth speed pickup is used in the electrical overspeed trip device. This pickup is located in the turning gear pedestal to provice physical separation from other speed sensing devices. There are additional pickups which are not relevant for overspeed protection. They are used for phase angle indications and spares. Overspeed Protection Ilierarchy Main Speed Control Loop When the circuit breaker opens, the main speed control loop calls for rate ' speed. Thus, when the uait exceeds rated speed, the governor valves move to the closed position. Overspeed Protection Controller (Breaker Status) If the unit carries more than 30 percent load and the main breaker opens, the governor and interceptor valves close rapidly. Speed is maintained below the overspeed trip point. The interceptor valves are oscillated between closed and partially open until the reheater steam is dis-ipated. Thereaf ter, the governor valves take over speed contr ol and maintain household at rated speed if the control system is in automatic. The turbine venerator coasts down to turning gear operation if the system is in manual. Overspeed Protection Controller (103 Percent Speed Setpoint) The governor and interceptor valves are closed rapidly when the unit exceeds 103 percent of rated speed. Thereafter the valves function as described above. Mechanical Overspeed Trip Weight If the speed reaches the setpoint of the trip weight (standardly 111 percent of rated speed), all steam valves are tripped (throttle , governor reheat stop, and interceptor valves) . Speed is maintained below 120 percent of rated speed. The unit coasts down to turning gear operation. 10.2-10 Amendment 1 7/30/74
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SWESSAR-P1 Electrical Overspeed Trip The electrical ove; speed trip channel is independent of the control system and uses a pickup in the turning gear pedestal. When the speed reaches the trip point (standardly 111 percent of rated speed) , all steam valves are tripped by energizing trip solenoids in the EH fluid lines. Speed is ; nuintained below 120 percent of rated speed. The unit coasts down to turning gear operation. 10.2.2.3 Lubricating Oil System The lubricating oil system supplies the lubrication needs of the turbine-generator. A bypass stream of lubricating oil flows continuously through an oil conditioning circuit. The lubricating oil system is described in Section 10.4.13. 10.2.2.4 Turbine Gland Sealing Syster. The turbine gland sealing system seals the turbine rotor between the turbine casings or the exhaust hood and the atmosphere, thus preventing leakage of air into the condenser and leakage of steam from the turbine into the turbine building. The turbine gland sealing system is described in Section 10.4.3. 10.2.2.5 Generator The generator is sized to accept the output of the turbine. The generator is equipped with an excitation system, hydrogen control system, and a seal oil system. The generator terminals are connected to the main step-up transformer and unit station service transformers with generator isolated phase bus Jeads. The generator excitation system controls the vol nge of the generator. The hydrogen control system includes pressure regulators, control for the hydrogen gas, and a circuit to supply and control the CO2 used during filling and purging operati r ns . A hydrogen seal oil system prevents hydrogen leakage through the generator shaft seals. This system includes pumps, controls, and a storage tank, and degasifies t he oil before it is returned to the shaft seals. 10.2.2.6 Generator Hydrogen A bulk hydrogen storage facility in the yard provides hydrogen for generator cooling. An automatic pressure reducing transfer station, located outside near the bulk storage area, reduces the normally high hydrogen storage pressure to a lower hydroger distribution system pressure. Local pressure reducing stations are provided where necessary to reduce the distribution system pressure to the pressure required by the serviced equipment. 10.2-11 Amendment 1
,f g p' 7/30/74 Ovd Uv'r
SWESSAR-P1 Since the hydrogen supply is outdoors, an explosive mixture of hydrogen and oxygen cannot be formed by hydrogen leakage because of atmospheric dilution. The distribution system is of welded construction and is leak tested prior to being placed in service. The designs of the generator and the generator cooling system and operating procedures are such that explosive mixtures are not possible under ope rating or maintenance conditions, including filling and purging the generator. Purging operations will be closely supervised by responsible personnel familiar with the correct procedures. The gene.ator is vented to the atmosphere and hydrogen is displaced under pressure 9l by CO2 for the CO2 storage tank in the turbine building to ensure that there is no mixing of hydrogen and air. The generator hydrogen system provides for purging and filling the generator housing, maintains the gases used in a moisture-free condition, and within predetermined limits of purity, pressure, and t emperature , and gives warning of improper operation of the gen erator . As indicated above, fires and explosions attributable to hydrogen are unlikely because of monitoring of the generator hydrogen system, reliable operating procedures, and location of the bulk s torage f acilities. In addition, the fire protection system (Section 9 . 5 .1) provides backup to mitigate the effects of fire. 10.2.3 Turbine Missiles An evaluation of postulated turbine missiles, in addi tion to discussing plant design as it pertains to protection of safety rel ated items from the ef fects of turbine missiles, must take into consideration the probabilities of occurrence both of the generation of missiles and of the ef fects attributed to them. Probability of Significant Damage (P4) The probability of significant damage to plant st ru cture s , systems, and components (P4), where such damage could cause significant radiological cons equences , is the product of three contributing factors : P4 = P1 x P2 x P3 where: P1 = the probability of generation and ejection of a high energy missile P2 = the probability that a missile strikes a critical plant region, given its generation and ejection O 10.2-12 Nnendment 9 efo Oua "f/30/75
SWESSAR-P1 P3 = the probability that the missile strike damages its target in a manner leading to unacceptable consequences Probability of Generation and Eiection CP1) A turbine missile can be caused by brittle fracture of a rotating turbine part at or near turbine operating speed, or by ductile fracture upon runaway af ter extensive, highly improbable; control system failures. The calculation of this probability (P 1) is the responsibility of the turbine manufacturer. For the purposes of P4 calculations, P1 was assumed to apply to the turbine disc for which the highest value of P2 would result. Probability of Missile Strike (P2) The probability of a strike on a critical plant region (P2) is a function of the energy and direction of an ejected missile and of the orientation of the turbine with respect to the critical plant regions. The arrangement of the PWR Reference Plant is such that the planes of rotation of the turbine discs do not intersect any safety related structures, systems, or components,thus minimizing the probability of significant adverse affects resulting from a 5 turbine missile. The orientation of the turbine is shown on the plot plan, Fig. 1.2-1. Values of P2 have been calculated using a solid angle approach. The turbine spins about the z-axis of the reference system shown in Fig. 10.2-2. Based on data provided by the turbine manufacturer, a postulated missile is thrown f rom the turbine with initial velocity Vc as shown. The variable angles required to describe the resulting motion are displayed in Fig. 10.2-2. Deflection anglesS j and 6 , provided by the turbine vendor 2 limit O to the range:
- 63 s05h+6 2 The probability that a single disc fragment strikes a critical area A g is defined as:
=
P (A, ) f(G) dQ (1) where, G, is the solid angle which must be subtended by the initial velocity vector for a missile to str4ke A . dQ is the differential solid angle, and f(g) is the probability density function. 10.2-13 Amendment 5 12/2/74 itn nr OvV UVd
SWESSAR-1-1 From Fig. 10.2-2, oil = cos @ d& d@ (2) Given Vo, the elevation angle c necessary to hit any point on A n (cescribed by r, y, and4 in Fig. 10.2.2) is deterir.ined from classical trajectory theory us: 1 i 2 1 - (rg/v o)2 2
- 2 (yg/v ,) 4 c
& = tan ~3 -
(3) (rg/v2) In Eg f 3) , air resistance is neglected and the i refers to high und low trajectory missiles respectively. The probability density function 1 (n) is determined by assuming: 1(n) = constant = fg for Os S 5 211and 11/2 - 6, , s0$ H /2 + 62 1(n) = o , tor all other e, From probubility theory it is required that f (0) dG = 1 all G Therefore, = 3 f, 2H (sin 6 1 + sin 6 2) The probability that n disc tragments strike a critical area A is then l 8 P2 (A,) = 2H (sin + sin 6 2 3 0, (4) l A computer program has been developed to calculate the strike 8\ probability using Eq (.t ) . Following Bush (1), the analysis considers high trujectory hits on the tops of all critical targets and low trajectory hits on the sides of all critical targets. Fig. 10.2-3 and 10.2-4 represent the top and side views of an iaealized target. The strike probability of the target is rounu hy numerically integrating Eq (4) , which gives ng P (cos Qg) ( A&f )o t
, 2
- 2H (sin 6 1
+ sin 6I 2 1=1 for H/2 - 6 3 s0 1 s H/2 + 6 2 10.2-14 Amendment 8 3/28/75 rr (c) V4 ()n bdI
SWESSAR-P1 and P2 = 0 0sOg < H/2 - 6 g , H/2 + 6 2<Og 5H
- where, O
i"C 8" (C 3 *i Cos $i) and n = number of ground angle increments taken Y through the target. From Fig. 10.2-3 and 10.2-4, _
- max ~
- min Q.1 = & min + (i - b) A$
A&i = l&h-& l
$i =b(&k+,&h) 1 Eg (3) is used to determine & 1.2* The low and high trajectory probabilities are calculated separately and added to obtain the final probability.
Probability of Damace (P3) The probability (P3) is a function of the energy of the missile, its angle of impact upon the af fected structure, and the energy and direction of the missile after penetration of the structure. The following criteria suggested by Bush (1) were used. l9 t > 6' , P3 = 0. cos2 And if a >450 , P3 = 0. where, t = thickness of reinforced concrete between the turbine and a critical component, and a = the incidence angle (angle between the normal to the concrete and the impact velocity vector) . Otherwise , P3 = 1. 10.2-15 Amendment 9 4/30/75 tn rr ' 1vV VuU
SWESSAR-P1 Overall Probability Calculation Turbine missile information provided by the turbine manufacturers is listed in Table 10.2-1(21(3)(*). With :.nis data as a basis, the strike probability (P2) was calculated for one of the units shown in Fig. 1.2-1 and tabulated in Table 10.2-2. The overall probability of turbine missile damage (P4) for a single unit is calculated in Table 10.2-3. Probability of turbine missile damage was also calculated for a two unit site, with strike probability given in Table 10.2-4 and overall probability given in Table 10.2-5. For the two unit site shown in Fig. 1.2-1, turbine A corresponds to Unit 1 and turbine B corresponds to Unit 2. Strike probabilities in Tables 10.2-2 and 10.2-4 are given only for those areas where P3 = 1.0. Turbine-target distances and effective impa ct areas for a two-unit site are given in Table 10.2-6. The Utility-Applicant's SAR will indicate whether the single unit or the two-unit site calculations are applicable. In addition, if more than two units are provided at one site, the additional probabilities will be provided in the Utility-Applicant's SAR. Based on the values given in Tables 10.2-3 and 10.2-5, the probability (P4) of significant damage to critical plant regions due to a postulated turbine failure is sufficiently low that design of the plant against turbine missile ef fects need not be considered. 10.2.4 Design Evaluation Primary protection of the main generator is provided by differential current and field failure relays. Protective relays automatically trip the turbine stop valves and electrically isolate the generator. The turbine generator is protected against destructive overspeed by redundant speed control systems during normal and transient conditions. If the primary system fails, either a mechanical overspeed or a backup overspeed system trips the turbine-generator. To ensure system reliability, requirements will be imposed on the turbine manuf acturer to design the overspeed protection systems and to provide installation instructions thereof to ensure that these systems remain operable under the most severe environmental 23 conditions for which the turbi nc building is designed. In addition, requirements will be impesed to ensure complete on-line testability of both the mechanical and electrical overspeed trip systems. Connections between the turbine and the reactor protection system and between the engineered safety features actuation system (ESFAS) and the turbine trip system shall be redundant, physically independent, and separated and designed to 10.2-16 Amendment 23 3/31/76 f fG f' } h d UV e
SWESSAR-P1 withstand a single failure. To ensure turbine trip and to minimize blowdown following a main steam line break, the turbine stop valves, the reheat valvea, and turbine bypass valves will U receive redundant steam line isolation (SLI) signals from the ESFAS. The turbine-generator and related steam handling equipment systems are radioactively contaminated only when there is a steam generator tube rupture resulting in leakage of reaccor coolant from the primary to the secondary side of a steam generator. Shielding of the turbine generator systems is not required because the activity level during operation is minimal and well within safe limits. The equilibrium concentrations of various isotopes in the turbine steam system are essentially the same as the equilibrium concentrations in the main steam system. These concentrations are tabulated in Tables 11.1.3-1 and 11.1.3-2. The design of the reinforced concrete pedestal supporting the main generator minimizes pockets on the underside in which escaped hydrogen could collect. The potential for an explosion is considered nil, since there is no high pressure gas within the building and the ventilation system prevents accumulation of any minor leakage that may occur. 10.2.5 Testing and Inspections To ensure proper operation, the turbine stop and control valves and the combined stop and intercept valves are exercised periodically to detect valve stem sticking. During this procedure, the valves are partially closed and then reopened. Tests to ensure operability of the overspeed trip ' system are performed periodically while under 2oad. Special test provisions prevent tripping of the plant during these tests. References for Section 10.2
- 1. Bush, S.H., " Probability of Damage to Nuclear Components Due to Turbine Failures," Nuclear Safety, Vol. 14, No. 3, May-June 1973.
- 2. General Electric Company, Memo Report - Hypothetical Turbine Missiles - Probability of Occurrence, 3/14/73.
- 3. Westinghouse Electric Corp., Analysis of the Probability of the Generation and Strike of Missiles from a Nuclear Turbine, March 1974.
Amendment 23 10.2-17 ' 3/31/76
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SWESSAR-P1 TABLE 10.2-1 VENDOR PROVIDED TURBINE IhTORMATION g Westinchouse Annual Average Probability of Failure, P1 1.4E-8 1.7E-6 Deflection Angles End disc: 0, 25 25 (degrees) 0 0 0 2 Interior disc: 0; 5 5 (degrees) 0 5 5 2 Low Overspeed Condition 8 Percent of normal running speed 120 120 Exit velocity, % (fps) 300 300 Number of fragments, n 4 4 , Fragment size (degrees) 90 90 High Overspeed Condition Percent of normal running speed 180 180 Exit velocity, V o (fps) 600 600 Number of fragments, n 3 3 Fragment size (degrees) 120 120 1 of 1 Amendment 8 3/28/75
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SWESSAR-P1 TABLE 10.2-2 STRIKE PROBABILITY (P2) FOR A SINGLE UNIT TURBINE MANUFACTURER - GENERAL ELIrTRIC, WESTINGHOUSE NSSS Vendor - Babcock & Wilcor, Ccunbustion Enqineering, and Westinghouse (3S) i) Vo = 300 FPS Vo = 600 PTS Unit- Iow High low liigh critical Plant Region Turbine Tra iect ory Traiectory. htal Trajectory Trajectory htal Containment Structure 1-A 0.0000E 00 0.1243E-02 0.1243E-02 0.0000E 00 0.5589E-04 0.5589E-04 Control Building 1-A 0.0000E 00 0.3313E-02 0.3313E-02 0.0000E 00 0.1535E-03 0.1535E-03 Diesel Generator Building 1-A 0.0000E 00 0.6300E-03 0.6300E-03 0.0000E 00 0.4814E-04 0.4814E-04 Fuel Oil Storage Tanks & 1-A 0.0000E 00 0.2274 E-0 3 0.2274E-03 0.0000E 00 0. 2537E-04 0.2537E-04 Pump House Fuel Storage Area 1-A 0.0000E 00 0.9818E-03 0.9818E-03 0.0000E 00 0.4559E-04 0.4559E-04 Auxiliary Feedwater Storage 1-A 0.0000E 00 0.118 2E-0 3 0.1182E-03 0.0000E 00 0. 5331 E-0 5 0.5331E-05 Tank h tal Strike Probability, P2 0.0000E 00 0.6514E-02 0.6514E-02 0.0000E 00 0.3338E-03 0.3338E-03 NSSS Vendor - Westinqhouse (41) 17 Containmes.t Structure 1-A 0.0000E 09 0.12 4 3E-02 0.1243E-02 0.0000E 00 0.5589E-04 0.5589E-04 Control Building 1-A 0.0000E 00 0. 3 313E-0 2 0.3313E-02 0.0000E 00 0. 's 5 3 5E-0 3 0.1535E-03 Diesel G nerator Building 1-A 0.0000E 00 0.9416E-03 0.9416E-03 0.0000E 00 0.7221E-04 0.7221E-04 Fuel 011 Storage Tanks & 1-A 0.0000E 00 0.3382E-03 0.3382E-03 0.0000E 00 0.3774E-04 0.3774E-04 Pump House Fuel Storage Area 1-A 0.0000E 00 0.9818E-0 3 0.9818E-03 0.0000E 00 0.4559E-04 0.4559E-04 s A Auxiliary Feedwater Storage 1-A 0.0000E 00 0.1182E-03 0.1182E-03 0.0000E 00 0.5331E-05 0.5331E-05 C.s Tank htal Strike Probability, P2 0.0000E 00 0.6936L-02 0.6936E-02 0.0000E 00 0.3702E-03 0.3702E-03 c) ~ Pa 1 of 1 Amendment 17 9/30/75
SWESSAR-P1 TABLE 10.2-3 OVERALL PROBABILITY (P4) FOR A SINGLE UNIT NSSS Vendor - Babcxx-k & Wilcox, Combustion Engineerinci, and Westinghouse (3S) i; Turbine Manufacturers M P22 P3 P4 = P1xP2xP_3 3 V, = 300 fps 1.4E-8 6.514E-3 1.0 9.120E-11 Vo = 600 fps 1.4E-8 3.338E-4 1.0 4.673E-12 Westinghouse Vo = 300 fps 1.7E-6 6.514E-3 1.0 1.107E-08 V o = 600 fps 1.7E-6 3 . 3 3 9 E-4 1.0 5.675E-10 tESS Vendor - hestinqhouse (41) 17 s Vo = 300 fps 1.4E-8 6.936E-3 1.0 9.710E-11 Vo = 600 tps 1.4E-8 3.702E-4 1.0 5.183E-12 Westinghouse Vo = 300 fps 1.7E-6 6.936E-3 1.0 1.179E-08 Vo = 600 fps 1.7E-6 3.702E-4 1.0 6.293E-10 c.x C'] s > L -J 1 of 1 Amendment 17 9/30/75
SWESSAR-P1 YABLE 10.2-4 STRIKE PROBABILITY (P2) POR A TWO-UNIT SITE WRBINE MANUFACTURER - GENERAL ELECTRIC, WESTINGHOUSE NSSS Vendor - Babcock S. Wilcor, Ctubustion Engineerinq, and Westinghouse (3S) l0 Vo = 300 FPS Vo = 600 FPS Unit- Iow High Low Hig') Critical Plant Region Turbine Tra iactory Traiectory Tbtal Trajectory Tra jectory Total Containment Structure 1-A* 0.0000E 00 0.2487E-02 0.2487E-02 0.0000E 00 0.1118E-03 0.11180-03 control Building 1-A* 0.0000E 00 0.6626E-02 0.6626E-02 0.0000E OC 0.3069E 43 0.3069E-03 Diesel Generator Building 1-A* 0.0000E 00 0.1260E-02 0.1260E-02 0.0000E 00 0.9629E-04 0.9629E-04 Fuel Oil Storage Tanks & Purp House 1-A* 0.0000E 00 0.4548E-03 0.4548E-03 0.0000E 00 0. 5 074 E-0 4 0.5074E-04 Fuel Storage Area 1-A* 0.0000E 00 0.1964E-02 0.1964E-02 0.0000E 00 0.9118E-04 0. 9118 E-0 4 Auxiliary Feedwater Storage Tank 1-A* 0.0000E 00 0.2364E-03 0.2364E-03 0.0000E 00 0.1066E-04 0.1066E-04 Contairunent Structure ** 1-B 0.9348E-02 0.1286E-02 0.1063"-01 0.5618E-02 0.55HE-04 0.5674E-02 {p Control Building 1-B 0.1633E-02 0. 3 5 01E-0 2 0.5134E-02 0.1211E-02 0.1539E-03 0.1365E-02 Diesel Generator Building 1-B 0.0000E 00 0.6168E-03 0.6168E-03 0.0000E 00 0.4831E-04 0.4831E-04 Fuel Oil Storage Tanks & Punp House 1-B 0.0000E 00 0.2409E-03 0.2409E-03 0.0000E 00 0.2545E-04 0.2545E-04 Fuel Storage Area 1-B 0.0000E 00 0.1002E-02 0.1002E-02 0.0000E 00 0.4568E-04 0.4568E-04 Auxiliary Feedwater Storage Talak 1-B 0.0000E 00 0.1182E-03 0.1182E-03 0.0000E 00 0.5331E-05 0.5331E-05 Containment Structure ** 2-A 0.93'8E-02 0.1286E-02 0.1063E-01 0. 5618 E-02 0. 5 59 9 E-04 0.5674E-02 lU Control Building 2-A 0.0000E 00 0.3338E-02 0.3338E-02 0.0000E 00 0.1535E-03 0.1535E-03 Diesel Generator Building 2-A 0.0000E 00 0.6272E-03 0 . 6272 E -03 0.0000E 00 0 . 4 817E-0 4 0.481/E-04 ' Fuel Oil Storage Tanks & Punp House 2-A 0.0000E 00 0.2292E-03 0.2292E-03 0.0000E 00 0.2538E-04 0.2538E-04 Fuel Storage Area 2-A 0.0000E 00 0.1026E-02 0.1026E-02 0.0000E 00 0.4577E-04 0.4577E-04 Auxiliary Feedwater Storage Tank 2-A 0.0000E 00 0.1207E-0 3 0.1207E-03 0.0000E 00 0.5333E-05 0.5333E-05 Total Strike Probability, P2 0.2033E-01 0.2642E-01 0.4675E-01 0.1245E-01 0.1336E-02 0.1378E-01
- Probability multiplied by 2 to account for a missile strike on unit 2 from turbine B as well as on unit 1 f rom turbine A.
1
** 'Ihe conservative assumption was made that the Westinghouse (3S) containment structure n is the same height as that for B&W and C-E. i
-w " TN
- D CD
, 1 of 2 Amendment 17 9/30/75
SWESSAR-P1 TABLE 10.2-4 (CONT) NSSS Vendor - Westinghouse (41) Vo = 300 FPS Vo = 600 FPS Unit- low High Low High Critical Plant Feqion Turbine Tra iect ory Traiect ory Total Tra iect o ry Tra je ctory Total Containment Structure 1-A* 0.0000E 00 0.2487E-02 0.2487E-02 0.0000E 00 0.1118E-03 0 .1118 E-0 3 Control Building 1-A* 0.0000E 00 0.6626E-02 0.66 26E -0 2 0.0000E 00 0.3069E-03 0.3009E-03 Diesel Generator Building 1-A* 0.0000E 00 0.1883E-02 0.18 8 3 E-02 0.0000E 00 0.1444E-03 0.1444E-03 Fuel Oil Storage Tanks & Pump House 1-A* 0.0000E 00 0. 6764 E-0 3 0.6764E-03 0.0;00E 00 0.7549E-04 0.7549E-04 Puel Storage Area 1-A* 0.0000E 00 0.1964E-02 0.19 64 E-0 2 0.0000E 00 0.9118E-04 0.9118E-04 Auxiliary Peedwater Storage Tank 1 -A* 0.0000E 00 0.2364E-03 0.2364E-03 0.0000E 00 0.1066E-04 0.106bE-04 Containment Structure 1-D 0.9 34 8 E -0 2 0.1286E-02 0.1063E-01 0.5618E-02 0.5599E-04 0.5674E-02 Control Building 1-B 0.1633E-02 0.3501E-02 0.5134E-02 0.1211E-02 0.1539E-03 0.1365E-02 Diesel Generator building 1-B 0.0000E 00 0. 9219 E-0 3 0.9219E-03 0.0000E 00 0.7245E-04 0.7245E-04 Etel Oil Storage Tanks & Pump House 1-B 0.0000E 00 0. 3 57 9E-0 3 0 . 3579 E-0 3 0.0000E 00 0. 3 78 7E-0 4 0.37?'E-04 Puel Storage Area 1-B 0.0000E 00 0.1002E-02 0.10 02 E-0 2 0.0000E 00 0.4568E-04 0.4568E-04 Auxiliary Feedwater Storage Tank 1-B 0.0000E 00 0.1182E-03 0.1182E-03 0.0000E 00 0.5331E-05 0.5331E-05 Containment Structure 2-A 0.9348E-02 0.12 8 6E-0 2 0.1063E-01 0.5618E-02 0. 5 59 9 E -0 4 0.5674E-02 Control building 2-A 0.0000E 00 0.3338E-02 0.3338E-02 0.0000E 00 0.1535E-03 0.1535E-03 Diesel Generator Building 2-A 0.0000E 00 0.9476E-03 G.9476E-03 0.0000E 00 0.722SE-04 0. 7 2 2 5E -0 4 Puel Oil Storage Tanks & Pump House 2-A 0.0000E 00 0.3404E-03 0. 3 4 04 E-0 3 0.0000E 00 0.3776E-04 0.3776E-04 Puel Storage Area 2-A 0.0000E 00 0.1026E-02 0.1026E-02 0.0000E 00 0.4577E-04 0.4577E-04 Auxiliary Feedwater Storage Tank 2-A 0.0000E 00 0.1207E-03 0.1207E-03 0.0000E 00 0.5333E-05 0. 53 3 3E -0 5 Total Strike Probability, P2 0.2033E-01 0.2882E-01 0.4845E-01 0.1245E-01 0.1482E-02 0.1393E-01
- Probability multiplied by 2 to account for a missile strike on unit 2 f rom turbine B as well as on unit 1 f rom turbine A.
(~. CD ( (J i 2 of 2 Amen dment 17 9/30/75
SWESSAR-P1 TABLE 10.2-5 OVERALL PEOBABILITY (P4) FOR A TWO-UNIT SITE NSSS Vendor - Babcock & Wilcox, Onmbustion Engineering and Westinc;nouse (3S) U Turbine Manufacturers M P2 P33 P4 = P1xP2xP3 V o = 300 fps 1. 4 E -8 4.575E-2 1.0 6.545E-10 Vo = 600 fps 1. 4 E -8 1.378E-2 1.0 1.929E-10 Westinghouse V=o 300 fps 1.7E-6 4.675E-2 1.0 7.94dE-08 Va = 600 fps 1.7E-6 1.378E-2 1.0 2.343E-08 NSSS Vendor - Westinqhouse (41) 11 Turbine Ptmufacturers P1 M P_3 P4 = P1xP2xP3 9E V,= 300 fps 1. 4 E -8 4.845E-2 1.0 6.783E-10 Vo = 600 fps 1.4E-8 1.393E-2 1.0 1.950E-10 Westinghouse Vo = 300 fps 1.7E-6 4.845E-2 1.0 8 .237E-0 6 Vo = 600 fps 1.7E-6 1.393E-2 1.0 2.368E-08 C' c.m C. O CD
~ ,
C-1 of 1 Amendment 17 9/30/75
SWESSAR-P1 TABLE 10.2-6 7URBINE-TARGET DISTANCES AND IMPAC1' AFEAS FOR A TWO-UNIT SITE NSS3 Vendoc - Babe')ck & Wilcor, Combustion Enqineering and West inghpuse (3S) 11 HICH TRAJECTORY IDW TRAJEL'IORY _ Impact Impa R Unit min #rnar y Area r Y max Y min Area Cri t ic.<il Pla nt Region Turbine ft ft ft fta ft it ft ftr Containr:ent Str acture 1-A* 304 438 112 10000 Control Duilding 1-A* 267 518 13 28200 Diesel Generator Building 1-A* 475 609 -33 8800 Fuel Oil Storage Tanks & Pug > I!ouse 1-A* 601 720 -46 4600 Puel Storage Area 1-A* 322 450 -5 8300 Auxiliary Feedwater Storage Tank 1-A* 298 333 110 960 Containment structure ** 1-B 652 765 112 10000 612 112 -5 3000 lIT Control Building 1-B 754 1002 13 28200 836 13 -5 790 Diesel Generator Building 1-B 930 1050 -33 8800 Fuel Oil Storage Tanks & Punp flouse 1-B 1007 1169 -46 4600 Fuel Storage Area 1-B 554 660 -5 8300 Auxiliary Feedwater Storage Tank 1-B 755 790 110 960 Containment Structure ** Control Building 2-A 2-A 652 386 765 600 112 10000 13 28200 612 112 -5 3000 {j Diesel Generator Building 2-A 573 709 -33 8800 Fuel Oil Storage Tanks & Punp flouse 2-A 697 736 -46 4640 Fuel Storage Area 2-A 754 862 -5 8300 Auxiliary Feedwater Storage Tank 2-A 571 606 110 960
**The conservative assumptim was made that the Westinghouse (3S) mntair:Jr.cnit g structure is the same height as that for BSW and C-E.
3 (.s CD C~) ~J
)
1 of 2 Amendment 17 9/30/75
SWESSAR-P1 TABLE 10.2-6 (CONT) NSSS Vendor - Westinohouse(41) !U HIGH N RY IDW TRAJECTORY r r Impact y y Impact Unit min max y Area r max min Area critical Plant Region Turbine ft ft ft ft2 ft ft ft ftr Containment Structure 1-A* 304 418 112 10000 Control Building 1-A* 267 518 13 28200 Diesel Generator Building 1-A* 458 608 -33 13200 Fuel Oil Storage Tanks & IET House 1-A* 594 720 -46 6900 Fuel Storage Area 1-A* 322 450 -5 8300 Auxiliary Peedwater Storage Tank 1-A* 298 333 110 960 Containment Structure 1-B 652 765 112 10000 612 112 -5 3000 Control Building 1-B 754 1002 13 28200 836 13 -5 790 Diesel Genrator Building 1-B 896 1050 -33 13200 Fuel Oil Storage Tanks & Pump House 1-B 990 1104 -46 6900 Fuel Storage Area 1-B 554 660 -5 8300 Auxiliary Feedwater Storage Tank 1-B 755 790 110 960 Containment Structure 2-A 652 765 112 10000 612 112 -5 3000 Contznl Building 2-A 386 600 13 28200 Diesel Generator Building 2-A 524 683 -33 13200 Fuel Oil Storage Tanks & Punp aouse 2-A 651 777 -46 6900 Fuel Storage Area 2-A 754 862 ~5 8300 Auxiliary Feedwater Storage Tank 2-A 571 606 110 9$0
- Distances and areas are the same for a missile strike on unit 2 frcan turbine B as those for a strike on unit 1 frcun turbine A.
** Refer to Fig.10.2-2 for definition of r and y.
The subscripts min and mar refer to minimum and maximum distance respectively. C cn CD C; 2 of 2 Amendment 17 9/30 /75
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SWE3SAR-P1 10.3 MAIN STEAM SYSTEM The function of the main steam system is to transport steam from the steam generators in the reactor coolant system (Chapter 5) to the turbine generator (Section 10.2) . The main steam system i shown in Fig. 10.3-1, 1A, and 1B. 10.3.1 Design Bases Tne design bases for the main steam system are:
- 1. Those portions of the main steam system extending from the steam generators up to and including the outermost containment isolation valves are safety related and Seismic Category I, and are designated Saf ety Class 2.
- 2. The piping in the steam supply line to the auxiliary feedwater pump turbine frcxn the motor-operated valves up to and including the turbine is also safety related and Seismic Category I, and is designated Safety Class 3.
- 3. The safety related portions of the ruin steam system are designed in accordance with ASME III, Code Class 2 (for the Safety Class 2 portions of the system) and in accordance with ASME III, Code Class 3 (for Safety Class 3 po d ons of the system); see Section 3.9.2 for system 33 analysis.
- 4. The balance of the main steam system is not safety related.
- 5. The nonsafety related portions of the main steam system are designed in accordance with ANSI B31.1.
l33
- 6. The following valves are considered containment isola-tion valves: -
Main steam isolation valves Main steam isolation valve bypass valves , Motor operated valves at steam supply branch connections to the auxiliary feedwater pump turbine.
- 7. The main steam system shall be able to remove the heat generated in the steam generators at 105 percent rated main steam flow (i.e., valves wide open condition) ;
reactor core power at rated flow equals 3,800 MWt.
- 8. The main steam system shall have design pressure and temperature equal to the design pressure and temperature of the steam side of the steam generators. (See Table 10.3-1 f or actual design conditions.)
10.3-1 Amendment 33 6/30/77
. . . 4 0-
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SWESSAR-P1
- 9. The main steam system design shall be such that, during normal operation, the maximum out-of-balance pressure between one steam generator and any other is as specified in Table 10.3-1.
- 10. The main steam system design shall ensure a supply of steam to the turbine driven auxiliary feedwater pump (Section 10.4.10) under all accident conditions which require the turbine driven pump to be in service.
- 11. The main steam system design shall prevent the uncon-trolled blowdown of more than one steam generator fol-lowing a main steam pipe break accident.
10 .3.2 Description Principal design and performance characteristics of the main steam system and its principal components are summarized in Table 10.3-1. Steem from the steam generators flows through carbon steel pipes, through a main steam isolation valve in each main steam line, to the main steam manifold. Steam from the manifold flows through the main steam turbine stop and control valves before entering the high pressure turbine. Because of the superheated steam temperatures inherent to the BSW NSSS, two additional manifolds U are required upstream of the primary manifold to ensure adequate mixing and equalized temperatures at the turbine inlets. The containment penetrations for the main steam piping are located in the main steam and feedwater valve areas of the annulus building. Two main steam pipes pass through each of the two areas, which are located 180 degrees apart. The main steam pipes are routed around the outside of the containment structure so that they are isolated from safety related systems and components. The piping is restrained from whipping following a pipe break. The turbine steam system is discussed in Section 10.2. Safety valves and atmospheric dump valves are provided for each steam generator immediately outside the containment structure upstream of the main cteam isolation valves. Steam piping connects the auxiliary feedwater pump turbine steam supply header to one or two main steam pipes (depending on NSSS Vendor) upstream of the main steam isolation valves. This piping and the header provide steam to drive the auxiliary feedwater pump turbine. The first valve on the turbine steam supply line is a motor operated stop-check valve when the turbine requires steam from two steam generate s. When steam is only required from one steam generator, the valve is a motor operated gate 10.3-2 Amendment 19 12/12/75 fbY
SWESSAR-P1 valve. Two solenoid air operated control valves, mounted in 9 parallel, admit steam to the auxiliary feedwater pump turbine. 10.3-2A Amendment 19 12/12/75
/ /. 0 '09
SWESSAR-P1 The main steam isolation valves, safety valves, atmospheric dump valves, and supply piping up to and including the turbine-driven auxiliary feedwater pump are housed within the annulus building. Pipes from the main steam manif old supply steam to the main teedwater pump turbinea, the single stage reheat of the moisture se pa rator reheaters (Section 10.2), the turbine gland sealing system (Section 10. 4. 3) , the turbine bypass system (Section 10.4.4), and the auxiliary steam system (Section 10.4.12) . 10.3.3 Safety Evaluation If a steam pipe breaks downstream of the main steam isolation valves, closure of these valves stops the flow of steam from the steam generators to the ruptured pipe section. Maximum closing time tor the main steam isolation valves is as specified by the NSSS Vendor (see Table 10. 3-1) . Valve closure checks the sudden release of main steam, tnereby preventing rapid cooling of the reactor coolant system (Chapter 5) . Valve closure does not limit the supply of steam to the auxiliary feedwater pump turbine. If a steam pipe breaks between a main steam isolation valve and a steam generator, the atfected steam generator continues to blow down. The main steam isolation valves prevent blowdown from another steam generator. This, the most serious postulated steam pipe break accident, is discussed in Section 15.1.14. The main steam system is capable of removing heat f rom the reactor coolant system following sudden load rejection or trip of the turbine generator by autoratically bypassing main steam to the condenser through the turbine bypass system (Section 10.4.4) , or by relieving to the atmosphere through the main steam saf ety valves or main steam atmospheric dump valves if the turbine bypass system is unavailable. Removal of the reactor coolant system sensible heat limits the main steam pressure at or below the design pressure. The main steam safety and the safety related main steam utmospheric dump valves have flow capacities stated in Table 10.3-1. Under certain conditions, the main steam atmospheric dump valves c91 ease reactor coolant system sensible and core decay heat to the atmosphere when the steam generators are in service. These valves operate during periods when the turbine generator or condenser is not in service, core physics testing, turbine trip on loss of condenser vacuum, or loss of electric power. The main \30 steam atmospheric dump valves preclude operation of the safety valves during normal operating transients by keeping the main steam pressure below the safety valve setpoints. The main steam atmospheric dump valves are not required for saf ety or the plant 10.3-3 < 7 ,, Amendment 30 CL0 '1
/ u o:)
1/28/77
SWESSAR-P1 because the steam generators are protected by the main steam safety valves. In the event or a main steam pipe rupture upstream of the main steum isolation velves, tna motor-operated stop-check valves in the steam supply piping to the auxiliary feedwater pump turbine prevent reverse flow of steam. This ensures that the steam supply piping to the auxiliary feedwater pump turbine inlet is continuously under steam generatcr pressure following a main steam rupture. All operating conditions of the auxiliary feedwater pump turbine are indi cated in the control room to enable the operator to adjust the feedwater flow. Information on the auxiliary feedwater pumps is contained in Sections 10.4.10 and 16.4.8. It the steam supply piping to the auxiliary feedwater pump turbine ruptures, the turbine driven pump is rendered inoperable. Depending on the NSSS Vendor, either one or two steam generators blow down through the ruptured pipe until the motor-opera ted valves in the turbine steam supply line can be closed. Flow elements upstream of the motor operated valves and interlocked with the steam admission valves are provided to detect and alarm flow into the line at any time other than when the steam ddmission valves dre open. This flow is indicative of a pipe rupture in the steam supply line. For any pipe rupture in the turbine steam supply piping, the break ar'ea for a double ended rupture (i .e . , steam flowing from both ends of the broken pipe) is less than the maximum main steam safety valve orifice size. Since the NSSS designs can accommodate the blowdown resultins from a safety valve stuck open, they can also accommodate the lesser blowdown resulting from this pipe break without excessive rapid cooling of the core. For this reason, operator action time is inconsequential, and the valves can be assumed to be manually closed arter 30 minutes. The stop-check valves, when provided, are designed in accordance with ASME III requirements. Included in the conditions of design are consideration of operating loads, earthquake loads, and dynamic system loads resulting from postulated pipe rupture, as further described in Section 3.9.2. Valve closure due to normal, inadvertent, or spurious action is controlled and therefore results in negligible accumulated fatigue damage. The valve plug assembly is held open by system pressure, and closure is achieved through valve operator (motor) movement of the plug against system pressure. Valve closure dynamics of the stop-check valve following postulated rupture of the piping between the steam generator and the main steum isolution valve are developed based on the methods out)u ed in Reference 1. Maintenance of structural integrity of the alve pressure boundary and pressure retaining parts is demonstrated for the conditions defined. 10.3-4 Amendment 30 1/28/77
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SWEdSAR-P1 Guide 1.75 (Section 3A.1-1.75) for redundant safety related circuits. Two parallel redundant solenoid air operated control valves automatically start the auxiliary feedwater pump turbine upon receipt of a starting signal as described in Section 7.3.3.8. Local and remote pressure indications monitor operation of the auxiliary feedwater pump turbine. The safety related atmospheric dump valves are provided with electrohydraulic operators powered from a Class IE power supply 30 to ensure operability when required to effect controlled cooldown of the plant. The safety related atmospheric dumi valves are normally under automatic control from steam generator pressure 09 , W-3S, and B&W) or are manually controlled from the control room (W, W-3S, C-E, and BSW). Pressure signals from the main steam manifold are supplied to the steam dump and feedwater pump turbine control. A flow element is located in each auxiliary feedwater pump turbine steam supply line immediately upstream of the first valve in the supply line. The flow element is interlocked with the steam admission valve to the turbine and initiates an alarm in the control room upon detection of flow when the steam admission valves are closed. 10.3.7 Interf ace Requirements Interface information applicable to the main steam system, as presented in the respective NSSS Vendor's SARs, is discussed in Table 10.1-2. Reference for Section 10.3
- 1. Gwinn, J.M. " Swing-Check Valves under Trip Loads," ASME Publication 74-PVP-51.
O 10.3-6 Amendment 30 (c - 1/28/77 o( V v ,,J
SWESSAR-P1 The main steam system piping supports are analyzed for the more severe condition of either turbine trip reaction or seismic forces up to and including the main steam manifold. The main steam system piping supports f rom the main steam manif old to the turbine are analyzed for turbine trip forces only. The main steam system is also stress analyzed for the forces and moments which result f*om thermal growth. The main eteam systua piping within the containment structure is reviewed for possible pipe rupture. Sufficient supports and guides are provided to prevent damage to the containment liner and adjacent piping, controls, or electrical cables. 10.3.4 Inspection and Testing Requirements All safety class valves require testing as specified in Section 16.4.2. The main steam isolation valves will be inservice tested for partial closure. In addition, containment isolation valves require testing as specified in Section 16.4.4. The auxiliary feedwater pump turbine air operated control valves will be tested each month. Code C1 ass 2 and 3 pipang within the jurisdiction or ASME III will be inspected and tested according to Articles NC-5000 and 6000, respectively, of that code. Piping within the jurisdiction of ANSI B31.1 will be inspected and tested in accordance with paragraphs 136 and 137 of that code. Inservice inspection will be performed as discussed in Section 16.4.2. 10.3.5 Water Chemistry Secondary side water chemistry is discussed in Section 10.4.7. The radioactive iodine partition coefficients for the steam generators are given in in Table 11.1.2-1. 10.3.6 Instrumentation Applications The NSSS Vendor supplies the main steam flow, pressure, and steam generator level instrumentation for protection and control. Descriptions of the feedwater control, steam generator level, steen piping break protection, and engineered safety feature inputs are supplied by the NSSS Vender (Chapter 7) . Redundant steam line isolation (SLI) signals ensure closure of each main steam isolation valve. A bypass valve around each main steam isolation valve also closes upon receipt of an SLI signal. Each SLI valve has two solenoid valves in series. Each solenoid valve is powered from a separate source. These solenoid valves are physically separated und supplied by redundant electric power sources to meet the requirements of IEEE 308 and Regulatory 10.3-5 Amendment 30 1/28/77 (p . .
' ' V L1 1 ;l
SWLSSAR-P'1 TAPLE 10.3-1 MAIN STEAtt SYSTD1 PRINCIPAL DESIGN AND PEhFOhMANCE GIAi:ACTLkISTICS Item Desirin and Perf orLince Characterist.ics Main Steam System h f,W C-E W-41 W-3S ho-load pressure, psia 1,200 1,??O 1,138 1,107 Rated luwei Conditions pressure, psia - 1,070 1,100 1,000 temperature, F - 553 556 545 flow, Ib/hr x 106 - 17.18 16.96 15.14 Turbine Maximum Capability Condi tion s pressure, psia 1,060 1,043 1,072 1,000 temperature, F 586.7 550 553 545 flow, lb/hr x 106 16.7 17.46 17.23 15.82 Design Conditions pressure, psia 1,250 1,270 1,300 1,200 temperature, F 630 575 600 000 Maximum out-ot-balance 5 No requirement 10 10 pressure between one 3$ steam generator and any other, psi Main Steam Isolation Valves Number 4 (one un each main 4 (one on each main 4 (one on each main 4 (one on each main steam line) steam line) steam line) steam line) Closing time, sec (sax) 5 (atter receipt 5 (af ter receipt 5 (atter receipt 5 (af ter receipt or closure signal) of closure signal) of closure signal) ut closure signal) Main steam Safety Valves Number 20 (Live on each 20 (five on each 20 (five on each 20 (11ve on each
- m main steam line) main steam line) nain steam line) anin steam line) g, 'Ibtal relieving capacity 112 percent maximum 19x106 lb/hr at set 105 percent maximwn 105 percent a m mum calculated flow at pressure of 1,255 psigt calculated operating calculated operating C set. pressure plus maximum individual tiow at 110 percent flow at 110 percent.
3 percent accumula- capacity of 1.9x106 design pressure design pressure; tion or 1,200 psig Ib/hr at 1,000 psia maximua individual 15
=
capacity ot _. 1.0 5x10
- lbou .
PJ 1 of 2 Jaendment. 35 10/6/77
~
SWESSAR-P1 TAPLE 10.3-1 (CONT ) Item Design and Perf onnance Characteristics C-E W-41 W-3S B&W Safety Related Atmospheric Dump Valves turnber 4 (one on each main 4 (one on each main 4 (one on each main 4 (one on each main steam line) steam line) steam line) steam line) Minimum ccxnbined At last 10 percent At least 15 percent l28 htal relieving capacity At least 7 percent maximun operat.ing maximum expected capacity of 3.5x105 maximum operating operating flo< lb/hr at 350 F: flow at no-load flow at no-load maximum individual pressure pressure ; maximum capacity of 1.9x106 individual cop. city 28 lb/hr. of 1.05x106 lb/hr. Os c.s CO m b CY 2 of 2 Amendment 28 e/6/76
1 ( MAIN l TUNNEL I _ TO TURBINE
' 3YPASS SYSTEM j flG.10.4.4-1 I
UXILI ARY M SYSTEM 10.4.12-1 l l TO TURBINE l T STEAM SYSTEM F I G.10. 2-1 I TURBINE ( STOP VALVE (TYP) l FIG 10.2-1 I I l 9_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ___________J l l l C l I I l C l l l l y TO TURBINE STE A!! SYSTEM
- _ _ _ _ _ ._ _ ]
FEEDIATER PUMP % FIG.10.2-1 [ TUkBINE STEAM SUPPLY FIGURE 10.3-1 HAIN STEAM SYSTEM Ra w l BYPASS SYSTEM PIR REFERENCE PLANT l SAFETY AN4LYSl3 REPORT GLAND F I G.10. 4. 4-1 sy[$$(p_pl STEM
. TO VENTILATION VENT
' FIG.6.2.3-1 y g- \_h AMENDMENT 30 1/28/77
FIG 103-1A! INSIDE INSIDE ANNULUS ---> 4- TURBINE INSIDE TO BUIL DIN:; INSIDE Bull 0 LNG #, ERE , g [ ! CONTAINNENT y ANNULUS ATM0 7 s l STRUCTURE BulLDING ( /NNS, o d' N A I N ST E A's SC2
~ ATMOSPHERIC (TYP)
CUNP VALVE
; & & b k kr ,
i 1 8g = NAIN STEAM l SC2 NHS ISOLATl0N VALVE g l (TYP) NNS l A d ' lUSS-C [M SS-2) l l SC2(TYP.) r1 I l
\ ' 1 +Tg I - SC2 SC2 -*@- NNS pg l
p----- ~b---------------._._ - ___ l NAIN STEAR SAFETY , YALVES(TTP) d 6 l d I hhhhh V I l t M u -- -SC2 SC2 -h NNS C3 l MSS-1) [555-4) l
)9- )D- )p- )g I s / 1 $g l SC2 MNS '
V l STEAM I GENERATORS TO ATIOSPHERE JL b n
\ n Q TURS SEAL l
U AUIILIARY FEEDIATER FIG 10.3-1B PUNP TURBINE NOTES- THIS SYSTER is NON-NUCLE 89 SAFETY CLASS INNS) EXCEPT WHERE OTHERflSE NOTED 4 a () I;.
INSIDE ) INSIDE INSIDE I
- N w ,'J S , M ~ Math
- TURBlhE STEAW DUWP &
WDSPHERE BUILDING STEAN BUILDING c ^ Fs PutP TURBihE MAIN STEAN TuhhEl M 1PT . - . YP) k / ATFOSPHERic CUMP V ALVE(TYP ) TO TURBINE 33p ; BYPASS SYSTEM
- ,o i F I G.10. 4. 4 - 3 y
4 3--- ,ft} M :S_ ' TO AUXILIARY SL' " - STEAM SYSTEM YP rg
'~ i;
- T T Bh i SC2 h kNS ' STEAW SYSTEM w
sN F E. ISTAT10N s FIG.10.2-1 OLVE(TfP) , k C)q "&" SLI SLI a () I TO TURBINE FC PLANT SAMPLING I SYSTEM l FIG 3.3.2-2 SC2 -y-Nh5
-q CB 1
-~ ~
~
- TURBINE STOP ygtygg79p) fFEEDIATER CONTROL SYSTEM 7 FIG. i0. 2-1
,A k ASP h__ __I D McB
.h 2 ) I i
I I b- G MCB -
.. . ,- ] S L t
'C (T, )
S@ _F SC2-hNNS
,( ..
W:B SLI TO TURBINE FE ~ ~' PLANT CONT.ON SAMPLING FIG.10.3-18 SYSTEu F I G.9. 3.2- 2 SC2 y NNS FIG.10.3-1A NAIN STEAM SYSTEM PIR REFERENCE PLANT SAFETT ANALYSIS REPORT SIESSAR-P1 C-E AMENCMENT 30 1/28/77 [; . ) [j
INSIDE lNSIDE l CONT AINMENT ->4- ANNULUS BUILDING BulLDING A NsS , MAIN STEAM SAFETY YALVES (TYP.) SC' (TkP [ 4 i I W W W N ~~ W PLANT D PROTECTl0N SYSTEM
/M '-~
- W l l
r -- r _J i
%J <j uus_>
c y 7 55-2_ ) 1
~O l
n w n n x-
\ /
SC2
'I ab
_5 Li SC3
\_j CONT.ON 5- flG 10.3-IB h GLs OR NOTES:
- 1. THIS PORTION CF THE MAIN STEAM SYSTEM 15 SAFETT CLASS 2 (SC2) EXCEPT MHERE DlhERelSE NOTED.
- 2. M AIN STE AM ISOL ATION VALVE HAS 5 SEC. MAI CLOSURE TIME.
- 3. *** ME ANS INSTRUMENT SUPPLIED BY NSSS VENDOR.
4
//n
() V U i iI
INSIDE l l INSIDE CS%EFE ANN'J LUS -F4- -> 4- TURBINE INSIDE
/gg Bul10 LNG BULL 0 LNG f{He- MAIN CONT.CN y ,) i v ,43p STEAM FIG.10.3-1A
, g TUNNEL 3 ,
{___h.9AINSTEMj uCB yA ATMCSPHERIC DUMP
.1 VALVE (TYP) #
INE STOP VALVE lS - 1 a s SC2 ->4-hNS FE FIG.10.2-1 blLv! T1P; Ng ,, A ii g
'O f0 E F j' t) 'f 4 y A:S
$Is ,1 TO TURBINE
[sG] l st6 l I SC2 - NN S ggg 3 h____
's ;g y SYSTEM FIG.9.3.2-2 FEED 84TER
- - - - - - -]
CONTROL SYSTEM
-I A AOHV g~~ ~l i
FC pg - WC') j A3p *SB l v (TYP)! _( S dj. ) M CS (L ISLI br-l SLt 1,c,
<> p d ${2 -h NNS U
,,7 ,
b 34 , ,I g TO TURBINE
'I' p STEAM SYSTEW F0 F0 p FE 3 FIG.10.2-1 H (-4 d)
CTV + FEEDWATER PUMP r "ITURBINE STEAM SUPPLY pf [SER [YtT] TO TURBINE r g P BYPASS SYSTEM SC2 - NNS SAMPLING SISTEM q, FIG.9.3.2- h SEALING SYSTEM TO ATMOSPHERE TO VENTILATION
""> VENT
-l FIG 6.2 3.1-1
[ ' FIG.10.3-1B
\ HAIN STEAM SYSTEM PER REFERENCE PLANT IlllARY FEEDIATER SAFETY ANALYSIS REPORT MP TURBINE SIESSAR-P1 CE , , ,
e I AMENCHENT 30 l'26/77
INSIDE _ INSIDE CONTAINWENT "'_ ANNULUS TC STRUCTURE BUILDING A S C 2 ->4-NNS( TYP ) If AIN STE AW SAFETY VALVES (TYP.) l M E'" & M A'
~
l M PLANT l l
~
/flh, _jiS\__ 'Nhq Q
l PROTECTICN ,l - (j gj 't, WCB i _SYSTEW i
- lk C
CONT. FRCW l l FIG 10 3-1A
- MSS-3) ,
I MM - V E LESS-4Y I j Md we l i:
\ /
V l STEAM GENERATOR (' $( Ti g F0 V\ l , d EC 4: - : y r X-
,g Ovv i i/
d l IDE MAIN l AM TUNNEL l I TO TURBINE
=
BYPASS SYSTEM l FIG.10.4.4-1 . I m TO AUXILIARY
' STEAM SYSTEM FIG.10.4.12-1 l
l TO TL"1BINE I
> STEAM SYSTEM l
FIG.10.2-1 l TURBINE STOP VALVE (TYP) l F I G 10. 2 -1 j l u l l < ____________J l t I
< l l
l I d' l l l l
- TO TURBINE _ _ _ _ _ --- _ _ _
' STEAM SYSTEM l FIG.10.2-1 l
% FEEDWATER PUMP FIGURE 10 3-1 TURBINE STEAM SUPPLY l
l NAIN STEAM LYSTEM m TO TURBINE l PWR REFERENCE l'LANT
' BYPASS SYSTEM SAFETY ANALYSIS REPORT l
FIG.10.4.4-1 - SWESSAR-P1 BINE GLAND e TO VENTILATION VENT LING SYSTFM FIG.6.2.3.1-1 l
- E , , '
a ^ n i m< A5ENDMENT 30 1/28/77
F:G.10 3-1Ai , INSIDE INSIDE i l INSIDE TO ANN' J L US --> 4l- TURBINE IN5IDE I BUILDING Bull 0lN"* l CONT AINWENT -*=4 ANNULUS ATMOSPHERE /p. ls STRUCTURE BUILDING (TYP) gss A j si l , St2 MAIN STEAM ATMOSPHERIC , i (TVP.# DUMP VALVE . I
/ 4 z i i s' i l / MAIN STEAM ISOLATION VALVE SC2 y - NNS l (TYP) l LJ s l NNS l SC2(TYP.)
l M- kr h- h- h- -- 4 l 1 8 l
\ / --
NAIN STE j SC2 ->4- NNa j M ANI FDL D l l
]
p _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 1 1 I MAIN STEAM SAFETY VALVES (T!P) v
^1Eqr-l l l E I
2- e I
\
/
N SC2 y-NNS j l i s ./ l A l l l I [ kE e' I d ' i- l Q~ 2 SC2 h NS I b I TD ATN0 SPHERE ' A 2, r l
; N R i
l [ U TUR AUllLIARY FEEDIATER FIC l'1 3-19l PU4P TURBINE NOTES: THi? SYMEM 15 NON-NUCL: 4 SAFETY CLASS .:NNS) EXCEPT WHERE nTHERtlSE NOTED.
*^4
,7e
{ <r t *-
INSl0F INSIDE
'b CONT AINif ENT ANN'JLUS STPUCiupr Bull 0 LNG l4--
NAIN STEAW SAFETY SC2 + y
' MSS-!)
(TYP.) OP0* g -
, VALVES (TYP.)
)(3- jf- kG- MM l
I ! W U
.1. ._
_L y f T -- T l l 4 l 1 s l \ h 'd
\ / L____ NSSS PRCTECTION AND CONTROL *
,_l PT PT l ,
'd I L- ------J l i STEAM GENERATCR M__________.-______
l USS-2) i I
", m -
..)
l FT f- ~
" - I kr & )ce & W-
- + TT I i V N / 't _ _ ___NSSS PROTECTION AND CONTROL .
, .j pi pi V :
t______ _1 _ _ .J GENEPATOR NOTES:
- 1. THIS PORTION CF THE MAIN STEAR SYSTEM IS SAFETY CLASS 2 (SC*) EXCEPT WHERE OThERnlSE NOTED.
- 2. M Ald STE AM ISOL ATION VALVE H AS 5 SEC. MAX. CLOSUFiE TIME.
- 3. *** EE ANS INSTRUMENTS SUPPLIE0 BY NSSS VENDOR.
l'
. ^q
,' ' u L
!'s O
A INSIDE ! INSIDE I INSILE
/ HC ANNULU MAIN M TURBINE ATMOSPHERE l SP Bull 0 LNG BullulNG STEAM a STEA> CUMP &
A I A C OUMP y IP ,__ F# PU.JP TUFBINE V S l VALVE (TYP) ( CONTROL NN;, I TO TURBINE BYPASS SYSTEM
, _j L FIG.10.4.4-1 (TYP)g SLI .,q Sll TO AUXILI ARY STE AM SYSTEM
,; ' F I G .10. 4.12 - 1 il S y CTV i SC2 hNS
' I FG 0 ISnLATION VALVE (TYP)
CTV F ' ' SLI SLI FC ' TO TURBINE PLANT SAMPLING SYSTEM FIG 9.3.2-2
ASP TURBINE STO' h l VALVE (TfP) py ;
FIG.lD.2-1 I r::8 t 2 (ifP) Sti . _. Sti i. II SC2 -** hNS FD l F0 t p n SlIl l FC SLI l TO TURBINE PLANT CONT.ON SAMPLING FIC.10.3-1B SYSTEM g gg FIG.9.3.2 2 FIG.10.3-1A MAIN STEAM SYSTEM PIR REFERENCE PLANT SAFETY ANALYSIS REPORT SIESSAR-Fl
,n
, I L AMEN 0!IENT 301/28/77
a INSIDE ! l iNSIDE 3 SPHERE YP;' I b ANNU;.US W-1INSIDE
+*4--- T U R B I N E l
BUILDING BullulNG JL PV MAIN CONT.0N i 3 STEAM FIG.10.3-1A l TUNNEL o , , d /g G-- 2 MAIN STE AM
) ATMDSPHERIC OUMP lSQ , r 1 SL I TURBINE STOP VALVE MAIN (TYP)
STEAM CT k SC2 M NS FIG.10.2 1 ISOL Ail 0N
- VALVE (TYP)
]
1 F0 , F0 j Af; A , r TO TURBINE ( SLI i SLIl PLANT i SC 2 ->4- NNS ggyptlyg SYSTEM FIG.9.3.2-2 M i i G ASP I h ( PV I
) -
k SLI l SLI h.r- i li SL2 -*A4- NNS r TO TURBINE F0 j F0 h STEAM SYSTEM f Il FIG.10.2-1 CW
,4 (M l{J '
t FEEDIATER PUMP TURBINE STE AM StiPFLY FC I AT TO TURBINE BYPASS SYSTEM SC2 NNS r FIG.10.4.4-1 SAMPLING SYSTEM FIG.9.3.2- 6 g g SEALIE SYSTEM TO ATMOSPHERE TO VENTILATION VENT 2 FIG.6.2.3.1-1 F I G. l D. 3 -18
\ NAIN STEAM SYSTEM PfR REFERENCE PLANT A EDIATER U
SAFETY ANALYS13 REPORT SIESSI'l P1
~~ ~
AMENOMENT 30 1/28/77
INSIDE INSIDE M _ _ _ _ _ _ _ __ _ _ - - - - - - CONT AIN"ENT ->+ ANNULUS ICB TO SIRUCTURE BUILDING , A
)
MAIN STEAM
! MSS-Q l SAFETY VALVES SC2 ->4 NNS(TYP.) (TYP.)
M FT w w w >,- p g d, i p t D C i
"4 -- A T T _- : :
l , e-T l w [
'e.
N / ,'- NSSS FROTECTIGl J Y ANO CONTROL
- PT ,P
', I Q .
L__ _ i
-- J GENERATOR M
W MCB d k ",u luSSa> { ee&&s e \ f I I i MCB 4 / (-~ NSSS '"ECT I G _ _'i d' AND CLNIROL
- PT PT i . .
g e w i 1 V l I t STE14 GEhERP. TOR l_ _ _ _ . _ 1. - - J F0
,eq -
4 3.
--{X}- N
,0e
<-mo IL 5
l 1 E MAIN TUNNEL l I
. TO TURBINE I
' BTPASS SYSTEM l
FIG.10.4.4-1
. TO AUIlLIARY
' STEAM SYSTEM I FIG.10.4.12-1 l
l TO TURBINE !
. STE AM SYSTEM j
FIG.10.2-1 TURBINE l ( STOP VALVE (TYP) FIG 10.2-1 l l 1 I C I ______________..____._________J l l I C l l l C l 1 l TO TUR91NE _ _ _ _ _ _ _ _ .- - STEA5 SYSTEM FIG.10.2-1 l 4 FEE 0 MATER PUMP FIGURE 10.3-1 TURB I Nt' STFAM SUPPLY j l MAIN SIEAM SYSTEM
. TO TURBINE ! PMR REFERENCE PLANT
' BYPASS SYSTEM SAFEiY ANALYSIS REPORT FIG.10.4.4-1 i
SMESSAR-P1 E GLANL G SYSTFM FIG.6.2.3.1-1 l% TO VENTil Ail 0N VENT l 1 1 35 (, r -;, i}' i AMENDMENT 30 1/28/77
FIG.10.3-1A , INSIDE - INSIDE j ANNULUS --> e TURBINE INSIDE TO BJILDING ' INSIDE > BUILDING l A AIMO ERE INS CONTAINMENT P NNULUS STRUCTURE Bull 0 LNG ( ) NNS g STE g I S2 M%IN STEAM l (yyp) ATMOSPHERIC S DUMP VALVE E I i 1 e A YALVE'SC2 p NNS l (TYP)
%J i l NNS SC2(TYP.)
i + >>he 3 l l 1 e l
\ / --
MAIN STEA) SC2 V NNS M ANI FDL D l 1 g _ _v_ _ _ __________ , _ _ _ _ L_ y MAIN STEAM SAFETT , l VALVES (TYP) d ; d , l b- h h 8 l 1 q ! , l SC2 - NNS o T l 4 I a XE i t y l l 3 , d~ l N / __ N l -SC2(TYP) SC2 -@NS _kSC3(TYP) I v i TO ATNOSPNERE A S ri l
\ b f TUR AUXILIARY FEEDIATER E F I G .11 3-19l PUdP TURBINE NOTES- THIS SYSTEtt IS NON-NUCLE AR S AFETY CL ASS (NNS) EXCEPT WHERE OTHERWISE N0iF0 c 1 n1 (f v s) 4 '/
INSIDE I INSIDE HC ANNULUS . - INSIDE BAlN r lI TURBINE i ' ASP BUILOlNG O ATNOSPHEPE STEAR BUILDING I BAIN STLAE TUNNEL O h (!TP) 4 l ATIOSPHERIC DURP q /PT .__ FB PudP TURBINE CONTROL I V ALVE(TTP) NNS' OPV I To TURBlNE B' PAS $ $1 STER FIG.10.4.4-1
]g _.'
(TYP) SLI -mr- Sll TO AUIlLIARY STEAR $YSTEE ll 7 F I G.10. 4.12 1
'li TO TURBINE STE AR ST!TER CTV SC2 -*'4 NN3 m
d = FIG 10 2 1 IStLATION VALVE (TTP) CT4 l ' o l'
, SLI SLI A LING SYSTEE
' ' ~
SC2 --#4-NNS
' ASP TURBINE STOP h I VALVE (TfP)
O ' FIG.10.2 1 py i FC] J f (TTP) gt, _, gt, n 1.
*e 31 SC2 +4NNS
&c % FC in SLI Sll 17 TO TURBINE t
o PLANT CONT.ON SAMPLING FIE.lc.3-1B SYSTER III* I' 3' 2' 2 SC2 NNS FIG.ll.3-1A MAIN STEAM SYSTEM PIR REFERENCE PLANT SAFETT ANALTSl3 REPORT SIESSAR-P1 , 1 iud W 3S ARENCIENT 30 1/28/77
INSIDE INSIDE . ga" CONTAINilENT ANNULUS STPt'CTURE SulL0 LNG , I RO ESS-1) EAIN STEAM SAFETY 3C2 *+* i VALVES (TYP ) (TYP.) 1 l I-FT l }9- & )p- }p- )g _L .. l 4 T-Tl l , I a
\ / L _ __ _ NSSS PRCTECTION ANU C0WTROL .
__j PT PT i . . I 1 l L- -------J STEAR GENERATCR b_________________ V MCB i [TSi D i I l 0
-j . .J n n s- n u FT f- -
- FT -
- v.
i s L -- _ L 4x g j I I
\ / ' _ ____
l NSSS PROTECTION _ _ _ AhD CCNTROL py py l Cl l t_ __ _ __ _. _ _ .1 _ _ .1 i i GENERATOR NOTES:
- 1. THIS PORTION CF THE EAlk STEA5 SYSTEE 15 SAFETT CLASS 2 (SCT) EICEPT INERI OTHERt15E NOTEO.
- 2. BA!N STEAE ISOLATION VALVE MAS 5 SEC. RAI. CLOSURE TINE.
- 3. *** NE ANS INSTRUMEN1S SUPPLIED BT NSSS VENDOR.
1 ^i1 ( ; v () I L /
~ . _ - __
- 'N ~ ,
~'
WSIDE l hSiCE TilC SPHIRE A u;;Ut + M-' TU R B I NE INSIDE TYPl 8v!L0lkG BUILDING
& / F, 'EAlh ;0NT.ON
! , STEAN l
FIG.10.3 1A 5lx~- Ai j TUNNEL i W a d
"'-T; . -
C7 m is 5:f:% TYP)y tip y_r4i n,; gut
**
O @ @ u (c ' [SIl- SLI f81NE SC 2 -M NNS puPLING SYSTEN FIG.B.3.2-2 9. W ASr i 4:n" X i lSLf --M ' _E2 -W NNS (qN8 TD TURBINE FC F0 d a STEAM SYSTEM. a f mu 2 F10.lC.2-1 Civ 5 C ., , (3 . My , FEECTATER PUNP i, & E [$j ' r TURRINE STEAM SUPPLY r SL 1I , l SLI j TO TURBINE FC ' ptgy; TO TURBINE BYPASS SYSTfu SC2 - M NNS $gyptigg FIG.10.4.4-1 l SYSTEu F I G. 9. 3. 2-D TM M I UI SEAllE SYSTEM TO ATuCSPHERE TO VENTILATION VENT 2* FIG.6.2.3.1-1 i p g L L1 h_.] l F I G .10. 3 18 MAIN STEAM SYSTEM 'N - - - -l PsR REFERENCE PLANT A'JXIll ARY FEE 0eiTER SAFETY ANALYSl5 REPORT F TURB hE 58ESSAR.P] _ ., i s V ( : ,W 35 AMENDutNT 30 i 29 77 INSIDE INSIC~ ;q CONTAINN NT - 'w ANNDLUS TC STRUCTURE gglLDINg h NAth STEAU ! 0 (535-3) i SAFETY VALVES _J SC2 --> 4. hhS(TVP ) (TyF .) g p* , f c o .k-} _ .k,_ i ~ - - ~ T T _ i * [~ , g n SC.z }k h J 'v' h-b- v \ / ,~~ NSSS R10 Elk .J u 14F ANC CONTROL -[ T Pf h- , SO ' i j ' r STEAu GlNERATOR L - -- - - l - - - - - J p ___ _______________ d RO, ass 4) W 7 i FT I
- I i i I
I g [~ [~ d b ?I i ? i __^ T _ g g MCB ~ T / [" NS$$ PROTECTla ~ - l it AND CONTROL . PT PT , i l yggo, L____ _ _ _ _a. _ _ _ ; d F0 Q( i ,0
- y. x1 o
,4x- ' ($ l f c. OUd I# b 1 MAIN I TUNNEL TO TURBINE , r BYPASS SYSTEM FIG.10.4.4-1 AUXILIARY ' STEAN SYSTEM i FIG.10.4.12-1
- STEAM SYSTEM FIG.10.2-1 I
l l l TURBINE STOP YALVE(TYP) l F I G.10. 2-1 I l l EJ __ _ _____________ ___________J i l T l I I G) I TO TURBINE l ; STEAM SYSTEM FIG.10.2-1 l FEEDWATER PUMP
- TURBINE STEAM SUPPLY
___-____]
- TO TURBINE BYPASS SYSTEM I 16'l Flc.10 4 4-1 FIGURE 10.3-1 TEM; l VENTILATION MAIN STEA51 SYSTBt
" l FIG.6.2.3.1-1 PWR REFERENCE PLANT l SAFETY ANALYSIS REPORT I SWESSAR-Pl l l 81W , 3 o u ;) 1 '" AMEN 0 MENT 30 1/ / t + FIG 10 3-tAl INSICE INS!DE ANNULUS --> - TURBINE INSIDE TO INSIDE BUILDING BUILDINF" CCNT AINUENT --*t4- ANNULUS ATMOSPHERE , (TYP;NNS A 4 7* lN: Sil l STRUCTURE BUIL0 LNG g b WAIN STEAM l ## A+ j@ ,h (SC2 "e> =$=' l { (TYP) I ,0, O ~~ ' l NAIN STEAM ISOLATION YALVE SC2- - NNS l (TYP) MSS-C MSS-2' l NNS 4 3s SC2(TYP yh ) l M b@ f@- [@- M y i '- l I e v r SC2 SC2 -b+ NNS y pt STEAu I GENERATOR --Y ' SC3 [ - - -- - -- - _ _ _ _ _ NAIN STEAM SAFETY & , i I VALVES (T?P) sb ! $th~ bh LY k~ X l 1 L ca 3 l C2 SC2 - NNS I LMSS-3 l uSS-O l ' i p h hF [0-I I h l Q) -- : SC2 -hSNS g i i a + STEAM GENERATOR TO ATMDSPHERE Li l in > l l \ S / ,o 4 "' 5 i AUIlLIARY FEE 0 RATER ! CU FIG 10 3-1B PUNP TURBlNE NGTES THIS SYSTEN IS NON-NUCLEAR SAFETY CL ASS (NNS) EXCEPT WilERE OTHERNISE NOTED INSIDE INSIDE INSIDE - ~ - ~-~~1 ANNULUS ,, pe MAIN ?lI TURBINE BU!LDING STEAM OUMP & ATMOSPHERE l MAIN STEAM BUILDING STEAM TUNNEL a FW PUMP TURBINE /PT (TYP)$ ATMOSPHERIC DUMP 4 .__ CONTROL P I VALVE (TYP) I TO TURBlNE NNS;, i ; BYPASS SYSTEM g l_ _ j F I G.10. 4. 4 - 1 qE]J T ._ SC2 - (TYP) Sll .r- 3LI ll MAIN s STEau CTV i SC2 +4 NNS - TO AUXILIARY ' - STEAM SYSTEM IRAil0H O FIG.10.4.12-i VALVE (TYP) I F0 p F0 TO TURBINE @ STEAM SYSTEM p{ ' o SLI SLI f F I G.10. 2 1 1 A LING SYSTEM SC2 ] 4-NNS RMP RMP Q l M ______.3 V TURBINE STOP V ALVE(TYP) i - " - , L h i FIG.10.2-1 RMP MP m =, , , Vi i i FC)h E/Jh (TYP) SLI SLI ,RS 'i L -- L J , '!i SC2 h MNS RE k CB FE SLI Sll _ _ . <. y TO TURBINE PLANT CCNT.ON CONT.0N SAMPLING FIG.10.3-18 FIG.10.3-lE SYSTEM FIG.9.3 2-2 SC2 -**- NH S FIG.10.3-1A NAIN STEAN SYSTEN PER REFERENCE PLANT SAFETT ANALYSIS REPORT qg b v v(; SIESSAR-P1 3 EM AMENUMENT 30 I '28/77 A INSIDF INSIDE [--------- CONTAIN4ENT : ANNULUS STRUCTUPE BUILDING l 1 l NNS - MAIN STEAM SAFETY SC2 -+ ESFAS h-7 VALVE S (TYP) (TTP) ii ; i PT* PT* hl hh I ,i I-i1 p MSS-1) " TT , i l i ) INTEGRATED ll PT T h__ 8 MSS-2 l ll ' l l l Mi l l l l l V ASP l l1 D r--- T ~ T -- -- MCB ASP ' l l I MCB ASP / l \ /M /M l D MCB ll SP -__ l g WG i i g GENE A DR i 1 I I __ L \I PT SC2 $N CONT. ON T I G. 10.3. NOTES:
- 1. THIS PORil0N CF THE EAIN STEAR SYSTER IS SAFETT CLASS 2 (SC2) EICEPT EMERE OThERTISE NOTED.
- 2. RAIN STEAN ISOLATION VALVE HAS 5 SEC. MAI. CLOSURE TluE.
- 3. *** ME ANS INSTRUMENT SUPPLIED BY NSSS VENDOR.
OuU i INSIDE I INSIDE 3 SPHERE I ANNL'LUS W- +4--- T U R B I N E P' ,I INSIDE Bul10 LNG Bull 0 LNG ji MAIN CONT.0N STEAM FIG.10.3-1A i TUNNEL , a , ~ MA N STEAM / ) ATMOSPHERIC QUMP / V AL VE(TYP) ' CONT.0N ( lS M ,r d lj FIG.10.3-IA. C3 -TURBihE STOP V ALVE MAIN L ,, (TYP) STEAM s CT SC2 -O-NNS FIG.10.2-1 'I ISOL ATION C VALVE (TYP) ; i k r0 F0 j afs ! A CB 8, <J sti TO TURBINE , fC sti l PLANT SC2 - >g- NNS SP RMP RMP j SAMPLING G 3.2-2 L_ _ J _ L q '" _ I. _ q' l lb" -J RS RS RT ) X t _. _1_ _7 J SLI h r- SLI !l SC2 h NNS TO luRBINE 7 X STEAM SYSTEM F0 F0 kg L FIG.10.2-1 j f d
- TV NE TE SUPPLY 2
p [$ll'] [ TIT] TO TURBlNE g f. BYPASS SYSTEM SC2 - NNS SAM ING SYSTEN FIG.9.3.2- 6 7g ig g SEALING SYSTEM TO ATMOSPHERE r V NT Pl FIG.6.2.3.1-I M FIG.10.3-1B } \ MAIN STEAM SYSTEM PER FIFERENCE PLAh"r IllARY FEEDIATER SAFETY ANALYSIS REPORT P TURBINE SIESSAR-P1 BSW f; 'l 9, i-J AMENOMENT 30 1/28/77 A INSIDE INSIDE , TO A CONTAl eENT +4_ ANNDLUS ( STRUCTURE SulLDING i , h h ESFAS F, I SC2 - > 4 hNS(TYP) gg, ! ' SAFETY VALVES (TYP) l l , , i ' ' S l l h-(T I PT PT ! ' i I I Il S h I ll D O ~~ # Y I , MSS-) J .L -- } r- _ 1 CB _ k I Ii - - CONT. ,RCM m {PT _ _ Ob '_0 d-' #_ _ _ _ _ _ _ . Afic l Il l INTEGRATED CONTR0'. SY STEM MCS ASP MSS-4) lg ,---- ______J.________.____ g l lI MCB ASP i ll I l l i yL,__L_] M Q_EL , li l i . ' PT PT hhh V I o STEAM I _ GENERATOR 7 i i b___ l ~ F0 3y X- !'i '"o QyQ 1 5 T / s 2 i i / 2 T 1 R 9 M T O 1 NP T E A E N E T L R M SP S D Y I N SES E V CY MNL l A A EA RN P E EA - r ClT F R o 3S EY A t O N RT S ma I E S er GAI WA R FWE te FMPS S I sn ye sg mm aa ee tts R sse A l S S nmz i oz E aro C Mf n ) S S r M o ( t ma er M F te T sn ye S Y sg S M 5 mm aa A 0 ee E 2 tts T sse S F l I A S nmz ioz I - aro A. B Mf n F S r T r o i t T ma O er P te sn ye E sg C A F F mm aa E S ee T 3 tt s t - sse I R l t A S nmz ioz J aro E E T R Mf n S Y S r o t a mr te sn ye sg mm aa 1 ee 4 tts - sse R l S A nmz ioz . E aro R Mf n 4 . - I : O 1 s N - - ' . S 7( C - LC D S I M .s
- 10.4 I
\ G - ,- (> U U is, SWESSAR-P1 10.4 OTHER FEATURES OF STEAM AND POWER CONVERSION SYSTEM 10.4.1 Main Condenser The function of the main condenser is to condense steam from the three low pressure turbine exhausts, the three feedwater pump turbines, and from the turbine bypass system (Section 10.4.4) , and to collect miscellaneous drains. The major connections to the condenser are shown in Fig. 10.4.1-1. 10.4.1.1 Design Bases The design bases of the main condenser are:
- 1. The condenser shall not be safety related.
- 2. The condenser shall maintain normal turbine backpressure for all operating conditions. Backpressu re during operation of the turbine bypass system may rise above the normal continuous range but shall remain within limits specified by the turbine manufacturer.
- 3. The condenser shall deaerate the turbine exhaust at all loads.
10.4.1.2 System Design The condenser is of conventional triple shell, single-pass divided water box design having impingement baffles to protect the tubes, steam and condensate equalizing sections, and flexible expansion joints between the condenser necks and the turbine exhaust flanges. Partitioned hotwells, open at one end, with sample p< .ints in each section, and leakage collections troughs on each tube sheet are provided to detect inleakage of circulating water (Section 10.4.5) . The total hotwell water storage capacity is equivalent to approximately 5 minutes of flow at full load operation. Two feedwater heaters are located in each condenser neck. The design equilibrium concentration of radioactivity in the condenser during normal operation for the design cace of 1.0 percent failed tuel coincident with 166 gallons per day steam generator primary to secondary leakage is the same as the equilibrium concentration in the main steam system. Table 11.1.3-2 gives the concentrations for various isotopes. During shutdown, the radioactivity in the condenser decreases. The anticipated air inleakage limit for the condenser is 52.5 setm (W-41, C-E) or 45 scfm 04-3S, BSW), calculated using the 19 method given in Heat Exchange Institute " Standard for Steam Surface Condensers," Sixth Edition, 1970. 10.4-1 Amendment 19 12/12/75 *} /o 0( 0 0 1 SWESSAR-P1 10.4.1.3 Safety Evaluation The condenser is designed for operation at maximum calculated plant output. Motor-operated butterfly valves are provided at the condenser outlet water boxes for maintenance. Water box vacuum br eakers interlocked with the circulating water pumps protect the water boxes in the event of circulating water pump g trips. The potential for hydrogen buildup in the condenser is n eg ligible. Noncondencable gases entering the condenser are removed by the condenser evacuation system (Section 10.4.2) . Pressure relief diaphragms furnished on the turbine exhaust shell avoid buildup of excessive pressures in the condenser shell. 10.4.1.4 Testing and Inspections Samples are taken from the condenser hotwells and from troughs mounted on the tube sheets to check the condenser for circulating water inleakage and to locate the condenser section containing the leak. 10.4.1.5 Instrumentation Applications All instrumentation on the condenser is nonsafety related. Level controllers and level alarms on the condenser are discussed under condensate and feedwater systems (Section 10.4.7). 10.4.2 Condenser Evacuation System The function of the condenser evacuation system is to remove noncondensable gases from the condenser shells. The condenser evacuation system is shown in Fig. 10.4.2-1. 10.4.2.1 Desian Bases The design bases of the condenser evacuation system are as follows:
- 1. The conden ser evacuation system shall draw the initial vacuum in the condenser shells during startup, maintain vacuum d uring operation, and dispose of the noncondensable gases from the condenser.
- 2. The condenser evacuation system is nonsaf ety related and is classified as nonnuclear safety (NNS).
9 10.4-2 Amendment 12 6/16/75 i SWESSAR-P1 10.4.2.2 System Design Two steam jet air ejectors, each having a double element first l12 stage and a single element second stage, complete with tubed inter- and af ter-condensers, remove noncondensable gases f rom the condenser shells. During normal operation, one unit operates with the other unit on standby. The steam jet air e jectors function by using steam from the auxiliary steam system (Section 10.4.12) . The auxiliary steam that condenses in the steam jet air ejector condensers flows through drain traps to the condenser (Section 10.4.1) . Two horizontal, motor-driven condenser air removal pumps are provided for initial condenser shell side air removal. The air removed from the condenser shells by the condenser air removal pumps is discharged to atmosphere. The air removed f rom the condenser shells by the steam jet air ejectors is discharged to the radioactive gaseous waste system (Section 11.3) after passing throuch a radiation monitor. 10.4.2.3 Safety Evaluation Maintaining vacuum in the condenser is necessary for operation of both the turbine bypass system (Section 10.4.4) and the t urbine-generator (Section 10.2) . Failure of the condenser evacuation system causes a gradual loss of vacuum in the condenser by buildup of noncondensable gases. When the pressure in the condenser creates too much of a backpressure against the turbine exhausts, the turbine generator trips. 10.4.2.4 Testing and Inspection Requirements Normally, one steam jet air ejector is in operation with the other on standby. The operation of these units is alt ernat ed periodically to eliminate the necessity for testing. The condenser air removal pumps normally operate only during startup and therefore necd not be tested during plant ope ration . 10.4.2.5 Instrumentation Applications All instrumentation in the condenser evacuation system is non-safety related. The condenser air removal pumps are manually started f rom the control room prior to plant startup. After sufficiently reducing pressure in the condenser during s tar tup , the condenser air removal pumps are manually shut down ano one steam jet air ejector is manually started. On indication of high absolute pressure in the condenser during normal operation , the second steam jet air ejector is manually started. 10.4-3 6(] ' ' ] Amendment 12 6/16/75 SWESSAR-P1 The steam jet air ejector discharge to the radioactive gaseous wasta system is monitored for radiation level. The radiation level is recorded and a high radiation level is alarmed. 10.4.2.6 Interf ace Requirements The Utility-Applicant shall . provide a supply of domestic water to 9 the condenser air removal pumps to be used as the compressing liquid for the pumps. This water is only required during plant startup and is not recoverable. Domestic water interface points are indicated on Fig. 10.4.2-1. 10.4.3 Turbine Gland Sealing System The function of the turbine gland sealing system is to seal the turbine shaf t (rotor) between both the turbine casings and the exhaust hoods and the utmosphere, thus preventing leakage of air into the condenser and leakage of steam from the turbine into the building. 10.4.3.1 Design Ba ses The design bases of the turbine gland sealing system are:
- 1. The system shall not be safety related and shall be designated nonnuclear safety class (NNS).
- 2. The systen shall seal the turbine continuously during startup and during full load operation.
- 3. The system shall prevent the occurrence of overpressure in the syst em.
10.4.3.2A System Description with General Electric Turbine A series of spring-backed segmented packing rings are fastened in the bores of turbine shells and hoods at every point where the rotor emerges tram the steam atmosphere. These rings are machined with specially designed teeth fitted with minimum radial clearance between the teeth and the turbine rotor. The small clearance and the resistance offered by the particular tooth construction so restrict the steam and air flow that it is held to a minimum. On pressur e packin gs , the small amount of steam that does leak past the packing teeth is piped from a leakoff passage in the packing casing to one of the stages in the turbine or to a feedwater heuter. This is done so that the heat energy in the steam can be utilized more efficiently. On vacuum packings, a very nall quantity of steam leaks into the exhaust easing and discharges to the condenser. 10.4-4 Amendment 9 , , 3 4/30/75 Uvo 6 - SWESSAR-P1 The steam seal header pressure is held autonatically by an air-operated feed valve and a direct acting unloading valve. At light loads, the steam seal feed valve supplies steam from the main steam system (Section 10.3) to the steam seal header. At higher loads, when more steam is leaking from the pressure packings than is required by the vacuum packings, the steam seal unloading valve discharges the excess to the condenser. During cold startup, the turbine gland sealing system operates f rom the auxiliary steam system. During normal operation, when requiring external steam supply, the system takes steam from the main steam system. A gland steam condenser and two motor-operated gland steam condenser exhausters maintain a slight vacuum in the system and exhaust the noncondensables to the ventilation vent 1 (Section 6.2.3.1) . The exhauster.e have automatically operated l9 discharge valves for isolation and regulation. 10.4.3.2B System Description with Westinghouse Turbine The turbine rotor ends are sealed by rotor glands of the labyrinth type, consisting of a number of seal strips machined into seal rings. Steam from the main steam system is throttled to the steam seal header to seal the turbine glands during startup. As the turbine load is in creased , the steam pressure inside the high pressure turbine increases and the steam leakage path is outward toward the rotor ends, thus eliminating the need to supply sealing steam to these glands. When this occurs, leakage from the high pressure glands supplies the steam sealing requirements for the low pressure glands. The leakoff steam and air mixture then flows to the gland steam condenser which is maintained at a pressure slightly below atmospheric so as to prevent the escape of steam from the ends of the glands. The gland steam condenser returns seal leakage to the main condenser as condensate. The air inleakage to the glands is exhausted from the gland steam condenser by one of two exhaust blowers to the ventilation vent ' (Section 6.2.3.1) . ,9 10.4.3.3 Safety Evaluation An analysis of a turbine gland sealing systen malfunction is given in Cection 15.1.35. Exhaust for this system passes to the ventilation vent where it is monitored for possible radioactive 9 releases. 10.4.3.4 Testing and Inspections Operation of the gland steam exhausters will be alternated periodically, thus eliminating the need for periodic testing. 10.4-5 Amendment 9 4/30/75 <0
- fVO i '.
SWESSAR-P1 Other components of the system will be tested and inspected as recommended by the turbine manufacturer. 10.4.3.5 Instrumentation Applications Instrumentation, as recommended by the turbine manufacturer to monitor systs operation, is provided. 10.4.4 Turbine Bypass system The function of the turbine bypass system is to enable the NSSS to follow a turbine generator step load reduction up to approximately 50 percent, without causing a reactor or turbine trip, and without lifting the main steam safety valves. The turbine bypass system is shown in Fig. 10.4.4-1. O 7 c - - - b u( u 3 ./ 10.4-6 Amendment 9 4/30/75 SWESSAR-P1 10.4.4.1 Design Buses The design bases of the turbine bypass system are as follows:
- 1. The turbine bypass system shall not be safety related.
- 2. The turbine bypass system shall be designed in accordan~ wi th AIFT 0 1.1.0b-1971.
- 3. 'Ih e turbine nypass system shall enable the turbine-genera tor (Section 10.2) to take a step load reduction up to 50 percent without causing a reactor or turbine trip and without lifting the main steam safety valves.
- 4. A single turbine bypass control valve sticking open shall not cause an uncontrolled plant cooldown.
10.4.4.2 System Design On a large external electrical load decrease (up to 50 percent) , the turbine bypass system relieves main steam directly to the condenser, thus preventing a reactor or turbine trip and lifting of the main steam safety valves (Section 10.3). The turbine bypass system includes two turbine bypuss headers, branching trun the main steam manifold in the main steam system (Section 10.3), and individual bypass valves between the bypass 9 header and the condenser. An uncontrolled plant cooldown caused by a single valve sticking open is prevented by the use of a group of smaller valves installed in parallel instead of a single larger valve. The full capacity of the turbine bypass system is 40 percent of muximum calculated steam flow ut tull load steum pressure which, together with the t;SSS transient capability, meets the design requirement in 10. 4.4.1 (3) . This steam flow is equally distributed among the three condenser shells by the preset opening sequence of the turbine bypass control valves anc by use 9 of pertoruted distribution piping inside the condenser. Af ter a normal shutdown of the turbine generator leading to plant coolcown, the turbine nypass control valves are opened to release steam g enerated f rom reactor coolant system sensible heat (Chapter 5) . Reactor cooldown, programmed to minimize thermal transients and based on sensible heat release, is accorrplished by gradually decreasing the setpoint of a steam pressure controller. This closes the turbine bypass control valves, thus trans1 erring the cooldown process to the resicual heat removal system (Section
- 5. 5.7) .
10.4 -7 ffn - - Amendment 9 00V a - 4/30/75 SWESSAR-P1 10.4.4.3 Safetv Evaluation All or several of the turbine bypass control valves can be opened in a preset sequence if the condenser vacuum permissive interlock is satisfied. During startup, shutdown, operator training, or physics testing, the turbine bypass control valves can be actuated remotely from the main control board. The turbine bypass centrol valves are prevented f rom opening on loss of condenser va cuum and, in such a case, exces s steam pressure is relieved to the atmosphere through the main steam safety valves and dae atmospheric steam dump valves (Section
- 10. 3) . Interlocks are provided to reduce the probability of inadvertent opening of the turbine bypass control valves.
10.4.4.4 Inspection and Testing During refueling shutdowns, the turbine bypass control valves and turbine bypass system controls will be inspected and tested for proper operation. Inservice testing for partial opening will be done periodically. Turbine bypass system piping will be inspected and tested in accordance with paragraphs 136 and 137 of ANSI B31.1.0b-1971. 10.4.4.S _ Instrumentation Applications Manual controls and loss of condenser vacuum interlocks are provided for the turbine bypass control valves. Automatic signals to open the turbine bypass control valves are discussed in Section 7.7 of the USSS Vendor's SAR. 10.4.4.6 Interface Requirements g Interf ace information applicable to the turbine bypass system, as presented in the respective NSSS Vendor's SARs, is discussed in Table 10.1-2. (. 4 U% \) J ./ 10.4-8 Amendment 9 4/30/75 SWESSAR-P1 10.4.5 Ci culating Water System This system and the vacuum priming system (if required) will be described in the Utility - Applicant's SAR. Interf ace reuuirements for the design of these systems are:
- 1. The systems shall not be safety related and shall be classified nonnuclear safety (mis) .
- 2. The circulating water system shall be physically isolated and remote from both the ultima te heat sink (Section
- 9. 2.5) and the reactor plant service water system (Section 9. 2.1) , so that a f ailure in the circulating water system will not be able to render any part of the reactor plant service water system inoperable.
- 3. The type of circulating water system, the amount of heat rejected to the condenser which must be removed by the circulating water system, and the need for a vacuum priming system will be determined for the specific site and described in the Utility-Applicant's SAR.
- 4. Circulating water system piping interface points with the condenser are as shown on Fig. 10.4.1-1.
- 5. Circulating water system piping interface points with the turbine plant service water system are as shown on Fig.
10.4.11-1. 10.4.6 Condensate Polishing System The function of the condensate polishing system is to remove from the condensate stream impurities resulting from condenser tube leakage to produce a high quality effluent capable of meeting feedwater and steam generator chemistry specifications. The condensate polishing system is shown in Fig. 10.4.6-1. 10.4.6.1 Design Bases The design bases of the condensate polishing system are: //r i O b g, inu 10.4-8A Amendment 9 4/30/75 SKESSAR-P1
- 1. The condensate polishing system shall not be safety related and shall be classified nonnuclear safety (NNS).
- 2. The system shall be sized to accommodate 100 percent condensate flow.
- 3. The system shall naintain the condensate water chentistry in accordance with the requirements of t'..e NSSS Vendor.
- 4. Suiticient demineralizer redundancy shall be provided to allow denineralizer regeneration while the system retains its normal polishing capacity.
10 .4.6.2 System Description The condensate polishing system consists of mixed-bed demineralizers in the condensate stream between the condensate pump discharge and the steam jet air ejector condensers. These lU I demineralizers are capable of handling the full condensate flow while one out of service demineralizer is being regenerated or is on standby. The resin used in the demineralizers is of the H+-OH- type, with the two resin types mixed in equal proportion by volume. The number of demineralizers is dependent on the condensate flow, which in turn is dependent on the NSSS. For Westinghouse (RES AR-41) , Combustion Engineering, and Babcock & Wilcox, there H are nine demineralizers. For Westinghouse (RESAR-3S) , there are eight demineralizers. The polisher regeneration equipment consists of a cation regeneration vessel, an anion regeneration vessel, and a resin mix and storage vessel, as well as appropriate equipment for regenerating when the polishing system is operated in the ammonia cycle. The ammonia cycle system varies among manutacturers. Selection of the specific ammonia cycle system is the responsibility of the Utility-Applicant. A concentrated acid day tank and pumps are required to regenerate the cation resin in both the hydroaen and the ammonia cycle. A concentrated caustic day tank and pumps are also required to regenerate the anion resin in the hydrogen cycle. Recovered water, acid, and caustic tanks und pumps reduce the cost of regeneration and minimize the volumes requiring waste treatment. The waste front the condensate polisher regeneration contains a varied mixture of dissolved and suspended solids. Wastes with a conductivity greater than 50 micromhos, i.e., high conductivity waste, are collected separately from low conductivity waste, i.e., waste with less than 50 micromhos. The suspended iron oxides that are collected from the condensate system are predominantly low conductivity waste. 9 10.4-9 Amendment 17 b< u o i l 9/30/75 SWESSAR-P1 High conductivity wastes are neutralized by the required reagent in a 22,000 gal neutralizing tank before transfer to a 36,000 gal storage tank. Neutralized wastes are pumped to the radioactive liquid waste system (Section 11.2) for evaporation. The evaporator distillate is returned to the low conductivity waste sump. Low conductivity wastes are collected in a surge tank to minimize flow variations downstream from the regeneration equipment. These wastes are pumped at a rate of 75 gpm through a filter and cleanup demineralizer. The demineralized water is returned to tha recovered water tank, to the condenser hotwell, or to the makeup water supplied to the system. The solids collected in the filter are removed by high pressure air and water into a filter backwash tank located adjacent to the tilter. These ' solids are pumped to the high conductivity waste storage tank. The cleanup dunineralizer has a bed of mixed cation and anion resins of the sane size and resin ratio as the condensate polisher bed. The resin is sluiced to the polisher regeneration equipment and regenerated in the same manner as the polisher beds. Radioactivity is concentrated in the condensate polishing system only if primary -to-secondary leakage occurs in the steam generators. 10.4.6.3 Safety Evaluation The condensate polishing system is capable of removing, on a con-tinuous basis, condensate impurities resulting from normal anticipated condenser tube leakage expected during operation of the plant. Based on operating experience, this leakage ranges from 0.2 to 0.5 gpm. The maximum tube leak that can be treated continuously will vary with the quality of the condenser circulating water. However, the system provides some degree of protection even during massive leaks, such as one complete tube failure when using sea water as coolant, thus af fording " reaction" time to take corrective action or initiate a plant shutdown. In addition, the demineralizers provide an iodine DF of 1,000, and credit for this iodine removal capability is taken in accordance with Regulatory Guide 1.42. Radiation shielding is provided around the condensate polishing area for personnel protection in the event of primary-to-secondary leakage. All tanks in the system which are potentially radioactive are located in a diked area or the turbine building. Any overflow from these tanks is collected in one of three area sun ps. The contents of the sunps are initially processed in the condensate f?n UVU 5 j .V 10.4-10 Amendment 17 9/30/75 SWESSAR-P1 polishing system and are then pumped to the radioactive liquid waste system for further processing. 10.4.6.4 Testing and Inspections The condensate polishing system is in continuous operation whenever the condensate system is operating. Even with no condenser inleakage, each demineralizer will be regenerated periodically; tLerefore, operability of the domineralizers and the regeneration system will be demonstrated on a regular basis. System equipment will be tested for leakage and proper automatic operation prior to initial s tartup of the plant. The conductivity of the condensate leaving the condenser hotwells and the demineralizer effluent is monitored continuously during plant operation, thus providing a method of evaluating system performance and determining the need for cemineralizer regeneration. 10.4.6.5 Instrumentation Applications The influent condensate to the condensate demineralizers, the effluent from eech demineralizer, and the condensate returning to the condensate header are sampled by the turbine plant sampling system (Section 9.3.2) . The conductivity at each location is measured and recorded continuously, and an alarm signal is provided on the condensate polishing panel to indicate high conductivity. A differential pressure transmitter is provided to monitor the differential pressure across the condensate demineralizers. An alarm signal is provided on the main control board and on the condensate polishing panel to indicate high ditferential pressure. Flow transmitters, .ecorders, and flow indicating totalizers are provided on the effluent of each co,ndensate demineralizer and the condensate return piping to the condensate header. All tanks in the system which are potentially radioactive are provided with high level indicators and alarms on the condensate polishing control panel in the turbine building. In addition, tanks which are emptied by pumping are also provided with low level indicators and alarms on the condensate polishing control panel. The potentially radioactive tanks and their level indications are listed in Table 11.2-38. 10.4.6.6 Interface Requirements The Utility-Applicant shall select the type ot ammonia cycle system that will be provided by the condensate polishing system supplier. The ammonia cycle system interfaces with the nalance h of the condensa te polishing system as shown on Fig. 10.4.6-1D. 10.4-10A Amendment 17 ,7g 3 r3 9/30/75 hOu isI SWESSAR-P1 10.4.7 Condensate and Feedwater Svstems The function of the condensate and feedwater systems is to return condensed steam from the condenser (Section 10.4.1) and the drains from the regenerative feedwater heating cycle to the steam generators, while maintaining the water inventories throughout the systems con stant . The systems automatically control the water levels in the steam generators and condenser hotwell during steady state and transient condition.1. The tlow diagrams of the condensate und feedwater systems are shown in Fig. 10.4.7-1 and 10.4.7-2, respectively. O a : e 10.4-10B Amendment 17 9/30/75 SWESSAR-P1 10.4.7.1 Design Bases The design bases of the teedwater and condensate systems are:
- 1. The portion of the feedwater system extending from and including the feedwater isolation valves to the steam h3 generator inlets shall be safety related (QA Category I) and Seismic Category I.
- 2. The entire condensate system and the portions of the feed-water system upstream of the feedwater isolation valves shall h3 be neither safety related nor Seismic Category I.
- 3. The feedwater isolation valves nearest the containment shall be categorized as containment isolation valvca and, as such,
' hall be located as close as practical outside the tainment structure.
- 4. The portion of the feedwater system from and including the feedwater isolation valves to the steam generator shall be designed in accordance with ASME III, Code Class 2 and is designated Safety Class 2 (SC-2) .
- 5. The condensate system and the nonsafety related portions of the feedwater system shall be designed in accordance with ASME VIII and ANSI-B31.1.0b and ce designated nonnuclear safety class.
- 6. The condensate and feedwater systems shall be isolated from l13 the steam generators following a safety injection signal (SIS , Section 7.3) within the following time for each NSSS Vendor:
Babcock 6 Wilcox: 15 see Combustion Engineering: 20 sec Westinghouse: 5 sec 10.4.7.2 System Description Principal opera ting characteristics of the condensate and feedwater systems and their principal components can be found on Fig. 10.1-2. The condensate is drawn f. tom the condenser hotwell by three half-capacity notor driven, vertical condensate pumps, each operating at two-thirds capacity during normal operation. The pumps discharge into a common header which passes the condensate through a full flow condensate polishing system (Section 10.4. 6) , 10.4-11 g 7 7 Amendment 13 Luu i ss 6/30/75 SWESSAR-P1 the steam jet air ejector condensers, and then the turbine gland steam condenser. Downstream of the gland steam condenser, condensate pastas through three parallel flow paths of six stages of low pressure feedwater heating (fifth point heater drain coolers and f eedwater teaters no. 6 through 2) . The three flow paths are combined to ensure mixing and pressure equalization upstream of the feedwater pumps. The condenser hotwell is sized to store condensate sufficient for 5 minutes of full load operation. The three one-third capacity turbine driven feedwater pumps take suction from the condensate system and discharge into a common header. The feedwater then passes through three high pressure feedwater heater shells (heater no. 1) in parallel. Downstream from these heaters, the feedwater piping is headered for mixing and distribution of feedwater to the steam generators through individua feedwater flow contr ol valves. These valves are controlled by the feedwater control 'ystam (NSSS Vendor's scope) . A condensate storage tank provides storage of makeup condensate and accommodates surges within the turbine plant. Makeup f1cw to the condensate storage tank is automatically controlled based on water level in the condenser hotwell and the condensate storage tank. Automatic heating maintains a minimum water temperature in the condensate storage tanks of 40 F. The condensate storage tank is sized to accommodate surges from the turbine plant when the tank level is already at its normal maximum level, thus precluding overflows from the tank. The feedwater/ condensate passing through the feedwater heaters is heated by extractions taken from the turbine steam system (Section 10. 2) . The feedwater heaters are horizontal, two pass, fixed tube sheet, U-tube heat exchangers. The fifth and sixth point heaters are located in the condenser neck. Drains from the first, second, and third point heaters cascade to the shell side of the second, third, and fourth point heaters, respectively. Drains from the fourth point heaters are pumped forward into the condensate system between the third and fourth point heaters. Drains from the fifth point heaters pass through an external drain cooler in the condensate system to the condenser. Drains from the sixth point heaters and drains f rom the gland steam condenser and the steam jet air ejector condensers pass to the condenser. The first, second, and third point heaters have drain cooler sections. A bypass is provided around the feedwater pumps to allow the condensate pumps to fill the steam generators during startup, when the feedwater pumps are inoperable. p Ch emical feed equipment is provided to ensure proper chemistry control of the steam system during all modes of operation. The 10.4-12 Amendment 21 2/20/76
- s. 1 LL N) i s '?
SWESSAR-P1 primary objective is to minimize corrosion of the steam generator internals, with secondary objectives being to prevent or minimize turbine deposits due to carryover from the steam generator; to reduce corrosion in the steam /feedwater cycle; to minimize sludge deposits in the steam generator; to prevent scale deposits on the steam generator heat transfer surfaces and in the turbine; to minimize feedwater oxygen content; and to minimize the potential for the formation of free caustic or acid in the steam generators. These objectives are met by system chemistry control after sampling, including comprehensive continuous sampling and laboratory analysis, chemical injection at selected points, normally continuous blowdown from each steam generator (for W41, W3S, and CE only) , and chemical protection of the steam generator and feedwater train internals during outages. 21 Chemicals for oxygen scavenging and pH control are added to the condensate system downstream from the condensate demineralizers. This allows good mixing in the condensate /feedwater systems prior to the entrance of the feedwater into the steam generator. Chemicals for oxygen scavenging and pH control can be added to the feedwater and/or auxiliary feedwater systems to allow manual addition of chemicals to the steam generators during startup and shutdown conditions when addition to the condensate system is either not effective or not sufficient. For example, addition to auxiliary feedwater is required during startup and during wet 'ayup of the steam generators when chemicals are required in great quantities. Chemical solutions are mixed and stored in covered tanks. The solutions are pumped from the tanks into the appropriate system by positive displacement pumps with adjustable strokes. 10.4.7.3 Safety Evaluation The condensate and feedwater systems are capable of operation at full load with one condensate pump out of service and at partial load with one feedwateg pump out of service. A loss of normal feedwater flow results in a reduced capability for steam generator heat removal. Such a loss could result from a pipe break, pump f ailure, valve malfunction, or loss of a-c power. In the event of such an occurrence, the auxiliary feedwater system ensures a sufficient supply of cooling water (Section 10.4.10) . Malfunction of any low pressure feedwater heater shell necessitates isolation of the flow path in which the malfunctioning feedwater heater shell is located. Two motor-operated isolation valves are provided for each train of low pressure heater shells and for each first point heater. In case 10.4-12A //n 5 Amendment 21 UvV 1ss ?/20/76 SWESSAR-P1 of rr.alfunction of any of the heater shells, the isolation valves are closed and a motor operated bypass valve is opened, pennitting flow +o be bypassed arocnd the out-of-service feedwater heaters. The turbine generator loading may be reduced when less than three strings of heaters are in service. The effects of condensate and feedwater systems equipment malfunctions on the reactor coolant system are described by the NSSS Vendor. A bypass is provided around the feedwater pumps to allow the condensate pumps to fill the steam generators during startup, when the feedwater pumps are inoperable. Release of radioactivity to the environment in the event of pipe rupture in the condensate or feedwater system is bounded by the release that would occur from a pipe rupture in the main steam system (Section 15.1.14) . 10.4.7.4 Testing and Inspections Piping in the condensate and feedwater systems will be hydrostatically tested during construction and all active system components such as pumps, valves, and controls will be functionally tested during startup. A bypass line with a locked closed valve is provided around the condensate polishing system for hydrostatic testing and prestartup system cleanup. Inservice inspections , as required by ASME XI, are discussed in Section 16.4.2. Samples are taken from the condenser hotwell, condensate pumps discharge, and feedwater pumps discharge to determine oxygen content, pH value, and possible contamination or deterioration. Safety class valves in the feedwater system u 10.4-12B Amendment 21 2/20/76 SWESSAR-P1 require testing as specified in Section 16.4.2 (for safety class valves) and Section 16.4.4 (for containment isolation valves) . 10.4.7.5 Instrumentation Applications The condenser hotwell level is automatically controlled by high and low level controllers. The high level controller opens the valve in the condensate return line allowing condensate to return to the condensate storage tank. The low level controller opens the valve in the condensate supply line allowing condensate to pass f rom the condensate storage tank to the condenser hotwell. High and low levels are alarmed on the main control board. f ~ uC (<) u. is/ 10.4 -13 Amendment 12 6/16/75 SWESSAR-P1 Low level in the condensate storage tank automatically opens the line from the demineralized water makeup system and a lower level alarms on the main control board. High level closes the makeup line and a higher level alarms on the main control board to alert the operator that makeup flow has not been stopped. The condensate storage tank level is continuously indicated on the main control board. The feedwater isolation vulves isolate the feedwuter pump upon 19 receipt of a teedwater isolation (FWI) signal. Steam generator water level is controlled by steam generator water level control equipment (NSSS Vendor's scope) . Minimum condensate flow is controlled by a flow contrcl condensate valve in a recirculation line to the condenser. A minimum recir culation flow control valve for each feedwater pump protects against undue temperature or vibration in the feedwater pump casing at reduced pump flow. 10.4.7.6 Interface Requirements Interface information applicable to the feedwater system, as presented in the respective NSSS Vendor's SARs, is discussed in Table 10.1-2. 10.4.8 Steam Generator blowdown System The steam generator blowdown system is used in conjunction with the chemical teed portion of the feedwater system (Section 10 .4.7) and the condensate polishing system (Section 10.4.6) to control the chemical composition and solids concentration of the feedwater in the steam generators. The design of this system allows for heat recovery by use of a flash tank that returns steam to the fourth point feedwater heaters and condensate to the condenser hotwell. This system applies to an NSSS provided by either Westinghouse or Combustion Engineering. Babcock & Wilcox utilizes a once through steam generator which does not require a blowdown system. The steam generator blowdown system is shown in Fig. 10.4.8-1. Table 10.4.8-1 lis ts the design and operating conditions of the steam generator blowdown system components. The hSSS design und operating interf ace parameters are given in Table 10.4.8-2. 10.4.8.1 Design Lases The design bases for the steam generator blowdown system are:
- 1. Piping and valves from the steam generators up to and including the containment isolation valves shall be 10.4-14 Amendment 19 1.2/12/75 s v i a
SWESSAR-P1 Safety Clacs 2, and shall be designed to ASMF Section III, Code Class 2.
- 2. Other piping and equipment in the steam generator blowdown system shall be nonnuclear safety class (NNS) and shall be designed to ANSI B31.1.0b-1971 and ASME Section VIII.
- 3. During normal operation, the steam generators shall collectively blow down liquid continuously to the steam generator blowdown system. In the event of a major steam generator tube leak, the steam gr~erator blowdown sys tem shall be capable of processing the maximum expected blowdown rate.
- 4. The system meets the design objectives Items 6, 7, 8, 9, and 10 of Section 11.2.1.
10.4.8.2 System Description The steam generator blowdown system consists of a flash tank and two pumps. Each steam generator is provided with a blowdown connection. The rate of blowdown for each steam generator is controlled by flow control valves. The liquid passes through the valves and flashes in the tank. In the flash tank, the steam is drawn off to the fourth point feedwater heaters, and the liquid is pumped to the condenser @ {s v{v0 1 Fq !s, 10.4-14A Amendment 9 4/30/75 SWEJSAR-P1 hotwell. One pump is normally operated. Upon high level signal in the flash tank, the second pump is started. Individual blowdown samples may be monitored separately to determine which steam generator is leaking. The steam generator can be manually isolated by the operator, based on leakage rate, activity level, and boron concentration. The steam generator blowdown line is isolated on a containment isolation phase A (CIA) signal which closes the containment isolation valve in each blowdown line. 10.4.8.3 Design Evaluation A failure analysis of the system components is presented in Table 10.4.8-3. Containment isolation valves are open during normal operation and close on loss of air or on a CIA signal. 10.4.8.4 Testing and Inspections Containment isolation valves in the steam generator blowdown system are tested monthly. In addition, containment isolation valves require testing as specified in Sections 16.4.2 and 8 16.4.4. 10.4.8.5 Instrument Applications The radiation monitoring of the steam generator blowdown system is described under the reactor plant sampling system (Section 9.3.2) . Solenoid operated pilot valves as shown on Fig. 10.4.8-1 are capable of actuation from the control room. 10.4.8.6 Interface Requirements 10.4.8.6.1 Westinghouse The information given in RESAR 41, Section 10.4.8, and in Table 10.1-2 is not applicable since this system is supplied by SSW. The maximum blowdown rate is 1 percent of the main steam flow. The SSW blowdown system meets this requirement. 10.4.8.6.2 Combustion Engineering In CESSAR, those portions of Section 10.4.6 that refer to the blowdown processing system are not applicable. The only requirement is that the system must handle the blowdown rate of 1 percent of the main steam flow. The SSW blowdown system meets this requirement. 10.4-15 Amen dment 8 3/28/75
- vv
<o 1 ivv 1 SWESSAR-P1 10.4.8.6.3 Babcock & Wilcox B-SAR has no blowdown system or interface requirements. O 10.4- 16 Amendment 8 3/28/75 e /. r 1 o O U t.) SWESSAR-P1 10.4.9 Turbine Plant Component Cooling System The function of the turbine plant component cooling system is to remove heat fran various nonsafety related turbine plant equipment. The turbine plant component cooling system is shown in Fig. 10.4.9-1. 10.4.9.1 Design Bases The design bases of the turbine plant camponent cooling system are:
- 1. The system shall not be saf ety related and shall be designated nonnuclear safety class (IMS) .
- 2. The system shall supply cooling water at a maximum temperature of 105 F to the components served by this system.
- 3. The system shall transfer heat to the turbine plant service water system, which is at a maximum inlet temperature of 95 F.
10.4.9.2 System Description The principal equipment served by the turbine plant component cooling system is as follows:
- 1. Turbine lubricating oil coolers (Section 10.2)
- 2. Electrohydraulic fluid coolers (Section 10.2)
- 3. Instrument air compressors and aftercoole rs (Section 9. 3.1)
- 4. Generator stator water coolers (Section 10.2)
- 5. Fourth point heater drain pump coolers (Section 10.4.7)
- 6. Exciter air cooler (Section 10.2)
- 7. Hydrogen coolers (Section 10.2)
- 8. Feedwater pump coolers (Section 10.4.7)
- 9. Condensate pump motor thrust bearing coolers (Section 10.4.7) 12 10.4-17 Amendment 12 e, n 1 a 6/16/75 Cs U 1vL
SWESSAR-P1
- 10. Turbine plant sample coolers (Section 9.3.2) 12
- 11. Turbine plant sample cooling bath makeup (Section 9.3.2)
Turbine plant component cooling water is pumped through shell and tube type heat exchangers where it is cooled by turbine plant service water. The cooled water then passes to the components listed above. Three 50 percent capacity pumps and three 50 percent capacity heat exchangers are provided. This capacity is based on the maximum heat load which could occur during normal plant operation with a service water inlet temperature of 95 F. At other times, each heat exchanger and pump are capable of supplying more than 50 percent of the required cooling capacity. The system is a closed loop. Variations in volume, due to temperature changes, are accommodated by a surge tank loccted at the pump suctions. The surge tank is at the high point of the system, and provides a net positive suction head for the pumps. The entire system and the equipment cooled by the system are located in the turbine building. Cooling water return piping from each component contains valves for control. The valves are either manually operated, positioned before plant startup, or automatic air-operated type, positioned by pressure or temperature control signals originating in the cooled system. Relief valves are provided on all equipment which might be overpressurized by a combination of closed cooling water inlet and outlet valves, and heat input from the isolated equipment. The s urg? tank level is automatically controlled and the tank capacity is sufficient to accommodate minor system surges and thermal swell. The surge tank is provided with a low level alarm to alert the operator to either a possible malfunction of the makeup valve or system leakage. Makeup is supplied from the demineralized water makeup system (Section 9.2.3) . An air-operated valve in the supply piping is automatically controlle l from a surge tank level switch. A chemical addition tank is connected to the pump discharge piping . To add chemicals to the system, the tank is isolated, drained , and filled with the desired chemicals. The tank isolation valves are then opened and the discharge pressure of the operating pump forces water through the tank, injecting the mixture into the ccramon return line f rom the equipment served and 12 the pumps. The desired water chemistry is obtained by the addition of appropriate chemicals for corrosion inhibition and pH control. 10.4-18 Amendment 12 6/16/75 fn 5 () C b Id SWESSAR-P1 10.4.9.3 Safety Evaluation The low pressure, high temperature, and surge tank low level alarms alert the operator to malfunctions in the system. If a malfunction causing low pressure, high temperature, or low lerel is not corrected, components and systems served by the system may be inadequately cooled, requiring the operator to shut down the affected component or system to prevent damage. During normal operation, two pumps and two heat exchangers can accommodate the heat removal load. The third pump and heat exchanger are spares, in the event of a pump or heat exchanger failure. All pumps and heat exchangers are rotated in service on a scheduled basis. 10.4.9.4 Testing and Inspections During the life of the plant, all portions of the system are either in continuous or intermittent operation, and performance tests will not be required. Components are accessible for visual inspections conducted periodically and following installation of spare parts or piping modifications to confirm normal operation of the system. Routine prestartup inspections will be performed in addition to periodic observation and monitoring of the system parameters during operation. 10.4.9.5 Instrumentation Applications Instrumentation and controls monitor system parameters and alert the operator to any component malfunction. Process variables of components required on a continuous basis for the startup, operation, or shutdown of the system are controlled from, and indicated and alarmed in , the control room. Those variables which require minimal operator attention are indicated locally. Motor control switches and indicating lights for the pumps are provided on the main control board. Electrically operated valves have controls and position indication in the control room. Pressure and temperature indicators in the control room monitor the system. A low pressure alarm in the system warns the operator of any major leak in the system. The operator manually starts the third pump upon a motor trip alarm of one of the operating pumps. Surge tank level is maintained by automatic control of the nakeup control valve. High and low level alarms in the control room warn the operator of a failed makeup control valve or of a major leak in the system. //- YG J i-10.4-19 Amendment 1 7/30/74 SWESSAR-P1 10.4.10 Auxiliary Feedwater System The function of the auxiliary feedwater system is to ensure a sufficient supply of cooling water to the steam generators so they can act as heat sin *w for sensible and decay heat removal from the reactor core under loss of power, feedwater line mal-function, or main steam line break conditions. The auxiliary feedwater system is shown in Fig. 10.4.10-1. 10.4.10.1 _ Design Bases The design baues of the auxiliary feedwater systen are': -
- 1. The system shall be safety related (QA Category I) and Seismic Category I.
- 2. The system, from and including the containment isolation valves and up to the connections with the steam 3 generators or the feedwater system, is designated Safety Class 2 and shall be designed in accordance with ASME III, Code Class 2.
- 3. The system, up to but not including the containment isolation valves, is designated Safety Class 3 and shall be designed in accordance with ASME III, Code Class 3.
- 4. The auxiliary feedwater storage tank (AEST) shall contain, as a minimum, sufficient water to hold the reactor at hot shutdown for two hours, followed by an 3
rderly cooldown consistent with the NSSS Vendor's requirements until the ~pr' essure at which the residual heat removal system starts operating has been reached.
- 5. The system shall deliver sufficient auxiliary feedwater 3l to the steam generators following loss of normal 8 feedwater to prevent lifting of the pressurizer relief valves caused by temperature and pressure buildup in the reactor coolant system.
- 6. The system shall deliver auxiliary feedwater against a steam generator pressure corresponding to the main steam safety valves set pressure plus accumulation.
- 7. The system shall include the capability of being controlled from the auxiliary shutdown panel following the unlikely event of control room inaccessibility.
10.4.10.2 System Description Principal design and performance characteristics of the auxiliary feedwater system and its principal components are summarized in Table 10.4.10-1. ,,p , ou o i J 10.4-20 Amendment 3 10/1S/74 SWESSAR-P1 The entire system is housed within the annulus building and containment structure and consists of auxiliary feedwater pumps, the AFST, and associated piping and valves. The auxiliary f eedwater pumps supply an emergency source of feedwater to the steam generators . The pumps ensure safe shutdown of the reactor in the event of a turbine generator trip with complete loss of a-c power and also supply water to the steam generators in the event of a safety injection signal to remove core sensible and decay heat. The pumps are on standby se rvice with only periodic startups to ensure operabi2ity and reliability (Section 16.4. 8) . The auxiliary feedwater pumps can be started either automatically as described in Section 7.3.3.8 or manually from the main control board. In addition, the pumps can be started manually from the auxiliary shutdown panel. Each auxiliary feedwater pump normally takes suction through a separate supply line from the tornado and missile protected AFST. Feedwater is pumped by the auxiliary feedwater pumps to each l13 steam generator through control valves. Flow is monitored in each supply line to the steam generators. Each control valve can be 'unually adjusted f rom the control room as dictated by the steam generator water level and auxiliary feedwater flow rate. The control valves can also be manually adjusted from the auxiliary shutdown panel. In the event of a loss of power, these valves fail as is. The control valves are equipped with handwheels for manual operation, if necessary. The auxiliary feedwater is discharged, depending on the NSSS Vendor, either directly to the steam generators or to the steam generators through connections in the feedwater piping inside the containment structure. This arrangement prevents loss of the auxiliary f eedwater should a f eedwater pipe break upstream of its containment isolation valve. Each auxiliary feedwater pump, when operating, recirculates o specified flow back to the AFST. The pumps are sized to supply their rated capacities plus this minimum recirculation and wear allowance. The continuous recirculation eliminates the need for redundant recirculation controls, which would normally be required to- ensure reliability of pumps which operate in termittently. Cooling water for each pump (and for the turbine oil cooler of the turbine-driven pump) is supplied fron an extraction point on the tirst stage of the associated pump. This provides a guaranteed source af cooling water under u.'l cperating cunditivna. - The turbine driva receives steam from the main steam piping uj-stream of the main steam isolation valves (Section 10.3) , thus ensuring that steum supply piping to the turbine drive is ut main steam pressure and temperature whenever operation of the turbine 13 10.4-21 , , 4 g Amendment 13 (. v i eV 6/30/75 SWESSAR-P1 driven pump is required . Steam traps are provided to remove condensate. Each motor-driven auxiliary feedwater pump receives power from a separate emergency electrical bus. The AFST has sufficient capacity to satisfy the design bases of the auxiliary feedwater system. The condensate storage tank provides a nonsafety related source of water to the AFST for longer periods of hot shutdown. When the motor operated valve in the line connecting the two tanks is opened, water will drain by gravity into the AFST. Makeup connections to the AFST are provided from the demineralized water makeup system (Section 9.2.3) . The long term emergency water supply is provided by connections to the pump suction lines f rom the reactor plant service water svatem (Section 9.2.1) . During plant startup, when main steam pressure is low, the auxiliary feedwater pumps provide feedwater to the steam generators by drawing suction from the AFST thus enabling sufficient steam to be produced to start up the main feedwater pumps. 10.4.10.3 Safety Evaluation Each auxiliary feedwater pump has sufficient capacity to remove sensible and decay heat from the reactor core. One pump is always available in the event of the loss of one emergency bus. The turbine-driven pump can be used for sensible and decay heat removal as long as adequate steam is available. An ample supply of steam for the turbine drive is available provided at least one steam generator is providing steam to the turbine drive and the associated main steam piping up to the main steam isolation valve is intact. The need for sensible and decay heat removal is reduced to a level where the residual heat removal system can be used before the main steam pressure decreases to the point where the turbine-driven pump can not operate adequately. Table 10.4.10-1 states the times allowed by the NSSS Vendors before the required auxiliary feedwater flow must be delivered to the steam generators. Based on investigations of the time required f or the diesel generators to reach operating speed, the diesel generator loading sequence, and the time required for the auxiliary feedwater pumps to reach operating speed, the auxiliary feedwater pumps are able to deliver the required flow in less igl than the times allowed by the USSS Vendors. The auxiliary teedwater pump flows and AFST capacities, shown in Table 10.4.10-1, are based on the requirements of the NSSS Vendors. Therefore, the auxiliary feedwater system has the capacity to accommodate the full spectrum of secondary system pipe breaks. ( u ~; v s ;u, 10.4-22 Amendment 19 12/12/75 SWESSAR-P1 Redundant piping flow paths ensure tha required flow for adequate decay heat removal, assuming a single failure. Controla on the auxiliary shutdown panel ensure that the reactor can be brought to hot shutdown should the control room become uninhabitable (Section 7.4) . The bornado and missile protected AFST meets Seismic Category I requirements and is available under all accident conditions. Isolation of the containment structure from the auxiliary feedwater lines can be performed under administrative control after the AFST is exhausted. The reactor plant service ' ster system provides an emergency long term source of kater to the suctions of the motor driven auxiliary feedwater pumps. Three 8 in. pipes connect to the pump suction lines. To prevent contamination of the auxiliary feedwater system, a spool piece is included at the auxiliary feedwater end of the piping, with a blind flange normally in h5 place. The spool pi : ;e is 8 in. diameter and approximately 1 f t long, and is stored alongside the pipe at the point of intersection. Service water is only required in the long term, after both the AFST and the condensate storage tank (if available) have been drained. Assuming that the condensate storage tank is not available, the spool piece must be installed before the AFST is emptied. The spool piece weighs approximately 100 lb, and can be installed by two workers in less thar, one hour. The shortest time in which the AFST would be emptied is approximately seven hours, for the Westinghouse RESAR-41 NSSS. 15 (Other NSSS storage capacitiec result in longer time periods.) This period allows more than adequate time for installation of the spool piece. The consequences of component failure are presented in Table 10.4.10-2. 10.4.10.4 Testing and Inspection Requirements The auxiliary feedwater pumps, their drives, and the pump discharge valves will be tested once a month, the pumps being tested as specified in Section 16.4.2. Steam is admitted to the turbine drive, and the motor drives are energized during these tests. Flow is established by recirculating auxiliary feedwater to the AFST. Following the completion of the test, the auxiliary feedwater pumps are shut off and the motor operated valves leading to the feedwater lines are opened. Safety class va]ves require testing as specified in Section 16.4.2 (for safety class valves) and Section 16.4.4 (for containment isolation valves) . t ! n 1 '^ tU" 10.4-22A OuO Amendment 15 8/8/75 SWESSAR-P1 10.4.10.5 Instrumentation Applications h The AFST is provided with redundant remote level indication and low level alarm on the main control board and indication on the auxiliary shutdown panel. A normally closed air operated valve in the pipe connecting the condensate storage tank to the AFST is opened upon low level in the AFST or can be manually opened following a loss of power. ,- 4 ,. .. '-) s' t U l y 10.4-22B Amendment 15 8/8/75 SWESSAR-P1 liigh level 3: does not ove ilow.the AFST closes the valve to ensure that the AFST ;3 Auxiliary feedwater control valves are normally open and can be remote manually modulated to maintain level in the generators. steum Auxiliary feedwater pump sta rting signals are given in Section 7.3.3.8. Flow indicators in the control room monitor system operation. 33 10.4.10.6 Interface Requirements Interface information applicable to the auxiliary feedwater system, as presented in the respective NSSS Vendor's SARs, is discussed in Table 10.1-2. 10.4.11 Turbine Plant Service Water System The function of the turbine plant service water system is to re-move heat from various nonsafety related plant equipment and to dissipate that heat to the environment. The turbine plant service water Fig. 10.4.11-1. system is shown in 10.4-23 ,g .. Amendment 13 0v0 t , u 6/30/75 SWESSAR-P1 10.4.11.1 Desian Bases O The design bases of the turbine plant service water system are: Y
- 1. The system shall not be safety related and shall be designated nonnuclear safety class (NNS).
- 2. The systen shall supply cooling water at a maxiznum temperature of 95 F to the components served by the system.
10.4.11.2 System Description The principal equignent served by the turbine plant service water system are:
- 1. Turbine plant component cooling heat exchangers (Section 10.4.9).
- 2. Mechanical refrigeration units (Section 9.2. 8) .
The major portion of the turbine plant service water system consists of three 50 percent capacity pumps and three self-cleaning strainers, along with the necessary piping and valves. The source of turbine plant service water will be discussed in the Utility--Applicant's SAR. During normal operation and normal plant cooldown conditions, two pumps discharge through the components listed above and t:1en into the circulating water discharge. Cooling water lines from each component contain valves for controlling flow. The valves are of the automatic air-operated type, positioned by temperature signals originating in the cooled system. , In addition to th e above equipnent, two 100 percent capacity recirculation pumps and appropriate instrumentation are provided 9l for cold weather operation of each set of mechanical refrigeration units. Operation of the recirculation loop ensures an inlet service water temperature suf ficiently high to enaW1e proper operation of the mechanical refrigeration units. 10.4.11.3 Safety Evaluation The low pressure alann alerts ther operator to malfunctions in the system. If a malfunction causing low pressure is not corrected, ccmponents and systems served by the system may be inadequately cooled, requiring the operator to shut down the affected component or system. No safety functions will be impaired by this component or system shutdown, because no safety related '~1 f unction is dependent on the system. (, e'Gv 1, i 10.4-24 Amendment 9 4/30/75 SWESSAR-P1 The lov temperature alarm on the mechanical refrigeration units @ inlet alerts the operator of a low temperature which may cause improper operation of the units. Following the alarm, the 9 10.4-24A Amendment 8 '~$ 3/28/75 y SWESSAR-P1 operator will manually start one of the recirculation pumps to raise the inlet service water temperature. The high temperature alarm alerts the operator to shut down the operating recirculation pump. During normal operation, two pumps can accommodate the heat removal load. The third pump is a spare so that in the ever.t of a pump failure, a replacement component is available. The- third pump is rotated in service on a scheduled basis. 10.4.11.4 Testing and Inspections During the life of the plant, all portions of the system except the mechanical refrigeration units recirculation pumps are either in continuous or intermittent operation, and performance tests are not required. The recirculation pumps will be tested periodically when recirculation is not required. When recirculation is required, the second pump will be rotated in service on a scheduled basis. Components are accessible for visual inspections conducted periodically and following installation of spare parts or piping modifications to confirm normal operation of the system. Routine prestartup inspections will be performed in addition to periodic observation and monitoring of the system parameters during operation. 10.4.11.5 Instrumentation Applications Instrumentation and controls monitor systs parameters and alert the operator to any component malfunction. Process variables of components required on a continuous basis for the startup, operation, or shutdown of this system are controlled from, and indicated and alarmed in, the control room. Those variables which require minimal operator attention are indicated locally. Motor control switches and indicating lights for the pumps are provided on the main control board. Pressure and temperature indicators in the control room monitor the system. A low pressure alarm in the system warns the operator of a major leak in the system or a failure of an operating pump. The operator manually starts the third pump upon a motor trip alarm of one of the operating pumps. When the inlet service water temperature to the mechanical refrigeration units is too low to permit proper operation of the units, a recirculation pump is started and the service water discharge valve throttled to maintain a sufficiently high service water temperature. Low and high temperature alarms alert the operator to either start or stop a recirculation pump. @ 10.4-25 " + SWESSAR-P1 10.4.11.6 Interface Requirements The source of turbine plant service water will be discussed in 9 Section 10.4.11 of the Utility Applicant's SAR. This water source interfaces with the balance of the turbine plant service water system as indicated on Fig. 10.4.11--1. 10.4.12 Auxiliary Steam and Condensate System The functions of the auxiliary steam and condensate system are to supply heating steam throughout the plant to various heating and processing equipment , and to recover the condensed steam frcxn the equipment served. The auxiliary steam and condensate system is shown in Fig. 10.4.12-1. 10.4.12.1 Design Bases The design bases of the auxiliary steam and condensate system are:
- 1. The system shall not be safety related.
- 2. Piping for this system shall be designed in accordance with ANSI B31.1.0-1971 and shall be designated nonnuclear safety class (NNS).
- 3. The system shall provide steam to the equipment requiring it both during normal operation and during plant shutdown.
- 4. The system shall have the capability to remove radioactive contaminants carried over from the equipment served.
10.4.12.2 System Description The auxiliary steam and condensate system is capable of supplying the auxiliary steam requirements of two nuclear power plants located adjacent to one another. The auxiliary boiler building and the equipnent contained therein and the steam supply to the dcxnestic hot water tank in the service building will be shared between the two plants. When one plant is shut down, auxiliary steam from the operating plant will be provided to the shutdown plant through a connection between the auxiliary steam supply headers of the two plants. A connection is also provided to return condensate from the shutdown plant to the operating plant to maintain fluid inventories in each plant. 9 10.4-26 Amendment 9 4/30/75 r b< u, Oo 5 -' ' 14 . SWESSAR-P1 For a single nuclear power plant, the system will be complete, as shown in Fig. 10.4.12-1 except the steam and condensate connections to the second plant will not be provided. The auxiliary steam supply header for each nuclear power plant normally receives its steam requirements from one of three sources. During normal operation, the steam is supplied f rom low pressure turbine extraction steam. When extraction steam pressure is too low, steam is supplied from the main steam manifold, through a pressure reducing valve. When main steam pressure is too low, or during plant shutdown, steam is supplied 10.4-26A Amendment 9 4/30/75 () (, ?) O SWESSAR-P1 either from the adjacent operating nuclear power plant or by the auxiliary boilers if there is only one nuclear power plant or if the second nuclear power plant is also shut down. Auxillary steam is used by and condensed in the equipment listed below:
- 1. Auxiliary boiler deaerator
- 2. Boron evaporator reboiler (Section 9.3.7)
- 3. Degasifier feed preheater (Section 11.3)
- 4. Waste evaporator reboiler (Section 11.2)
- 5. Boric acid batch tank (if required by NSSS Vendor)
(Section 9. 3.4)
- 6. Domestic hot water tank (Section 9.2.4)
- 7. Laundry waste evaporator (Section 11.2)
- 8. Building heating heat exchangers (Section 9.4.7)
- 9. Demineralized water storage tank heater (Section 9.2.3)
- 10. Condensate storage tank heater (Section 10.4.7)
- 11. Steam jet air ejectors (Section 10.4.2)
- 12. Turbine gland seal steam system (Section 10.4.3)
- 13. Steam generator blowdown system (Section 10.4.8)
The condensate from the boron evaporator reboiler, the degasifier feed preheater, the waste evaporator reboiler, the boric acid batch tank (if heating steam to this component is required by the NSSS Vendor), the laundry waste evaporator, and the steam generator blowdown system are collected in the annulus building auxiliary condensate receiver. On high level in the condensate receiver, the auxiliary condensate is pnmped by one of two 100 percent capacity pumps to the condenser via the condensate system (Section 10.4.7). I ,' The condensate f rom the building heating heat exchangers, the turbine gland sealing system, the demineralized water storage tank heater, and the condensate storage tank heater is collected in the turbine building auxiliary condensate receiver. On high level in the condensate receiver, the condensate is pumped by one of two 100 percent capacity pumps to the condenser via the condensate system. 12 The condensate from the steam jet air ejectors drains to the condenser (see Section 10.4.2). A line from the condensate pumps 10.4-27 / :, Amendment 12 00U l# U 6/16/75 SWESSAR-P1 12l discharge , containing a flow limiting device, connects to the turbine building auxiliary condensate receiver. 12l The device is sized such that the mass flow passing from the condensate system to the auxiliary condensate receiver is the same as the auxiliary steam flow to the steam jet air ejectors. When auxiliary steam is supplied from a second nuclear power plant, the condensate collected in the duxiliary condensate receivers will be pumped directly to the condenser of the plant which is operating. When the auxiliary boilers are operating, the condensate will be pumped to the auxiliary condensate tank in the auxiliary boiler building. The auxiliary boiler condensate tank provides the source of auxiliary feedwater for the auxiliary boilers. On low level in the auxiliary boiler condensate tank, makeup is provided from the demineralized water makeup system (Section 9.2.3) . On high level in the tank, the condensate is pumped by one of two 100 percent capacity pumps either to the condenser of either plant, depending on system fluid inventories, or to the auxiliary boiler deaerator, should low level be indicated in the deaerator. When operation of the auxiliary boilers is required, auxiliary boiler feedwater is pumped by one of two 100 percent capacity pumps from the auxiliary boiler deaerator. Blowdown from the auxiliary boilers flows to the auxiliary boiler blowdown tank. The portion of the blowdown which flashes into steam passes to the ventilation vent (Section 6.2.3.1) . Pressure in the turbine building auxiliary condensate receiver, the auxiliary boiler condensate tank, and the auxiliary boiler blowdown tank is equalized through interconnecting vent lines. Pressure in the auxiliary boiler deaerator is relieved to the same vent line through a restricting orifice. The vent lines combine and relieve to the radioactive gaseous waste system. The annulus building auxiliary condensate receiver also vents to the radioactive gaseous waste system. The drain and overflow from the auxiliary boiler blowdown tank flow to the aerated portion of the reactor plant vents and drains system (Section 9.3.3) . Two packaged water tube auxiliary boilers are provided for low load and shutdown operation. Each auxiliary boiler is equipped with controls and indication for automatic operation. 10.4.12.3 Safety Evaluation Together, the auxiliary boilers can accommodate a normal plant shutdown with normal building heating being provided. With loss of one auxiliary boiler, the other auxiliary boiler can accommodate a normal plant shutdown and an orderly plant startup. 10.4-28 g{r Amend SWESSAR-P1 with building heating to 40 F being provided. The auxiliary steam header is protected from malfunction of the pressure l3 reducing valve by a safety valve. 10.4.12.4 Testing and Inspections The auxiliary steam and condensate system is normally in continuous operation, and thus performance tests are not required. Visual inspections will be conducted following system maintenance to confirm normal operation of the systems. 10.4.12.5 Instrumentation Applications Each auxiliary boiler is provided with automatic combustion controls, burner controls, and a three element f eedwater control system. Safety valves on the auxiliary boilers are set at the design pressure of the auxiliary boilers. Control valves in the auxiliary steam lines to the various heaters regulate the temperature in the equipment being serviced. A relief valve on the boric acid batch tank jacket protects the batch tank. The level in the auxiliary boiler condensate tank is maintained by modulating a level control valve to control condensate flow to the auxiliary boiler deaerator and to the condenser. Level switches in the auxiliary condensate receivers and the auxiliary boiler condensate tank shut off the associated pump when the low level boiler switch settings are reached. Level controls naintain condensate level in the steam-to-water heat exchanger shells to improve heat transfer and allow subcooling of the condensate. 10.4.13 Lubricating oil System The functions of the lubricating oil system are to receive, store, purify, cool, and provide lubricating oil to the bearings of the main turbine generator and the feedwater pump turbines, to provide oil to the generator hydrogen seal oil system, and to provide high pressure oil to the turbine control system (if required by the turbine manuf acturer) . 10.4.13.1 Design Bases The design bases of the lubricating oil system are:
- 1. The system shall not be safety related and shall be designated nonuclear safety class (NNS).
- 2. The system shall furnish lubricating oil to the thrust and journal bearings of the main turbine and the feedwater pump turbines.
n i 7., 1, .a uu , I . v 10.4-29 Amendment 3 10/15/74 SWESSAR-P1
- 3. The system shall supply oil to the generator hydrogen seal oil system.
- 4. The system shall supply high pressure oil to the turbine control system (if required by the turbine manuf acturer) .
- 5. The system shall reclaim used oil from the equipment supplied by the system.
- 6. The system shall purity a side stream of oil on a continuous bypass basis.
- 7. The lubricating oil shall be maintained at a temperature compatible with the requirements of the turbine manuf a cturer.
10.4.13.2 System Description The lubricating oil system consists of two integrated sections (1) the turbine generator lubricating oil section which includes the bearing oil pumps, turbine lubricating oil reservoir, and the oil coolers; and (2) the lubricating oil conditiening and storage circuit consisting of clean and used oil storaae tanks, an oil purifier, and a motor driven transfer pump. The pump is a positive displacement type, capable of two-speed operation to accomplish both the transfer and circulation requirements. The clean and used oil storage tanks are located inside a fireproof room equipped with a trap drain, water sprays, and vent fans. The pumps and piping are arranged so that oil can be processed from the turbine lubricating oil reservoir or either of the storage tanks. The processed oil can be returned to either of the storage tanks or to the turbine lubricating oil reservoir as required. Vapor extractors purge oil fumes from the reservoir and exhaust them to the atmosphere outside the turbine building. Lubricating oil to the turbine generator is normally supplied from a turbine shaft driven pump. An a-c motor driven t urning-gear oil pump supplies bearing lubrication for startup, shutdown, and standby operation when a-c power is available. A d-c motor driven bearing oil pump, operated from the normal station battery, ensures bearing lubrication in the event a-c power fails. Turbine lubricating oil coolers, located in the turbine lubricating oil reservoir, remove heat generated in the turbine-generator bearings and transfer it to the turbine plant component cooling system (Section 10.4.9).
- n 1 O' U v 1 , .)
10.4-30 Amendment 3 10/15/74 SWESSAR-P1 10.4.13.3 Safety Evaluation In the event plant a-c power f ails, the turbine-generator safely comer to re'_ t using the backup d-c bearing oil pump. The normal station bat _ary provides an uninterrupted source of power to operate this pump. 10.4.13.4 Tests and Inspections, The d-c bearing oil pump will be tested periodically. Other components will be tested in accordance with turbine vendor recommendations. 10.4.13.5 Instrumentation Applications Turbine-generator bearing oil pressure and temperatures are indicated both locally and in the control room. Low pressure and high temperature alarms are provided in the control room. Alarms also announce low oil level in the turbine lubricating oil reservoir. 10.4-31 e eo q Amendment 3 CvV iuV 10/15/74 SWESSAR-P1 Table 10.4.7-1 is deleted. 8 1 of 1 Amendment 8 /,p 4 ^1 1VI 3/28/75 OvV SWESSAR-P1 TABLE 10.4.8-1 STEAM GENE'lA'IOR BLOWDOWN SYSTEM COMPONENT DESIGN AND PERFORMANCE CHARACTERISTICS Flash Tank Number 1 Capacity, gpm 380 Design pressure, psig 100/ full vacuum Design temperature, F 350 Material of construction Carbon steel 7 Flash Tank Pumps Number 2 Capacity, gpm 380 Design pressure, psig 115 Design temperature, F 350 Material of construction Carbon steel 1 of 1 Amendment 7 2/28/75 <c 'r' 0< 0 0 Iva SWESSAR-P1 TABLE 10.4.8-2 NSSS DESIGN AND OPERATING INTERFACE PARAMETERS Number Expected Design NSSS of Steam Blowdown Blowdown Vendor Generators Flow Flow Westinghouse- 4 60 gpm 360 gym 41 20 Westinghouse- 4 60 gpm 360 gpm 3S Combustion 2 150 gpm 375 gpm Engineering Babcock & not applicable Wilcox g/p $ o Uvu i vs 1 of 1 Amendment 20 1/23/76 SWESSAR-P1 TABLE 10.4.8-3 CONSEQUENCES OF COMPONENT FAILURES, STEAM GENERATOR BLOWDOWN SYSTEM Components Malfunctions Comments and Consequences System valves Loss of air or All air operated valves electric power fail closed on loss of air or electric power. Flash tank Rupture A relief valve prevents 7 overpressure of the tenk. Pump Failure The pumps are each full capacity so that system integrity is ensul- d. CL t. I i 1 of 1 Amendment 7 2/28/75 SWESSAR-P1 TABLE 10.4.10-2 CONSEQUENCES OF COMPONENT FAILURES AUXIL1ARY FEEDWATER SYSTEM Components Malfunctions Cbmments and Consequences Auxiliary feedwater Pump casing Each pump can be isolated pumps ruptures. by suction and discharge isolation valves. Full system capability can be retained by using any one pump. Pump fails to One pump can be used to start. achieve full system capability to bring 9 the plant to hot shutdawn conditions and to Either motor- remove residual heat for driven pump core protection. fails to start. System valves Improper posi- Should any single valve tion be improperly positioned, full system capability can be retained by using any one pump. l9 Failure to System capability, in the operate event of a failure of the control valve on the dis-charge of any one of the pumps, is retained by using any one of the other pumps. 9 Electrical supply Diesel Failure of one diesel generator fails generator does not pre-to operate. vent operation of another motor-driven pump or the turbine-driven pump, any one of which can 9 provide sufficient cooling water for all accident conditions. ~ , ,, o r; J L ,_ O iu W 1 of 1 Piendment 9 4/30/75 SWESSAR-P1 TABLE 10.4.10-3 has been deleted. 5 n 5 m (f, e o !uJ W 1 of 1 Amendment 9 4/30/75 SWESSAR-P1 TABLE 10.4.10-1 AUXILIARY FEPDWATER SYSTEM COMPONFXP DESIGN AND PF ItVtWMANCE MIA R ACTERISTI CS I t a=u ly= sign .nnd Per f ormance Ch< tract e_r int ics Turbine-Driven Auxiliary DEW C-E W-41 W-1S Feelw.st er Itm13 Numler 1 1 Design pressure, psia 1,700 1,900 1 1,900 1 Design temperature, P 120 120 1,900 Required flow to steam 120 120 generators, gia 1,235 875 htal developed head, ft 500 940 3,100 3,527 3,360 Design f low of purrps, gpm 1,660 1,186 693 3,300 1,275 !btor-Driven Auxiliary Feedwater Pumps Number 2 2 3 Design pressure, psia 1,800 1,900 1,900 2 Design temperature, P 120 120 120 1,900 Required iIow to steam 120 generators, gpm 620 438 htal developed head, ft 500 470 3,100 3,495 3,332 Design flow of puups, gpm 820 581 665 3,300 625 Auxiliary Peedwa ter Storarre Tank (AFST) Number 1 1 1 Capacity, gal 200,000 225,000 1 Design pressure, psia 250,000 214,000 Atmospheric At mospheric Design temperature, P I40 140 Atmospheric Atmospheric 140 140 Time allcwed before Within 40 within 45 within 60 required flow must see frura within 60 see from see fran see from be delivered to receipt of receipt of steam generators. signal initiating initiating signal signal signal CN c .s C.D C. 3 1 of 1 Amen <tnent 35 10/6/77 SWESSAR-P1 TABLE 10.4.10-2 CONSEQUENCES OF COMPONENT FAILURES AUXILIARY FEEDWATER SYSru' Components Malfunctions Cbmments and Consequences Auxiliary feedwater Pump casing Each pump can be isolated pumps ruptures. by suction and discharge isolation valves. Full system capability can be retained by using any combination of two pumps. Turbine-driven Two motor-driven pumps can pump fails to be used to achieve full start. system capability to bring the plant to hot shutdown conditions and to main-tain steam generator level. Either motor- The second motor-driven driven pump pump can be used to remove fails to start. residual heat for core protection. The turbine-driven pump can maintain a steam generator water level. System valves Improper posi- Should any single valve tion be improperly positioned, full system capability can be retained by using either of the other two pumps. Failure to System capability, in the operate event of a failure of the control valve on the dis-charge of any one of the pumps, is retained by using either of the other two pumps. Electrical supply Diesel Failure of one diesel generator fails generator does not pre-to operate. vent operation of the second motor-driven pump or the turbine-driven pump which can provide suffi-cient cooling water for all accident conditions.
- c. S o3
(,s . O IU W-3S 1 of 1 Amendment 17 9/30/75 SWESSAR-P1 TABLE 10.4.10-2 CONSEQUENCES OF COMPONENT FAILURES AUXILIARY FEEDWATER SYSTEM Components Malfunctions Comments and Consequences Auxiliary feedwater Pump casing Each pump can be isolated pumps ruptures. by suction and discharge isolation valves. Full system capability can be retained by using any combination of two pumps. Turbine-driven Two motor-driven pumps can pump fails to be used to achieve full start, system capability to bring the plant to hot shutdown conditions and to main-tain steam generator level. Either motor- The second motor-driven driven pump pump can be used to remove fails to start. residual heat for core protection. The turbine-driven pump can maintain steam generator water level. 3 System valves Improper posi- Should any single valve tion be improperly positioned, full system capability can be retained by using either of the other two Pumps. Failure to System capability, in the operate event of a failure of the control valve on the dis-charge of any one of the pumps, is retained by using either of the other two pumps. Electrical supply Diesel Failure of one diesel generator fails generator does not pre-to operate. vent operation of the second n:otor-driven pump or the turbine-driven pump which can provide suffi-cient cooling water for all accident conditions. ,,o on OOu tV . BSW 1 of 1 Amendment 1 7/30/74 SWESSAR-P1 TABLE 10.4.10-2 CONSEQUENCES OF COMPONENT FAILURES AUXILIARY FEEDWATER SYSTEM Comnonents Malfunctions Comments and Consequences Auxiliary feedwater Pump casing Each pump can be isolated pumps ruptures. by suction and discharge isolation valves. Full system capability can be retained by usino any combination of two pumps. 6 Turbine-driven Two motor-driven pumps can pump fails to be used to achieve full start. system capability to bring the plant to hot shutdown conditions and to main-tain steam generator level. Either motor- The second motor-driven driven pump pump can be used to re-fails to start. move residual heat for core protection. The turbine-driven pump can 6 maintain steam aenerator water level. System valves Improper posi- Should any single valve tion be improperly positioned, full system capability can be retained by usina either of the other two pumps. Failure to System capability, in the operate event of a failure of the control valve on the dis-charge of any one of the pumps, is retained by using either of the other two pumps. Electrical supply Diesel Failure of one diesel generator fails generator does not pre-to operate. Vent operation of the second motor-driven pump or the turbine-driven pump which can provide suffi-cient cooling water for all accident conditions. OuO n 1 I ^} C-F 1 ol' 1 Amendment 6 1/17/75 A (CES-5 / CVST} (CES-3 (tsS-4 FEEDIATER FRDW PUMP TURBINE 1 ' FROM ' ' I ' CONDENSER 1 r EIHAUST (TYY) CONDENSATE EVACUATION SYSTEu SYSTEM F I G .10. 4.1 -1 FIG.10.4.2-1 0 , ,, ,, , , , 0 , , , , ,rSCREEN , l , 3 7 i rS 3 ,,S S (VACUUN BREAKER (TYP) TO CONDENSATE aTSTEM FIG.10.4.7-1 (TYP) e e a o a A x m x 3 x - i ,S 4 i rS i ,S @ i rs .f S . y3 FROM CONDENSATE i r i r i fS , , 3 , POLISHING SYSTEW FTG 10.4.6-1B i r i , i f xCES-11 (CES-12 .C55-9 \ CTS / NOTE 2 FIG.10.4.1-1 CONDENSER PER REFERENCE PL ANT SAFETY !#ALYSIS AcFORT ~ SeESSAR-PI (' ,' , h ; , AMEMMNT 12 6'16'75 4 .h 1 th 2 [ FROM FEED-g BATER SYSTEM
- F I G .10. 4. 7-2
/ CMS,1 (CE S-2 (Typ) i r 1 r FR[M TURBINE PLANT SAaP.ING SYS FIG.9.3.2-2 1 r O FROM STEAM ' 'GEEPATOR BLO100tN SYS ~ )[V F 1 .10.4. 8-1 G3 i MN]f , ,S 1 'S M T - - r- ", "o LC [^ cs }H,SEE FIE.10.4.7-1 * ]{ a
- t'
\\ s\ (, ** s N N -lSEEFIC.10.4.7-1 g4 T m oc \\ 's LC t $e ' {SE E FIG.1U.4.7-1 M o g 1 2 0 $ 3 S 3 , S i r i t TO TURBihE PLANT SAMPLING SYSTEM TO CONDENSER F I G. 9.3.2-2 EVACUATION SYSTEM (TYP) FIG.10.4.2-1(TYP) i t i r 1 l (CES-7 (cts-8 l NOTE:
- 1. THIS SYSTEM 15 NON-NUCLE AR SAFETY CL ASS (NNS)
LOCATED IN TURBlNE BUILDINC. 2, SYSTEM INTERFACE POINTS CIS-1 THRU 6:CWS-7 THRU 12 1.oF WITH CIRCULATING WATER SYSTEM INLETS /0UTLETS. SEE UTILITY APPLICANT'S SAR. SECTION 10 4.5. 0 in1 l t u ,- a O @] } hr V - i i RSH V'---'------H y v HV RN '; ] r' K X STEAM SYSTEM FIG.10.4.I2-1 (TYP) , GS kST - hfk.f5.3-IF L]T + = -________ W O )i FROM AUXill ARY STEAR SYSTEM FIG.10.4.12-1 (TYP) y E 4 : .__________ l ; V 1 r I.00P SEAL T i r (TYP) D DRAIN TRAP (TYP) STEAX JET AIR EJECTORS F I G. 10. 4. 2-1 CONDENSER EVACUATION SYSTEN NS PFP REFERENCE PLA;<T SAFETY ANALYSIS REPORT SIESSAR-P1 ,, / / () OGU 1 J ARENDEENT 12 6 /16M5 1 E - 2 0 - e i O a t a t J L J L J L J L % ,7 TO ATMOSPHERE (TYP) N N N JL / $ TE 2 _ -SILENCER (TYP) ~_ FROM CONDENSER ] FIG.10.4.1 - (!YP) 055-1 , 3 NOTE 3 v 1 6 M 1 r - 1 6 ~ {b l055-2 )l 3 , NOTE 3 CONDENSER AIR REBOVAL PURPS O TO CONDENSER FIG 10.4.1-1 : i r TURBINE tulLDING , FLOOR OR 1 TNIS SYSTEM IS NON-NUCLEAR SAFETT CLASS (55). LOCATED IN TURBINE BulLOl u. , p ,
- 2. NURSER OF CONDENSER CCNNECTIONS TO BE DETERMINED /. G r BY CONDENSER MANUFACTURER. b' I" d '
- 3. SYSTEh INTERFACE POINTS 0t$-182 ARE DOMESTIC IATER SUPPLY PROVIDED BY UTILITY APPLICANT.
b 1
- m
-1. _ TO CONDENSER / F I G .10. 4.1-1 ( T Y P ) t 4 1
- s W ,
f 2 FIC 10.4.4 1 TlEBINE BYPASS SYSTEM PER REFERENCE PLANT SAFETT ANALYSIS REPORT SIESSAR-Pl ~ sc ' / {_', i,J AEll@GE NT 12 6/1675 x. $ FROM 3 MAIN e STEAM S MANIFOLD FIG.10-3-1B / l l-s TURBINE BYPASS CONTROL )$ s m (TYP) 'f d ' w TROM MAIN " STEAM ,-- MANIFOLD* FIG.10-3-1B 4 W I' THis STSTEM 15 NON-NUCLEAR SAFETT CLASS (NNS), LOCATED IN TURBiltE BUILDING. < '- J C E
- i N E 5 h ! ," S :.
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- : -e -. ; _ _
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- j. l l
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- : : : b __ : '9ECEIVER
' L'N I T IG 10 4.6-1B , i , i r i r < r f # 4 Y [' di J J J _r , ry _g-i ,_.x_ S i _w i S i _<_. i +3 d s -!D} 1 f d Q -- UM u =M i r ~Xn ' fi / fl FT) TEX g_ TE _. FT /TE _ TE . (N _ {'N MLN 4,cb 4:fU '~ -*[LP 4h bh d2 h[ ) h Y Y Y FIGURE 10.4.6-IA CONDENSATE POLISHING SYSTEM PsR REFERENCE PLANT SAFETY ANALISIS REPORT SsESSAR-PI e n iA ~7 i / / [i i._: U AMENDUENT 17 9'30 75 FF:w ::s:ENSATE St:TEW FIL.10.4.7-! tts Es;. 61 k --- ,__ .I .I ; 1'. 1 i hkF0 h ,FC
- FC
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- 44. 447 4 47 E [A0'V fi@ i FRCW CEulN. ( ,
WATER 'q ' c WAKEUP .- ; , X - - - SYSTEW ' , , FIG,9.2.3-1 ' FRCW , , , , , , yg i RECOVEREC ' WATER 'I Y TRANSFER PUWPS l i FIG.10.4.6-tB l i _._J l _ _ i _ , , D i l l v' i (, ' -x , w/ y) , , , , , , l ' i r i , / / ~I -S ~S -- S _I 1 -S 4,nb l-_l - ;c6 I J 4,t$ a,0 6 L____ i r 1 r 1 ' ' i r IO TURBINE PLANT = al- == C } -- == q- =lcF LING SYSTEM FT ' E1 FE - FT 'TE' _ g., F13 9.3.2-2 4q" ,g ~ -y - - c'r '^ S _ ( 1 41 U (TYP) ?}s ' ? :~~? hult4EF.LIZER 'g (TYP), UNTROL . _ . - y { 'g' TO CCNDENSATE SYSTEW FIG,10.4.7-1 @ NOTE:
- !. THIS SYSTEM 15 h0N-huCLEAR SAFETY CLASS (NNS) LOCATED , 3 R IN TURBihE BUIL0thL -
/ / () d j 2. NUWBER OF DEMINERAltlERS 15 DEPEN 0ENT CN CONDENSATE FLOW 10 SECTION 10.4.6.2 FCR HUWBER FOR EACH hS$5. REFER ni U I g _ _ __ ~%- a "- TO C0h EhSEk , FIG 10.4 1-1 C0er$EWSATE ' thERALilERS q , .ll.4.5-1A 1r1 r RECOVERIO : TO DEulN. WATER RESIN RECEIVER WATER % NAREUP LlhE UNIT TANK _ F I G.10. 4. 6-1 A 3 r _ [ d i FRCN RECOVERED 1ATER 3i -t O TRANSFER PUMPS O Ol0 ACTIVE LOW _ RECCVERED ' CLEANUP 8 ASTE $15. CONOUCTIVITY _ IATER SUuP ' CE!!hERAllIER .2-1I gag pggp IACKIASH 9 IASTE FILTER LOW rN ~)y [- Ent0CTIVITY FILTER BACK5 ASH f BASTE SUR E TAhK TW [ - %J r, - ( r o y o Ls LOI CONDUCTIVITY d' IASTE SusP Ako Puut i t i , sASTE TRANSFER f ' LOS CCh00CTidlTY PUMPS EASTE TRANSFER PUpFS : Hi@ M h'h Q M UCil/ITY CDOUCTIVITY C . BASTE NEdTRAllflhG _ WASTE STORA2 TM TAM N Nq N] TO RADIO- 't (f C_ ' k . [ _ [ ACTIVE i ,L1 0 HIGH C0h0UCTIVITY k , , WA1TE SutP. TANK $, AND PUNPS ( FIG.ll.2-1F 7 /- ' ( ' 7 HIGh NEUTRAllZED - - HIGH CONDUCTIVITY CONDUCTIVITY f ASTE FORIARDING IASTE [_] f~ TRANSFER CHEulCAL sASTE ]~ PUMPS PURPS StuP AND PUuP V F I G .10. 4. 6-1 B z CONDENSATE POLISHING SYSTEM i; PER REFERENCE PLANT ' SAFETY ANALYSIS REPORT - r, } i ' { SIESSAR-Pl O;o , l 15ENDRENT I2. 6/I645 A TO CONDENSATE DEEINERAlllERS l FIG.10,4.6-1A , c r TO DEulN. , I ' ' IATER EAKEUP LINE NOTE 2 I ' l FIG.10.4.8-1A i , i l ' '7CND-3g ; 1 r - i r : FR0u CONDENSATE, OEglNERAllZER$' FIG.10.4.6-1A ,q rN /^ _ _ - i i _ CAT l@ ANI@ CAil0N REEN. REEN. 2 RESIN VESSEL YESSEL + + NIX AND STORAGE in # VESSEL p go. - - LIOL II8 a I 9 ~ g 3 ~ 1 Atl0 : TRANSF'R PUNP b = " u o y CJ END C ACIO RECCYERfD CAUSTIC CAUSTIC CAUSTIC DAY ACIO DAY ACIO STORAGE TANK 0 LUTI@ + IANI TANK _ TANK TANL i r 1 r R ER , , PUMP y ( ta } /- - CAUSTIC STORAGE TANK f g ACID 0 N pgups R % PUMPS L , , ( , , _ [ o ( ARMONIA STORAGE TANK A010 REGENERANT RECOVERED Atl0 M , CAUSTIC mRST RECOVEREI CAUSTIC PUMPS q , [ , , PUNPS FROM DERINERAllIED - fE TATER u1KEUP SYSTEM pgup5 FIG.9.2.3-1 1r - CND-l) g SEE NOTE 2 (CND-NOTES:
- 1. THIS SYSTEM 15 NON4UCLE AR SAFETY CLASS (NNS) LOCATED IN THE TUREINE BUILDING. FOR THE
- 2. SYSTEM INTERFACE POINTS CND-1 THRU 3 ARE T0/FR05 ONE OF THE THREE SYSTEMS AV AIL ,-
AIMONIA CTCLE. SELECTION OF THIS $TSTER IS THE RESPONSIBILITY OF THE UTILITY-APPLIC ,e ,'. q cv ' A SEE FIC 1C 4.7-2 ! M SATE _ _ _ _ _ _ _ ___ p . j e pt. ti T3 1 ) / l l / ) g 6 1 PUWP5 FIC.10.4.7 2 d I d d (TYF) $0LATION VALVf g , (TYP) L. - - _ _.__J [SEEFIC.10.4.7-21 I Z W 13 r------ - - - ,i . _r s FM % . D J l _I J J - L__________d 10 = FIC.10.4.7-2 r, d5EEFIC.10.4.7-Z FC a x- I r d - - ---- --- ----a ' ) ~ ) J )' l .. J )1)I ) " STH PT.HTR. ETH FT.HTR. 5TH PT.HTP 1 $TH PT. HTR. 3RD PT. HTR. 2ND Pl. HTR. DRAIP. COOLER li_. _ _ __ __.__J _ _._ _ FIE. 10.4.7-1 CONDENSATE SYSTEM PIR REFERENCE PLANT SAFETT ANALYSIS REPORT SIESSAR-PI , ,e ; ' L (Ju AMM00LMT 12 8/16/75 I a TO AUXILLARY STEAN j ANO CONCENSATE SYSTEW F I G 10. 4.12-1 p MN _ YARD m _ INSICE l 3 I O M- l l i I i v MCB CCNDENSATE -(x: : i CONDENSATE - A" % N NK H ATER EA l & FIG.10.4.12-1 ___a v . l FRCE S b- W' l ~ LV . CONCENSATE STORAGE I AT P UP J - '" I TANK NEATER SYSTEN F I G. . 2. .N _ {p__ __ _._ __ ~ - -) CIRCULATING PUNP l TO AyllLIARY N - - - -.I %SE E F IG.10.4.1 -1 L___ _ _ _s M EECIATER ,,, io...io_, SYSTEM b m TO CONDENSATE Q plu!RGENCY MAKE-UP ' POLISHING SYSTER FIG.10.4.6-1B ' {-} -- c FROM AUIlLIARY CONDENSATE FIG.10.4.12-1 SEE F I G.10.4.1 l+ . MSEEFIG.10.4.1-1 NCRWAL < _ _ me MAKE-UP / ' ' N C0%CENSATE 'F [C . _/M IJ MAKE-UP x TO CGhDENSER r, F.C. i TO TURBINE PLANT S AMPLING FIG. S.3.2-2 I "- i N FI . 4.1' 1 - tCON]ENSATE RECikCULATION 'r ,'0. I " STEAM JE AIR,FJEC ORS y FHD ORAI-0FF g H ! W, Qe .> m_ e a cc
- a
- 3, , * ' ' FRDU CONDENSER EN FIG 4.1- g + D " g rl.C. p TD TUR INE PLANT SAUPLING 4 M SYSTEE C0h'JENSATE FIG.B.J.2-2 PURPS Y, TO AUllLIART STEA3 F TO TURBINE PL ANT pQ.me>Ax0CONDENSATESYSTEM SA3PLillE SYSTER Fig 13,A,12-1 FIG. B.3.2-2 T0/TR05 COND{NSATE POllSHING SYSTEM l g NOTES: FIG.18.4.5-1 =
- 1. THIS SYSTER 15 NON-NUCLEAR SAFETT CLASS (NWS),
LOCATED IN TURBINE BUILDING. k VS [ f 1 bbU Lui I . -- m FR6d AUIILIARY ; FEEDWATER SYSTEM STEA3 FH0s R FIG 0 4 10-1(TTP) GEUERATOR (TYP) ISOLATiDN y l l VALVES Xe N 43p fT* -- i M.,* / HW , f - u' i NN ? 3 c's '3 C2 l W ~ 5 . w A,- l j g---------- I C/ I. ~ 8 P I __ I !TEAU GENERATjR WATER f'\6}8CE. -*] LEVEL PROTICTl0N & CChTROL _ __ _______.J N - X ASP / LL l' , -W )MX r i h 1, ! l rdFWI i d F#ll ' M,4 4 1 Ul! 'n en - C,lOtg 's" \ f ' . ,FjSD h [a 4 I f f v Y We,cl====== - l
- t. uIn,ggma'n'" t Rot TE ~ - - ~ ~ - ~ ~ - - - - -
l [N ' y.W #5 F T * }. g7 L ._w" r i d l,A3 rd FWI Ib . W W L T, , l ) , aj '- 4:F p x ^ g;g i i '---- M , ; 4. m STEAW GENERATOR WATER
- k. ! ,j - - -
- > LEVEL PROTECTICW & CCNTRS V - ___- -) ~ 408 IT 7 ^ s M Q .y ' g F III IU gg') , { LT . [0)"( d L LR f M - lV Q
- W '"""{n} j ASP
{; l x x ' i h=S-4 > L_
- I T V I
- i T." STEAU GENERATCR BATER
.__, LEVEL PROTECTION & CONTROL h-- ' _._) INSIDE m *-~~ ANNULUS BUILDING INSIDE FIG.10.4.7-2A TUNNEL pggg79 gyg7g PIR REFERENCE PLANT SAFETY ANALYSIS REPORT SIESSAR-P1 ? , t h-AMENDRENT 12 8/16M5 a }-- t S E E r i G.10. 4. 7 - 1l A S ,~hG CB s s REClRCULAilCN UINidJu h CIRCULATION TO TURBINE PLANT O 9' /- FLC1 CCNTPJL V ALVE(TYP; SA3PLIN; SYSTEia N, iW TO CON:ENSER (Typ) FIG.10.4.1-1
- p @ F I G. g.3. * - 2 8 [3 O.ae . A 1 F. C. (TY n X,Ns FR W &'
CON 1ENSATE SYSTE3 \l ) l\L u__- F l(.10.4.' l ' ('Yf) ',, {- HI AS yp CB T 'e' ' F'd PU2P TURD.CDNTROL -X I. U - X-h! FIG.10.d.7IN fs it P M A S N.J
- n @ @ MCB En
,\ M
- 1 X"
m k J {0? M@X UW Q-- CB A $ AG -- -- 8 ; d-WA' , ?W D u $v. Ql"" FR[W s's @ FIG 'O 4 7-1 _ ' j4M S- " I i' h Fit 10 4. 71 f+ ~~l ) (= = ASa m l - ( UCB l l d- p L * ~ { & d/ & G- ~ Q {.'. C y V g -l A ' S I& ' D 5 HARGE ISOLATION VALVE (TTP) @ IN P0thi HE ATERS o FEE 0W ATER FLfit O CONTROL VALVE (TYP) TURBINE ORivEN FEEDIATER PUWPS I u INSIDE _ TURBINE Bull 0 LNG N1TES:
- 1. THIS SYSTEM 15 NON-NUCLEAR SAFEiY CLASS (NNS)
EXCEPT WHERE OTHERWISE NOTED.
- 2. "'" IN0lCATES INSTRUMENT SUPPLIED BY NSSS VENDOR.
n. ) - ou uv i INSILE INSICE -~ STEAM GENERATOPS E IG - C _ _ _ _ AS ' ~~~ utg I Y. e5 p,' ' I' ) ,. I - p-yg u- m , 1 (FIS-1 g7 i WCB WCB h r- - 8 "M ASP AS - On; ASP ! .ww[ @MwS : i i I */ 'M- 1 l I('",C ' - X ' i HS U2 =C mucsaC IAL % i (FRS2 I i l 1 J j .l ,Fel j ' , i L.D. l(d'.d*>l I Fl_g' N j ; l I j g WCE , r -- THS A gy , l ; JL7 IT I l h - 1Ft1-~j ; ss 4v b ,flJ(_ '/ i T. --J FEEC*ATER y.[ ' ~ ~ %{ T I C FE D i F - f~ ~- PLANT PROTECTION CCNTROL f C i j SYSTEW SYSTEN Xn[ -P)T i X d i n f- (F'S -3 ! i ;ir-< , , , I I ! l yp) (TYP) I L_ _ _ _ _ _ _ _ __; I I L __ _ %_ _- I ' l______________________d i l I I ' l I l 1_______._________J_________J i i l j I i I l l l i i ' l / "I A l l I I , {r . i l , l CE l l T- 1 F#1 A5 4 j O l l 1 l AS VWC'% e uC,1y i I r i Y. _ - i f em ' ' [ I ! , b1 : g. 4 ASP I 6 ,l 1 i ! I l MCB MC 3p pl l j l Pt (7 '.' h L LT / LT @'l @i & 1- 'l$' Q N l Xq 4 hAQ [FlYFANi W MCB MCB[_$ [w -i Fwl l A /% g FSL FT FSk --lfsl @} 3) 1 (7 1u v )y 4 X N [ (FIS6 X 3 , y F l 9.10. 4. 7 2 A FEECWATER SYSTEM PER REFERENCE PLANT lF DW E SAFETY ANALYSIS REPORT FI G.10.4 10-1 SE*SSAR-P1 g p,) , / Ci i g ,_ t /28.'7 7 AMENDMENT 30 E , ;--- - ~ - M EE FIG.10.4.7-1 q_ TUMEL suliclNG -- A%. ' RECIRCULAtl0N 6 (MC j E U l l C 'l'- TO CCNCENSER : I0 TO TURBINE PLANT A3 ( T)'P ) F,c, 'y@p -) ; sAvptlNG SYSTEW P h ;P! E ' ' [Mw' FIC.10.4.1 1 "X @ FIG.9 'J 2-2(TYP. ) ^ FE FROM ' li l! r t w"- CONDENSATE SYSTEU "!,' - p ' ,' ~__ FIG.tt.4.7-1(TYP; jj l ', , FWN W FT i I AJI!LI A:t 'x _ ' f! , FEEC8'iER y l FIG. tC 410-1 - r o a M i I . ggg ~ ,- i i SEE FIG.10.4.7-1 Fs PutP , , TURB.CCNTRDL j FEEC*G F l ll CONTECL SYSTEu [ j'h E ; } ,p 4 .g3_ F.D. y;g =X---> o p T ) 7 ll W@W <@x. , T fl ,a , , - . +,,, [ - ____f. F90u h FIG.10.4.7-1 g I I SEE FIG.10.4.7 1 ==> 7_ U .lbC') F.O. > j v i FT As ^ .F 9 ' TEECTATER ?>l;5 , PUNP , i (. T. w I DISCHARGE ISOLATION VALVE (TYP) 1 f' i *)M)7[ ' FR0 r 'L' F T' ' TURBINE DRIVEN M UAD O , FEEDIATER PUMPS / i I IFEEJtarER J^ h IST POINT HEATERS L__ \ FIC .10.4.I f y; ____ l i___ D - i l 1l FEEDIATER N0!ES. : CCNTFCL F SYSTEN 1 THIS STSTEN 13 NON NUCLE AR SAFETY CL ASS (NNS) C, ;e, *l*I s, . ncEPT i s t OTw aiiSE NOTE 0
- 2. . iN0lCms INSuum1 Su,Pu ED , NSSS ,nm. cy@f ;
~ FT l + O ; i h [MFRi i FR85 AUIlLIARY FEE 01ATER SYtTEE STE12 FIC 10.4.1C-l(TTP) GEWERATGR (TTP) 7 T' - l VE I M h b IG [ rDI i T e U M
- M U
D ASP NN N 3C2 FE y y' 9 s V f
- V II' 'L-- --
V STEA:I GENERATOR WATER i LEVEL PROTECTION & CCNTR0L l 3 y ASP , n &
- i *
[dIU ' [ I ['t # # g lll l i 9 L- , * % t '8' I i ' . l I MF 8 i & I t t V i f LE R T H& ROL _ , - l l Q g l XgM - A I ,1. _ _ _ OY rh d F'l ! . -ca: 4 [Qv ' , l p ' i l E l [ TIFT) i I ' l 7 7 V f ^ h - STEAM GENERATOR TATER LEVEL PROTECTION & CONTROL - -~ ~ B W * "$c m ASP I r 471) Hrvi "* " fv i 1,o, ptT w oc !u x1hE l l y v' i a ' I T. L - t t .V STEAR GENERATCR WATER t I o INSIDE l j LEVEL PROTECTION & CONTROL INSIDE _ _ "- ANNULUS # 4 ' CONTAINWENT BUILDING INSIDE STRUCTURE FIG.10.4.7-2A T M EL FEEDWATER SYSTEM PIR REFERENCE PLANT nq7 5AFETY ANALY313 REPORT [) l f ', evi SIE311R-Pt E3S AMENDMENT IT 9 30 75 fHSEEFIG.10.4.71} b-- 6 A/S % C8 REClRCULATICM TO CCNCENSER EINluJM RECIRCULATION M / FLDI CCNTROL VALVE (TYP) TO SA.TURBikE PLANT f m2 (TTP) C ,, @ FlG.9.3.22 PLIN SYSTEU N FIG.10.4. -1 F.0 (I"P) c . [, Q 3 ,R,, _ o - im FU FIC.!O.4.1-1 (M) A /S CB FB PUNP $'
- TURB.CONTR0L
= Xr ' I. ' . C y t SIEFIC.10.4.7IN ,. i ECB e 'M Iol L_ M, @ M* g.. g AS, CI -Oc : a -X , y >0-D b G 10.4.7-) 2 SEE Fir,10 4.1-1 h X" (n3 3 r, I A/S ECB l G t fh- b
- ~Y
W . _ O 1!!!=l"'" / et , ) x--w ' IN PCFNT HEATERS CON TURBINE ORIVEN V VE ( YP) FEEDIATER PUMPS l L ___ INSIDE TURBlNE _ BUILDING NOTES: l . !. THIS SYSTEN 15 NON-NUCLEAR SAFETY CLASS (NNS) EICIPT INERE OTHERflSE NOTED. g
- 2. '" INDICATES INSTRUMENT SUPPLIED IT NS$$ VENDOR.
- s i
i
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). _ ) _ MCB i
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t I 1 I- - l--
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MCB MC8 l
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- b. INTEGRATED CONTROL SYSTEM
___-~ __
__ _ _ _ _ _ _ _ _ ___ ______ _ _7 E INSIDE INSIDE INSIDE
*E ->4- MAIN ANNULUS ->* CONTAINMENT lhG STEAM BUILDING STRUCTURE TUNNEL F I G.10, 4. 7 - 2 A FEF0nATER SYSTEM PIR REFERENCE PLANT SAFETT ANALYSIS REPOR1 7 n 9!!')
SftSSAR PI hQO LV/
2&R ABENOMENT I9 I2/I2/75
f.i A
// /!5EEFIG.10.4.T-1l REllRCULATION MINIMUM RECIRCULATION T0 TURBINE PLANT TO CDNCENSER , d, -- FLOR CONTROL VALVE (TYP; S A:.tPt itC SYST Ei.1 ,e (TYP) r,- @W F I G . 9 3 . ? - 2 (1 FIG.10 4.!-1 F 0. h C iM t (TYP) c',
,l - M,FT!
.tw : -
t FRD1 & O s N Mf I@ fq
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, i FC f I G. ! D.4.7 1 . O (TYP,
; j E
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Fe PUWP TURB CONTROL 1
I
[SEEFIG.10.4.7-Ik
~
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_ C i r,
F 0. g 1
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M m F-~
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. 0. g yI EDRATER FLOR CONTRC MK U '
i V ALVES (TYF
- FEEDIATER PUuP
= I DISCHARGE g ISCLAil0N Q)
VALVE (TYP)
IST POINT HEATERS TURBINE DRIVEN FEEDWATER PuuPS v L______
p Tl Bt NOTES.
- 1. THIS SYSTEM IS NON-NUCLE AR S AFETY CL ASS (NNS)
EXCEPT WHERE OTHERelSE NOTED.
- 7. *** INDICATES INSTRUMENT SUPPLIED BY NSSS VENDOR.
{
, , r. l O v i.; e i d
SLN DM'ERFACE POD:TS - FEEDWATER SYSTEM (FWS)
ID NO. RESAR-41 RESAR-3S B-SAR 205 CESSAR WS-1-4 Feedwater systm Feedwater systemt Feedwater system Feedwater systen to steam generator to steam generator to steam generator to steam generator nozzles nozzles nozzles nozzles FWS-5-6 Not Applicable Not Applicable Not Applicable Feedwater system to steam generator nozzles CN c,w CD F IG.10. 4.7- 28 I3 FEEDWATER SYSTEM
__, PWR REFERENCE PLANT SAFETY AN ALYSIS REPORT SWESSAR-Pl AartssoutmT is 12/12/[5
a
/1TL'N /$ -
TO CONDENSER F I G .10 . 4.1 -1 MCB V MCB l TO 4TH POINT 7 FEEORATER HEATERS g LSL _ LSH q
l i i ; i I I e i l L _ L _ L r '-- J l I
l l l A3 l
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i l l l T-1 I I FLASH TANK lI Li_'
l r-i
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LT LC , ,, - ,,
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/. }_
1 AMENOMENT 13 6/30 15
-m 4
FROM STEAM GENERATORS I (NSSS SCOPE) r-iClA SGB -1
) :
SC2 ++ NNS l'
l PL ANT SAMPLING \
l SYSTEM ) f FIG 9.3.2-IAf M
- (TYr>
l4 cia Fit . , U-SGB -2
): g y
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)
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I FROM REACTCR P SAMPLING SYSTE INSIDE INSIDE F I G . 9. 3. 2 -1 CONTAINMENT 44- ANNULUS STRUCTURE BUILDING NOTE-
- 1. THIS SYSTEM l$ NON-NUCLEAR SAFETY CLASS (NNS),
EICEPT IHERE OTHER11SE NOTED.
R 3
i E
g f,o um, o,, ' ~j
A h
a C0 IG p --__
l ,
1 TO 4TH POINT Stt I r- 11
$g 7 Ng ; FEEDIATER l l l l HEATERS I
l I I l l 3 I L _ $ _1_ _ l __ jl l
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l l -
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l
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l 1- - - - - - -
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FLASH TANK f
/ FROM REACTOR PLANT i SAtPLING SYSTEN PUMP F I G. 012-1
-~~
FIG.10.4.8-1A STEAM GENERATOR BL0hD0hN SYSTEM PIR REFERENCE PLANT SAFETY ANALYSi$ REPORT SIESSAR-P1 o'
, g ,
\ ) \:. U h15
2 i
FROM STEAM /
GENERATORS AF AS h r--i CI A pg (NSSS SCOPE)
SGB-1f '; __ % C l8@#
SC2 -D4- NN S ,
l I'l }
TO REACTOR PLANT SAMPLING SYSTEM 37,3 , y FIG.9.3.2-1A ,
(TYP)
SCB-2 ); e
,- g [ l,p [ g II SC2 -D4- NNS I
T M l' N lM ' --iCI A p; SGB-3 ): __
g_c l , )__c y SC2 ->4-NHS -
I v rN C l'i >
Fl
--{ CI A
{ 1 SGB-4 f
; __ M ,'i,' yy SC* NN S FI l
V --C l'l D-INSIDE INSIDE CONTAINMENT ; ; ANNULUS STRUCTURE I
BUILDING NOTES:
- 1. THIS SYSTEM IS NON-NUCLEAR SAFETY CLASS (NNS)
EXCEPT IHERE OTHEREISE NOTED.
E o' ..
E / c,J g
=-
Q.UV/. O I
E
4 Q @ TO CONDENSER
[,
- FIG.10.4.1-1
- ~ ~ -
! _ TO 4TH PnlNT FEEDIATER HEATERS 3 (3 I I I I
l l l t l l
I L_ _ __L _ _1 7 _L J l
l I I I l A 'S l
ll l 2
FLASH i e i _ TANK l
r--
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L_1 LT LC
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l I f
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m l ry [ s ON0thSE R i PIA I '-; HDivELL L_____ _ _ _ _ _ _ _ . - - -- m FIG.10.4.1 1
['
PIB FL ASH TANK PullPS
'IG.10.4.8-1A F
STEN 4 GENERATOR BL0nD0nN SYSTEM PIR REFERENCE PLANT SAFETT ANALYSIS REPORT SIESSAR-P1 n* }
j(> n' CE /3aa AIIEN0 PENT 13 6/30/75
3 a
FROM STEAM l r GENERATORS FIC FY l r--4 CI A ,
(NSSS SCOPE) l SGB-1 )
g l I
SC2 O NNS TO REACTOR PLANT Q SAMPLING SYSTEM v- i FIG 9. 3 2-1 A ute l 1 I k r---I CI A ,c ,,
"p' SEB 2 , ; A, ]
SC2 ; NNS TO REACTOR PLANT I
SAMPLING SYSTER FIG 9.3.2-1A I
INSIDE INSIDE FROM REACTOR F CONTAINMENI ANNULUS SUPLING SYSTI BulLDING p;g,g,3,7,g STRUCTURE NOTES:
- 1. THl3 SYSTEN 15 NON NUCLEAR SAFETY CLASS (NNS),
EICEPT INERE OTNERIISE NOTED.
I M
q^
i
, t. o ci t Qv d g
I
SYSTEM I?f!TPJACE POINTS - STEAM CENERA'N1P PIXWDE MN SYSTEM (TIQ 20 ID R) . RESAF -41 FESAR-3S B-sap 205 cES mF 3GB-1-2 From point downstream of Frtri point downstream of NA From p> int downstJea:n blowdown line pipe tee into blowdown line pipe tee into of blowkun line pipe steam generator blowdown steam generator blowdown tee into steam gen-system (Fig. 10.4-1, sheet 1) sy s t er. (Fig. 10.4-1, sheet 1) erator blowdown system (Fig. 10.4.8-3)
SGB-3-4 trom point. downsteam of From point downstream of NA NA blowdown line pipe tee into blowdown line pipe tee into steam generator blowdown steam generator blowdown system (Fig. 10.4-1, sheet 1) systm (Fig. 10.4-1, sheet 1) s FIG 1046-18 u STE AM GENERATOR BLONDOWN CN SYSTEM C PWR REFERENCE PL ANT S AF E T Y AN ALY Sls RE PORT SWESSAR-Pt 7- ')
A M E N 0 ** E N T 2 0 t/23
J E PL ANT E WATER SYSTEW 4.ll 1(T YP) il PLANT 2 SYSTEW
.2-2 L
- t ;
7 X X X X X X X 4
kX X X j 'i 1r 1 r 1r i 1r r ' 1 r ,
r 1
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1 r 1
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f i L_ _
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3 r i r 1 r
1 r 1 r
s D a@sS3x x x Vx D D wax TUP 31%E EHC INSTRLWEN1 STATO< 4TP PT. TURBINE EXCITER HYOR0 GEN FEE 0 EATER SAWPLE LUBRICATING FLUID AIR W AT E R HEATER PLANT AIR COOLERS PUWP C0CLERS Olt CCOLERS CCMPRESSORS COOLERS DRAIN COOLERS SAMFLING COOLER (TYP 0F 2) COOLERS (TYP OF 11)
(TYP.0F 2) AD (TTP.0F 2)PuuF MECHANICAL (TYP 0F 2) AiTE? COOLERS (TYP'OF 3 C0CL ERS REFRIGERATION g (TVP.0F 3) (TYP.0F 3) L' NITS F I G. 9. 3. 2-2 WCB F I G. 10. 4. 9-1 TURBINE PLANT CO@0NENT COOLING SYSTEM PfR STANDARD PLANT SAFETY INALYSIS REPORT SIESSAR P1 LJ m
A
- y. --g ., y TURBINE PLANT ,-
C0WPONENT CCOLING D E R A' e l 2ED SURGE TANK WATER WAREUP ][
p .~ SYSTEM VENT 1 IIC 9 2 3'I i : he r 3 TURBINE PLANT
,q-g } CCMPCNENT COOLING
[ (gD CHEMICAL ACDITICN TANK
-Oc I s
@A l_] --
TURBINE PLANT TUR f3 r
/
C0wPCNENT COOLING HE AT EXCHANGERS SERi pig, i r
-l-> 'TD TUR
+ , Th SAWPL 3r ".J (I'l')
\s FIG.
ss D*/ / /
^ T T i i Pl
; mr I db P
l
+ '
3r {v- _.hid X
f>-X 1 4 X+
p ..
pi Ty
' y i u u d PI 3r 1 ' Ji eh __ g _ _ ,
TURBINE PLANT J L COMPONENT COOLING PUWPS 1d >-z x 3 x: ,
T T
. u ' EI WN 0 $ W J f g
m e "
NOTE.
- 1. THIS STSTEM 15 NON-NUCLE AR SAFETY CL ASS (NNS)
@h g;g LOCATED IN TURBINE BUILDING.
c , (
, 9, w)
La
@ c'-@ i 3 1 -x- .c31 o o
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() :
5 XNW. -
l I
TO FFECIATER f 0.4. 7-2 q
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(TYP.)
(FO FC J ,
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- wb-c; :
/TC SC3 +4 SC2 f. ,
lE FC y -_ 4 i FC t1 m --
1 l
47 s 7 @ Sc3 ++ Sc2' ~
l INSIDE INSIDE ANNULUS : : CONTAINEENT BUILDING STRUCTURE F IC. 10. 4.10-1 A AUXILIARY FEEDWATER SYSTD4 PIR REFERENCE PL ANT v" SAFETY ANALYSIS REPORT v "'
SIESSAR-PI E
AWENCHENT 11 5'30 '75
'4 d
H FRCE REACTOR II i PLANT SERWILE >
Sit NOTE 2-
[ . 1-1 (ifP )
f ggg ORIVEN t FRCu CONDEN$ ATE
- e. '
sisTEs ris r0 4.T_ / A AFP, T" 9 is, ,c, AUllllARY FEED M h WATER STORAGE ,
r- MCB i TANK
-7 ASP i/
7 ^ NOTE 4
@Q
/ 4 [o U,[
wp L.0
-!EE NOTE 2 L.D' MOTOR y .
DRIVEN AFP d b d ' ' ' .
R0 W
L.D.
2 L.D. H i &
.1TE 4
[
MOTOR CRIVEN AFP R0
- , 1 TURBINE R0 NOTES:
I. AFP DENOTES AUCILI ARY FEEN 1 ATER PUMP g; 2. RETURN LINES ABOVE TANK WATER LEVEL M T CLAS$ 3 53 EXCEPT WHERE OTHERWISE NOTED .
$ f,' hHh$ ,5AF g
qG1 o '
L a t, u
, J h
.a NCB NCB l-- h FT l ASP si h
w
[ --
m "TO FEEDIATER SYSTEM n ^ -
FIG 10 4.7-2 SC2 f: SC2 (typ)
FE I -
h H k_ n r-C@
4 N 6\Asp T
,n 1
Q}
s.
FE $C3 +4- SC2 ^
2i U
--h l
M, 2 % ^
h_
M . .
I FI 103 . ,4 5C2 , . ,
25 d '
E l
.; n Hf l A7 4 g_
m :.~ x :
h sca-. .s[ ~
25 4 , . 6 g
INSIDE IN3tDE ANNULUS : C CONTAINdENT BUILDING 1 STRUCTURE FIC.10.4.10-1 A AUXILIARY FEEDWATER SYSTDI PIR REFERENCE PLANT SAFETT ANALYSl$ REPORT ITE!!AR~PI
-t E.3S I. g g
/ s ARENCIENT 17 9/30/15
is i
i-
- SEE NOTE 2 SEE NOTE 2 EC8 r--->
l e-
'_ s l FROM CONDENSATE SYSTEM FIG 10 4. 7-1
' FRCN REACTOR ASP ECB AUllLIAAT TEE 0 BCB ip f IATER STORAGE FIG.9 2 1-1 I I TANK r- ll E0B ~, (typ)
L- A5P 7 l/ 7 N SE! h0TE 4
// 4 g a LC 50 TOR i SIE NOTE 2 L.O.
g , , , g M C ORIVEN AFP a
~
l y R0 L.0.
L.0. I ' SEE NOTE 4 U
sW g V {
r EDTOR ORIVEN AFP C ,
TURS1NE ORIVEN AFP 4 ,
NOTES:
- 1. . AFP OENGTES AUAILI ART FEEDIATER PURP g 2. RETURN LINES ABOVE TANK IATER LEVEL g 3. .THl3 STSTER IS SATETT CLASS 3 (SC3) EICEPT THERE OTHER115E NOTER.
a 4. SPOOL PIECE TO BE ADDE 0 IHEN NEEDE0. ~
i , io e
() O d I
i FT !
t_..;
I ASP $ @ FWA-I f wk $ '
f l FE I
I
' SC3 ->%- SC2 I
i i-i NAM '
! I \
l ~
~
- f O i ! STEAM I SC3 D4-SC2 GENERATORS
,f yr.Ril e i
300 b r , r,- ,
va i
~
? ~>C 4 ); ,
l} ! -N FIA-2)
SC3 ->4- SC2 /
i l i
I SP MCB L _ _ 7 ._ _ J r
W u Im 3 SC3 $C2 _
INSIDE , INSIDE ANNULUS ' ' jCONTAINMENT BUILDING STEUCTURE FIG.10.4.10-1A AUXILIARY FEED W TER SYSTEM FPR REFERENCE PL ANT ,
SAFETY ANALYSIS REPORT n ^g SIE S.S A R -P1 ,
gu B&W
. '.g,;O AMEN 0 MENT 23, 3/3146
4
.1
, ~7_ m (SC3 ->4- NNS X h ,
i g e _ _ _ ,
~^
T" L5 SYS EM x ASP FIG.10.4.7-1 FROM REACTOR \
/Ux NCB
,M . AuflLI ARY FEED .
PLANT SERVICE Ny C WATER STORAGE TANK l3CB RATER SYSTEM N I L. !!CB F IG.9.2.1-1 (TYP ) \
L-- h ASP ,- \
i/
>/ 4X ) _
\- S E E NO T E 4,/
\ 29/
s v WK ,
-. SEE NC
'k 2
l'U- MOTOR DRIVEN AFl-a 6 a 6 a 6 i/L.O R O' 7 5y
'_Ii ~~
\ l
\)@/f'{ /
~ -\
\
MOTOR R0 DRIVEN AFP
\
TURBINE R0 DRIVEN AFP O , ,
3 NOTES:
I. AFP DENOTES AUXill arf FEE 0 TATER PUNP.
- 2. RETURN LINES A20VE TANK IATER LEVEL. >
g 3 THIS SYSTEM 13 SAFETY CLASS 3 (SC3) EICEPT WHERE OTHERtlSE NOTED"
& 4 SPOOL PIECE TO BE A00E0 IHEN NEEDE0.
E 3 n n/ 3 y , fC Ls' x
h b a ')
INSIDE l INSIDE L.C. ~ TO FEE 01ATER _ _ _
~l ANNULUS CONTAINMENT FIG.10.4.7-2A
' " - STRUCTURE (TYP) , . . -_..__... s SC3 -D}te- NNS ~
SC3 +4-SC2 . I C_B sp [ MCB /
~~
G 04 2A
\' ,
j-- (. ' (TYP)
HI Q r FE l ,,
._ _C y ASP
\ NCD' d
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f py s' r
+u LQ
/1 Q)
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~
l HIC l
, liiih
', f' VMCB i ,
Pi L g3p /
I, CB W :
\ SC3 +4- SC2 /
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FIG.10.4.10-1 AUXILIARY FEECnATER SYSTEM PER REFERENCE PL ANT .^
I SAFETY ANALYSIS REPORT u-SIESSAR-P1 f
']
CE AJ1ENDRENT 23, 3/31M6
A SC3 N NNS g SEE NOTE 2 l
i V MC8 9 FROM REACTOR PLANT SERVICE BATER I l SYSTEM l l FSK-9.2.1-1
' )M /\ j I /
M, g3p U
_] 8
, b ri 7 FROM CONDENSATE l ') SYSTEM FIG.10.4.7-1 FEE 0 RATER LS M e ST RAGE [3__ __INOTE4 s / F F L _ __ Li ASP , p
[ T s/ ,
h d d r-i AFAS 3'c -a L .D.
"(
N L.O. MOTOR i , , 6 ,
, '-SEE NOTE 2 : DRIVEN AFP
@L.O.
h o @
O ,r d AF AS f
MOTOR ORIVEN AFP RO 2 ,,
AFAS TURBlNE ORIVEN AFP 1
8 i ,'
NOTES:
- 1. AFP DENOTES AUIlLIARY FEEDIATER PURP
- 2. RETURN LINES ABOVE TANK IATER LEVEL.
h
- 3. THl3 SYSTEM is SAFETY CLASS 3 (SC3) UNLESS OTHERWISE NOTED.
- 4. SPOOL PIECES IILL BE ADDED THEN NEEDED.
E n .m m
3 o
g , r Cy u-
SYSTEM INTERFACE POINTS - AUXILIARY FEEDWATER SYSTEM ID NO. RESAR-41 RESAR-3S B-SAR 205 CESSA_R 19 INA-1-2 Not Applicable Not Applicable Auxiliary fealwater Not Applicable system to steam generator rv22zles r s c "":
FIG 10. 4 .10 - 1 B AUXILIARY FEEDWATER SYSTEM 7j PWR REFERENCE PLANT p) SAFETY AN ALYSIS REPORT
-O SWESSAR - P1 AYE NDYE N T 19 12/12/75
a MCB AIR CON 0lil0NING l
r- CHILLED WATER m
gs + 6 + i!EEEh (TYP 05 3)
"~'"
x 0 "
CCNTAINEENT STRUCTURE 1 1 CHILLED BATER RECHANICAL UNITS g M y$
PC 3) 1 1 I (D0EdSER -. MECHANICAL REFRIGERATION 6a ( '
RCULATION
" - d b PUMPS
[
BECHANICAL
( 4VAP, REFRIGERAT10N UNITS RECIRCULATION PUMPS I
FS y d 6
! h ""
CHILLER INTERLOCK f T
==
T T' ,g '
1.
[ NOTE 3 D ,
TO CIRCULATING
- - RATER DISCHARGE a
FIG. 10.4.11-1 TURBINE PLANT SERVICE WATER SYSTEM PtR REFERENCE PLANT SAFETY ANALYSIS REPORT SIESSAR-Pt e 1 c s}
n' AMENDMENT 12. 6 16 M
)
a 5 @'I a, P Pi NC8 TURBINE PLANT SERVICE EATER PURPS ' ;
S , %d
, , g di i
SE S-1 )
i
{
NOTE 2 y @MCBM TURBINE PLANT COMPONENT COOLING IATER FIG.IO.4.9-f Pi ri X ..
4 C340DGER -
3 4
TURBINE PLANT l@
e COMPONENT COOLING '
[
d i HEAT EXCHANGERS (TYP OF 3) ( % )
i SrS-2)
,-- FS NOTE 2 h CHI LER l 3} ,,
IN!.RLOCK Pi
-\
' T T
-. %n ek StS-3 )
kOTE2 NOTES:
- 1. THIS SYS1EM is NON-NUCLE AR SAFETY CL ASS (NNS).
- 2. SYSTEM INTERFACE POINTS 555-1 THRU 3 ARE WITH TURBINE PL ANT SERYlCE BATER SOURCE. SEE UTillTY APPLICANT'S SAR. SECTION 10.4.l(.
- 3. SYSTEM INTERFACE POINT CWS-13. IS tlTH CIRCULATING IATER SYSTEN.
SEE UTillTY APPLICANT'S SAR, SECTION 10 4.5.
-. s y { ,
b-
.b
m
-- - - --l m. TURBINE CLAND
,gi g j, i XM r- -
i TO l
SEALING SYSTEu FIG.10.2 1 p PiC j DEWINERAllZED TO I 4
2 g -I WATER y OTV CONDENSATE i 6Ei
, STORAGE TANK FIG.9.2.3 1 STORAGE TANK' 1 '
'\ / \
\
1 '
\ \
F I G.10. 4. 7 - 11
' I '
!2 > l l
l IC l l STEAM JET AIR EJFCTORS FIG.10.4.2-1 L1 OuEStiC i 10/
HDT WATER l DEMINERAllZE CONDENSATEI figj--) ' FROW WEDIUM TEMPERATURE I ATER STORAGE I yw ,IATER BUILDING HEATING EA T] HEATER T ANK I T ORAGE T I SY SHM F IG. 91. 7-1 TAE ', i _. . NEATER
_ YARD- > ^d "'d HEATER i
___ _ 1 __ i _. _. -~ - - -
r ,
e i -
TO VENTILATION RAH N -- .
+ VENT Bull 0 LNG HEATING g
F 6.2.3.1-I V l HEAT EXCHANGERS d
3JILCIMi AUllll ARY MENSATE PICEIVER RB M ITO VENTILATION
-*<c>s =e FROM f VENT FIG 6.2.3.1-1 <
s ;
---~- ---
2 F IG.10. 4. 7-1
-- { , , , , , ,
l TURBINE BulLCtNG ANNULUS BUILCING AullLIARY ' ~
/ fN SATE i RtCEIVER CONCENSATE PUMPS l ; - ------
---___q
_ - - - . - _ - - _ . - - - - - -._--. _ a l r i FROM i
-> I
)- ------J
; 6 g TO UNIT 1 TURBINE CUILDINC FIG.9.2.3-1 l i
N ME' C E PUNPS I FI G .10. 4. 7 -1 1 --* TO UNIT 2 LC a i CONDENSATE SYSTEM I
(IF APPLICABLE)
AUIlLIARY
] B0lLER CONDENSATE I IARY p TANK g
ATOR g AUIILIARY l F I G.10. 4.12-1 RY CONCENSATE PUMPS I AUXILIARY STEAM L COLENSATE SYSTEN FEEDI ATER I
PER REFERENCE PL ANT -
l SAFETY ANALYSi$ REPORT L ~'.
; SIESSAR-P1 I g l
AREN05(NT 12 8 /I E '75
Ek 0- a R
S ,F FC FC u $
l ~l
,,e TO e e*x:,
- EE i
l- d h -{k 4p OEGASIFIER d ,
e 1 FIG.11.3-16 H ^
LAUNDRY TASTE F ROM M A l4 g, s ]D. l EVAPORATOR
' 'd G 0.3IApl 6 d ' l F I G. 1. 2 -1 F I
l LAUNDRY WASTE
'ID'FROM e LFIC.11.2-1F
' ' ' V bli2 M'
NANIFOLO l
'RE G EN .
BORON WASTE -- },---
klF AFRICARE) FVAPOR'ATO EVAPORATOR EVAPORATOR '- a l (f
~
g i EBOILER T REB 0lLER I REBOILER T r_ __
FIG 11.2- ! FIG.9.3.6-1 FIG.11.2-1E RV >
CEGASIFIER t I '
I FEEC I i '
PREHEATER I l
I i 3 18 l \ '
/
< i I 1 s r 3
, i r ' BORIC ACIO !
l BATCH TANK T
(IFREQUIRE BY NS$$
TURBINE l - VENDOR)
BulLDING l AN
_ ___ __ _ _ L _ _ _ _ _ 1 _NULUS BUILDING ._ _ _____ _._ _ _ _ _ _
______q AUXILIARY BOILER BUILDING g f-
} } s i l C &( ) '
~~'8 l TO pi V TJ2lPE PC TO THREE / / ANT ELEMENT FEECWATER
( l
' SAfLE SYSTEM p-g S p==--
CONTROL (TYP) FIG. 9.3. 2-2 Y /
SYSTEu(TYP) AUIILIARY B0lLER hh d (/ BLCfDDIN T ANK
- M FC
( FC ^ ][
L o (
TO AERATED YENTS AND ORAINS At FT - < b FIG.9.3.3-1 to DE;
. AUllLIARY BOILERS Plf E NOTE: THIS SYSTEN IS NON NUCLEAR SAFETY CLASS (NNS).
3 y f. O n-
, ouu es i}}