ML19344A625
| ML19344A625 | |
| Person / Time | |
|---|---|
| Site: | McGuire, Mcguire  |
| Issue date: | 05/02/1977 |
| From: | DUKE POWER CO. |
| To: | |
| Shared Package | |
| ML19344A621 | List: |
| References | |
| MDS-PDG-77-1, MDS-PDG-77-1-R3, NUDOCS 8008210364 | |
| Download: ML19344A625 (180) | |
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i ! l !, l 3 I l j EVALUATION OF THE EFFECTS OF-POSTULATED PIPE FAILURES OUTSIDE CONTAINMENT _( ! i i, FOR MCGUIRE NUCLEAR STATION / j i i May 2, 1977 j 9 ! i 5 REPORT NO. MDS/PDG-77-1 r i l i e
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O TABLE OF CONTENTS Page l FOREWORD i
1.0 INTRODUCTION
1-1 2.0 PLANT DESCRIPTION 2-1 2.1 General 2-1 2.2 Piping Layout 2-1 3.0 CRITERI A FOR POSTULATING RUPTURES 3-1 3.1 Piping Systems Subject to Postulated Pipe Ruptures 3-1 3.1.1 High Energy Piping Systems 3-1 3.1.2 Moderate Energy Piping Systems 3-2 3,2 Break Location and Configuration 3-2 3.2.1 Break Locations in Duke Class B, C, & F Piping Runs 3-2 3.2.2 Break Locations in Other Piping Runs 3-3 3.2.3 Break Configuration 3-4 3.3 High Energy Piping Outside Containment 3-6 3.4 Moderate Energy Piping Outside Containment 3-6 4.0 SYSTEMS AND EQUIPMENT EVALUATION 4-1 4.1 General 4-1 4.2 Protection From Rupture of High Energy Piping Systems 4-2 4.2.1 High Energy Piping Systems Physically Separa- 4-2 ted From Essential Structures and Systems 4.2.2 Piping Systems Enclosed Within Structures 4-4 4.2.3 Other High Energy Piping Systems 4-4 4.3 Protection From Through-Wall Cracks in Moderate Energy Piping 4-5 4.4 Protection Criteria and Assumptions 4-5 4.5 Essential Systems 4-8 4.5.1 Normal Shutdown 4-9 4.5.2 Emergency Shutdown 4-10 5.0 DAMAGE EVALUATION 5-1 5.1 Pipe Whip / Jet Impingement 5-1 5.1.1 Break Criteria 5-1 5.1.2 Establish Plant Arrangement and Layout 5-1 5.1.3 Preliminary Interaction Matrices 5-1 5.1.4 Final Interaction Matrices 5-2 5.1.5 Pipe Whip Model 5-3 5.1.6 Jet Model 5-5 l G
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() 5.2 Compartment Pressurization 5-5 5.2.1 TMD Code-Short Term Analysis 5-5 5.2.2 RELAP Code 5-7 5.2.3 Hand Calculations 5-10 5.3 Flooding Effects 5-11 5.3.1 Discharge Rates 5-11 5.3.2 Moderate Energy Piping 5-11 5.3.3 High Energy Piping 5-12 5.4 Environmental Consequences 5-12 6.0
SUMMARY
AND CONCLUS10NS 6-1 6.1 Pipe Whip and Jet Impingement Effects 6-1 6.1.1 Main St'eam and Feedwater Systems 6-1 6.1.2 Steam Generator Blowdown System 6-2 6.1.3 Auxiliary Feedwater System 6-3 ' 6.1.4 Safety injection System (Upper Head) 6-3 6.1.5 Boron Thermal Regeneration System 6-4 6.1.6 Chemical and Volume Control System 6-4 6.1.7 Main Steam Supply to Auxiliary Equipment 6-5 6.2 Compartment Pressurization Effects 6-5 6.2.1 Main Steam and Feedwater 6-5 6.2.2 Upper Head injection 6-6 6.2.3 Steam Generator Blowdown 6-8 6.2.4 Letdown Line, CVCS System 6-8 q 6.3 Flooding Effects 6-8 Q 6.3.1 Auxiliary Feedwater Pump Room 6.3.2 Containment Spray /RHR Pump Rooms 6-9 6-9 6.4 Environmental Effects 6-10 6.4.1 Water Spray 6-10 6.4.2 Temperatures 6-10 APPENDlX A Mitigation Devices - General Design Considerations A-1 APPENDIX B Blowdown Forces and Methods of Calculations B-1 I a
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D LIST OF FIGURES Figure Number Title 2-1 McGuire Nuclear Station, Key Plan 2-2 Compartment Locations, Elevations 695 and 736 2-3 Compartment Locations, Elevation 716 l 2-4 Compartment Locations, Elevation 733 2-5 Compartment Locations, Elevation 750 2-6 Compartment Locations, Elevation 767 3-1 Flow Diagramatic, Steam Generator Blowdown System - BB 3-2 Flow Diagramatic, Auxiliary Feedwater System - CA 3-3 Flow Diagrammatic, Feedwater System - CF 3 -4 Flow Diagramatic, Safety injection System - NI 3-5 Flow Diagramatic, Boron Thermal Regeneration System - NR 3-6 Flow Diagramatic, Chemical & Volume Control System - NV j 3-7 Flow Diagramatic, Main Steam Supply to Auxiliary Equipment - SA 3-8 Flow Diagramatic, Main Steam System - SM 3-10 Piping Layout, Steam Generator Blowdown System 3-11 Piping Layout, Auxiliary Feedwater System (See Figure 3-12 also) 3-12 Piping Layout, Feedwater System 3-13 Piping Layout, Safety injection System (Upper Head Portion) 3-14 Piping Layout, Boron Thermal Regeneration System 3-15 Piping Layout, Chemical & Volume Control System 3-16 Piping Layout, Main Steam System and Main Steam to Auxiliary Equipment 4-1 Logic Symbols 4-2 Main Turbine Trip Logic Diagram 4-3 Start /" rip Logic Diagram for Main and Auxiliary Feedwater Pumps 4-4 Reactor Trip Logic Diagram 4-5 Reactor Coolant Pump Start / Trip and Main Steam isolation Valve Logic Diagram 4-6 Safeguards Actuation, Feedwater Isolation, and Makeup Control Logic Diagram
6-1 Main Steam System - Isometric 6-2 Main Steam System - Guard Pipe / Process Pipe Details 6-3 Main Steam System - Pipe Rupture Restraints 6-4 Main Steam System - Pipe Rupture Restraints 6-5 Doghouse Model - Pressure Rise Analys's 6-6 Elevation - Peak Temperatures 6-7 Typical Temperature Response Curves for BB Line Break B-1 Pipe Rupture Reaction Thrust Force Transient B-2 Moody's Steady-State Separated Flow Thrust Coefficient Without Frictional Effects B-3 Friction Effect on Steady Blowdown Force B-4 Thrust Force as a Function of Stagnation Enthalphy, h , and Pressure, P B-S Subcooled Water Blowdown Thrust Force as a Function of Stagnation Enthalphy for Various Valves of Pipe Friction Parameter, fl/D B-6 Water Blowdown Thrust Force as a Function of Pipe Friction Parameter, fl/D, For Various Stagnation Enthalples i 4 4 s O g
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LIST OF TABLES Table Number Title 3-1 Auxiliary Building, High Energy Piping Reviewed for Pipe Rupture 3-2 Turbine Building, High Energy Piping - 3-3 Auxiliary Building, Moderate Energy Piping Systems 6-1 High Energy Pipe Break Locations 6-2 Unacceptable Pipe Whip / Jet Impingement Effects 6-3 Results of Damage Evaluation, Water Spray - Moderate Energy Piping 6-4 Doghouse Pressure Rise Analysis Model r i O
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FOREWORD This report was prepared in response to Mr. A. Giambusso's December 19, 1972 letter to Duke Power Company in regard to the consequences of pipe rupture outside containment during the operation of the McGuire Nuclear Station. This report meets the intent of NRC Branch Technical Positions, MEB 3-1 and APCSB 3-1 with the exceptions identified in FSAR Table 3.6.1-3. This report has been prepared under the direction of Duke Power Company's Design Engineering Department, Mechanical and Nuclear Division. 3 The first phase of this report includes the criteria and procedures used for evaluating the postulated failures and the results of all evaluations for Unit 1. Subsequent revisions will include any pertinent differences between Unit I and Unit 2. For resolutions 3 to unacceptable consequences detailed in Chapter 6, alternate resolations that may accomplish the same results may be used. O v Revision 3 i
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1.0 INTRODUCTION
This report presents the results of the evaluation of effects of postulated pipe failures outside containment for McGuire Nuclear Station. The report describes criteria and procedures used in the analysis as developed from the Nuclear Regulatory Corrsnission Branch Technical Positions MEB 3-1 and APCSB 3-1. The intent of this report is to comply with all licensing commitments as provided in FSAR Section 3.6. Postulated rupture locations and types were determined in accordance with the criteria of Section 3.0. Systems and equipment essential to achieve plant shutdown and mitigate effects of piping failures were determined in accordance with Section 4.0. Sections 5.0 and 6.0 pro-C vide the methods used to evaluate possible damage and the results of the evaluation. All required mitigative devices are identified in Section 6.0. O 1-1 .
O 2.0 PLANT DESCRIPTION 2.1 General ! The McGuire Nuclear Station is located on Lake Norman in Mecklenburg County, North Carolina and consists of two 1180 MWe generating units. The Nuclear Steam Supply System for each unit is a pressurized water reactor with four coolant loops and is supplied by Westinghouse Ele ctric Corporation. Each containment consists of a free standing cylindrical steel shield enclosed by a separate reinforced concrete Reactor Building. Major plant structures consist of the Reactor Buildings, the Auxiliary Building, Service Building, and Turbine Buildings. The Reactor Building houses the containment vessel, reactor olant and ice condenser. The common Auxiliary Building contains the spend fuel storage facilities, diesel gene-rators, safeguards system, waste disposal systems, reactor aJxiliary systems, and control room. Non-safety shared equipment is housed in the Service Building. The Turbine Building contains the turbine generators and associated secondary system pumps and heat exchangers. These structures and their relationship are shown in Figure 2-1. Figures 2-2 through Figure 2-6 show . the various compartments of each Auxiliary Building elevation. Compartm;nt locations are given by building elevation and compartment number. O , 2-1
(' 2.2 Piping Layout Main steam and feedwater piping represent the greatest damage potential from pipe ruptures outside containment dee to their large size and high operating pressure. These lines have been routed outside the Auxiliary Building, which contains the bulk of the safety related equipment. The main steam and feedwater piping penetrate the Reactor Building in the doghouses (room 750-23, -24, -25, -26, Figure 2-5) and pass over the Auxiliary Building roof into the Turbine Building. While the possibility for structural damage resulting from main steam or feedwater ruptures outside containment does exist, potential consequences are minimized by this layout. Separation of high energy piping from essential components is the I s- / most desirable method of precluding unacceptable pipe break damage. Careful attention has been given to location of essential components and the routing of piping systems. In every possible instance, equipment susceptible to pipe break damage is located remote from the piping postulated to fail. The extensive compartmentalization in the Auxiliary Building provides separation of safety related fluid system components from redundant equipment and other high and moderate energy piping systems. The Turbine Buildings are located directly adjacent to the Auxiliary Building as shown in Figure 2-1 This plant arrangement dictates that Turbine Building piping be routed nearby the Auxiliary Building. However, efforts have been made to separate Turbine Building high energy piping from the Auxiliary Building to the greatest extent pratical. (~ ,e Although the potential for some damage to the Auxiliary Building wall is l l 2-2 .
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3.0 CR ITER I A FOR POSTULATING PIPE RUPTURES 3.1 Piping Systems Subject to Postulated Pipe Rupture Specified ruptures are postulated to occur in plant piping sysi uns,
, and the potential for damage evaluated on the basis of the level of energy stored in the systern. Systems are classified as high-energy or moderate-energy.
3.1.1 High-Energy Piping Systems High-energy piping systems are those systems, or portions of systems, that during normal plant conditions are either in operation or maintained pressurized under conditions where either or both of the following are met: a) Maximum temperaturs exceeds 200* F, or b) Maximum pressure exceeds 275 psig. Except that (1) non-liquid piping systems (air, gas, steam) with a maximum pressure less than or equal to 275 psis are not considered high energy regardless of the temperature, and (2) for liquid systems other than water, the atmospheric boiling temperature can be applied. Systems are classified as moderate energy if the total time that either of the above conditions are met is less than ! either of the following: a) One (1) percent of the normal operating 1ifespan of the plant, or b) Two (2) percent of the time period required to accomplish I its system design function. O b 3-1
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3.1.2 Moderate-Energy Piping Systems Moderate-Energy Piping Systems are those systems, or portions of systems, that during normal plant conditions are either in operation cr maintained pressurized (above atmospheric pressure) under conditions where both of the following are met: a) Maximum temperature is 200* F or less (or less than the atmospheric boiling temperature for non-water systems), and b) Maximum pressure is 275 psig or less. 3.2 Break Location and Configuration 3.2.1 Break Locations in Duke Class B. C. and F Pipina Runs Breaks are postulated at the following locations in each Duke Class B, C, ud F piping runs. a) The terminal ends of the pressurized portions of the run, b) At intermediate locations selected by either one of the following methods:
- 1. At each location of potential high stress or fatigue, such as pipe fittings (elbows, tees, reducers, etc.),
valves, flanges, and welded attachments, or
- 2. At all locations where the stress, S, exceeds 0.8 l (1.2Sh + $A ), where S = stresses under the combination of loadings associated with the normal and upset plant l condition loadings, as calculated from the sum of equations (9) and (10) in Subarticle NC-3600 O
V of the ASME Boiler and Pressure Vessel Code, 3-2
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S = all wa le stress range for expansion stresses, A as defined in Subarticle NC-3600 of the ASME Boller and Pressure Vessel Code, Section 111. c) If there are not at least two intermediate locations where S exceeds 0.8 (1.2S h + I A), a minimum f two separated locations are chosen based upon highest stress. If the piping run has only one change of direction, a minimum of one intermediate break is postulated. The pattern of postulated intermediate break locations shall be deter-mined for the normal plant condition load combination and upset plant condition which has the highest stress. Intermediate breaks are not postulated in sections of straight pipe where there are no pipe fittings, valves, flanges, nor welded attactinents, nor in piping runs where ver the length of the S is less than 0.4 (1.2Sh+ A) run. 3.2.2 Break locations In Other Piping Runs Breaks are postulated to occur at the following locations in each Duke Class E, G, and H piping run. a) At each location of potential high stress or fatigue, such as pipe fittings (elbows , tees , reducers , etc.), val ves , flanges, and welded attachments. 3-3
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b) The terminal ends of the pressurized portions of the run. 3.2.3 Break configuration 3.2.3.1 High-Energy Piping The following types of breaks are postulated in I high-energy piping systems: a) No breaks are postulated in piping having a
! nominal diameter less than or equal to one (1) l Inch.
b) Circumferential breaks are postulated in piping having a nominal diameter between one (1) and four (4) Inches. c) Longitudinal and circumferential breaks are postu-lated, b'ut not concurrently, in piping having a ncminal diameter equal to or greater than four (4) inches. At terminal ends where piping has no longitudinal welds, no longitudinal breaks
- are postulated. Also, at intermediate locations 1
where the criterion for a minimum number of break locations must be satisfied, only circum-ferential breaks are postulated. Where break locations are postulated at fittings without the benefit of a detailed stress calculation, breaks are assumed to occur at each pipe-to-fitting weld. If detailed stress analyses or tests are performed, the maximum stressed loca-tion in the fitting may be selected as the break location. Where two or more breaks are postulated, break locations are O 3-4 .
. . - - - - . , - , , , y .-- , - . , - , ,,,-r . - - - - - - - . . -
. _ . ~ , , - - - . , - - , , . - , . - . . . , , , . - , , , . . . . , . ,
.,,e.,., ., - - , - - - , - , , . . . - - - - ,.w-.,
rx selected with at least 10% difference in stress, or, i f stresses differ by less than 10%, locations are selected so as to be separated by a change of direction of the pipe run. A circumferential break results in pipe severence with full separation, except as limited by structural design features. The break is assumed perpendicular to the longitudinal axis of the pipe, and the break area assumed to be the cross-sectional flow area of the pipe at the break location. The break discharge coefficient used may be substantiated ana-lytically or experimentally. In the absence of this data, the discharge coefficient is assumed to be 1.0. A iodgitudinal break results in an axial split without severence. The split is assumed to be oriented at any point [G) about the circumference of the pipe, or alternately at the point (s) of highest stress, as justified by detailed stress analyses. For the purpose of design, the longitudinal break is assumed to be circular or eliptical (2D x iD) with an area equal to the largest piping cross-sectional flow area at the point of the break, a length equal to twice the piping inter-nal diameter at that cross-section, and have a discharge coeffi-cient of 1.0. Any other values used for the area, diameter, or discharge coefficient associated with a longitudinal break are verified by test data or analysis which define the limiting break geometry. For purposes of analysis, circumferential and longitudinal
) breaks are assumed to reach full size within one (1) 3-5
, - . - _ . -<w,,
. - - , , , , . . . , .,,m.. e-- .- - . - -,s----,-~e , .
O millisecond after break initiation. 3.2.3.2 Moderate-Enerov Piping Crack openings are assumed as a circular orifice of cross-sectional flow area equal to that of a rectangle with a length of one-half the pipe inside diameter and a width of one-half the pipe wall thickness. The orifice is asstaned to be oriented at any point about the circumference of the pipe. Cracks are not postulated in piping that contains no pressurization equipment; i . e., systems without pumps, pressurizing tanks, boilers, etc., and which operate only from gravity flow or storage tank head. Also, cracks are not postulated in portions of Class B, C, and F piping where the stresses are less than 0.4 (1.2Sh*I}' A 33 High Enerav Pipinc. Outside Containment High energy piping outside containment is reviewed by plant area. Auxiliary Building high energy piping is identified in Table 3-i. This table also lists the figure for the applicable flow diagranwnatic. All high energy piping is shown by system on figures 3.10 through 3 3.16 . Table 3-2 identifies all Turbine Building piping that has been reviewed for pipe rupture. 3.4 Moderate Enerov Pipina Outside Containment Only Auxiliary Building moderate energy piping is reviewed in detail. Turbine Building moderate energy piping is incapable of ctusing any unacceptable damage due to its location away from essential co.npo-nents. Auxiliary Building moderate energy piping systems are identi-fied in Table 3-3. Revisio., 3
. - - - - - - - . , , . , _ , - - . ,, , - ,,-_, - -,-a-_ , - - - , - - - . , - -,_.~,.,-,,---,,..,,,.,n,. ,c,, ,-- , , , - , - - . - - , , - -
i Table 3-1 McGUIRE NUCLEAR STATION 1 AUXILIARY BUILDING HIGH ENERGY PlPING REVIEWED FOR PIPE RUPTURE
- 1. Steam Generator Slowdown System - 88 (See Figure 3.1)
From: Containment Penetrations M-300, M-301, M-303, and M-304; i To: 1. The outlet of valve 188101;
- 2. The service b1dg. side of the trench.
- 2. Auxiliary Feedwater System - CA (See Figure 3 2)
- From
To: Motor Driven Aux.
- 1. Containment FWD Pumps Penetrations 1 A and M-156, M-218; 86,. M-3100 and 3
M-465 up to and including check valves ICA37, ICA49, ICA53 and ICA65; i 2. The outlet of valves ICA70 and ICA72.
- 3. Feedwater System - CF (See Figure 3.3)
From: The Turbine 81dg. header; ' To: Containment Penetrations M-153, M-262, M-308, and M-440.
- 4. Safety Inlection System - NI (See Figure 3.4)
) From: Upper Head injection Nitrogen Accumulator; To: Upper Head injection Water Accumulator. From: Upper Head injection Water Accumulator; To: 1. Containment Penetrations M-334 and M-349;
- 2. Four 4" Stand Pipes.
- 3. Valves INI326, INI255B i 5. Boron Thermal Regeneration - NR (See Figure 3.5)
From: Valve INR92 (See NV System); To: Letdown Reheat Hx. From: Letdown Reheat Hx; To: Valve INR95 (See NV System). O Revision 3
,,,,-,-...-,,,.,-.-,..-,..._,,,,.,,-...,-_n -
, , , - . . _ , . , , , - - ,.,.,,,,,,.,,,,,,,,,,,m,,,.,.,., ,,,,-r, , ,,,,,,.,,.n.,.-.w,-.,-,.-,,e- - .-
Table 3-1 (Continued) 9 5. Chemical & Volume Control System - NV (See Figure 3.6) From: 1. Reciprocating chargine pump
- 2. Letdown Hx
- 3. Sealwater injection Filters IA and IB 3 To: lA. Penetrations M-350, M-339, M-344, M-343 and M-329; IB. Sea 1 water injection Filters IA and IB; 2A. Penetration M-347;
- 28. Valves INR92 and INR95; 2C. Valves INV121 and INV124; 3A. Valves INV225, INV231 and BIT outlets
- 38. Sealwater injection Filters A & B.
7 Main Steam Supply to Auxiliary Equipment - SA (See Figure 3 7) From: Main Steam lines IB and IC; To: The outlet of valves ISA48 and ISA49.
- 8. Main Steam System - SM (See Figure 3.8) 9 3 From:
To: Containment Penetrations M-154, M-261, M-393, and M-441; 1. 2. Turbine Bldg. 48" header; The outlet of the safety valves and power operated relief valves. 3 The outlet of low point drain valves. Note: Piping less than or equal to 1" NPS need not be considered for effects of pipe rupture.
's v
Revision 3
Table 3-2 McGUIRE NUCLEAR STATION TURBINE BUILDING HIGH ENERGY PIPING
- 1. Auxiliary Steam - AS From: Valva ISMI3; To: Valves 1ASil, IAS88.
3
- 2. Steam Generator Blowdow, - BB From: Service Bldg. trench; To: Valves 188123, 188124, 188125, 188126.
From: Steam Generator Blowdown Blowoff Tank; To: Steam Generator Blowdown Blowof f Pumps I A and 18. From: Steam Generator Blowdown Blowoff Tank Pumps IA and IB; To: Condensate System.
- 3. Ileating Boiler Feedwater - CB From: Aux. Electric Boller A and B Feedwater Pumps; To: Aux. Electric Boller A and B.
W 4. Feedwater - CF . From: Main FDV Pumps IA and 1B; To: 1. HP Heaters 181, 182, 183;
- 2. Valves ICF75, ICF81, ICF76.
From: HP Heaters 101, 182, 183; To: HP Heaters lAl, IA2, IA3 respectively. From: 1. HP Heaters IAl, IA2,1A3;
- 2. Valve ICF75; To: 1. Auxiliary Building Roof;
- 2. Valves ICF124, ICF107
- 5. FDWP Condensate Seal - CL From: Valves ICLi, ICL4; To: F0WP Seal injection Pumps I A and 18.
From: FDWP Seal injec' tion Pumps 1 A and 18; To: FDWP Seal injection Rx 1A and IB. From: FDWP Seal injection Hx 1A and IB; To: Main FDW Pump 1A and 18. U Revision 3
- , . -- - n.--,. -, . . , .- -.
Table 3-2 (Continued) 9 6. Condensate - CM From: 1. 2. LP Heaters IFI, IF2, IF3; Valves ICMl30, ICM420; To: Condensate Booster Pumps IA, IB, IC. From: Condensate Booster Pumps 1A, IB, IC; To: 1. LP Heaters IEl, IE2, IE3;
- 2. Val res ICH230, ICL1, ICL4.
From: LP Heaters IEl, IE2, IE3; , I To: LP Heaters 101, 102, 103 respectively. i From: 1. LP Heaters 101, 102, 103;
- 2. Valve ICH230; To: 1. LP Heaters IC1, IC2, IC3; ,
- 2. Valve ICH231.
From: 1. LP Heaters IC1, IC2', IC3;
- 2. Valves ICH231, IHW82, 1HW83, lHW84; ICF124; To: 1. UST Dome;
- 2. Main Feedwater Pumps IA and 18.
- 7. "A" Heater Bleed Steam - HA From: 1. HP Turbine; s 2. Valves IHM19,1HM20, lHM21,1HM22,1HM23, IHM24; To: 1. HP Heaters lA1, IA2, IA3;
') 2. MSR's 1st Stage.
- 8. "B" Heater Bleed Steam - HB From: 1. HP Turbine;
- 2. Valves IHM34, IHM35, lHM36,1HM37, lHM38,1HM39; To: HP Heaters 181, 182, 183 3l 9 Moisture - Separator - Reheater Bleed Steam - HM l From: Valves IHMI, lHM2, lHM3, lHM4, lHMS, lHM6, lHM13, lHM14, IMM15, lHM16, 1HM17, IHM18; To: MSR's 2nd Stage.
From: MSR's 2nd Stage; To: Valves lHMI9,1HM20, lHM21, IHM22, lHM23,1HM24. From: MSR's 1st State; To: Valves IHM34, IHM35,1HM36,1HM37, lHM38, lHM39 Revision 3 0
Table 3-2 (Continued)
- 10. Polsture - Seoarator - Reheater Drain - HS V From: MSR IAI, IA2, 181, 182, ICl, IC2; To: 1, 1st Stage Reheater Drain Tank 1Al, IA2, IBI,182, ICI, IC2 respectively; ,
- 2. 2nd Stage P.eheater Drain Tank !AI, l A2,181,182, ICI, IC2 respectively; '
- 3. Noisture Separator Drain Tar.k IAl, lA2,181,182, ICI, IC2 respectively.
From: 1st Stage Reheater Drain Tank 1A1, IA2, 181, 182, ICI, 1C2; To: 1. MSR,1st Stage, I A1, lA2,181,182, IC1, iC2 respectively;
- 2. Valves IHS35, IHS36, lHS93, 1HS94, IHS151, lHS152 respec-tively.
From: 2nd Stage Reheater Drain Tank 1Al, lA2, 181, 182, IC1, IC2; To: 1. MSR, 2nd Stage, lA1, IA2, 181, 182, IC1, IC2 respectively.
- 2. Valves 1HS57, iHS58, 1HSil5, IHSil6, 1HS173, lHS174 respec-tively.
From: 1st Stage Reheater Drain Tank 1A1, IA2, 181, 182, IC1, IC2; To: 1. HP Heaters 181, 182, 183 respectively;
- 2. Valves 1HS31, iHS32, lHS89, lHS90, lHSl47, IHS148 respec-tively.
From: 2nd Stage Reheater Drain Tank 1A1, IA2, IBI, 182, ICI, IC2; To: 1. HP Heater 1A1, I A2, I A3 respectively;
- 2. Valves IHS53, IHS54, lHSill, IHSil2, lHS169, IHS170, respec-
-} tively.
From: Moisture Separator Drain Tanks IAl, I A2,181,182, ICI, IC2; To: 1. Heater Drain Tanks ICl, IC2, IC3 respectively;
- 2. Valves IHS13, lHS14, lHS71, 1HS72, IHS129, lHS130 respec-tively.
II. Heater Drain - HW From: HP Heaters lAl, IA2, IA3; To: 1. HP Heaters 181, 182, 183 respectively;
- 2. Valves lHW22, 1HW23, IHW24 respectively.
From: HP Heaters 181, 182, 183; To: 1. Heater Drain Tanks ICI, IC2, IC3 respectively;
- 2. Valves IHW37, lHW38, lHW39 respectively.
From: Heater Drain Tank 1C1, IC2, IC3; To: 1. Heater Drain Tank Pumps ICl, IC2, IC3 respectively;
- 2. Valves IHW43, 1HW44, 1HW45 respectively.
l lO l
Table 3-2 (Continuzd) j 9 From: Heater Drain Tank Pumps IC1, IC2, IC3; To: 1. 2. Heater Drain Tank ICl, IC2', IC3 respectively; LP Heaters ICl, IC2, IC3 respectively;
- 3. Valves IHW85, IHW86, lHW87 respectively;
- 4. Valves IHW82, 1HW83, 1HW84 respectively.
From: LP Heaters 1D1, ID2, ID3; To: 1. LP Heatets IEl, IE2, IE3 respectively;
- 2. Valves IHW106, lHW107, lHW108 respectively; ;
I From: LP Heaters IEl, IE2, IE3; To: 1. LP' Heaters IFI, IF2. IF3 respectively
- 2. Valves IHW121, IHW122, lHW123 respectively.
- 12. Main S te a m Bypass to Condenser - SB -
From: Valve ISBl; To: Valves ISB3, 1586, 1589, ISB12, 15B15, 15818, 15821, 15824, 1S327.
- 13. Main Steam - SM From: Auxiliary Dullding Roof; To: 1. HP Turbine
- 2. Valves ISV30, ISV32, ISV34, ISV36; ISV38, ISV40, ISV42, ISV44, ISM 2, ISP1, ISP2, IZJ105, 1HM1, iHM2, 1HM3, lHM13, lHM14, IHMIS, lHM4,1HMS,1HM6, lHM16,1HMl7, lHM18, ISM 12, IS81.
- 14. Maln Steam Supply to FDWP Turbine - SP From: Valves ISPI, ISP2; To: FDW Pump Turbines IA and 18.
- 15. Main Turbine Leakoff & Steam Seal - TL From: Valves ITL21, ISM 2; To: Valves ITL6 and ITL8.
- 16. Plant Heating - YH i
3 i l l 17 Condenser Steam Air Elector - ZJ From: Valves IZJ105, lZJiO6; To: Valves lZJ2,1ZJ4, IZJ96 l O Revision 3
---,-,a- , . - -- , - _ , . ,., ,.--
MCGUIRE tiUCLEAR STATION AUXILIARY BUILDING MODERATE ENERGY PIPING SYSTEMS
- 1. Auxiliary Steam - AS
- 2. Steam Generator Wet Layup Recirculation .BW 3 Diesel Generator Engine Fuel Oil - FD
- 4. Refueling Water - FW .
5 Component Cooling - KC
- 6. Diesel Generator Engine Cooling Water - KD
- 7. Spent Fuel Cooling - KF
- 8. Recirculated Cooling Water -
KR 9 Diesel Generator Engine Lubricating Oil - LD
- 10. Boron Recycle - NB
- 11. Residual Heat Removal - ND
- 12. Ice Condenser Ref rigeration -
NF 13 Nuclear Sampling - NM
- 14. Containment Spray - NS
- 15. Fire Protection -
RF
- 16. Nuclear Service Water - RN
- 17. Containment Ventilatton Cooling Water -
RV
- 18. Breathing Air - VB 19 Diesel Generator Engine Starting Air - VG 20, riesel e Generator Engine Air intake & Exhaust -
VN
- 21. Station Air - VS
- 22. Equipment Decontamination -
WE O 23 Waste Gas - WG 24 Liquid Waste Recycle - WL -
, - , - , - , - - - ,.ce , - - - . , - - . . - - - , , - - - - , - -, - - - - - - - ,- -,
Table 3-3 (continued) O s 25. Liquid Waste Monitor and Disposal - WH t
- 26. Diesel Generator Room Sump Pump - WN 27 Nuclear Solid Waste Disposal - WS
- 28. Groundwater Drainage - WZ v 29 Chilled Water - YC
- 30. Plant Heating - YH
- 31. Makeup Demineralized Water - YM
- 32. Diesel Generator Engine Crankcase Vacuum - ZD 9 -
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