TXX-4418, Forwards Addl Requested Changes to Tech Specs Affecting 840904 Final Draft Tech Specs Amended on 841019
| ML20117B985 | |
| Person / Time | |
|---|---|
| Site: | Comanche Peak  |
| Issue date: | 04/30/1985 |
| From: | Beck J TEXAS UTILITIES ELECTRIC CO. (TU ELECTRIC) |
| To: | Noonan V NRC - COMANCHE PEAK PROJECT (TECHNICAL REVIEW TEAM) |
| References | |
| TXX-4418, NUDOCS 8505090292 | |
| Download: ML20117B985 (31) | |
Text
,_. ._.
s-Log # TXX-4418 TEXAS UTILITIES GENERATING COMPANY Fi1e # 10 MKYWAY TOWER . 400 NORTH OLIVE MTRE:ET. L.B. 81
- DALLAN TEXAM 75201
?
??"1%"'S April 30, 1985 Director of Nuclear Reactor Regulation Attention: Mr. Vincent S. Noonan, Director Comanche Peak Project Division of Licensing U. S. Nuclear Regulatory Commission Washington, D.C. 20555
SUBJECT:
COMANCHE PEAK STEAM ELECTRIC STATION (CPSES)
DOCKET NOS. 50-445 AND 50-446 ADDITIONAL REQUESTED CHANGES TO UNIT 1 FINAL DRAFT TECHNICAL SPECIFICATIONS
Dear Mr. Noonan:
Attached are requested changes to the CPSES Unit 1 Technical Specifications. These changes affect Final Draft Technical Specifications as transmitted by NRR letter of September 4, 1984, and later amended by NRR letter of October 19, 1984.
Sincerely, O VM.
John W. Beck RWH/grr Attachment 4
8505090292 850430 PDR ADOCK 05000445 {
A PDR A DEVEN10N OF TEXAN t"TELETERN ELECTRit' COMi*ANY i40 L.___._____________.__._.____.__
s
, DESCRIPTION OF TECHNICAL SPECIFICATION CHANGES The following items are requested changes to the Comanche Peak Unit 1 Technical Specifications (Final Draft) of September 4,1984 as amended by NRR letter of October 19, 1984:
- 1. Editorial changes and typographical errors noted on the following pages and specifications: (13 marked-up pages included as Attachment 1):
Page Specification 2-7 2.2.1 3/4 1-21 3/4.1.3.6 3/4 3-87 3/4.3.3.11 3/4 4-18 3/4.4.6.1 3/4 6-17 3/4.6.3 3/4 6-19 3/4.6.3 3/4 6-20 3/4.6.3 3/4 6-24 (Supercedes TXX-4360 of 11/15/84) 3/4.6.3 3/4 6-25 3/4.6.3 3/4 8-27 3/4.8.4 3/4 8-28 3/4.8.4 3/4 8-29 3/4.8.4 3/4 10-4 3/4.10.4
- 2. Table 3.3-5, pages 3/4 3-33, 3-34 and 3-35 (Supercedes TXX-4360 of 11/15/84). For containment vent isolation, the 18-inch containment pressure relief valves must close in < 5 seconds due to pressurizer pressure low signal. No credit is taken in the accident analyses for the operation of these valves due to other signals. Also, the lower value of 6.5 seconds for steam line isolation is required due to the FSAR Chapter 6 containment analyses instead of the FSAR Chapter 15 LOCA analyses. See Attachment 2.
I s
9
.3. Surveillances 4.2.3.4 and 4.2.3.5, page 3/4 2-10. Indicate that measurement instrumentation used for RCS calorimetric flow measurements shall be calibrated within 90 days preceeding the calorimetric flow measurement. This is required because CPSES does not have the capability to calibrate these instruments on-site and within 7 days. See Attachment 3.
- 4. Table 3.3-2, page 3/4 3-7. Add asterisk to response times for Items 7 and 8 to exempt N-16 gamma detectors from time response testing. This is a calculated time and no method exists for testing these detectors. Also, revise footnote as shown on Attachment 4.
- 5. Specification 3.3.3.4, page 3/4 3-52. Revise to conform to wording used throughout the Technical Specifications. See Attachment 5 for details.
- 6. Surveillance 4.6.1.5, page 3/4 6-7. Add clarifying words to surveillance requirement and revise locations of containment air temperature monitors as shown on Attachment 6. This change is required to meet the basis for the technical specification.
- 7. Table 3.7-6, page 3/4 7-45 (Supercedes TXX-4360 of 11/15/84).
On Item 9, Detector Well, change CPSES supplied nomenclature and value of temperature limit. Detector well temperature is measured at the detector well exhaust and the correct temperature is 1500F. Also, editorial corrections are included in this table. See Attachment 7.
- 8. Surveillances 4.8.1.1.2.a.4 and 4.8.1.1.2.g on pages 3/4 8-3 and 3/4 8-6 respectively. Change CPSES supplied minimum engine speed from 450 to 441 rpm to correspond to lower frequency value. See Attachment 8.
- 9. Basis 3/4.3.2, page B3/4 3-3. Add wording of Attachment 9 to 1
clarify and expand the discussion of the P-12 interlock description.
- k.
, 10. Table 3.6-1, page 3/4 6-29. Insert the work " leak" as shown on
, Attachment 10 and replace the text for Note 6 with "Not Used".
- 11. Table 3.6-1, Note 8, page 3/4 6-30. Revise Note 8 as shown on Attachment 11. This change is required by NRR letter of 10/11/84, Staff Evaluation Findings Pertaining to Containment Isolation Itens for CPSES.
- 12. Surveillance 4.7.7.e.4, page 3/4 7-17. Change plant specific heater kW rating from 20 to 10 as shown on Attachment 12. Also change reference of ANSI N510-1975 to ANSI N510-1980 to be consistent with the remaining specification.
4 4
9 4
TABLE 2.2-1 (Continued) 8 g
a -
M TABLE NOTATIONS E
- o g NOTE 1: Overtemperature N-16 7 N = Ki-K2 [ Tc-Tc + a (P-P') - f t (Aq)
E y Where: N = Measured N-16 concentration by ion chambers, s
T c
= Cold leg temperature, *F, T = 559.6*F, Reference T at RATED THERMAL POWER, c
Ki = 1.078, K2 = 0.00948/*F, r? 1+TS2 N = The function generated by the lead-lag compensator for measured T 1+TS2
- 4 ti, T2 = Time constants utilized in the lead-lag compensator for Tc ' '1 = 10 s, and T2=3s, K3 = 0.000494/psig, i
- )
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' ATTACHmm 1 (SR. 2 o% 13)
REACTIVITY CONTROL SYSTEMS CCT 191984 CONTROL R00 INSERTION LIMITS LIMITING CONDITION FOR OPERATION '
~3.1.3.6 The control banks shall be limited in physical insertion as shown in Figure 3.1-1. ~ '
APPLICABILITY: MODES 1* and 2*#. '
ACTION:
With the control banks inserted beyond the above insertion limits, except for surveillance testing pursuant to Specification 4.1.3.1.2:
- a. Restore the control banks to within the limits within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />, or
- b. Reduce THERMAL POWER within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> to less than or equal to that fraction of RATED THERMAL POWER which is allowed by the bank positionusingtheabovefigure/,or
- c. Be in at least HOT STANDBY within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
SURVEILLANCE REQUIREMENTS 4.1.3.6 The position of each control bank shall be determined to be within the insertion limits at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> except during time intervals when the Rod Insertion Limit Monitor is inoperable, then verify the individual rod positions at least once per 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.
- See Special Test Exceptions Specifications 3.10.2 and 3.10.3.
- With K,ff greater than or equal to 1.
COMANCHE PEAK - UNIT 1 3/4 1-21
TX.x- 44ig ATTac.4 m arr i (54. b
.2 la) bf -
L 2 -
TABLE 4.3-9 (Continued)
TABLE NOTATIONS At all times. -
During WASTE GAS HOLDUP SYSTEM operation.
- Also prior to any release from the WASTE GAS HOLDUP SYSTEM or containment PURGING or VENTING.
(1) The ANALOG CHANNEL OPERATIONAL TEST shall also demonstrate that automati isolation of this pathway and control room alarm annunciation occurs if any of the following conditions exists:
a.
Instrument indicates measured levels above the Alarm / Trip Setpoint, or
- b. ' Circuit failure, or
- c. Instrument indicates a downscale failure, or
- d. Instrument controls not set in operate mode.
(2) The ANALOG CHANNEL OPERATIONAL TEST shall also demonstrate that control room alarm annunication occurs if any of the following conditions exists:
- a. Instrument indicates measured levels above the Alarm Setpoint, or
- b. Circuit failure, or
- c. Instrument indicates a downscale failure, or
- d. Instrument controls not set in operate mode.
(3) The initial CHANNEL CALIBRATION shall be performed using one or more of the reference standards certified by the National bureau of Standards (NBS) or using standards that have been obtained from suppliers that participate in measurement assurance activities with NBS. These standards shall permit calibrating the system over its intended range of energy and measurement range. For subsequent CHANNEL CALIBRATION, sources that have been related to the initial calibration shall be used.
(4) The CHANNEL CALIBRATION shall include the use of standard gas samples containing a nominal:
Eght ..
(5) The CHANNEL CALIBRATION shall include the use of standard gas samples containing.a nominal:
E;3M e
COMANCHE PEAK - UNIT 1 3/4 3-87
. - ATracumspr i . . .
(SQ f & 13 *~
REACTOR COOLANT SYSTEM _ . , ,_.
, 374.4.6 REACTOR COOLANT SYSTEM LEAKAGE LEAKAGE DETECTION SYSTEMS LIMITING CONDITION FOR OPERATION
..~... ... . .. . . . . -
3.4.6.1 The following Reactor Coolant System Leakage Detection Systems shall be OPERABLE:
a.
The Containment Atmosphere Particulate Radioactivity Monitoring System, b.
The Containment Sump Level and Flow Monitoring System, and e
- c. ;
~
Either the Containment Air' Cooler Condensate Flow Rate or a Con- *.
tainment Atmosphere Gaseous Radioactivity Monitoring System.
APPLICABILITY: MODES 1, 2, 3 and 4. -
ACTION:
~
With only two of the above required Leakage Detection Systems OPERABLE, operation may continue for up to 30 days provided grab samples of the contain-ment atmosphere are obtained and analyzed at least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> when the
-(- required Gaseous or Particulate Radioactive. Monitoring System is inoperable; otherwise, be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUTDOWN witt.in the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.
SURVEILLANCE REQUIREMENTS 4.4.6.1 The Leakage Detection Systems shall be demonstrated OPERABLE by: -
a.
Containment Atmosphere Gaseous and/or Particulate Monitoring System-performance of CHANNEL CHECK, CHANNEL CALIBRATION and ANALOG CHANNEL OPERATIONAL TEST at the frequencies specified in Table 4.3-3,
- b. Containment Sump Level and Flow Monitoring System performance of CHANNEL CALIBRATION at least once per 18 months, and
- c. Containment Air Cooler Condensate Flow Rate Monitoring System-performance of er A^M?'CC CM?.MNCL 0.": ATIONAL T :T at least once per 18 months. CihWN E L C N B1twnoW
/*
%s v.
COMANCHE PEAK - UNIT 1 3/4 4-18
DX-4418 o AmcHmwT I (SH. S~el (3)
TABLE 3.6-1 (Continued) , 2 -
CONTAINMENT ISOLATION VALVES
~~ ~~~ ' - --
ISOLATION TYPE FSAR TABLE VALVE NO. REFERENCE NO.* TIME LEVEL -
LINE OR SERVICE (Seconds) TESTING
- 1. Phase "A" Isolation Valves (Continued) 1-8871 83 Accumulator Test and 10 C Fill l Note 9 1-8888 83 Accumulator Test and 10 C Fill Note 9 1-8964 83 Accumulator Test and 10 C Fill Note 9 1HV-5556 84 Containment Air PASS 5 C Return 1HV-5557 84 Containment Air PASS 5 C Return r
IVH-5544 94 J Radiation Monitoring 5 C
- Sample e
1N H-5545 94 v Radiation Monitoring 5 C Sample 1HV-5558 97 Containment Air PASS 5 C Inlet 1HV-5559 97 Containment Air PASS 5 C Inlet 1HV-5560 100 Containment Air PASS 5 C Inlet 1HV-5561 100 Containment Air PASS 5 C Inlet 1HV-5546 102 Radiation Monitoring 5 C Sample Return 1HV-5547 102 Radiation Monitoring 5 C Sample Return 1-8880 104 N2 Supply to 10 C Accumulators Note 9 1-7126 105 H2 Supply to RC Orain 10 C Tank
COMANCHE PEAK - UNIT 1 3/4 6-17
Txx-44:g
- ATT4c4mtr.MT I (54. (, of 13)
TABLE 3.6-1 (Continued)
CONTAINMENT ISOLATION VALVES ISOLATION TYPE FSAR TABLE TIME VALVE NO. LEVEL REFERENCE NO.* LINE OR SERVICE (Seconds) TESTING
- 2. Phase "B" Isolation Valves 1HV-4708 117 CC Return From RCP's 10 C Motors 1HV-4701 117 CC Return From RCP's 10 C Motors 1HV-4700 118 CC Return From RCP's 10 C Motors 1HV-4709 li9 CC Return From RCP's 10 C Thermal Barrier 1HV-4696 119 CC Return Frcm RCP's 10 C Thermal Barrier 3.
Containment Ventilation Isolation Valves 1HV-5542 58 Hydrogen Purge Supply 10 C Note 9 1HV-5543 58 Hydrogen Purge Supply 10 C Note 9 1HV-5563 58 Hydrogen Purge Supply 10 C 1HV-5540 59 Etha.ust Hydrogen Purge pply 10 C Note 9' 1HV-5541 59 Hydrogen Purge 10 C Note 9 1HV-5562 59 Hycrogen Purge Exhaust 10 C Note 9 1HV-5536 109 Containment Purge Air 5 C Supply Note 9 1HV-5537 109 Containment Purge Air 5 C Supply Note 9 (s 1HV-5538 110 Containment Purge Air 5 C :
Exhaust Note 9 COMANCHE PEAK - UNIT 1 3/4 6-19
TXX- 44 6 ATTAc4meurI C5H.7oI13J
' _ TABLE 3.6-1 (Continued)
OCII 91994
... [.
_ CONTAINMENT ISOLATION VALVES FSAR TABLE ISOLATION TYPE VALVE NO. TIME REFERENCE NO.* LEVEL
_LINE OR SERVICE (Seconds) TESTING _
- 3. -
Containment Ventilation Isolation Valves (Continued) 1HV-5539 110 Containment Purge Air 5 Exhaust C 1HV-5548 Note 9 122 Containment Pressure 5 Relief C 1HV-5549 122 Containment Pressure 5 Relief C 1FW-158 20b Feed d r k yss b ar Dra.lg Ch:ri:21 re:d +c c+a-N.A.
Generator #1 Note 1 IFW-106 20c N2 Supply to Steam N.A.
Generator #1 Note 1 1FW-157 Fer_A.woter S3pm Be.Aer ben.h
( 22b Chern_. r;;d i: St:::
Generator #2 N.A. Note 1 IFW-104 22c N2 Supply to Steam N.A. Note 1 Generator #2 1FW-156 24b Tcad,M--ica. ^r k'PSh bar r :d t: S t;;r.bridw N.A. ' Note 1 Generator #3 IFW-102 24c N2 Supply to Steam N.A. Note 1 Generator #3 IFW-159 26b M ts.h.h::,r k;. p M NetdcP h rD.In r;;d to St;..;
Generator #4 N.A. Note 1 IFW-108 26c N2 Supply to Steam Generator #4 H.A. Note 1 1-87088 33 RHR From Hot Leg Loop N.A.
- 4 (Relief) Note 5 1-8708A 34 RHR From Hot Leg Loop H.A.
- 1 (Relief) Note 5 1-7135 52 RCDT Heat Exchanger to
,L Waste Holdup Tank N.A. C
. I COMANCHE PEAK - UNIT 1 3/4 6-20 !
i
i tx-4418
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(.584. 8 cl /3)
_ TABLE 3.6-1 (Continued) h P _ CONTAINMENT ISOLATION VALVES ISOLATION TYPE FSAR TABLE VALVE NO. TIME LEVEL REFERENCE NO.* LINE OR SERVICE (Seconds) TESTING 5. Power-Operated Isolation Valves (Continued) 1HV-4782 127 Containment Recire. N.A. C to Spray Pumps (Train A) 1HV-4783 128 Containment Recirc. N.A. C to Spray Pumps (Train 8)
- 6. Check Valves .
1-8818A 35 RHR to Cold Leg Loops N.A. Note 2
#1 and #2 1-8818B 35 RHR to Cold Leg Loops N.A. Note 2
#1 and #2 1-8818C 36 RHR to Cold Leg Loops N.A. Note 2
#3 and #4 1-88180 36 RHR to Cold Leg Loops N.A. Note 2
#3 and #4 1-8046 41 Reactor Makeup Water N.A. C to Pressurizer Relief Tank and RC Pump Stand Pipe 1-8815 42 Safety Injection to N.A. Note 2' Cold Leg Loops #1,
#2, #3, and #4 1SI-8905B 43 SI to RC System Hot N.A. Note 2 Leg Loops #2 and #3 ISI-8905C 43 SI to RC System Hot
' N.A. Note 2 Leg Loops nd 4
15I-8905D 44 SI to RC S em Ho N.A. Note 2 Leg Loops #1 and #4 3 ISI- 9A 45 SI to RC System Cold (% A- Leg Loops #1, #2, #3, N.A. Note 2 e-
& #4 -
1SI-8905h 44 sI ts'~RC 5 3shr.m dot N.g, gg L*$ b a t 5 # \ a. d 4 4 COMANCHE PEAK - UNIT 1 3/4 6-24 segm mt.b 4/5o165
~TXX- Olb ATrac4 m6Ar7 1 . L54.9oII3)
_ TABLE 3.6-1 (Continued) ! CONTAINMENT ISOLATION VALVES FSAR TABLE ISOLATION TYPE VALVE NO. TIME LEVEL REFERENCE NO.* LINE OR SERVICE (Seconds) TESTING
- 6. _
Check Valves (Continued) ISI-8/19B 45 SI to RC System Cold 8 Leg Loops #1, #2, #3, N.A. Note 2
& M4 ISI-8/19C 45 SI to RC System Cold 4 N.A. Note 2 Leg Loops #1, #2, #3,
& #4 ISI-8)(190 45 SI to RC System Cold 8 Leg Loops #1, #2, #3, N.A. Note 2
& #4 1-8381 46 Charging Line to N.A.
Regenerative Heat C Exchanger 1CS-8368A 47 Seal Injection to RC N.A. C Pump (Loop #1) 1CS-8368B 48 Seal Injection ta RC N.A. C Pump (Loop #2) ICS-8368C 49 Seal Injection to RC N.A. C Pump (Loop #3) 1CS-83680 50 Seal Injection to RC N.A. C Pump (Loop #4) ICS-8180 51 .. Seal Water Return and N.A. C Excess Letdown ICT-145 54 Containment Spray to N.A. Spray Header (Tr. 8) Note 3 ICT-142 55 Containment Spray to N.A. Spray Header (Tr. A) Note 3 ICI-030 62 Instrument Air to N.A. C Containment g 1-8841A 63 RHR tc. Hot Leg Loops N.A.
#2 and #3 Note 2 COMANCHE PEAK - UNIT 1 3/4 6-25
ru-44tB Arrace urrl
. .- , (S4.loaI13)
~ TABLE 3.8-1 (Continued)
.[ A '
OC.~ 19 ~,c34 _ CONTAINMENT PENETRATION CONDUCTOR .
._, OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER AND LOCATION _ SYSTEM POWER [0 4.
480VAC From Pane 1 boards For Pressurizer Heaters Pressurizer Heaters a. Primary Breakers - General Electric Type TJJ Thermal Magnetic b reaker. Breaker No. & Location - Ckt. Nos. 2 thru 4 of Pan IEB1-2, 1EB2-2, 1EB3-2, IEB4-1, 1EB4-2 and Ckt.1EB3-1. and Nos. 2 thru 5 of Pane 1 boards IEB2-1 b. Backup Breakers - General Electric Type THJS with ss longtime a solid state trip device with 400 Amp. sensor. Breaker No. & Location - Ckt. No.1 of Pane 1 boards IEB
, IEB1-2, 1EB2-1, 1EB2-2, 1EB3-1, IEB3-2, 1EB4-1 and IEB4-2.
5.
--ee Power From Rod Control Power Cabinets Rod control Fuse Location - Rod control power Cabinets IAC,180, 2AC
, 2BD and SCOE.
- a. Primary Fuses FUSE LOCATION
& NUMBER
_ SYSTEM POWERED FU13 to FU20 Stationary Gripper Coils FU21 to FU24 Moving Gripper Coils FU25 to FU32 Stationary Gripper Coils FU33 to FU36 Moving Gripper Coils FU37 to FU44 Stationary Gripper Coils , FU45 to FU52 A51/FU1 & FU2 to Moving Gripper Coils A58/FU1 & FU2 Lift Coils 1
/
'k COMANCHE PEAK - UNIT 1 3/4 8-27
%X-Ol8 Arncamwr I TABLE 3.8-1 (Continued)
(54. Il ok 13) _ CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE OEVICES DEVICE NUMBER AND LOCATION _ SYSTEM POWERED 5. Mb. Power From Rod Control Power Cabinets (Continued) Backup Fuses FUSE LOCATION AND NUMBER SYSTEM POWERED FU1 to FU9 Stationary Gripper Coils Movable Bus-Duct Moving Gripper Coils Plug-in Unit A102-FU1 to FU3 Lift Bus-Duct Lift Coils Plug-in Unit A101-FU1 to FU3
- 6. 120V Space Heater Circuits from 480V Switchgears Containment Recire. Fan and CRDM Vent. Fan Motor Space Heaters
- a. Primary Breakers BKR. LOCATION
& NUMBER WESTINGHOUSE BKR. TYPE Swgr. 1EB1, Cubicle 3A EB101(i CP1-VAFNAV-01 Spa:e Heater Bkr.
Swgr. IEB2, Cubicle 3A EB1010 CP1-VAFNAV-02 Space Heater Bkr. Swgr. IEB3, ! Cubicle 9A EB1010 - CP1-VAFNAV-03 Space Heater Bkr. Swgr. IEB4, EB1010 Cubicle 9A CP1-VAFNAV-04 Space Heater Bkr.
*/
-( Swgr. IEB3, Cubicle 8A, EB1010 CP1-VAFNCB-01 Space Heater Bkr. " COMANCHE PEAK - UNIT 1 3/4 8-28 L .______ _ _ __ - ------ - - -
TX x-MlB ATTAc p1mr 1 (.54.12 oI 13 ) TABLE 3.8-1 (Continued) GCT 191984 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER AND LOCATION
- 6. 120V Space Heater Circuits from 480V Switchgears (Continued)
BKR. LOCATION WESTINGHOUSE
& NUMBER BKR. TYPE Swgr. IEB4, EB1010 Cubicle 8A CP1-VAFNAV-02 Space Heater Bkr.
- b. Backup Breakers Panel IEC3-2 TED Ckt. No. 3 Panel IEC3-2 TED Ckt. No. 4 Panel 1EC4-2 TED Ckt. No. 3 Panel 1EC4-2 TED Ckt. No. 4
- 7. 120V Space Heater Circuits From 480V MCC's
- a. Primary Fuses Location - Each MCC Starter Compartment MCC's 1EB1-2, IEB2-2, 1EB3-2 and IEB4-2.
- b. Backup Fuses FUSE LOCATION AND NUMBER SYSTEM POWERED MCC 1EB1-2 Space Heater Circuits from Compt. 12E, 1FU MCgEB1-2 MCC 1EB2-2 pace Heater Circuits from Compt. 12F, IFU MCC 1EB2-2 MCC 1EB3-2 Space Heater Circuits from Compt. 7C, IFU MCC 1EB3-2 COMANCHE PEAK - UNIT 1 3/4 8-29 1
ru-44LB dvrncumwr l (SH .13 oI 13 ) _SPECIAL TEST EXCEPTIONS
~ ,- n '
3/4.10.4 REACTOR COOLANT LOOPS .
.n n .
LIMITING CONDITION FOR OPERATION 3.10.4 The limitations of the following requirements may be suspended:
- a. 3.41.1 Specification TESTS in MODE3.4.1 1 or 21provided:
- During the performance of STARTUP and PHYSICS 1)
The THERMAL POWER does not exceed the P-7 Interlock Setpoint, a
- 2) The Reactor Trip Setpoints on the OPERABLE Intermediate and Power Range channels are set less than or equal to 25% of RATED THERMAL POWER.
b. Specification 3.4.1.2 - During the performance of natural circulation tests in MODE 3 provided at least three reactor coolant loops as listed in Specification 3.4.1.2 are OPERABLE. APPLICABILITY: During operation below the P-7 Interlock Setpoint or performance of natural circulation tests. ACTION: ( a. With the THERMAL POWER greater than the P-7 Interlock Setooint during open the theReactor performance of STARTUP and PHYSICS TESTS, immeoiately trip breakers, b. With less than the above required reactor coolant loops OPERABLE place two reactor coolant loops in operation.during the perform SURVEILLANCE REOUIREMENTS 4.10.4.1 Setpoint at least once per hour during STARTUP and PHYSICS T 4.10.4.2 Each Intermediate and Power Range channel, and P-7 Interlock shall be subjected to an ANALOG CHANNEL OPERATIONAL TEST within 12 hours prior to initiating STARTUP and PHYSICS TESTS. 4.10.4.3 OPERABLE within 4 hours prior to the initiation of the. natural verifying correct breaker align:nents and indicated power a COMANCHE PEAK - UNIT 1 3/4 10-4
i n-4418 4TTAcHn)f47' 2 7" ( 5 14 . l .) 3) B r" ? ii') :U]i !'5" t" *01 TABLE 3.3-5 . d" u ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATING SIGNAL AND FUNCTION RESPONSE TIME IN SECON05
- 1. Manual Initiation
- a. Safety Injection (ECCS) N. A.
- b. Containment Spray N.A.
- c. Phase "A" Isolation N.A.
- d. Phase "B" Isolation N.A.
- e. Containment Vent Isolation N.A.
- f. Steam Line Isolation N.A.
- g. Feedwater Isolation N.A.
h Auxiliary Feedwater , N.A. i Station Service Water N.A.
- j. Component Cooling Water N.A.
- k. Control Room Emergency Recirculation N.A.
- 1. Reactor Trip N. A.
- m. Emergency Diesel Generator Operation N.A.
- n. Safety Chilled Water N. A.
- o. Turbine Trip N.A.
T. OPS Venkla.+ os 83. h.
- 2. Containment Pressure-High - 1
- a. SafetyInjection(ECCS)(5) 1 27(1)/12(4)
- b. & Reactor Trip i2 c., 4 Feedwater Isolation 5 (. 5
~
cl. 4)--- Phase "A" Isolation < 17(2)/27(1)
- e. 4)-- Containment Vent Isolation 2d"/1/2) g3,g,
- h. 4)-- Auxiliary Feedwater N 60 3 4)-- Station Service Water 1 47 /37(2) g.h,
- h. 4}-- Component Cooling Water N. A.
II. 4)-- Safety Chilled Water N.A.
}. <9)-- Emergency Diesel Generator 1 l?.
Operation R. 46)-- Turbine Tri~p N.A.
- l. +1-)-- Control Room Emergency Recirculation N.A. -
, m. UPS b Wa.ke t COMANCHE PEAK - UNIT 1 3/4 3-33
T)ot-44tB ; ATTac4 muT 2. (.s4. 2 J- 3) nCT 191984 TA8LE 3.3-5 (Continued) ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATING SIGNAL AND FUNCTION RESPONSE TIME IN SECONOS
- 3. Pressurizer Pressure-Low
- a. Safety Injection (ECCS)(.5) < 27(1)/12(4)
- b. d t- Reactor Trip _2
- c. det- Feedwater Isolation <7
- d. 4)-- Phase "A" Isolation i 17(2)/27(1) f.. 46)-- Containment Vent Isolation h 2d"/id' 5 N I 4)- Auxiliary Feedwater N < 60 3 4)-- Station Service Water [07 f13/07(2) g ,g ,
- k. @)-- Component Cooling Water N.A
- i. 4)- Safety Chilled Water N. A.
- f. 4)- Emergency Diesel Generator 5 le-- 12.
Operation k 46)-- Turbine Trip N.A.
- l. 41)-- Control Room Emergency Recirculation N.A.
4. M. OPS hth% u.h. Steam Line Pressure-Low
- a. Safety Injection (ECCS) $ 22(3)/12(4)
- b. 6 Reactor Trip _2 C. 4)-- Feedwater Isolation <7 65
- d. 4)- Phase "A" Isolation I17(2)/27(1) e.. M Containment Vent Isolation I 2dD/1/2I 'M .h .
- 4. 46)- Auxiliary Feedwater UN 60 3 4)-- Station Service Water h47IU/37(21 g,g, h, 4)- Component Cooling Water N.A.
't, 4)- Safety Chilled Water N.A.
- j. & Emergency Diesel Generator 3 Operation
- k. 46)-- Turbine Trip N.A.
I- Con;rol Room Emergency Recirculation N
- m. u y 1 M. A.
- h. 4 eam Nm)I+
ne sol ~ation 3 N 6.5
- 5. Containment Pressure-Hf -3
- a. Containment Spra ?omy 3td2)jg7(1) 22.
[ b. Phase "B" Isolation <',dII/7/23 Q .h , COMANCHE PEAK - UNIT 1 3/4 3-34 S uBmm8 b / /85
F TXX.- 44-18 ATTatamur 2. LSS. S eh 3)
.bA -
3 :.n .. w:: inn n.:.1 TABLE 3.3-5 (Continued) ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATING SIGNAL AND FUNCTION RESPONSE TIME IN SECONOS
- 6. Containment Pressure--High-2 Steam Line Isolation 17 (o.3
- 7. Steam Line Pressure-Negative Rate-High Steam Line Isolation _7
- 8. Steam Generator Water Level-High-High
- a. Turbine Trip N .h .
1 .
- b. Feedwater Isolation 1 11
- 9. Steam Generator Water Level - Low-Low
- a. Motor-Drive Auxiliary Feedwater Pumps 1 60
- b. Turbine-Oriven gxiliary Feedwater Pump L*)
1 60
- 10. Loss-of-Offsite Power
- a. Auxiliary Feedwater N.A.
- b. Safety Chilled Water N.A.
- c. Control Room Emergency Recirculation N.A.
- 11. Trip of All Main Feedwater Pumps All Auxiliary Feedwater Pumps N.A.
- 12. RWST Level-Low-Low Coincident With Safety Injection Automatic Initiation of ECCS Switchover to Containment Sump 1 30
- 13. Loss of Power (6.9 kV Safeguards System Undervoltage) a
- a. .r;f rr;- C:f:: Srure: -
be.gr;aAgA VoVtage-EveryM3" d:r::!t:4:b . Opratles< 70 b-UU Y Rh'#L_suru m b4.ce b110 THIS PAh! 0.". !lT$tn RdEIPT OF INFORMA;i.1. del f.li A:%.tCANT COMANCHE PEAK - UNIT 1 3/4 3-35 uBwuTTt.b 4[30/65
%k-4418 ATT4c4mEvr 3 C 54. l .I l.)
POWER DISTRIBUTION LIMITS GCT 191984 LIMITING CONDITION FOR OPERATION ACTION (Continued)
- b. Within 24 hours of initially being outside the above limits, verify through incore flux mapping and RCS total flow rate comparison that the combination of R and RCS total flow rate are restored to within the above limits, or reduce THERMAL POWER to less than 5% of RATED THERMAL POWER within the next 2 hours.
- c. Identify and correct the cause of the out-of-limit condition prior to increasing THERMAL POWER above the reduced THERMAL POWER limit required by ACTION a.2. and/or b., above; subsequent POWER OPERATION may proceed provided that the combination of R and indicated RCS total flow rate are demonstrated, through incore flux mapping and RCS total flow rate comparison, to be within the region of acceptable operation shown on Figure 3.2-3 prior to exceeding the following THERMAL POWER levels:
- 1. A nominal 50% of RATED THERMAL POWER,
- 2. A nominal 75% of RATED THERMAL POWER, and
- 3. Within 24 hours of attaining greater than or equal to 95%
of RATED THERMAL POWER. SURVEILLANCE REQUIREMENTS 4.2.3.1 The provisions of Specification 4.0.4 are not applicable. 4.2.3.2 The combination of indicated RCS total flow rate and R shall be determined to be within the region of acceptable operation of Figure 3.2-3:
- a. Prior to operation above 75% of RATED THERMAL POWER after each fuel loading, and
- b. At least once per 31 Effective Full Power Days.
4.2.3.3 The indicated RCS total flow rate shall be verified to be within the region of acceptable operation of Figure 3.2-3 at least once per 12 hours when the most recently obtained value of R, obtained per Specification 4.2.3.2, are assumed to exist. 4.2.3.4 The RCS total flow rate indicators shall be subjected to a CHANNEL CALIBRATION at least once per 18 months. The :::;ur;;;nt instrum:ntation 5 hell b; ::libr:t:d within 7 d y; prior to th p;rfor;= = cf th; ::1:ri; t-1: 'le
=;;at .
4.2.3.5 The RCS total flow rate shall be determined by precision heat balance measurement at least once per 18 months. "The Tedwab Tressort ed rahre
*he N W Siam Tre%on , o wA %e Teedwdev, F)og bMerobt Tee.,., ore ,
L*oments s6t\cdorimetek coMvded rnent % % Aags A %e p b
. , ,)
Abt oQ rne.aaodlba. COMANCHE PEAK - UNIT 1 3/4 2-10
- - , _ - .. .,-__.n,- ~ . -, -,-- .
t I n
~
l TABLE 3.3-2 REACTOR TRIP SYSTEM INSTRUMENTATION RESPONSE TIMES y FUNCTIONAL UNIT RESPONSE TIME n
- 1. Manual Reactor Trip N.A.
c {
- 2. Power Range, Neutron Flux 1 0.5 second*
- 3. Power Range, Neutron Flux. N.A.
High Positive Rate l 4. Power Range, Neutron Flux, ' High Negative Rate 1 0.5 second*
- 5. Intermediate Range, Neutron Flux N.A.
- 6. Source Range, Neutron Flux N.A. i
- 7. Overteeperature, N-16 _< 7 seconds # k
- 8. Overpower, N-16 1 7 seconds Y
- 9. Pressurizer Pressure--Low 1 2 seconds - .g
. :. :.m .
- 10. Pressurizer Pressure--High < 2 seconds 1~.w t 2*
- 11. Pressurizer Water Level--High N.A.
i,., l 8
^ 3>
(A h"* /AmmA 3 k.d -
*NeutronVd etectors are exempt from response time testing. Response time of the neutronVflux d5~I [S.In.
signal portion of the channel shall be measured from detector output or input of first -
;**is +3A
! electronic component in channel.
's y $5 '
y '$ N Response time includes the thermal well response time. 9
m';ot-44iB ATretHmWT' 5 _ INSTRUMENTATION , ( ', AETEOROLOGICAL INSTRUMENTATION -.
~ ~ ~ '
LIMITING CONDITION FOR OP'ERATION ~ ' ~ ~ ~ ~ ~ ~ ~' 3.3.3.4 '~ 3.3-8 shall be OPERABLE.The meteorological monitoring instrumentation chan'nel 1 =- - ' - - - - APPLICABILITY: At all times. ACTION: ne nomber d C)?ERh%\E c.hnne\s OVE9.%%\.E v-e C.b ^ ndIS bSS b A Oe. m'iwimom
. a. WithVee e 'ac e q'd d gobemant -
for more than 7 days, prepare and submit a Special Report to the Commission pursuant to Specification 6.9.2 within the next 10 days outlining the channelthe (s)cause of the malfunction to OPERABLE status, and the plans for restoring b. The provisions of Specifications 3.0.3 and 3.0.4 are not applicable. SURVEILLANCE REOUIREMENTS 4.3.3.4 shall be demonstrated OPERABLE by the performance of CHANNEL CALIBRATION at the frequencies shown in Table 4.3-5. I 1 e 1 COMANCHE PEAK - UNIT 1 3/4 3-52
)
~TX.X.- Ol B ATTect4 MENT 4 , CONTAINMENT SYSTEMS bNI* O AIR TEMPERATURE *
-T' . - ,-lk.idiA7t> P '" LIMITING CONDITION FOR OPERATION 3.6.1.5 Primary containment average air temperature shall not exceed 120*F. APPLICABILITY: MODES 1, 2, 3, and 4. ACTION: With the containment average air temperature greater than 120*F, reduce the average air temperature to within the limit within 8 hours, or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. SURVEILLANCE REOUIREMENTS 4.6.1.5 The primary containment average air temperature shall be the arith-metical average determined of once at least the temperatures per 24 hours:at4 the followingf locations a u lgg m e g.nd shall be Location , ,or ahT4,
- a. Centainment, El. 011' 0" bome, El. \ 000 - (,"
- b. C:nt:in;;nt, El. 955'-0" boof 3 E\. 90[ -9 i u
- c. C;ntain; cat, El. 317'-0" Ficar , E.\. %D -O A. Fioor , E\. Bloo'- o "
e.. Fiooy 3 El. Bob'- o"
~
.. . I COMANCHE PEAK - UNIT 1 3/4 6-7
i u-44to ATT ACH mE+Jr 7
~ (.SR.Ic.4I) .
TABLE 3.7-6 FINAL DRAFT . AREA TEMPERATURE MONITORING AREA TEMPERATURE LIMIT (*F)
- 1. Control Room 80
- 2. Fuel Handling Building (Normal access areas) 104
- 3. Safeguards Building (Normal access areas) 104
- 4. Auxiliary Building (Normal access areas) 104
, 5. Electrical & Control Building (Normal access areas) 104
- 6. Diesel Generator Building 122
- 7. Service Water Intake Structure 122
- 8. Turbine Building - Switchgear Area 115
- u
"#huTskf CRDM Shroud Nkk!\[ SdEdh hkb
_ 163 Detector Well d Reactor Cavkg $ NrrIt
- 10. R Pump Rooms 122
- 11. ump Rooms 122
- 12. CCW Pump Rooms 122
- 13. Centrifugal Charging Pump Rooms 122
~
- 14. UPS/ Battery Room Areas 104
- 15. Spent Fuel Pool Cooling & Cleanup Pump and Heat Exchanger Rooms 122
- 16. AFW Pump Rooms 122
- 17. Pu 122 Conia/mmeni Syra)
COMANCHE PEAK - UNIT 1 3/4 7-45 50 5 4/30/N
' T X.)L- 4 N ATTAC4m M 8 * ( 54% . I cA 2.)
ELECTRICAL POWER SYSTEMS
' SURVEILLANCE REQUIREMENTS (Continued) 2)
Verifying the fuel level in the fuel storage tank,
- 3) Verifying the fuel transfer pump starts and transfers fuel from the storage system to the day tank, 4)
Verifying th 4d esel starts from ambient condition and accelerates to at least-45& rpm in less than or equal to 10 ' seconds.* The generator voltage and frequency shall be 6900 690 volts and 60 1.2 Hz within 10 seconds
- after the start signal. The diesel generator the following shall be started for this test by using one of signals:
a) Manual, or b) Startup transformer secondary winding undervoltage, or c) Simulated loss of preferred offsite power by itself, or d) Simulated safeguards bus undervoltage, or e) Safety Injection Actuation Test signal in conjunction with loss of preferred offsite power, or f) Safety Injection Actuation test signal by itself.
- 5) Verifying the generator is synchronized, loaded to between 5800 and 5980 kW in less than or equal to 60 seconds," and operates with a load between 5800 and 5980 kW for at least 60 minutes, and 6)
Verifying the diesel generator is aligned to provide standby power to the associated emergency busses. b. At least once per 31 days and after each operation of the diesel where the period of operation was greater than or equal to 1 hour by checking for and removing accumulated water from the day tank; c. At least once per 92 days by checking for and removing accumulated water from the fuel oil storage tanks; d. By sampling new fuel oil in accordance with ASTM-04057 prior to addition to storage tanks and:
*These diesel generator starts from ambient conditions shall be performed only once per 184 days in these surveillance tests and all other engine starts for the purpose of this surveillance testing shall be preceded by an engine pre-lube period and/or other warmup procedures recommended by the manufacturer so that the mechanical stress and wear on the diesel engine is minimized. ,,
COMANCHE PEAK - UNIT 1 3/4 8-3
l W X.-Olb ATTAcamtar
, C54. 2 el 1 .
- . ELECTRICAL POWER SYSTEMS OCT 19198 SURVEILLANCE REQUIREMENTS (Continued) i ;
, after the start signal; the steady-state generator voltage and frequency shall be maintained within these limits during this ! test. Within 5 minutes after completing this 24-hour test,
- perform Specification 4.8.1.1.2e.6)b);*
! 8) Verifying that the auto-connected loads to each diesel , generator do not exceed the continuous rating of 7000 kW;
- 9) Verifying the diesel generator's capability to:
i a) Synchronize with the offsite power source while the i generator is loaded with its emergency loads upon a
- simulated restoration of offsite power, b) Transfer its loads to the offsite power source, and c) Be restored to its standby status.
- 10) Verifying that with the diesel generator operating in a test mode, connected to its bus, a simulated Safety Injection signal overrides the test mode by: (1) returning the diesel generator to standby operation, and (2) automatically energizing the emergency loads with offsite power;
- 11) Verifying that the fuel transfer pump transfers fuel from the fuel storage tank to the day tank of its associated diesel via the installed lines;
- 12) Verifying that the automatic load sequence timers are OPERABLE with the interval between each load block within + 10% of its ~
design interval;
- 13) Verifying that the following diesel generator lockout" features prevent diesel generator starting by an SI signal:
a) Barring device engaged (PS-13B closed), or - b) Maintenance lock out mode,
- g. At least once per 10 years or after any modifications which could affect diesel generator interdependence by starting both diesel generators simultaneously, during shutdown, and verifying that both diesel generators accelerate to at least 466 rps in less than or equal to 10 seconds; and 44)
*If Specification 4.8.1.1.2f.6)b) is not satisfactorily completed, it is not necessary to repeat the preceding 24-hour test. Instead, the diesel generator may be operated between 5800 and 5980 kW for 1 hour or until operating tempera-ture has stabilized.
COMANCHE PEAK - UNIT 1 3/4 8-6
' Tx A-44 tg
+
ATT1tRmwT 9 lj . I of I INSTRUMENTATION Q [D b.J ..
- BASES REACTOR TRIP SYSTEM and ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION (Continued)
The Engineered Safety Features Actuation System interlocks perform the following functions: P-4 Reactor tripped - Actuates Turbine trip, closes main feedwater valves on T,yg below Setpoint, prevents the opening of the main feedwater valves which were closed by a Safety Injection or High Steam Generator Water Level signal, allows safety injection block so that components can be reset or tripped. Reactor not tripped prevents manual block of Safety Injection. P-11 On increasing pressurizer pressure, P-11 automatically reinstates Safety Injection actuation on low pressurizer pressure and low steam line pressure. On decreasing pressure, P-11 allows the manual block of safety injection actuation on low pressurizer pressure and low steam line pressure. .t.. pavent a.n onc. b\ led. m\deon due. tb P-12 ste m d.uq otero. ion Onincreasingreactorcoolantlooptempedature,P-12 automatically provides an arming signal to the steam dt:mp system. On decreasing reactor coolant loop temperature, P-12 at:tomatically removes the
, arming signal from the Steam Oump SystemVand allows the operator to go to bypass interlock to continue 3cooldown using three cooldown values. o. coo tvot\ed.
P On increasing steam generator water level, P-14 automatically trips all feedwater isolation valves and inhibits feedwater control valve s modulation, trips the main feed pumps, and trips the main turbine. 3/4.3.3 MONITORING INSTRUMENTATION 3/4.3.3.1 RADIATION MONITORING FOR PLANT OPERATIONS The OPERABILITY of the radiation monitoring instrumentation for plant operations ensures that: (1) the associated action will be initiated when the radiation level monitored by each channel or combination thereof reaches its Setpoint, (2) the specified coincidence logic is maintained, and (3) suffi-cient redundancy is maintained to permit a channel to be out-of-service for testing or maintenance. The radiation monitors for plant operations senses radiation levels in selected plant systems and locations and determines whether or not predetermined limits are be...g exceeded. If they are, the signals are combined into logic matrices sensitive to combinations indicative of various accidents and abnormal conditions. Once the required logic combination is completed, the system sends actuation signals to initiate alarms or automatic isolation action and actuation of Emergency Exhaust or Ventilation Systems. COMANCHE PEAK - UNIT 1 B 3/4 3-3
TX]t-44tB perTatameur to
- ' ( su . I d 1)
. r, TABLE 3.6-1 (Continued) .b. . 9 .m t' :4 TABLE NOTATIONS
- Identification code for containment penetration and associated isolation valves in FSAR Tables 6.2.4-1, 6.2.4-2, and 6.2.4-3.
Note 1: These are closed systems which meet the requirements of NUREG-0800 Section 6.2.4, II.6, paragraph o. required to be4 tested. These valves are therefore not Note ?.: WK These valves inside containment are part of closed systems outside containment which are in service post accident at a pressure in excess criterion.of containment design pressure and satisfy single failure These valves are therefore not required to bestested. Note 3: These are closed systems outside containment which are \ta.K in service post accident and have a water-filled loop seal on the containment side of the valves for a period greater than 30 days following the accident. These valves are therefore leak rate tested with water. Note 4: These ESF valves are normally open and remain open during post-accident conditions. Postaccident they are continually pressurized in excess single of containment failure criterion. pressure from an ESF source which meets the testeo. These valves are therefore not required ( Note 5: tobe$R\ An effective fluid seal on these penetrations is provided by the suction lowing an sources to the residual heat removal pumps during and fol-accident. In addition, these containment isolation valves are non-automatic, are not required to operate postaccident and are located inside containment. These valves are therefore not required t to be4 ested. 14a.K Note 6: '5::: ESF v:!ver er: dur n; p::t :::fd:nt ::ndit'en:.9:r :!!y :!cred, i
'Sc but 5 e desired +c epen
- cr"yiceare p :t p:rt f ci:.:d
- t : ;y;;;;;
- t:td:
3-ence:S
- ent i ::nt tic.' :r: '
20 ident pr:::u +
<-iteria. Of-contei eent d::!;n precru e and satisfy !! ;!e fa!!ure-In-the-event th: :lve f: n:t ep:n d p :t :::id: 1, lee W;e e' ecatata ent ateesphara is -prevented by p=p prueii. = aa +ha t:: id: :nd wetee-seal :n th: ::nt:f ::nt id: Of th: V:lv . cos-
- tincti:n of th; valv; di : ;;;l :nd th; d,31 t a seel5 p. w iude The
-th p ::i M Hty-of :ignificant :t; 10 h ;; und:r the 101. ::nt:in-
"::nt pre::ur; condition: :::r '- th pcetu!:ted post 20 ! dent : ndi-
-tten. Therefever-these-v 1v::
-te:ted. cr n:t required te b; Not (hed,,
Hote 7: These are parallel ESF valves that are normally closed, but are designed to open during post-accident conditions. Failure of one valve to open will not prevent system pressurization on both sides of both valves in excess of containment pressure. therefore not required to be tested. These valve are L w 4 COMANCllE PEAK - UNIT 1 3/4 6-29
u x.-44tB
' ATTRC4M NT- Il
- r tsu. I J lj TABLE 3.6-1 (Continued) g.
n q... . TABLE NOTATIONS Note 8: These valves located outside containment are normally closed and see a pressure in excess of containment pressure in post-accident conditions.<__,_A v:1v: :t; ; 1;;k;;; :t,;ck .;il' 5: ;;;rf:r :d :r :
...-_.. s.. .
;; 333 , , ,,, , ; ,, 7 ; ,,,t 3;;, , ;;;. ,;g 3;gg F I"
^^ 5 t- iCCi"'0 7.t 0 0 7.d i t ieftt:--
Hote 9: These valves are classified as " passive" in accordance with Specifi-cation 4.0.5 and are stroke time-tested only following maintenance which could effect the stroke time of the valve. Note 10: These valves require steam to be tested and are thus not required to be tested until the plant is in MODE 3.
- 6. guarterig va.\9e shm \a.o.kja. c. c.hed te h pr$ormel.
on aA q \ve d \.mM. to o. mo.x.ivnom o k 2.5 m\/mW par va\ve. On a. se\eche b. sis 3 diodme.wh wk. t=7o.\vs d\\ 6. maA4. tg veA.ou ( dem \ca.ko.ge en hose %\ves
- o. pro ^c b]
-b mwon -hem \eahge va.\oe .
1 s l r 6 COMANCHE PEAK - UNIT 1 3/4 6-30
T %X- O l8
- ATTAC.RTMAT O_
(.5% \c.4 Q PLANT SYSTEMS o SURVEILL'ANCE REQUIREMENTS (Continued) r
- 3) Verifying that the Emergency Pressurization System maintains the control room at a positive pressure of greater than or equal to 1/8 inch Water Gauge relative to the adjacent areas, including the outside atmosphere, at a flow rate of less than or equal to 260 cfm during system operation;
- 4) Verifying that the heaters in the Emergency Pressurization System dissipate 40 t 1 kW when tested in accordance with ANSI N510-1995; and to MBO
- 5) Verifying that on a High Chlorine test signal, the system auto-matically switches into the recirculation mode of operation with flow through the recirculation HEPA filters and charcoal adsorber banks within 10 seconds.
- f. After each complete or partial replacement of a HEPA filter bank in the Recirculation System, by verifying that the cleanup system satisfies the in place penetration and bypass leakage testing acceptance criteria of less than 0.05% in accordance with ANSI N510-1980 for a 00P test aerosol while operating the system at a flow rate of 8000 cfm 210%;
- g. After each complete or partial replacement of a charcoal adsorber bank in the Recirculation System, by verifying that the cleanup system satisfies the in place penetration and bypass leakage testing acceptance criteria of less than 0.05% in accordance with ANSI H510-1980 for a halogenated hydrocarbon refrigerant test gas while operating the system at a flow rate of 8000 cfm 210%;
h. After each complete or partial replacement of a HEPA filter bank in . the Emergency Pressurization System, by verifying that the cleanup system satisfies the in place penetration and bypass leakage testing acceptance criteria of less than 0.05% in accordance with ANSI . N510-1980 for a 00P test aerosol while operating the systera at a flow rate of 800 cfm i 10%; and
- i. After each complete or partial replacement of a charcoal adsorber bank in the Emergency Pressurization System, by verifying that the cleanup system satisfies the in place penetration and bypass leakage testing acceptance criteria of less than 0.05% in accordance with ANSI N510-1980 for a halogenated hydrocarbon refrigerant test gas while operating the system at a flow rate of 800 cfm t 10%.
THIS PAGE 0??l PENnlNi RECEIPT OF 1 INFORMATIR . iG.l i.E APAl0AN T .. COMANCHE PEAK - UNIT 1 3/4 7-17
-______________-____ __ ___ _ _ J}}