ML19256F030
| ML19256F030 | |
| Person / Time | |
|---|---|
| Site: | Peach Bottom  |
| Issue date: | 11/16/1979 |
| From: | Daltroff S PECO ENERGY CO., (FORMERLY PHILADELPHIA ELECTRIC |
| To: | Kane W NRC - TMI-2 BULLETINS & ORDERS TASK FORCE |
| References | |
| NUDOCS 7911200593 | |
| Download: ML19256F030 (110) | |
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PHILADELPHIA ELECTRIC COMPANY 2301 M ARKET STREET P.O. BOX 8699 PHILADELPHIA PA.19101 SHIELDS L. DALTROFF ELtcTm c Pn o cTiom November 16, 1979 Re: Docket Nos.: 50-277 50-278 Mr. William F. Kane Bulletins and Orders Task Force United States Nuclear Regulatory Commission Washington, DC 20555
Dear Mr. Kane:
Attached is the remainder of the information requested by the Bulletins and Orders Task Force for preparation of the NRC staff generic report on boiling water reactors. This Peach Bottom plant specific information is provided in a form recommended by the chairman of the BWR Owners Group and supplements the generic inf orma tion contained in General Electric Company Report NEDO-24708.
Should y ou have any questions, please do not hesitate to contact us.
Very t ru ly yours,
' l' < n. ;/ j/
,c .e Attachment b h c(4 3 p s 180
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PLANT Peach Bottom UNIT (S) II & III BYPASS CAPACITY Plant Steam Bypass Capacity, % Rated 26 1376 181
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PLANT Peach Bottom II & III SYSTEMS AND COMPONENTS SHARED BETWEEN UNITS PAGE 1 CONTINUED PAGE N/A Single-unit plant check here and do not c omp le t e Shared Between System or Component Units Numbers
- 1. The Emergency Service Water System II & III (Shown on attached drawing M-315 FD)
- 2. Condensate and refueling water transfer II & III system. (Shown on attached drawing M-309 FD)
- 3. The emergency diesel generators can II & III be connected t o buses on either unit.
- 5. The high pressure service water II & III systems share the emergency cooling t ower, and their supply line to the tower is common.
Neither the emergency cooling tower or the common supply line are required f or normal high pressure service water system operation.
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PI_ Ah'T P E ACH DOTTOM UNITS II & II PLANT SPECI FIC SYSTEM INFURMATION FREQUENCY OF SYSTEM GFNEFAL WATEk SOURCES INSTPUMENTATION E CONTkOL E COMPONENT TESTS Safety Seismic Safety Seismic Safety Seismic 9YRTEM Classtfication Category Classification Category Cl ssification Category O- abb CD RCIC Group II Class i Suppression Suppression Quality Class I See Attached Sheets Except Pool - GroupI Pool-class! Assured as noted cond. Stor. Cond.Stor. Equipment on M-309F3 Tank-Group III Tank-Non Seismic isolation N/A N/A N/A N/A N/A N/A N/A Condenser H PCS N/A N/A N/A N/A N/A N/A N/A H PCI Group II Class I Suppression Suppre ssion Quality Class I See Attached Sheets Except as Pool-Group I Pool-Class I Assured noted on Cond.Stor. Cond.Stor. Equipment
[ M-365 FD Tank-Group III Tank - Non i
Seismic I.PCS Group II Class I Suppression Suppression Quality Class I See Attached Sheets Except as Pool -Group I Pool-Class 1 Assured noted on Cond.Stor. Cond.Stor. Equipment M-362FD Tank-GroupIII Tank - Non Seismic LPCI Groups 1 E Il Class I Suppression Suprresion Quality Class I See Attached Sheets See M-361 FD Pool-Group I Pool-Class! Assured Equipment ADS ASME III A ASME III A N/A N/A Quality Class I See Attached Sheets Assured
~~^ Equipment L/4 N Quality Class I See At tached Strets (js SFV ASME III A ASME III A N/A N/A Assured Equipment C3 FHF (i nclu.11 ng Groups I,II class I Supression Suppression Quality Class I See Attached St.eets C7%
Shut down III, See Paol-Group I Pool-Class! Assured Cooling,Stess M-361 FD Hiqt Pressure High Pressure Equipment coniensing, Service Water Service Suppression Group II Water-Classi Pool Cooling, cont ainment Spriy Modes)
P PLANT PEACil BOTTOM UNIIS II 6 II PLANT SPECIFIC SYSTEM INFOkHATION FPE00Lt;CY OF SYSTEM WATEP SOURCES I NSTb tlMENT ATTON 6 CONTkOL 6 COM PONt HT TESTS G FH EP 41.
Saf et y Seismic safety Seismic safety Seismic Classification Category Cl SYSTEM Clatsific4 tion e
C a tegory
&%sificationCategory Group II Class I Morral source Normal source Quality Class I See Att ached Sheets SSV (l!PSW) Assured is river' la river nackup source: Backup source: Equipment Emergency Emergency C00 ling Cooling Tower-Group II Tower-class I dD System is normally Group III Non-Se is mi c N/A closed N/A closed Non-Quality Non Seismic F BCCW Loop Loop Assured in service Equipment No routine testing requirel I
wa I
CRDS Scram Systen Scram System Cor.densate Condensate Quality Class I See Attached Sheets Group I class I Sys: Group III Sys: Non- Assured Bemainder- Pemminder- Cond. Stor. Seismic Equipment Group III Non Seismic Tan >-Group III Coni. Stor.
See M-356FD See M-15bFD Tank - Non Seismic Non-Seismic Non-Quality Non Seismic Ho Foutine Testing CST Group III Non-9eismic Group III Assured Pe r f or.n ed Equipment Class I-From Group III Non-Scismic Non-Quality Non Seismic See Attacted Steets Feedwater Group I-From ostboard chk. outboard chk. Assurei viv. to viv. to Equipment reictor to reictor Remainder- Fem 4 i n ter-
__. Group III Non-Seismic
@ System is normally
d kecire. Group III Hon-Seismic N/% closei tUA closed Non-Quality Non-Seismic CJN ' um p/ Mot o r Assured in service Equipment No rout ine Testani Cooling is requirel.
N
NOTES FOR SEISMIC / SAFETY CLASSIFICATION TABLE
- 1. General classification of piping and equipment pressure parts in defined as follows:
Group I - Piping and equipment pressure parts within the react or p rimary pressure boundary th r ou gh the outer isolation valve, inclusive.
Group II - Piping and equipment pressure parts downstream of the ou ter is ola tion valve and extensions of containment and the Core Standby Cooling Systems.
Group III - Balance of plant piping and equipment pressure parts, including p ower generation systems .
Requirements for these different groups appear in the Peach Bottom Final Saf ety Analysis Report Appendix A. A copy of Appendix A is included with our submittal f or your convenience.
2.- The RBCCW heat exchangers, Emergency Service Water interface, piping f rom containment penetrations th r ou gh is olation valves and the isolation valves are being analyzed and/or modified to meet seismic class I requirements.
3 Safety classification and seismic category ref er to essential instrumentation only.
- 4. The Peach Bottom Quality Assurance list is the single controlling document which c omp le t e ly identifies the s t ru c t u r e s , systems, and comp onents important to safety and -
required to assure:
a) integrity of the reactor coolant pressure boundary b) capability to achieve and maintain safe shutdown c) capability to prevent or mitigate the consequences of an accident which could result in p otential of f site exp s,"re comparable to the guidelines of 10 CFR 100.
Specific a trf ormance criteria must be met for all such equipment and its acceptability must be documented. Non-quality assured equipment may meet or exceed the performance criteria of quality assured equipment but its performance is not documented.
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requency of System and Component Tests 1375 194' TEST TITLE FREQUENCY SYSTEM = RCIC TEST TITLE FREQUENCY
- 1. RCIC Logic System Functional Test Once per 6 months
- 3. RCIC Pump, Valve, Flow and Cooler Once per month Test
- 4. RCIC Pump Test Once per operating cycle
- 5. RCIC Torus Suction Check Once per operating Valve Operability cycle
- 6. RCIC Flow Rate at 150 psig once per operating Steam Pressure cycle
- 7. RCIC Simulated Auto Actuation Once per operating Test cycle .
- 8. RCIC Vacuum Relief Valve Quarterly Functional Test
- 9. RCIC Turbine Governor Each Refueling Calibration Outage
- 10. RCIC Steam Line High Flow Quarterly Differential Pressure Switch Calibration Check
- 11. RCIC Steam Line High Flow Once per month Differential Pressure Switch Functional Test
- 12. RCIC Steam Line Pressure Switch Quart e r ly Calibration Check
- 13. RCIC Steam Line Pressure Switch Once per month Functional Test
- 14. RCIC Steam Leak Detection Once per month Te mp e ra tu r e Switch Functional Test
- 15. Calibration Check of RCIC Quarterly (accessible Steam Leak Detection switches) - Once Temperature Switch per operating cycle -
(inaccessible switches)
- 16. Calibration Check of RCIC Once per operating low level initiation trans- cycle.
mitters/ switches
- 17. Functional Test of RCIC low Once per month level initiation switches
- 18. Calibration Check of:
A. RCIC Pump Discharge Header Once per 2 years Pressure Transmitter B. RCIC Pump Suction Header Pressure Transmitter TEST TITLE FREQUENCY C. RCIC Turbine Steam Pressure Transmitter D. RCIC Turbine Exhaust Pressure Transmitter
- 19. RCIC Turbine Speed Sensor Once per operating Calibration Check
- 20. Calibration Check of:
A. RCIC Pump Suction Header Once per operating Pressure Switch B. RCIC Pump Turbine Exhaust Pressure Switch C. RCIC Vacuum Tank Level Switch 1375 196 SYSTEM = HPCI TEST TITLE FREQUENCY
- 1. HPCI Logic System Functional Once per 6 months Test
- 3. HPCI Pump. Valve, Flow, and Once per month Coo;er Test
- 4. HPCI Torus Suction Check Once per operating Valve Operability cycle
- 5. HPCI Auxiliary 011 Pump Weekly Surveillance
- 6. HPCI Flow Rate at 150 psig once per operating Steam Pressure cycle
- 7. HPCI Simulated Automatic Once per operating Actuation Test cycle
- 8. HPCI Vacuum Relief Valve Quarterly Functional Test 9 HPCI Turbine Covernor Calibration Once per operating cycle
- 10. Functional test of HPCI High once per month Drywell Pressure Initiation Switches
- 11. Calibrati on Check of HPCI High once per 3 months -
Drywell Pressure Initiation Switches
- 12. Functional Test of HPCI steam Once per 3 months Supply Low Pressure Switches
- 13. Calibration Check of HPCI Once per 3 months Steam Supply Low Pressure Switches
- 14. Functional Test of HPCI Steam Once per month Supply Line High Flow Differential Pressure Switches
- 15. Calibration Check of HPCI Steam Once per 3 months Supply Line High Flow Differential Pressure Switches
- 16. Functional Test of HPCI Area Once per month High Temperature Switches
- 17. Calibration Check of HPCI Area once per 3 months High Temperature Switches (accessible)
Once per operating cycle (inaccessible switches)
- 18. Calibration Check of HPCI Once per operating Reactor Low Level Initiation cycle Switches / Transmitters
- 19. Functional Test of HPCI Reactor Once per month Low Level Initiation Switches
- 20. Functional Test for Condensate Once per month Storage Tank Low Lsvel Switches 1375 i97 SYSTEM = HPCI TEST TITLE FREQUENCY (t rans f er HPCI Pump Suction to Torus)
- 21. Calibration Check of Condensate Once per 3 months Storage Tank Low Level Switches
- 22. Calibration Check of:
A. HPCI Pump Discharge Pressure Once per 2 years Transmitter B. HPCI Turbine Steam Pressure Transmitter C. HPCI Turbine Exhaust Pressure Transmitter D. HPCI Pump Suction Pressure Transmitter
- 23. Calibration Check of HPCI Once per operating Flow Transmitter cycle 24 Calibration Check of HPCI Speed Once per operating Element cycle
- 25. Calibration Check of:
A. HPCI Pump Turbine Exhaust once per operating High Pressure Switches cycle B. HPCI Pump Suction Low Pressure Once per operating Switch cycle kb{
SYSTEM - LPCS TEST TITLE FREQUENCY
- 1. Core Spray 'A' Logic System Once per 6 months Functional Test
- 2. Core Spray 'B' Logic System Once per 6 months Functional Test
- 3. Core Spray 'A' Pump, Valve, Once per month Flow, and Cooler Test
- 4. Core Spray 'B' Pump, Valve, Flow Once per month and Cooler Test
$. Core Spray 'A' Pump Test Once per operating cycle
- 6. Core Spray 'B' Pump Test once per operating cycle
- 7. Daily Core Spray System Test Daily if one diesel, one core spray pump, or LPCI is inoperable
- 8. Core Spray Simulated Automatic Once per operating Actuation Test cycle
- 9. Functional Test of Drywell High Once per month Pressure Core Spray Initiation Switches
- 10. Calibration Check of Drywell once per 3 months High Pressure Core Spray Initiation Switches
- 11. Functional Test of Reactor Once per month L ow Pressure Switches (Core Spray Permissive)
- 12. Calibration Check of Reactor Once per 3 months Low Level Pressure Switches
- 13. Calibration Check of Reactor Once per operating Low Level Core Spray Initiation cycle Switches /tramsitters
- 14. Functional Test of Reactor Once per month Low Level Core Spray Initiation Switches
- 15. Functional Test of Core Spray Once per operating Stayfull Level Switches cycle
- 16. Cali'..ation Check of:
A. Core Spray suction pressure Once per operating indicators cycle B. Core Spray pump differential switches f or pump minimum flow protection C. Core Spray pump discharge pressure indicators D. Core Spray Discharge Pressure Switches E. Core Spray Discharge Pressure Transmitters F. Core spray Loop Flow 1375 199 SYSTEM - LPCS S TITLE FREQUENCY Transmitters
- 17. Functional Test of Core spray Once per month Sparger t o Reactor Dif f erential Pressure Switches
- 18. Calibration Check of Core Spray Once per 6 months Sparger to Reactor differential Pressure Switches 1375 200 SYSTEM: LPCI TEST TITLE FREQUENCY
- 1. RER 'A' Logic Syssem Functional Once per 6 months Test
- 2. RHR 'B' Logic System Functional Once per 6 months Test
- 3. RHR 'A' Pump. Valve, Flow and Once per month Cooler Test
- 4. RER 'B' Pump, Valve, Flow and Once per month Cooler Test
- 5. RHR Pump Functional Test once per operating cycle
- 6. Daily RHR System Operability Daily if one diesel Test or one RHR pump is inoperable
- 7. RHR Simulated Automatic Once per Operating Actuation Test Cycle
- 8. LPCI system Valve Swing B i-mo n t h ly Bus Test 9 LPCI Cross Connect Valve Each refueling outage Position
- 10. Functional Test f or Dryvell Once per month High Pressure LPCI Initiation Switches
- 11. Calibration Check for Drywell Once per 3 months High Pressure LPCI Initiation Switches
- 12. Functional test for Reactor Once per month Low Level LPCI Initiation Switches
- 13. Calibration Check of Reactor Once per operating Low Level LPCI Initiation cy cle S wit ch e s / Transmit t ers
- 14. Functional Test for Reactor Once per month Low Pressure Switches (LPCI Permissive)
- 15. Calibration Check for Reactor Once per 3 months Low Pressure Switches
- 6. Functional Test of LPCI stayfull Once per operating System Switches cycle
- 17. Calibration of RHR pressure, Once per operating flow, transmitters & indicators cycle and pump dif f erential pressure switches kbY SYSTEM: ADS TEST TITLE FREQUENCY
- 1. ADS 'A' Logic System Functional Once per 6 months Test
- 2. ADS 'B' Logic System Functional Once per 6 months Test 3 ADS Simulated Automatic Actuation Prior to Startup Test f rom each refueling outage
- 4. ADS Relief Valve Accumulator Once per operating Leak Test cycle
- 5. Functional Test of High Dryvell Once per month Pressure ADS Initiation Switches
- 6. Calibration check of High Once per 3 months Drywell Pressure ADS Initiation Switches
- 7. Functional Test for Core Spray Once per month Pump Discharge Pressure Switches (AD S Permissive)
- 8. Calibration Check of Core Once per 3 months Spray Discharge Pressure Switches (ADS Permissive)
- 11. Calibration Cheek of Reactor Once per operating Low Level ADS 21tiation cycle Switches / transmitters
- 12. Functional Test of Reactor Low Once per month Level ADS Initiation Switches
- 13. Calibration Check of Reactor Once per operating Low Level ADS Permissive Switches / Transmitters.
- 14. Functional Test of Reactor Once per month Low Level ADS Permissive Low Level ADS Permissive Switches 1375 202 SYSTEM: SRV TEST TITLE FREQUENCY
- 1. Relief Valve Manual Actuation Once per operating cycle
- 2. Relief Valve Bellows Leak Once per operating Detection Pressure Switch cy cle Functional Test 1375 203 SYSTEM: RER TEST TITLE FREQUENCY
- 1. RHR 'A' Logic System Once per 6 months Functional Test
- 2. RHR 'B' Logic System Functional once per 6 months Test
- 3. RHR 'A' Pump, Valve, Flow, and Once per month Cooler Test
- 4. RHR 'B' Pump, Valve, Flow, and Once per month Cooler Test
- 5. RHR Pump Functional Test Once per operating cycle
- 6. Daily RBR system Operability D aily if one diesel Test or one RHR Pump is inoperable
- 7. RHR to Fuel Pool Vacuum Relief Once per Operating Valve Functional Test
- 8. Head Spray Check Valve Functional Each time lead spray Test is used
- 9. Calibration Check of Shutdown Cooling Permissive Switches (React or Pressure)
- 10. Functional Test of Shutdown Cooling Permissive Switches (Reactor Pressure)
- 11. Calibration Check of Once per operating Containment Spray Reactor Level Permissive Switches /
Transmitters
- 12. Functional Test of Contain- Once per month ment Spray Reactor Level Permissive Switches
- 13. Functional Test of RHR once per operating Stayfull System Level cycle Switches
- 14. Calibration of RER pressure Once per operating
& flow transmitters / indicators cycle and pump dif f erential p ressure switches 1375 204 SYSTEM: SSV (HPSW)
TEST TITLE FREQUENCY
- 1. HPSW Pump and Valve Once per month Operability and Flow Rate Test
- 2. HPSW Pump Operability Once per operating cycle
- 3. Daily HPSW System Operability and Daily while two or more Flow Rate Test HPSW pumps, 1 diesel, or 3 containment cooling subsystem are inoperable
- 4. HPSW Pump Bay MUD Accumulation Once per month Measurement
- 5. HPSW Pressure and Flow Loop Once per operating Calibration Check cycle
- 6. HPSW Bay level indication Once per operating calibration cycle t
1375 205 SYSTEM: CRD TEST TITLE FREQUENCY
- 1. CRD Withdraw Stall Flow Test Once per month 2, CRD Check Valve ISI Each time CRD is used Functional Test for reactor makeup.
At least once per operating cycle
- 3. CRD Hydraulic Control Once per 2 years Calibration NOTE: Additional testing on the Reactor Protection System and the Reactor Manual Control 3ystem may also involve the CRD system i375 206 SYSTEM: FEEDWATER TEST TITLE FREQUENCY
- 1. Calibration of Feedvater Once per 6 months Control Ins truments (Reactor Pressure and Level)
- 2. Calibration of Feedwater Once per operating cycle Flow Loops
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16 Water = Inside RO I Core Plate 31 Out side KFCV Pressure N-52F 1" Inst Gas No 10 Air - -
Outside CK Flow - - - - 0 0 C -
Surrly AO-2969B II(A,B) Outside OCV InstAir Sprin, 5 B D 0 0 C C N-53 8" Chilled W tr. f. om NO 29 Water MD-2201B RM Outside GT AC Motor Manual 42 3 D 0 0 C as is Drywell cooleri t loop A N-54 8" Chilled water NO 29 Water Mo-2200B RM Gutside GT AC Motor Manual 42 3 D 0 0 C as is from drywell coeters IoorB N-55 8" Chilled wtr. fri a No 29 Water Mo-2200 L RM Outside GT AC Motor Manual 42 3 D O O C as is drywell coolers Loop B U N-56 8" Chilled wtr to No 29 Water Mo-2201A RM Outside GT AC Motor Manua 42 3 D 0 0 C as is q Drywell cooler i g I4OP A 1(A B,C,1>,E)Inside C N-57 -3/4" Main sta.line No 24 Steam AO-2316 DCV Inst Can Sprini 5 A D C C C N "D" sample AO-2-317 1 ( A,b ,C.D E) Outsic e DCV InstAir Sprin, 5 B D C C C C
P1 ANT Peach Botene UNIT (S) II & III .
PRIMARY CONTAINMENT ISO 1ATION SYSTEM DATA Page 7 i ,
I
@ @ l
@ Made of b @ @
Valve Position Actuation S c S I 3 E a pc G t -
c aO 5 3 .3 .7 8: c : :
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N-1323 1" Inst.Line -Unit Yes 19 Air 538,D Outside GB 2 Dryvell Press 60B D Outside GB N-203 1" CACS & CAD Sampi ?
Line - CACS No 27 Air SV-2671B III Outside SV AC Coil Spring -
A I O O C C
-CACS No SV-2978B III outside SV DC Coil -
B I O O C C
- CAD Yes SV-4960D RM Outside SV AC Coil - D N C C O C
- Rad Ces No SV-4966D RM Outside SV AC Coil -
3 N C C C C nat Yes - Outside CB - -
- d'AD Yes SV- 49610 RM Outside SV AC Coil Spring D N C C 0 C N-20$A 20" Torus V acuum Yes 30 Air AO-2502B RM Outside B Inst. Ali Spring 5 3 D C C C 0 Breiker 9-268 - Outside VB Flow - - - - C C C -
1 - Outside CB - - l ta s~
l N-206A,t 2" Inst Lines - Yes 15 Air / -
Outside CB Torus Level water N-210A, 18" RHR Test & Pool Yes 31 Water FD-lO-34 VII Out side CB AC letor Manual 24 C,D D C C C as is l B cooling return A,8 10-19A B, ., - Outside CK Plow - - - - C 0 0 -
D N-211A, 6" RIIR Iorus Spray B -RHR Yes 31 Water HD-10-38 VII Outside CB AC Motor Manual 30 C,D D C C C as in A,B
-RNR MD 39 VII Outside GT AC Motor Manual 112 C.D D C C C as is A,B
-RNR HO-10-34 VII Outside CB AC Motor Manual 24 C,D D C C C as is A,B
-CAD sy-4950 RM Outside SV AC Coil - - C,D N C C 0 C AB b -CAQ syI4951 R1 Outside SV AC Coil - - C,D N C C 0 C N' AB Os -CAD . -
Out side CK Flow - - - - C C O -
N-212, 12" HICI & BCIC N 214 Turbine Exhaust -
~
2178 -RCIC No 33 S teasi 13-9 - Outside SCK Flow - - - - 0 0 0 -
D -RCIC No 13-50 -
Outside CK Flow - - - - 0 0 0 -
-RCIC NO RO-4240 TT Outside DCV Inst Air Spring 5 6 D O O O C
-RCIC No A0-4241 TT Out side DCV Inst Air S pring 5 6 D 0 0 0 C
, 2 4 -HFCI Yes steam 23-12 - Outside SCK Flow - - - -
0 0 0 -
-HPCI Yes 23-65 - Outside CK Flow - - - - 0 0 0 -
-itI'Cl Yes AO-4247 TT Outside DCV Inst air Spring 5 6 D 0 0 0 C
. e PLANT Peach Bottom tNIT(S) IT & III ,
PRIMARY CONTAINMENT ISOIATION SYSTEM DATA Fage 8 h @ h Nde of h h @ !
Act ua tion valve Position 5 c o I
. 3 E e c c M E . 1 E
%. o S O 8 D
3 e.3 .7 8 i t .E t t *
.t "
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ag : : .[.
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-HPCI Yes AO-4248 TT Out side DCV Inst Aid Spring 5 6 D 0 0 0 C 2" -Vac relitf No Air HD-4244 IV(C D.E) Out side GT DC Motor Nnual 15 E D O O C as is .
-Vac relief Yes MD-4244A IV(C.D.E) Outside CT DC Motor Nnual 15 F D 0 0 C us is N-213A 1" Torus Drain (with level inst) - 15 Water - Outside CB N-215 1" Inst Line -Unit -
15l Air - Outside CB 2 Torus level N-216 4" HPCI Min. Flow Yes 32 "Ja te r 23-62 -
Outside ! CK Flow - - - -
C C C -
N-218A 1" Inst. Cas Supply No 10 Air - -
Out side CK Flow - - - - O O C -
l AO-2468 II . A, B) Out side DCV Inst Air Spring 5 B D 0 0 C C w
N-2188 1" CACS Sample No 26 Air SV-2671A III Outside SV AC Coil - - A I O O C C
[ Line SV-2978A III Outside SV DC Coil - -
B I O O C C N-218C 3/4" ILRT Connectior No 18 Air -
II Outside GBC Manual - - - -
C C C -
N-219 18" Torus Purge Exhaust -CACS No 34 Air AO-2511 III Out side B Int Air Spring 5 A D C 0 C C
-CACS No AO-2512 III Outside B Int Air Spring 5 8 D C O C C
-CAD Yes AO-2513 III Outside DCV Int Ar i Spring 5 A D C C 0 C
-CAD Yes AO-2514 III Outside DCV Int Air Spring 5 B D C C O C
-CACS anal No SV-2671F III Outside SV AC Coil - -
A I O O C C
-CACS ANAL No SV-2978F III Out side SV DC Coil - -
B I O O C C
-CAD anal Yes SV-4960A RM Outside SV AC Coil - -
C N C C 0 C
- -CAD u anal Yes SV-4961A RH Outside SV AC Coil - - C N C C O C y -Rad Gas No SV-4966A RM Outside SV AC Coll - -
3 N C C C C (JN N-221 2" HCIC Vacuum No 35 Air 13-10 -
Out side SCK Flow - - - - 0 0 0 -
N Pump Disch 13-38 -
Outside CK Flow - - - - C C O -
23-13 Flow 0 0 0 m HPCI Turbine -
N-273 2" Yes 35 Water - Outside SCK - - - -
Drain 23-56 - Outside CK Flow - - - - C C O -
N-224 10" Core S tray test Yes 36 Wster MO ".4-26 6 VI Outside CE AC Ntoi Nnua l 1 C C C C C as is Line-Unit 2
PtANT Peach Bottom LHIT(S) 11 & III .
PRIMARY CONTAINHENT ISO!ATION SYSTEM IATA Page 9 h @ @ Hode of h @ h valve Position Actuation o e o I
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No sater - -
Outside CKC Flow - - - -
C C C -
14-66A,C Outside CKC Flow - -
C C C -
Yes - - -
N-225 6" RCIC & Turus No 37' Water m-13-41 RH Outside GT DC Motor Manual 33 E D C C O as in Water Cleerup No m-14-70 II(p,B) Outside GT AC Motor Manual 20 E D C C C as la Suct. No Ho-14-71 II(A,B) Outside CT D C Hotor m nual 20 A D C C C as la i
N-226A 24" RHR Pump Suctio ayes 38 Water m-10-13 RH Out side GT AC Motor Manual 30 A.B.C.D. D 0 0 0 as is to D A to D RV-10-72 -
Outside RV Flow - - - - C C C -
A to D 8 N-227 16" HfCI Pump Suctian Yes 39 Water H0-23-58 IV(A,B,C l Outside GT DC Motor Manual 5 Y D C C 0 as is w
4-228 16" Yes 40 Ho-14-7 Out side GT AC M2 tor Manual 80 A,B,C,D, D G O O as is f A to D Core Spray Pump suction water A to D BH N-229 4" Core spray pum; Yes 41 Water 14-668,IJ - Outside CK Flow _ _ _,
- 0 0 0 -
Hin Flow - - - Outside CK Flow - - - -
C C C -
Unit 2 N-230 2" HCIC Pump Min No 42 6 Water 13-29 _
Outside CK Flow - - - -
C C C -
now ,
9 N-233 4" liFCI Test Line- Yes 43 Water Ho- 23-31 V(D.F) Outside GT DC Motor Manua 15 F D C C C as is Unit 2 N-234 10" Core array ,est Line -Unit 2 Yes 44 Water HO-14-2tli VI Out side GB AC Hotor Manual 14 D D C C C as is Outside CK Flow - - - - C C C e N-234A 10" C. > r e Spray tesi Yes 44 Wates i HO-l+-2U VI Outside CD AC Hotor Manual la D D C C C as is
~ N-234B 10" Co"reNrYy*Mest Yes 44 Water Mo-14-26L VI NNe GB" AC tor Mahal ITe C D' [ b b as~1s y Line - Unit 3 - -
Outside CK(2) Flow - - - C C C -
N N-235 4" HICI Test Line V Unit 3 Yes 43 Water Ho-23-31 V(DF) Outside GT DC Motor Manual 15 F D C C C as is N N-236A 4" Core S pray PumF Yes 45 Water 14-66B.D - Out side CK Flow - - - - 0 0 0 -
Hin. Flow -
,y Unit 3 N-236B 4" Core S tray PumF Yes 41 Water 14-66-A,( - Outside CK Flow - - - -
0 0 0 -
Min Flow - No : CK Flow - - - ~
C C C - I Unit 3
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PEACH BOTTOM ATOMIC POWER STATION Containment Isolation Valves NOTES:
- 1. Valve Numbering: All valve numbers apply to both units, except 4 digit numbers. For those valves, the first digit designates the unit: 2 or 4 - Unit 2; 3 or 5 - Unit 3.
Vacuum Breaker CK -
Check IV - Explosive Valve BL - Ball RO - Restricting Orifice B - But terf ly BCK - Ball Check SV - Solenoid HCU - Hydraulic Control Unit RV - Relief IFCV - Excess Flow Check Valve SCK - Stop Check
- 3. Isolation Signals:
Group I 'A. Reactor Low Water Level (-48")
B. High Steam Line Flow (140%)
C. High S team Tunnel Temp . (2001F)
D. Low Steam Line Pressure (850 psi in Lun mode)
E. High Steam Line Radiation (3 x normal)
Group II A. Reactor Lov Water Level (o")
B. High Drywell Pressure (2 psig)
C. RWCU High Flow (300%)
D. RWCU non-regen. heat exch. high temp. (2001F)*
E. High Reactor Pressure (s hu t d own cooling -
75 psig)
F. High Reactor Pressure (600 psig)
G. Standby Liquid Control System Operation
- Group III A. Reactor Low water Level (0")
B. High Drywell Pressure (2 psig)
C. Reactor Bldg. High Radiation (16 mr /hr)
D. Ref ueling Floor High Rad. (16 mr /h r)
Group IV A. RCIC Steam Line High Flow (300%)
B. RCIC Steam Tunnel High Temp.
2001F)
C. RCIC Steam Line Low Pressure (50 psig)*
D. High Drywell Pressure (2 psig)
E. RCIC Steam Line Isolated Group V A. HPCI Stm. Line High Flow (300%)
~38- 1375 218
B. HPCI Stm. Tunnel High Temp.
2001F)
C. HPCI Sem. Line Low Pressure (100 psig)*
D. High Drywell Pressure (2 psig)
E. HPCI Stm. Line Isolated F. Reactor Low Watsr Level (-48")
Group VI - Reactor Low Water Level (-144")
- High Drywell Pressure (2 psig)
Group VII LPCI Initiation:
- Reactor low Water Level (-144")
- High Drywell Pressure (2 psig)
& React or Low Pressure (450 psig)
RM - Remote Manual M - Manual (local only)
LC -
Locked Closed TT - Turbine Trip
- RMP - Push Bottom, momentary contact opens valve for test
- Process Signals
- 2. Valve control cables are not presently assigned to a safeguard channel. Modification in p rogress to s up p ly valve with correct designation, diverse isolation signal, and p roper reset logic.
- 4. "S" indicates standard closing time. The standard minimum closing rate for automatic isolation valves is based on a nominal line size of 12 inches. Using the standard closing rate, a 12-inch line is isolated in 60 seconds. Conversion to closing time can be made on this basis using the actual size of the line in which the valve is installed.
- 5. The p ower supplies for the valves are identified as one of the following:
A - safeguard AC channel A (onsite emergency diesel buses)
B - safeguard AC chan'nel B (onsite emergency diesel buses)
C - s af eguard AC channel C (onsite emergency diesel buses)
D - safeguard AC channel D (onsite emergency diesel buses)
E - safeguard DC channel A (onsite emergency diesel buses)
F - safeguard DC channel B (onsite emergency diesel buses)
N - non-safeguard 1375 219
For cable routing purp os es , channels A&C - AC and A-DC are assigned to Division I and channels B&D - AC and B-DC are assigned t o Division II.
The f ollowing special notes apply:
- 1. The p ower f or valve 10-25 A au t oma tically transfers between A and C depending upon availability. The controls are assigned t o saf eguard channel A. The power for valve 10-25B automatically transfers between B and D depending upon availability. The controls are assigned to saf eguard channel C.
- 2. Testable che ck valve , power and controls do not affect isolation function.
- 3. Valve control cables are not presently assigned to a cafeguard channel. Modification in progress to supply valves with correct designations.
- 4. Valves are not powered f rom onsite supplies and control cables are not assigned t o saf eguard raceways. Modification in p rogress t o correct concern.
- 5. Controls for the TIP ball, shear and purge valves are not separated and are not assigned to safeguard channels.
- 6. Valve control cables r;e not presently assigned to a saf eguard channel. Modification in progress to supply valve with correct designation, diverse isolation signal, and p roper res et logic.
- 6. Position indication for the valves is identified as follows:
D. direct indication f rom position switches at the valve.
I. indirect indication - usually light is electrically parallel t o s olenoid.
N. no indication as to valve p osition.
Position is indicated in the control room.
- 7. Isolate only if in shutdown cooling mode.
- 8. Modification in progress to cap this line.
1375 220
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PLANT Peach Bottom UNIT (S) II & III DESIGN REQUIREMENTS FOR CONTAINMENT ISOLATION BARRIERS Question:
Discuss the extent to which the quality standards and s eismic design classification of the containment isolation provisions follow the recommendations of Regulatory Guides 1.26,
" Quality Group Classifications and Standards for Water ,
Steam , and Radioactive-Water-Containing Comp onents of Nuclear Power Plants", and 1.29, " Seismic Design Classification".
Response
NRC regulatory Guides 1.26 and 1.29 had not been issued at the time Peach Bottom Atomic Power Station was being designed and constructed. The approach to Quality Group and Seismic Class of the piping and valves associated with each line penetrating primary containment is described in the FSAR, Appendix A.
Appropriate Quality Groups are listed on the at tached t able.
All lines penetrating primary containment are Seismic Class I, out to and including the outer is olation valve, with the following exceptions:
- 1) Piping at the f ollowing penetrations is pres ently being upgraded to Seismic class I:
N-21, Service Air Supply N-23, 24 RBCW to and f rom Recire. Pumps N-53 to 56 Chilled Water to and f rom Drywell Coolers
- 2) Evidence of seismic analysis of the f ollowing s mall lines can not be located at the present time:
Penetration Line Description N-36 A to E TIP Drives N-35F TIP Purge Our Engineering Department is continuing to investigate these lines. Reanalyses and/or modifications will be made as necessary to meet seismic standards.
- 3) Seismic analyses for certain valves can not be located at the present time. All appropriate manufacturers have been contacted and are in the p rocess of s u p p ly in g analy s es for these valves.
1375 243
PLANT Peach Bottom UNIT (S) II & III PROVISIONS FOR TESTING Question:
Discuss the design provisions for testing the op e rabili ty of the isolation valves.
Response
Isolation valves are designated for operability testing as f ollows:
- a. p ower op erated, automatically initiated isolation valves are tested once per operating cycle f or sinulated automatic initiation and closure times.
- b. normally open, p ower cp erated is olation valve s (except MSIV's) are fully closed and reopened once p er quarter.
- c. MSIV's are tripped individually to verify closure time at less than 75% reactor power, once per quarter.
- d. Ins t rume nt line excess flow check valves are tested once per operating cycle.
Local leak rate tests are p erf ormed once p er op erating cycle, as indicated on the attached table.
1375 244 PLANT Peach Bottom UNIT (S) II & III CODES, STANDARDS, AND GUIDES Question:
Identify the codes, standards, and guides applied in the design of the containment isolation system and system c omp onent s .
Response
The f ollowing codes, standards, and guides were applied in the design of the containment isolation system and system c omp onent s :
10 CFR 5 0, Appendix A , General Design Criteria 54, 55, 56, and 57 IEEE 279 (August 1968)
ANSI B31.1.0 (1967)
Other codes and s tandards used f or design, fabrication, installation, and inspection of piping systems are discussed in detail in FSAR, Appendix A.
By NRC request, isolation valve tes ting p rovisions have been reviewed against 10 CFR 50, Appendix J. A Technical Specification change request resulting f rom this review was submitted in November, 1976.
1375 245 PLANT Peach Bottom UNIT (S) II & III NORMAL OPERATING MOEES AND ISOLATION MODES Question:
Discuss the normal operating modes and cantainment isolation provision and p rocedures for lines that t ransf er p otentially radioactive fluids out of the containment .
Response
The following are the systems that have the ability to trans f er p ot entially radioactive gases or liquids outside the primary containment:
Cas Systems Containment Ventilation and Purging System Dryvell Oxygen Analyzer System Standby Gas Treatment System Containment Atmospheric Dilution System CAD 0xygen and Hydrogen Analyzer Systems Main Steam Lines and Drains Reactor Core Isolation Cooling Steam Line High Pressure Coolant Injection Steam Line Liquid Systems Residual Heat Removal System Core Spray System High Pressure Coolant Injection System Reactor Core Isolation Cooling System Reactor Water Cleanup System Dryvell Sump S y s t e ms Torus Water Cleanup System Primary Coolant Sampling Sys tems
- a. No interlocks currently exist to prevent transfer of potentially radioactive gases or liquids when high radiation leve ls exist in the p rimary containment. However, the applicable p rocedures do require measurement of activity levels within containment prior to venting of containment or resetting of is ola tion s ignals .
- b. All such systems are isolated by the applicable containment isolation signals with the exception of the f ollowing:
1 The containment Atmospheric Dilution System Oxygen and Hydrogen Analyzer System which is required f or p os t LOCA gas ana ly s is .
1375 246
- 2. The Residual Haat Removal Sys tem s amp le valves. An Engineering review request has been initiated to review the design to determine if au t oma tic is ola tion of these lines is necessary
- c. The functional capability of the Primary Containment Isolation System is verified by surveillance testing every 6 months in accordance with the Technical Specifications.
1375 247 P3APS APPENDIX A PRESSURE INTEGRITY OF PIPING AND EOUIPMEUT PRESSURE PARTS CONTENTS A.1
SUMMARY
DESCRIPTION A.l.1 Code and Specifications A.2 CLASSIFICATION OF PIPING AND EQUIPMENT PRESSURE PARTS A.3 DESIGN REQUIREMEUTS A.3.1 Piping Design A.3.1.1 Allowable Stresses A.3.1.2 Wall Thickness A.3.1.3 Reactor Vessel Nozzle Load A.3.1.4 Seismic Design A.3.1.5 Analysis of Piping A.3.2 Valve Design A.3.3 Pump Design A.4 MATERIALS A.4.1 Brittle Fracture Control for Ferritic Steels A.4.2 Furnace Sensitized Stainless Steel Materials A.5 WELDING PROCEDURES AND PROCESSES A.5.1 General A.5.2 Procedures and Processes A.5.3 Dissimilar Metal Welds A.6 FABRICATION AND ERECTION A.6.1 Welded Construction .
A.6.2 Branch Connections A.6.3 Bending A.6.4 Heat Treatment A.6.4.1 Heat Treatment of Welds A.6.4.2 Carbon and Low Alloy Steel A.6.4.3 Austenitic Stainless Steel A.6.5 Defect Repair A.6.5.1 General A.6.5.2 Repair Welding A.6.5.3 Inspection of Repair Welds A.6.5.4 Heat Treatment after Repair Welding A-i 1375 248
dBAPS CONTENTS (Continued)
A.7 TESTING AND INSPECTION REQUIREMENTS A.7.1 Radiography A.7.1.1 Welds A.7.1.2 Castings A.7.2 Ultrasonic Examination A.7.2.1 Forgings A.7.2.2 Piping and Fittings A.7.3 Liquid Penetrant Testing A.7.4 Magnetic Particle Testing A.7.5 Ferrite Testing A.7.6 Hydrostatic Testing A.8 CLEANING A.8.1 Stainless Steel Piping A.8.2 Carbon Steel and Low Alloy Piping A.9 PIPING DESIGN REQUIREMENTS A.9.1 General Schedule I Schedule II Schedule III 1375 249 A-ii
PBAPS APPENDIX A PRESSURE INTEGRITY OF PIPING AND EQUIPMENT PRESSURE PARTS FIGURES Figure No. Title A.2.1 Piping Code Classification (NSSS) 1375 250 9
A-iii
PBl.PS APPENDIX A PPESSURE INTEGRITY OF PIPING AND EQUIPMENT PRESSURE PARTS TABLES Table No. Title A.9.1 Summary Classification of Piping Systems A.9.2 S.ummary of Equipment Design Guides 1375 251 A-iv
PEAPS APPENDIX A PRESSURE INTEGRITY OF PIPING AND COUIPMENT PRESSURE PARTS A.1
SUMMARY
DESCRIPTION This appendix provides additional information pertinent to the preceding sections concerning the pressure integrity of piping and equipment pressure parts.
Piping and equipment pressure parts are specified according to service and location. The design, fabrication, examination, and testing requirements are defined for the equipment of each category to assure the proper pressure integrity.
For the purpose of this appendix, the pressure boundary of the process fluid includes but is not necessarily limited to: branch outlet nozzles or nipples, instrument wells, reservoirs, pump casings and closures, blind flanges, studs, nuts, and fasteners in flanged joints between pressure parts, bodies and pressure parts of in-line components, such as traps and strainers, and instrument lines up to and including the first shutoff valve.
Specifically excluded from the scope of this appendix are vessels and heat exchangers or any components which are within the scope of the ASME Boiler and Pressure Vessel Code, Sections III and VIII; and non-pressure parts such as pump motors, shafts, seals, impellers, wear rings, valve stems, gland followers, set rings, guides , yokes, and operators; and non-metallic material such as packing and gaskets; fasteners not in pressure part joints such as yoke studs and gland follower studs; and washers of any kind.
This appendix defines the design limitations for piping and valves associated with the reactor coolant primary pressure boundary (nuclear steam supply), primary containment pressure boundary (drywell) and related auxiliary systems within the power generation (operational) systems.
Table A.9.1 specifies systems falling within the applicable codes and the scope of this appendix.
A.1.1 Code and Specifications The piping and equipment pressure parts in this nuclear power plant are designed, fabricated, inspected, and A.1-1 1375 252
PDAPS tested in accordance with recognized codes, as far as these codes can be applied, and in accordance with project specifications. Where conflicts occur between the industrial codes and project specifications, the project specifications take precedence.
All piping systems within the scope of this Appendix including pipe, flanges, bolting, valves and fittings are in accordance with ANSI B31.1.0," Power Piping,"
including requirements for design, erection, supports, tests, inspections, and additional requirements specified herein.
The weld reinforcement height limitations recommended for pipe butt welds in paragraph 127.4.2 (d) and 127.4.3 of ANSI B31.1.0 (1967) for those piping systems not within the scope of ANFI B31.1.0 Case 74, are modified as follows:
- a. Under cutting shall not exceed 1/32 inches deep, provided it does not encroach on the minimum wall thickness.
- b. The maximum thickness of reinforcement of butt welds shall not exceed the values tabulated below, when the thickness of the thinner component being joined is considered:
Thickness of Base Metal Thickness of Reinforcement *
(inches) (inches)
Column I Column II Up to 3/16 inclusive 1 1/16 l Over 3/16 to 1/2 inclusive 1/k6 1/16 over 1/2 to 1 inclusive 5/32 3/32 Over 1 to 2 inclusive 3/16 1/8 Over 2 1/4 S/32 The weld reinforcement thickness shall be deter-mined from the higher of the abutting surfaces involved.
For double welded butt joints, the limitation on reinforcement given in Column I shall apply separately to both inside and outside surfaces of the joint.
For single welded butt joints, the reinforcement limits giren in Column I shall apply to the outside only and the reinforcement given in Column II shall apply to the inside. _
1375 253 A.1-2 OCTOBER 1971
PDAPS The plant piping is classified in three groups, depending on the design requirements for the service.
The design requirements for piping systems designated in Groups I and II are in accordance with the requirements of ANSI B31.1.0 (1967) and supplementary requirements in the project specifications. Namely, these systems require full radiography and supplementary surface inspections of the weld joints and supplementary non-destructive test requirements of the pressure components.
Additionally, some of these piping systems are analyzed for seismic Class I design criteria as indicated in Table A.9.1.
The design requirements for some piping in Group III, such as main steam lines downstream of the outer isolation valve to the main turbine stop valve, but excluding the stop valves, are in accordance with the requirements of ANSI B31.1.0 (1967) and supplementary requirements in the project design specifications, namely, full radiography of pressure weld joints.
The above mentioned systems in Groups I and II and a portion of Group III are designated as " critical piping" for design, stress analysis, fabrication, inspection, erection, testing and quality control purposes.
The remaining portion of piping systems in Group III is in accordance with ANSI B31.1.0 and these systems are designated as non-critical systems.
Table A.9.1 summarizes the classification of piping systems and Table A. 9.2 lists design guides for plant equipment.
1375 254 A.1-3
PBAPS A.2 CLASSIFICATION OF PIPING AND EOUIPMENT PRESSURE PARTS Piping and equipment pressure parts may be classified as follows and as shown on Figure A.2.1:
Group I - Piping and equipment pressure parts within the reactor primary pressure boundary through the outer isolation valve, inclusive.
Grou's II - Piping and equipment pressure parts downstream of t3e outer isolation valve and extensions of containment and the Core Standby Cooling Systems.
Group III - Balance of plant piping and equipment pressure parts, including power generation systems.
1375 255 A.2-1
PBAPS A.3 DESIGN REQUIREMENTS A.3.1 Piping Design Pressure and temperature conditions to which the piping pressure components are subjected are described in the appropriate system design section of the FSAR.
A.3.1.1 Allowable Stresses The allowable stresses for piping design are as follows:
- a. For carbon steel, the allowable stress values of ANSI B 31.1.0 are used.
- b. For austenitic stainless steel, the allowable stress values of ANSI B31.1.0 are used. For material not covered by ANSI B31.1.0, the higher stress values of the ASME Boiler and Pressure Vessel Code,Section I, Appendix A-24 are used.
A.3.1.2 Wall Thickness Pipe wall thickness, fittings, and flange ratings are in accordance with ANSI B31.1.0, including adequate allowances for corrosion and erosion according to individual system requirements for a design life of 40 years.
A.3.1.3 Reactor Vessel Nozzle Load All piping including instrument piping connecting to the reactor pressure vessel nozzles is designed so that the nozzle to pipe interface load will not result in stresses in excess of the allowable material stresses. Thermal sleeves are used where nozzles are subjected to high thermal stresses.
A.3.1.4 Seismic Design -
Seismic Class I piping is defined as that portion of a piping system whose failure might cause, or increase the severity of, the design basis accident, or which is essential for safe shutdown of the reactor.
The piping is designed and supported to satisfy seismic criteria specified in the loading criteria (Appendix C) .
The piping systems indicated as seismic Class I in Table A.9.1 are analyzed for the maximum credible seismic condition.
^ 3-'
)375 256
FBAPS g A.3.1.4.1 Supplementary Analysis of Seismic Class I Piping Seismic Class I piping is classified aa either rigid or flexible. Rigid piping is that which has a fundamental frequency in the rigid range of the spectrum curves for the building locations. This corresponds to frequencies greater than 20 Hz. These piping systems are analyzed with static loads corresponding to the acceleration in the rigid range of the spectrum curves.
The dynamic analysis of flexible seismic Class I piping systems for seismic loads is performed using the spectrum response method, as applied to a lumped mass mathematical model of the piping systems. The maximum responses of each mode are calculated and combined by the root-mean-square method to give the maximum response quantities resulting from all t-ndes. The response thus obtained was combined with tre results produced by other loading conditions to compute the resultant stresses. All modes are used which have frequencies less than 20 Hz. The percentage of critical damping for all modes is 0.3 for the design earthquake and the maximum credible )
In lieu of the above procedure, some seismic Class I piping is analyzed for a static load equivalent to the peak of the spectrum curve for the applicable floor elevation.
The horizontal acceleration spectrum curves applied to the piping systems are developed as part of the seismic analysis for the building in which the piping is located.
A.3.1.5 Analysis of Piping
- a. Primary Stresses (Sp)
Primary stresses are as follows: ,
- 1. Circumferential primary stress (SR ) : circumferential primary stresses are below the allowable stress (Sh) at the design pressure and temperature.
- 2. Longitudinal primary stresses (SL ): the following loads are considered as producing longitudinal primary stresses: internal or external pressures; weight loads including valves, insulation, fluids, and equipment; hanger loads; static external loads and reactions; and the inertia load portion of seismic loads.
When the seismic load is due to the Design Earthquake (0.05g horizontal) , the vectorial combination of A.3-2 j 'g r.,] OCTOBER 1971
PBAPS all longitudinal primary stresses (SL) does not exceed 1.2 times the allowable stress (Sh)+
When the seismic load is due to the Maximum Credible Earthquake (0.12g horizontal) , the vectvrial combination of all longitudinal primary stresses does not exceed material yield stress at temperature unless higher allowable limits are calculated and substantiated by the methods outlined in Appendix C.
- b. Secondary Stresses (SE)
Secondary stresses are determined by use of the Maximum Shear Stress theory:
T,,x - S2 ,4g2', g E
therefore, SE" bS + 4S t
(see ANSI B31.1.0).
The following loads are considered in determining longitudinal secondary stresses:
- 1. Thermal expansion of piping
- 2. Movement of attachments due to thermal expansion
- 3. Forces applied by other piping systems as a result of their expansion
- 4. Any variations in pipe hanger loads resulting from expansion of the system, and'
- 5. Anchor point movement portion of seismic loads.
1375 258 A.3-3
P3APS The vectorial combination of longitudinal secondary stresses (SE) does not exceed the allowable stress range SA, i.e., S E I8,A, where Sg =
f (1.25 (Sc+Sh) ~SLI (This is Equation 1 from paragraph 102.3.2 of ANSI B31.1.0 modified to include the additional stress allowance permitted when SL is less than Sh*)
A.3.2 Valve Design valves are designed and rated by the manufacturer to meet the design pressure and temperature. They are in compliance with ANSI B 31.1.0, " Power Piping", ANSI B16.5,
" Steel Pipe Flanges and Flanged Fittings", or Manufacturers Standarization Society, Standard Practice MSS +SP-66,
" Pressure-Temperature Ratings for Steel Butt-Helded End Valves."
A.3.3 Pump Design The pressure retaining parts of pumps are designed to meet the design pressure and temperature in the piping to which they are attached.
- a. For pumps used in piping systems classified as Group I, the requirements of Section III of the ASME Boiler and Pressure Vessel Code for Class C were used as a guide in calculating the thickness of pressure retaining parts and in sizing the cover bolting.
- b. For pumps used in piping systems classified as Group II, the requirements of Section VIII, Division I of the ASME Boiler and Pressure Vessel Code are used as a guide in calculating the thickness of pressure retaining parts and in sizing the cove,r bolting.
- c. When a pump is used in piping systems classified as Group III, the standard commercial design is accepted for the specific service.
A.3-4
PB.TPS A.4 MATERIALS The material for piping and equipment pressure parts is in accordance with the applicable design code and the supplementary requirements of the project design specifications.
A.4.1 Brittle Fracture Control for Ferritic Steels The fracture or notch toughness properties and the operating temperature of ferritic materials in systems which form the reactor coolant boundary (Group I) are controlled to ensure adequate toughness when the system is pressurized to more than 20 percent of the design pressure. Such assurance is provided by maintaining the material service temperature at least 60 F above the nil ductility transition temperature (NDTT). Further requirements are:
- a. Ferritic steel piping that forms the reactor coolant boundary (Group I) is tested by the Charpy V-notch impact test (ASTM A-370) or drop weight test (ASTM E-208). Such tests are not required for: bolting, wi_th a nominal size 1" and smaller, including nuts;
~
materials whose section thickness is 1/2 inch and less; piping, valves, and fittings whose nominal inlet pipe size is only six inches in diameter and less, regardless of thickness; consumable insert material.
- b. Impact testing is not required on components or piping within the reactor coolant boundary having a minimum service temperature of 250 F or more when pressurized at more than 20 percent of design pressure. For example, the main steam line is excluded from the brittle fracture test requirement since the steam tenperature will exceed 250 F when the steam line pressure is at 20 percent of the design pressure,
- c. Impact testing is used to determine that the material and weld metal will meet brittle fracture requirements at test temperature. The acceptance standards are in accordance with Table N-421 of the ASME Boiler and Pressure Vessel Code,Section III, for the minimum service temperature.
A.4.2 Furnace Sensitized Stainless Steel Materials An effort has been made to minimize furnace sensitized austenitic stainless steel materials in the reactor pressure vessel, piping, and pressure retaining components in the critical systems. Austenitic stainless steel is A.a-,
1375 260
PBAPS considered to be furnace sensitized if it has been heated by other than welding within the range of 800 to 1800 F, regardless of the subsequent cooling rate.
1375 261 h
i I
A.4-2
e t PBAPS A.5 WELDING PROCEDURES AND PROCESSES A.S.1 General All welding procedures, welders, and welding machine operators are qualified in accordance with the requirements of Section IX of the ASME Doiler and Pressure Vessel Code for the materials to be welded. Qualification records, including the results of procedure and performance qualification tests and identification symbols assigned to each welder, are maintained.
A.5.2 Procedures and Processes Welding procedures and processes are employed which produca welds of complete penetration, of complete fusion, and free of unacceptable defects. The finished surfaces of the weld (both root and crown) merge smoothly into the adjacent component surfaces. Weld layers are built up uniformly around the circumference and across the width of the joint. Weld starts and stops are staggered.
Pressure countaining and attachment welds are made by any of the following processes within the limitations described in this appendix:
- a. Gas tungsten-arc welding with filler metal added
- b. Shielded metal arc welding with low hydrogen coated electrodes
- c. Submerged arc welding with multipass technique
- d. Gas metal arc welding within the limitations in the project specifications,
- e. Gas metal arc welding using shorting arc mode on carbon steel only.
A.S.3 Dissimilar Metal Welds Transition pieces are used wherever possible when carbon steel valves are welded to stainless steel piping. For piping systems with nominal wall thicknesses 3/4 inches and greater, the carbon steel transition piece mating to stainless steel is clad, a minimum of 3/16 inches after machining, with stainless steel weld metal (type 309) and stress relieved.
1375 262 A.5-1
e PBAPS A.6 FABRICATION AND ERECTION A.6.1 Welded Construction Piping and equipment pressure parts are assembled and erected by welding, except that flanged or screwed joints are used where necessary for maintenance.
Piping 2 1/2 inches and larger is V groove butt welded.
Piping 2 inches and smaller is generally socket welded.
A.6.2 Branch Connections For critical piping, branch connections are made by using commercially available standard welding fittings.
Integrally reinforced fittings are used for branch connections where standard fittings are not available; however, these fittings are not used for branch connections with nominal sizes larger than one half the nominal size in the main run. For piping where the branch is 2 inches or smaller, welded on forged fittings suitable for full penetration attachment welding are used. Branch connections are attached by full penetration welds.
For non-critical piping, standard fittings are used for the same size branches or one size reductions. Integrally reinforced fittings are used for two or more size reductions; however, stub-ins are permitted in certain special cases.
A.6.3 Bending A section of pipe may be bent by eitner cold or hot methods within the following limitations:
- a. Sections of pipe shall be selected so that thinning will not reduce the wall thickness below the minimum specified. *
- b. Hot bending of austenitic stainless steel is not permitted unless followed by solution annealing heat treatment.
- c. The bend radius is limited to five times the nominal pipe diameter, unless otherwise specified.
1375 263 A.6-1
PDAPS A.6.4 IIeat Treatment A.6.4.1 Heat Treatment of Welds Pre-heat and post-heat treatment of welds are in accordance with qualified welding procedures per the ASME Boiler and Pressure Vessel Code,Section IX.
A.6.4.2 Carbon and Low Alloy Steel The heat treatment of carbon steel and low alloy steel piping components and' equipment pressure parts is in accordance with requirements of the ASTM material specifications.
A.6.4.3 Austenitic Stainless Steel Austenitic stainless steel piping components and equipment pressure parts are solution annealed at least once.
Materials are annealed by heating to a temperature between 1900 and 2050 F and held at this temperature for one hour per inch of thickness, but not less than 1/2 hour, followed by rapid cooling to below 800 F.
A.6.5 Defect Repair A.6.5.1 General Repair of base metal or weld metal defects is in accordance with the following requirements:
- a. Surface defects such as laps, sreabs, slivers, seams, or tears, which do not encroach on minimum wall thickness, are removed by machining or grinding and are blended into the adjacent metal surfaces.
- b. When defects or defect removal encroaches on minimum wall thickness, repairs are made by welding.
A.6.5.2 Repair Welding Repair welding is performed employing welding procedures and welders qualified in accordance with Section IX of the ASME Boiler and Pressure Vessel Code.
A.6.5.3 Inspection of Repair Welds Repair welds of a depth greater than 10 percent of the wall thickness must meet the inspection requirements for welds specified for the applicable classification of piping. Other inspection methods are not employed without approval.
A.6-2 )37s 264
PBAPS A.6.5.4 Heat Treatment After Repair by Welding Base material repair welds are heat treated as required by the applicable materials specifications. Weld repairs are heat treated as required, in accordance with the project specifications.
1375 265 A.6-3
PBAPS A.7 TESTING AND INSPECTION REOUIREMENTS A.1.1 Radiography A.7.1.1 Welds Radiographic procedures and standards of acceptance for welds are in accordence with the ASME Boiler and Pressure Vessel Code Section VIII, Division I, Paragraph UW-51,Section III, Paragraph N-624, or Section I, Paragraph PW-51.
A.7.1.2 Castings Radiographic procedures for inspection of castings and casting repair welds are in accordance with ASTM E-94 and E-142, plus the following:
- a. Radiographic film shall be of the high contrast, high definition, fine grain type " Kodak AA", "Ansco Superay A", "Dupont 506", or approved equal.
- b. All radiography is done with lead screens.
- c. Film density in the area to be interpreted is within the range 1.7 to 3.5 as determined by either a film density strip or by a densitometer.
- d. Film location and identification markers are permanently marked on weldments and castings in accordance with the manufacturer's standard shop practice.
Acceptance standards for casting and casting repair welds less than 2 inches thick are in accordance with ASTM E71 as follows:
Category Severity Level (acceptable)
A A2 B B2 C C2 D None acceptable E None acceptable F None acceptable G None acceptable 1375 266 A.7-1
PBAPS Acceptance standards for casting and casting repair welds 2 inches to less than 4-1/2 inches thick shall be in accordance with ASTM E186 as follows:
Category Severity Level (acceptable)
A A2 B B2 C Type 1 - CA2 Type 2 - CB2 Type 3 - CC2 D None acceptable E None acceptable Acceptable standards for casting and casting repair welds 4-1/2 inches to 12 inches thick shall be in accordance with ASTM E 280 as follows:
Category Severity Level (acceptable)
A A2 B B2 C Type 1 - CA2 Type 2 - CB2 Type 3 - CC2 D None acceptable E None acceptable A.7.2 Ultrasonic Examination A.7.2.1 Forgings
., Ultrasonic methods and acceptance standards for forgings are in accordance with ASTM A-388, " Ultrasonic Testing and Inspection of Heavy Steel Forgings", or the standard of acceptance is in accordance with Paragraph N-322.1 of the ASME Boiler and Pressure Vessel Code,Section III ,
as modified in the following paragraphs.
A.7-2 DI3]-
137t a
FBAPS A.7.2.1.1 Normal Beam Testing - Acceptance Standards The materials are considered unacceptable, unless repaired, based on the following test indications:
- 1. Indications of discontinuities in the material that produce a complete loss of back reflection not as-sociated with the geometric configuration of the piece.
(A complete loss of back reflection is assumed when the back reflection falls below 5 percent of full screen height.)
- 2. Traveling indications of discontinuities with 10 per-cent or more of the back reflection losts. (A travel-ing indication is defined as an indication which dis-plays sweep movement of the oscilloscope pattern at a relatively constant amplitude as the search unit is moved along the part being examined.)
A.7.2.1.2 Angle Beam Testing - Acceptance Standards Materials are unacceptable where oscilloscope indications exceed those produced by the reference standard. The re-ference standard notch is the smaller of a depth equal to 5 percent of the material thickness of 3/8 inch.
A.7.2.2 Piping and Fittings Ultrasonic methods and acceptance standards for seamless pipe are in accordance with Paragraph N-324.3 of the ASME Boiler and Pressure Vessel Code,Section III. Plate for seam welded piping and fittings is examined prior to fabrication in accordance with Paragraph N-321.1 of the ASME Boiler and Pressure Vessel Code,Section III, or ASTM A-7 35 or E-273 or A-388.
Seamless fittings made from pipe are ultrasonically examined in accordance with Paragraph N-324.3 of the ASME code, Section III,or ASTM E-213 prior to forming of the fi':-
ting. After final forming and any required heat treatment specified in the material specification, seamless fittings will be magnetic particle or liquid penetrant examined on all accessible surfaces.
A.7.3 Liquid Penetrant Testing Methods, techniques and acceptance standards for liquid penetrant testing are in accordance with Section VIII, Appendix M-627.
VIII of the ASME code or Section III, Paragraph
\b
PBAPS A.7.4 Magnetic Particle Testing Methods, techniques and acceptance standards for magnetic particle testing are in accordance with Section VIII, Appendix VI of the ASME code or Section III, Paragraph N-626.
A.7.5 Ferrite Testing Austenitic stainless steel welds are subject to ferrite tests in order to determine the presence of a controlled amount of ferrite. The minimum amount of ferrite shall be 3-8 percent as determined by Schaeffler Diagram or by magnetic ferrite indicator.
A.7.6 Hydrostatic Testing Hydrostatic testing of pipe and components is in accordance with ANSI B31.1.0 or the ASMS coce , as appropriate.
1375 269 A.7-4
PDAPS A.8 CLEANING To minimize the requirement for cleaning after erection and to prevent damage during shipment, storage or handling, piping and equipment pressure parts are cleaned and capped by the pipe fabricator prior to shipment.
A.8.1 Stainless Steel Piping Austenitic stainless steel interior surfaces are mechanically cleaned, blast cleaned, or in a pickled condition and are free of scale. Blast cleaned surfaces are free of residual quantities of the cleaning medium. The final cleaning operation consists of cleaning with process. controlled water with chemical additive. Immediately after cleaning and inspection, all openings in the pipe assemblies are covered with suitable protective covers or caps, A.8.2 Carbon Steel and Low Alloy Piping Carbon steel and low alloy piping steel surfaces are mechanically cleaned per PFI Standard ES-5, shot blast cleaned per Steel Structural Painting Council Standard SP-5, or pickled. After cleaning, piping assemblics are blown out with clean, oil free air. After cleaning and inspection, all openings of the pipe assemblins are covered with suitable protective covers or caps.
1375 270 A.8-1
PBAPS A.9 PIPING DESIGN REQUIREMENTS A.9.1 General Piping design requirements for the plant piping systems may be classified into the following schedules:
Schedule I summarizes the pipe material specifications and design requirements for piping systems in Group I and Group II. Note that Group I piping has additional design requirements above Group II.
Schedule II summarizes the pipe material specifications and design requirements for certain piping systems in Group III. These systems are:
Main steam lines downstream of outer isolation valves to the "irst remotely operated stop valves, excluding the turbine stop valves.
Feedwater lines upstream of outer isolation check valves to-the first remotely operated stop valve in the feedwater pump discharge lines.
Schedule III summarizes the balance of plant piping.
The piping design requirements for the major components of the piping are described in general. No attempt has been made to completely describe each and every detailed component requirement in these piping systems. Various minor deviations from the basic design requirements, e.g.,
materials substitution, have been reviewed to ensure that such deviations meet the applicable codes and standards to assure the structural integrity of piping systems.
liowever, no deviations are made for non-destructive testing required by codes (radiographic, magnetic particle and liquid penetrant examinations).
1375 27i A.9-1 April 1971
PBAPS SCHEDULE I PIPING DESIGN REQUIREMENTS FOR GROUPS I AND II
- 1. MATERIAL SPECIFICATIONS
- a. Carbon Steel Piping Seam welded pipe, 26" and larger, is ASTM A-155-65 Gr. KC-70 (Firebox quality), Class I.
Seamless pipe, 24" and smaller, is ASTM A-106, Gr. B.
Seam welded fittings, 26" butt welding, are ASTM A-234, Gr. WPB-W or WPC-W and MSS SP-48.
Butt weld fittings, 24" through 2-1/2", are ASTM A-234, Gr. WPB, WPB-W or WPC-W. Welded seams are 100 percent radiographed after forming operation and either magnetic particle or liquid penetrant inspection is made on the final weld layer. Surfaces of fittings in the finished condition are examined by either magnetic particle or liquid penetrant method.
Seamless fittings, 2" and smaller, are forged carbon steel, ASTM A-105, Gr. II.
Seamless pipe, 12" through 2-1/2", is ASTM A-376 TP 304 or A-312 TP 304. Seamless pipe, 2" and smaller, is ASTM A-376 TP 304 or A-312 TP 304.
Butt weld fittings are ASTM A-403, Gr. WP304 or WP304-W. Welded seams are 100 percent radiographed after forming operations and liquid penetrant test is made on the final layer.
Surfaces of fittings, 2-1/2" and larger, are examined by liquid penetrant method.
A.9-2 April 1971 1375 272
PBAPS Seamless fittings, 2" and smaller, socket weld forged stainless steel, are ASTM A-182, Gr. F-304.
Stainless steel flanges are ANSI Standard, forged to ASTM A-182, Gr. F-304 or F-316. Surfaces of stainless steel flanges, 2-1/2" and larger, are examined by either magnetic particle or liquid penetrant method.
- 2. INSPECTION
- a. Butt welds for 2 1/2" and larger pipe joints in the shop and field are 100 percent radiographed.
- b. The final layer of pressure welds in the shop and field are examined by either magnetic particle or liquid penetrant method. This requirement covers all pipe sizes for butt welds.
- c. Pressure retaining forgings over 4" in thickness are examined by ultrasonic method plus either liquid penetrant or magnetic particle methods.
- d. Pressure retaining parts of valves 2 1/2" and larger in nominal pipe sizes are radiographed.
- e. Valves are shop hydrostatic tested in accordance with the ANSI B 16.5 or MSS SP-66 requirements.
- 3. FABRICATION RI.:QUIREMENTS Fabrication requirements are in accordance with the project design requirements for critical systems.
4 SPECIAL REQUIREMENTS FOR GROUP I SYSTEMS
- a. Brittle fracture control for ferritic steel is required for the following portions of Group I systems:
A.9-3 April 1971 1375 273
PBAPS Feedwater System - from RPV to the outer isolation check valve (valve 6-96) and startup recirculation line isolation valves 38 A and 38 B.
High Pressure Coolant Injection Line - from feedwater line to testable check valve (valve 23-18).
Core Spray - isolation valves14-14A and 14-14B.
Reactor Core Isolation Cooling System - from feedwater line to testable check valve (valve 13-22).
RHR System shutdown cooling isolation valves (10-17, 10-18 and 10-88), LPCI valves (10-81 A and 10-81B)
Cleanup System Return - from feedwater line to check valve (valve 12-62).
Control Rod Hydraulic System Return Line - from valve 3-11.0 to valve 3-114.
- b. Pressure retaining bolting greater than 1" is examined by either magnetic particle or liquid penetrant method.
- c. Pipe and fittings, 2-1/2" and larger pipe sizes, in Group I systems are 100 percent volumetrically examined per Section III of the ASME code. This requirement applies to Unit 3 only.
1375 274 A.9-4 April 1971
PBAPS SCIIEDULE II PIPING DESIGN REQUIREMENTS
- 1. MATERIAL SPECIFICATIONS
- a. Carbon Steel Piping Seamwelded pipe, 26", is ASTM A-155-65, Gr. KC-70 (Firebox quality), Class I.
Seamless pipe, 24" and smaller, is ASTM A-106, Gr. B.
Seamwelded butt weld fittings, 26", are ASTM A-234, Gr. WPC-W and MSS-SP-48. Welded seams are 100 percent radiographed after forming operations and magnetic particle inspection is made on the final weld layer.
Seamless butt weld fittings, 24" through 2-1/2",
are ASTM A-234, Gr. WPB.
Seamless socket weld fittings, 2" and smaller, are forged carbon steel to A-105, Gr. II.
- b. Stainless Steel Piping Not applicable.
- 2. INSPECTION
- a. Butt welds for 2-1/2" and larger pipe' joints in the shop and field are 100 percent radiographed.
- b. The final layer of pressure welds are examined by either magnetic particle or liquid penetrant method.
- c. Pressure retaining parts of valves, 2-1/2" and larger, are radiographed.
A.9-5 April 1971 1375 275
- d. Valve butt weld end preparations for field welding are examined by either magnetic particle or liquid penetrant method.
- e. Valves are shop hydrostatic tested in accordance with ANSI B16.5 or MSS SP-66 requirements.
- 3. FABRICATION REQUIREMENTS Fabrication requirements are in accordance with the project design specifications for critical systems.
1375 276 A.9-6 April 1971
PBAPS SCIIEDULE III
- 1. MATERIAL SPECIFICATIONS (Partial List)
- a. Carbon Steel Piping Seamwelded pipe is ASTM A-155-65, Gr. KC-70 C1.2 or ASTM A-155, Gr. C-55 C1.2.
Seamless pipe is ASTM A-106, Gr. B or A-53, Gr.
A or B.
Fittings are ASTM A-234 WPB, WPB-W or WPC-W, or ASTM A-105, Gr. II.
- b. Stainless Steel Piping Seamwelded pipe is ASTM A-312 TP-304, 304L plus eddy current test, or ASTM A-358, TP-304 or 304L, Class I.
Seamless pipe is ASTM A-376 TP 304 or ASTM A-312 TP 304 or 304L.
Fittings are ASTM A-403, WP 304WL or ASTM A-182, Gr. F-304.
- c. Low Alloy Piping Seamless pipe is ASTM A-335, Gr. P-11 or P-5.
Seamwelded pipe is ASTM A-155, Class II, Gr.
1-1/4 CR.
Fittings are ASTM A-234 WP-11, WP-11We WP-5, or WP-5W, or ASTM A-182, F11 on FS.
- 2. IMSPECTION REQUIREMEUTS Inspo'ctions are in accordance with material specifications or the requirements of ANSI B31.1.0.
Inspection of valves conforms to ANSI B31.1.0 requirements.
1375 277 A.9-7 April 1971
- 3. FABRICATION REQUIRE!iENTS Fabrication requirements shall conform to the project design specifications. Those systems requiring thermal stress analysis and special fabrication techniques are identified as Schedule IIIc, the "c" denoting a critical system.
1375 278 A.9-8 April 1971
PBAPS TABLE A.9.1
SUMMARY
CLASSIFICATION OF PIPING SYSTEMS Design Seismic Group I (Primary Pressure Boundary) Schedule Class Recirculation System I I Systems from RPV to Outer Iso. Valve:
Feedwater Lines I I Main Steam Lines I I Main Steam Drain Lines I I Steam to HPCI I I Steam to RCIC I I Core Spray I I Residual Heat Removal:
Shutdown Supply I I Head Spray I I LPCI I I Reactor Water Cleanup Supply & Return I I CRD Return I I Standby Liquid Control I I Reactor Vessel Instrumentation I I Sample Lines .I I Small Lines, 2" and under To and including first shutoff valve I I Beyond shutoff valve III -
CRD System Insert and Withdraw Lines I I Scram Discharge Volume I I April 1971 1375 279
PBAPS TABLE A.9.1 (Continued)
Group II (Core Cooling and Containment Design Seismic Extension) Schedule Class Residual Heat Removal:
LPCI I 1 Containment Cooling and Spray (excluding spargers) I I Shutdown Cooling I I Reactor Head Spray I I Core Spray I I HPCI:
Steam Supply and Exhaust I I Suction I I Discharge I I RCIC:
Steam Supply.and Exhaust I I Suction I I Discharge I I Reactor Water Cleanup System High Pressure System Only I -
Standby Liquid Control System:
Excluding system test components I 1 Essential instrument lines for Standby Core Cooling Systems I I Inerting System:
From Containment to the Second Isolation Valve I I April 1971 1375 280
PBAPS TABLE A.9.1 (Continued)
Group II (Continued) Design Seismic Schedule Class Containment Ventilation System:
From Containment to the Second Isolation Valve I I Special Auxiliary Systems:
High Pressure Service Water I I Emergency Service Water I I Emergency Cooling Water I 3 Post - LOCA Containment Atmosphere Dilution System I I i375 281 APRIL 1973
PBaPS TABLE A.9.1 (Continued)
Desian Seismic Group III (Balance of Plant Systems) Schedule Class Main Steam:
Downstream of Outer Isolation Valves to Main Stop Valve or First Remotely Operated Valve II --
Turbine Steam Bypass II --
Feedwater:
Upstream of Outer Isolation Check Valves to Firsr Remotely Operated Valves II --
Feed Pump Recirc. IIIc* --
Control Rod Hydraulic System:
Suction line to Pump III --
Condensate Supply to CSCS Pumps III I offgas System:
Air Ejector to Holdup Pipe IIIc* --
Holdup Pipe IIIc* --
Holdup Pipe to Offgas Filters IIIc* --
Downstream of Offgas Filter to Stack III --
Inerting System: .
From the Second Isolation Valves to Storage Tank III --
Standby Liquid Control System:
System Test Components IIIc --
- All welds 100% radiographed j}/j 282 April 1971
, 9 PBAPS TABLE A.9.1 (Continued)
Design Seismic Grouo III (Continued) Schedule Class Reactor Water Cleanup System:
Blowdown to Condenser and Radwaste IIIc --
Low Pressure System IIIc --
RCIC:
Suction from Cond. Storage Tank IIIc I Radwaste:
Liquid Process III --
Fuel Pool Cooling and Cleanup III --
Extraction Steam IIIc --
Condensate:
Pump Suction IIIc --
Pump Discharge IIIc -
Condensate Service III --
Auxiliary Steam IIIc --
Plant Heating III --
Service Water III --
Reactor Building Cooling Water III --
Turbine Building Cooling Water ,
III --
Instrument Air III --
Service Air III --
Fire Protection System III --
Domestic Water III --
1375 283 April 1971
PBAPS TABLE A.9.1 (Continued)
Design Seismic Group III (Continued) Schedule Class Lube Oil III --
Fuel Oil III --
Chemicals III --
Chilled Water System III --
Makeup Water System III --
1375 284 April 1971
w .
r4APS TABLE A.9.2
SUMMARY
OF EQUIPMENT DESIGN GUIDES Group I Reactor Pressure Vessel ASME III, Cl. A Recirc. Pumps See Par. A.3.3 Recirculation Valves MSS-SP-66 Safety Valves, RV ASME III Relief Valves, RV ASME III Main Steam Valves B16.5 Recirc. Flow Nozzle B31.1.0 Steam Flow Nozzle B31.1.0 Feedwater Isolation Check Valves MSS-SP-66 Isolation Valves: Except Listed Below B16.5 MO-10-25, AO-46 MSS-SP-66 AO-13-22, AO-23-18 MSS-SP-66 MO-14-12, AO-14-13 MSS-SP-66 1375 285 April 1971
PBAES TABLE A.9.2 (Continued)
Group II Containment Vessel ASME III, Cl. B Cleanup System Non-Regenerative Heat Exchanger Shell: ASME VIII Tube: ASME III, Cl. C Regenerative Heat Exchanger ASME III, Cl. C Filter Demineralizer ASME III, C1. C HPCI Turbine Per design specification Pump See Par. A.3.3 RCIC Turbine Per design specification Pump See Par. A.3.3 Core Spray Pumps See Par. A.3.3 Residual Heat Removal Pump See Par. A.3.3 Heat Exchanger Shell: ASME III, Cl. C Tube: ASME VIII Standby Liquid Control Pump See Par. A.3.3 Containment Vacuum Relief Valves and B31.1.0 & ASME Drywell Vacuum Breakers Sec. III, C1. B Post - LOCA Containment Asme Section III (1971)
Atmosphere Dilution System Class 2 Liquid N Tank 2
1375 286 APRIL 1973
PB.tPS TABLE A.9.2 (Continued)
Group III (Partial List)
Radwaste:
Waste Filter ASME III, Cl. C Floo:- Drain Filter ASME III, Cl. C l Waste Demineralizer ASME III, Cl. C Fuel Pool Heat Exchangers ASME VIII, Div. I Reactor Building Cooling Water Heat g Exchangers ASME VIII, Div. I Turbine Building Cooling Water Heat Exchangers ASME VIII, Div. I Offgas Filter Vessels ASME VIII, Div. I Air Compressor After Coolers ASME VIII, Div. I Condensate Demineralizer Vessels ALME VIII, Div. I Make-up Demineralizer Vessels ASME VIII, Div. I Auxiliary Boilers ASME I Auxiliary Boiler Blowoff Tank ASME VIII, Div. I Auxiliary Boiler Deaerator ASME VIII, Div. :
Compressed Air Receivers ASME VIII, Div. I Moisture Separator Tanks ASME VIII, Div. I Moisture Separator Drain Tanks ASME VIII, Div. I i375 287 April 1971
= .
SYSTEM LEGENDS GROUP I:
- 1. REACTOR RECIRCULATION PIPING AND EQUIPMENT PRESSURE PARTS
- 2. MAIN STEAM WITHIN THE REACTOR PRIMARY PRESSURE BOUNDARY THROUGH THE OUTER ISOLATION
- 4. REACTOR WATER CLEAN-UP
- 5. REACTOR CORE ISOLATION VALVE, INCLUSIVE.
COOLING (RCIC)
- 6. CORE SPRAY GROUP II:
- 9. REACTOR HEAD SPRAY DOWNSTREAM OF THE OUTER ISOLATION
- 10. STANDBY LIQUID CON".ROL VALVE AND EXTENSIONS OF CONTAINMENT
- 11. HIGH PRESSURE COOLANT AND THE CORE STANDBY COOLING SYSTEMS, INJECTION (HPCI)
- 12. LOW PRESSURE COOLANT INJECTION (LPCI) GROUP III:
BALANCE OF PLANT PIPING AND EQUIP-MENT PRESSURE PARTS INCLUDING POWER ANSI B31.1.0 - PIPING M GROUP I GENERATION SYSTEMS.
M GROUP II M GROUP III EQUIPMENT CODE M ASME SECTION III A M ASME SECTION III C E ASME SECTION VIII, API CONTAINMENT BOUNDARY PHILADELPHIA ELECTRIC COMPANY PEACH BOTTOM ATOMIC POWER STATION UNITS 2 AND 3 FINAL SAFETY ANALYSIS REPORT PIPING CODE CLASSIFICATION (NSSS) 1375 288 FIGURE A.2.1 April 1971
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