ML20148L086
| ML20148L086 | |
| Person / Time | |
|---|---|
| Site: | Cooper  |
| Issue date: | 11/14/1978 |
| From: | Pilant J NEBRASKA PUBLIC POWER DISTRICT |
| To: | Ippolito T Office of Nuclear Reactor Regulation |
| References | |
| TAC-03760, TAC-3760, NUDOCS 7811200115 | |
| Download: ML20148L086 (13) | |
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GENER AL OFFICE P. O. box 499, CoLUMOUS, NEBRASKA 68601 Nebraska Publ.ic Power D. tr. t is ic men o~E sou se4..sei
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November 14, 1978 Director, Nuclear Reactor Regulation Attention:
Mr. Thomas A. Ippolito, Chief Operating Reactors Branch No. 3 Division of Operating Reactors U.S. Nuclear Regulatory Commission Washington, DC 20555 Subj ect: Atmospheric Containment Atmosphere Dilution System Cooper Nuclear Station NRC Docket No. 50-298, DPR-46
Dear Mr. Ippolito:
In our letter of April 5, 1978, NPPD proposed Technical Specifica-tion changes relating to the Atmospheric Containment Atmosphere Dilution (ACAD) System for Cooper Nuclear Station.
In light of the soon to be effective regulation (10CFR50.44) which specifies stand-ards for combustible gas control systems, eaclosed are amplified Technical Specifications NPPD is proposing to cover the operation and surveillance testing requirements for the ACAD system. Please disregard the Technical Specifications proposed earlier.
Tables 3.2.E and 4.2.E are being amended to delete the surveillance requirements for the Containment Oxygen Analyzer which is no longer required with an ACAD system.
It should be noted that although the ACAD isolation valves being added were not included in the Techni-cal Specifications previously, they have been tested during local leak rate tests performed during past outages.
In addition to three signed originals, 37 copies are submitted for your review.
If additional information is required, please do not hesitate to contact me.
Sincerely yours,
. it. Pilant Director of Licensing and Quality Assurance JMP/jw: str8/3
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Attachment v811200lif I
6 Mr. Thomas A. Ippolito Page Two November 14, 1978 l
STATE OF NEBRASKA )
) ss PLATTE COUNTY
)
Jay M. Pilant, being first duly sworn, deposes and says that he is an authorized representative of the Nebraska Public Power District, a public corporation and political subdivision of the State of Nebraska; that he is duly authorized to submit this information on behalf of Nebraska Public Power District; and that the statements in said application are true to the best of his knowledge and belief.
M Q M.' Pilant Subscribed in my presence and sworn to before me this /
day of November, 1978.
[ NOTARY'PUBLIC My Commission expires DHHAL HTHY State of h6tasta MARILYN R. HOHNDORF dm My Comm. Esp, Oct 14, t000
COOPER NUCLEAR STATION TABLE 3.2.E INSTRUMENTATION TIIAT MONITORS DRYWELL LEAK DETECTION -
Action Required When Instrument Setting Minimum Number Of Component Operability Instrument I.D. No.
Limit-Operable Components-Is Not Assured (2)
Drywell Floor Drain. Sump Flow (1)
RW-FT-354 N.A.
1 A
Drywell Equipment Drain Sump RW-FT-364 N.A.
1 A
Flow (1) l 1
240TES FOR TABLE 3.2.E 1.
The two (2) flow transmitters, one for the equipment drain sump and the other for-the floor drain sump, comprise the basic instrument system.
The air sampling system is an alternate system to this system.
2.
Action A.
Refer to Specification 3.6.C of this Technical Specification.
COOPER NUCLEAR STATION TABLE 3.2.H INSTRUMENTATION THAT INITIATES AND CONTROLS ACAD SYSTEM OPERATION No. Of Minimum No.
Action Required When Instrument Setting Redundant Of Operable Minimum Component Oper-Instrument I.D. No.
Limit Components Components (1) ability Is Not Assured PC-H A-3160A
<3.6% Hi 2
1 (2)
Ilydrogen concentration 2
PC-H A-3160B
<3.6% Hi analyzers 2
High drywell pressure PS-2103 Al
<28 psig 2
1 (2) switches (system A)
PS-2103 A2
<28 psig High drywell pressure PS-2103 B1
<28 psig 2
1 (2)-
switches (system B)
PS-2103 B2
<28 psig Vent Flow monitor FR-2105 A
<26 cfm 2
1 (2)
FR-2105 B
<26 cfm i
liigh torus pressure PS-2102 Al
<28 psig 2
1 (2) switches (system A)
PS-2102 A2
<28 psig Iligh torus pressure PS-2102 B1
<28 psig 2
1 (2) switches (system B)
PS-2102 B2
<28-psig MOTES FOR TABLE 3.2.11 1.
Whenever the reactor is in the RUN Mode, the redundant component may remain inoperable for up to the allowable repair time of 30 days.
If this cannot be met, the indicated action shall be taken.
2.
Reduce power and place the mode selector-switch in a mode other than the RUN Mode.
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COOPER NUCLEAR STATION TABLE 4.2.E MINIMUM TEST AND CALIBRATION FREQUENCY FOR DRYWELL LEAK DETECTION Instrument Item Item I.D. No.
Function Test Freq.
Calibration Freq.
Check Instrument Channel 1.
Equipment Drain Sump Flow FW-FT-364 Once/ Month (1)
Once/3 Months Once/ Day 2.
Floor Drain Sump Flow RW-FT-354 Once/ Month (1)
Once/3 Months once/ Day I
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COOPER NUCLEAR STATION TABLE 4.2.H MINIMUM TEST AND CALIBRATION FREQUENCY AND ACAD SYSTEM INSTRUMENTATION Function Test Calibration Instrument Item Item I.D. No.
Frequency Frequency Check PC-H A-3160 A once/ month once/6 months once/ day Hydrogen concentration 2
PC-H A-3160 B once/ month once/6 months once/ day analyzers.
2 High drywell pressure PS-2103 Al once/ month once/6 months switches PS-2103 A2 once/ month once/6 months PS-2103 B1 once/ month once/6 months PS-2103 B2 once/ month once/6 months N.A.
1 i$
High wetwell pressure PS-2102 Al once/ month once/6 months I
switches PS-2102 A2 once/ month once/6 months PS-2102 B1 once/ month once/6 months PS-2102 B2 once/ month once/6 months N.A.
Vent flow monitor FR-2105 A once/ month once/6 months FR-2105 B once/ month once/6 months N.A.
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LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENT 3.7.A (cont'd) 4.7.A (cont'd) c.
The total leakage between the dry-c.
Once each operating cycle, each well and suppression chamber shall vacuum breaker valve shal! be visu-be less than the equivalent leakage ally inspected to insure proper through a 1" diameter orifice, maintenance and operation of the po-sition indication switch.
The dif-ferential pressure setpoint shall be verified.
d.
.If specification 3.7.A.4.a, b, or c, d.
Prior to reactor startup after each cannot be met, the situation shall refueling, a leak test of the dry-be corrected within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or the well to suppression chamber struc-reactor will be placed in a cold ture shall be conducted to demon-shutdown condition within the sub-strate that the requirement of sequent 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
3.7.A.4.c is met.
3.7.A.5 Hydrogen Concentration 4.7.A.5 Hydrogen Concentration a.
Both ACAD subsystems shall be a.
ACAD subsystem testing shall be as operable prior to reactor startup follows:
from a Cold Shutdown Condition and l
during reactor power operations Item Frequency except as specified in 3.7.A.5.b and 3.7.A.5.c below.
1.
Compressor & Valve once/ month Operability b.
From and after the date that one ACAD compressor is made or found 2.
Compressor Capacity After com-to be operable for any reason, Test.
Each pressor main-continued reactor operation is Compressor shall tenance and permissible only during the deliver 41.0 cfm every 6 succedding thirty days provided at 35 psig months.
that during such thirty days and remaining active components of b.
When it is determined that any both ACAD subsystems are operable.
ACAD compressor is inoperable, the remaining active components in the c.
From and after the date that one ACAD subsystem shall be demonstrated ACAD subsystem is made or found to to be operable immediately and weekly be inoperable for any reason, thereafter.
continued reactor operation is permissible only during the suc-c.
When it is determined that an ACAD ceeding seven-days provided that sybsystem is inoperable, the during such seven days the active remaining ACAD subsystems shall be components of the remaining ACAD demonstrated to be operable immed-subsystem are operable.
iately and daily thereaf ter.
d.
If the requirements of 3.7.A.5.a, b, and c cannot be met, an orderly shutdown of the reactor shall be initiated and the reactor shall be in cold shutdown' condition within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
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LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENT 3.7.B Standby Gas Treatment System 4.7.B Standby Gas Treatment System 1.
Except as specified in 3.7.B.3 below, 1.
At least once per operating cycle both circuits of the standby gas the following conditions shall be treatment system and the diesel gen-demonstrated, erators required for operation of such circuits shall be operable at all times when secondary containment integrity is required.
a.
Pressure drop across the combined HEPA filters and charcoal absorber banks is less than 6 inches of water at the system design flow rate.
b.
Inlet heater input is capable of reducing R.H. from 100 to 70% R.H.
2.a.
The results of the in-place cold 2.a.
The tests and sample analysis of DOP and halogenated hydrocarbon Specification 3.7.B.2 shall be tests at design flows on HEPA performed at least once per year filters and charcoal absorber banks for standby service or after every shall show 299% DOP removal and 720 hours0.00833 days <br />0.2 hours <br />0.00119 weeks <br />2.7396e-4 months <br /> of system operation and 2,99% halogenated hydrocarbon.
following significant painting, fire or chemical release in any ventilation zone communicating with the system, b.
The results of laboratory carbon b.
Cold DOP testing shall be performed sample analysis shall show 2,95%
after each complete or partial radioactive methyl iodide removal replacement of the HEPA filter bank at a velocity within 20 percent of or after any structural maintenance actual system design, 0.5 to 1.5 on the system housing.
mg/m3 inlet methyl iodide concen-tration, 2,70% R.H. and 3,900F.
c.
Fans shall be shown to operate c.
Halogenated hydrocarbon testing within +10% design flow, shall be performed after each com-plete or partial replacement of the charcoal absorber bank or after any structural maintenance on the system housing.
d.
Each circuit shall be operated with the heaters on at least 10 hours1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br /> every month.
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A-4 LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENT 3.7.B (cont'd) 4.7.B (cont'd) e.'
Test sealing of gaskets for housing doors downstream of the HEPA filters and charcoal absorbers shall be per-formed at, and in conformance with, each test performed for compliance with Specification 4.7.B.2.a and Specification 3.7.B.2.a.
3.
From and after the date that one 3.
System drains where present shall circuit of the standby gas treat-be inspected quarterly for ade-ment system is made or' found to quate water level in loop-seals.-
be inoperable for any reason, reactor operation or fuel handling is permissible only during the suc-ceeding seven days unless such cir-cuit is sooner made operable, pro-vided that during such seven days all active components of the other standby gas treatment circuit shall be operable.
4.
If thess canditions cannot be met, 4.a.
At least once per operating cycle procedu, shall be initiated automatic initiation of each immedic-
_f to establish reactor branch of the standby gas treat-conditions for which the standby ment system shall be demonstrated.
gas treatment system is not re-
- quired, b.
At least once per operating cycle manual operability of the bypass valve for filter cooling shall be demonstrated.
c.
When one circuit of the standby gas treatment system becomes in-operable the other circuit shall be demonstrated to be operable immediately and daily thereafter.
C.
Secondary containment integrity 1.
Secondary containment surveil-shall be maintained'during all lance shall be performsd as in-modes of plant operation except dicated below:
when all of the following condi-tions are met.
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s TABLE 3.7.4 PRIMARY CONTAINMENT TESTABLE ISOLATION VALVES TEST PEN. NO.
VALVE NUMBERS MEDIA j
l X-7A MS-AO-80A and MS-AO-86A, Main Steam Isolation Valves Air 1
X-7B MS-A0-80B and MS-AO-86B, Main Steam Isolation Valves Air
~X-7C MS-AO-80C and MS-AO-86C, Main Steam Isolation Valves Air X-7D MS-AO-80D and MS-AO-86D, Main Steam Isolation Valves Air X-8 MS-M0-74 and MS-MO-77, Main Steam Line Drain Air X-9A RF-15CV and RF-16CV, Feedwater. Check Valve Water X-9A RCIC-AO-22, RCIC-MO-17, and RWCU-15CV, RCIC/RWCU, Connection to Feedwater Water X-9B RF-13CV and RF-14CV, Feedwater Check Valves Water X-9B HPCI-AO-18 and-HPCI-MO-57, HPCI Connection to Feedwater Water X-10 RCIC-MO-15 and RCIC-MO-16, RCIC Steam Line Air X-11 HPCI-MO-15 and HPCI-MO-16, HPCI Steam Line Air X-12 RHR-MO-17 and RHR-MO-18, RHR Suction Cooling Air X-13A RHR-MO-25A and RHR-M0-27A, RHR Supply to RPV Air X-13B RHR-M0-25B and RHR-M0-27B, RHR Supply to RPV Air X-14 RWCU-M0-15 and RWCU-M0-18, Inlet to RWCU System Air X-16A CS-MO-11A and CS-M0-12A, Core Spray to RPV Air X-16B CS-MO-llB and CS-MO-12B, Core Spray to RPV Air X-17 RHR-M0-32 and RHR-MO-33, RPV Head Spray Air X-18 RW-732AV and RW-733AV, Drywell Equipment Sump Discharge Air X-19 RW-765AV and RW-766AV, Drywell Floor Drain Sump Discharge-Air X-25 PC-232MV and PC-238AV, Purge and Vent Supply to Drywell Air
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TABLE 3.7.4 (Page 2)
PRIMARY CONTAINMENT TESTABLE ISOLATION VALVES TEST PEN. NO.
VALVE NUMBERS MEDIA
]
X-25 MV 1305 and MV 1306, ACAD A Loop Supply to Drywell Air j
X-26 PC-231MV and PC-246AV, Purge and Vent Exhaust from Drywell l
MV 1310, ACAD Drywell Vent Air X-36 CRD-11CV and CRD-12CV, CRD Exhaust Water Air X-39A RHR-M0-26A and RHR-MO-31A, Drywell Spray Header Supply Air X-39B RHR-M0-26B and RHR-M0-31B, Drywell Spray Header Supply.
Air X-39B MV 1311 and MV 1312, ACAD B Loop Supply to Drywell Air i
X-41 RRV-740AV and RRV-741AV, Reactor Water Sample Line Air X-42 SLC-12CV and SLC-13CV Standby Liquid Control Air X-205 PC-233MV and PC-237AV, Purge and Vent Supply to Torus Air X-205 PC-13CV and PC-243AV, Torus Vacuum Relief Air-X-205 PC-14CV and PC-244AV, Torus Vacuum Relief Air X-205 MV-1303 and MV-1304, ACAD A Loop Supply to Torus Air l l
X-210A RCIC-M0-27 and RCIC-13CV, RCIC Minimum Flow Line Air X-210A RHR-MO-21A, RHR to Torus Air X-210A RHR-MO-16A, RHR-10CV, and RHR-12CV, RHR Minimum Flow Line Air X-210B RHR-M0-21B, RHR to Torus Air X-210B HPCI-17CV and HPCI-M0-25, HPCI Minimum Flow Line Air X-210B RHR-MO-16B, RHR-11CV, and RHR-13CV, RHR Minimum Flow Line Air X-210A and 211A RHR-M0-34A, RHR-MO-38A, and RHR-M0-39A, RHR to Torus Air X-210B and 211B RHR-MO-34B, RHR-MO-38B, and RHR-MO-39B, RHR to Torus Air X-211B MV 1301 and MV 1302, ACAD B Loop Supply to Torus Air l X-212 RCIC-15CV and RCIC-37, RCIC Turbine Exhaust Air
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1 TABLE 3.7.4 (Page 3) l PRIMARY CONTAINMENT TESTABLE ISOLATION VALVES TEST
' PEN. NO.
VALVE NUMBERS MEDIA X-214 HPCI-15CV and HPCI-44, HPCI Turbine Exhaust Air l
l X-214 HPCI-AO-70 and HPCI-AO-71, HPCI Turbine Exhaust Drain Air i
l X-214 RHR-MO-166A and RHR-MO-167A, RHR Heat Exch. Vent.
Air X-2,14 RHR-MO-166B and RHR-MO-167B, RHR Heat Exch. Vent.
Air X-220 PC-230MV and PC-245AV, Purge and Vent Exhaust from Torus MV 1308, ACAD Torus Vent Air l X-221 RCIC-12CV and RCIC-42, RCIC Vacuum Line Air X-222 HPCI-50 and HPCI-16CV, HPCI Turbine Drain Air X-223A CS-M0-26A and CS-MO-5A, Core Spray Test and Minimum Flow Air X-223B CS-MO-26B and CS-MO-5B, Core Spray Test and Minimum Flow Air X-225A-D RHR-MO-13A, RRR-MO-13C, RHR-MO-13B, RHR-M0-13D, RHR Suction From Torus Air X-224 RCIC-MO-41, RCIC Suction From Torus Air i
X-226 HPCI-MO-58, HPCI Suction From Torus Air X-227A, B CS-MO-7A and CS-MO-7B, Core Spray Suction From Torus Air i
l L
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