NLS2011026, License Amendment Request for Administrative Revisions to Technical Specifications and to Remove an Expired One-Time Exception to the Five-Year Test Frequency for a Single Safety Valve

From kanterella
(Redirected from ML110900167)
Jump to navigation Jump to search

License Amendment Request for Administrative Revisions to Technical Specifications and to Remove an Expired One-Time Exception to the Five-Year Test Frequency for a Single Safety Valve
ML110900167
Person / Time
Site: Cooper Entergy icon.png
Issue date: 03/26/2011
From: O'Grady B
Nebraska Public Power District (NPPD)
To:
Document Control Desk, Office of Nuclear Reactor Regulation
References
NLS2011026, TAC MD6580
Download: ML110900167 (53)
v • d • e


Text

H Nebraska Public Power District Always there when you need us 50.90 NLS2011026 March 26, 2011 U.S. Nuclear Regulatory Commission Attention: Document Control Desk Washington, D.C. 20555-0001

Subject:

License Amendment Request for Administrative Revisions to Technical Specifications and to Remove an Expired One-Time Exception to the Five-Year Test Frequency for a Single Safety Valve Cooper Nuclear Station, Docket No. 50-298, DPR-46

Reference:

Letter from Carl F. Lyon, U.S. Nuclear Regulatory Commission, to Stewart B.

Minahan, Nebraska Public Power District, dated December 4, 2007, "Cooper Nuclear Station - Issuance of Amendment Re: One-Time Exception to the 5-Year Test Frequency for a Single Safety Valve (TAC No. MD6580)"

Dear Sir or Madam:

The purpose of this letter is for the Nebraska Public Power District (NPPD) to request an amendment to Facility Operating License DPR-46 in accordance with the provisions of 10 CFR 50.4 and 10 CFR 50.90 to revise the Cooper Nuclear Station (CNS) Technical Specifications (TS). This request revises several pages to correct formatting errors and typographical errors.

This request also revises TS Section 5.5.6, Inservice Testing Program, to remove an expired one-time exception of the five-year frequency requirement for setpoint testing of safety valve MS-RV-70ARV (Reference).

NPPD requests Nuclear Regulatory Commission (NRC) approval of the proposed TS change and issuance of the requested license amendment by March 30, 2012. The amendment will be implemented within 60 days of issuance of the amendment.

Attachment I provides a description of the proposed TS changes, the technical analysis basis for the changes, the no significant hazards consideration evaluation pursuant to 10 CFR 50.91(a)(1),

and the environmental impact evaluation pursuant to 10 CFR 51.22. Attachment 2 provides marked up pages with the specific changes to the current CNS TS. Attachment 3 provides the revised TS pages in final format. No TS Bases pages are affected by this amendment request.

ADO(

Cooper Nuclear Station Nuclear Training Department 1 R(

P.O. Box 98 / Brownville, NE 68321-0098 Telephone:-(402) 825-3811 / Fax: (402) 825-5584 www.nppd.com

NLS2011026 Page 2 of 2 This proposed TS change has been reviewed by the necessary safety review committees (Station Operations Review Committee and Safety Review and Audit Board). Amendments to the CNS Facility Operating License through Amendment 237 dated February 28, 2011, have been incorporated into this request. This request is submitted under oath pursuant to 10 CFR 50.3 0(b).

By copy of this letter and its attachments, the appropriate State of Nebraska official is notified in accordance with 10 CFR 50.91(b)(1). Copies to the NRC Region IV office and the CNS Resident Inspector are also being provided in accordance with 10 CFR 50.4(b)(1).

Should you have any questions concerning this matter, please contact David Van Der Kamp, Licensing Manager, at (402) 825-2904.

I declare under penalty of perjury that the foregoing is true and correct.

Executed On: 03/,L]*d/11 Date Sincerely, Brian J. O'Gradj Vice President - Nuclear and Chief Nuclear Officer

/jo Attachments cc: Regional Administrator w/ attachments USNRC - Region IV Cooper Project Manager w/ attachments USNRC - NRR Project Directorate IV-1 Senior Resident Inspector w/ attachments USNRC - CNS Nebraska Health and Human Services w/ attachments Department of Regulation and Licensure NPG Distribution w/o attachments CNS Records w/ attachments

NLS2011026 Page 1 of 6 ATTACHMENT 1 LICENSE AMENDMENT REQUEST FOR ADMINISTRATIVE REVISIONS TO TECHNICAL SPECIFICATIONS AND TO REMOVE AN EXPIRED ONE-TIME EXCEPTION TO THE FIVE-YEAR TEST FREQUENCY FOR A SINGLE SAFETY VALVE COOPER NUCLEAR STATION DOCKET NO. 50-298, DPR-46 Revised Technical Specification Pages 3.1-9 3.1-12 3.1-13 3.3-4 3.3-36 3.3-51 3.3-57 3.3-65 3.3-68 3.5-6 3.5-10 3.6-2 3.6-40 3.7-9 3.8-3 3.8-13 5.0-2 5.0-6 5.0-9 5.0-10 5.0-12 1.0 Description 2.0 Proposed Change 3.0 Technical Evaluation 4.0 Regulatory Analysis 4.1 Precedence 4.2 No Significant Hazards Consideration 4.3 Conclusion 5.0 Environmental Consideration 6.0 References

NLS2011026 Attachment I Page 2 of 6 1.0 Description This license amendment request (LAR) proposes changes to correct formatting errors and typographical errors and also removes an expired one-time exception of setpoint testing of a single safety valve (Reference) from the Cooper Nuclear Station Technical Specifications (TS).

2.0 Proposed Change This LAR is proposed to revise the following:

TS Section 3.1.3, Control Rod Operability, Page 3.1-9, by capitalizing the word "Actions" in the header of the Actions table.

TS Section 3.1.4, Control Rod Scram Times, Page 3.1-12, by adding the word

"(continued)" to the bottom of the Surveillance Requirements table.

TS Section 3.1.4, Control Rod Scram Times, Page 3.1-13, by adding the word

"(continued)" to the header of the Surveillance Requirements table.

TS Section 3.3.1.1, RPS Instrumentation, Page 3.3-4, by adding the word "(continued)"

to the bottom of the Surveillance Requirements table.

TS Section 3.3.5.1, ECCS Instrumentation, Page 3.3-36, by formatting the footer with the Amendment number in the right margin.

TS Section 3.3.6.1, Primary Containment Isolation Instrumentation, Page 3.3-51, by formatting the footer with the Amendment number in the right margin.

TS Section 3.3.6.2, Secondary Containment Isolation Instrumentation, Page 3.3-57, by formatting the footer with the Amendment number in the right margin.

TS Section 3.3.8.1, LOP Instrumentation, Page 3.3-65, by formatting the footer with the Amendment number in the right margin.

TS Section 3.3.8.2, RPS Electric Power Monitoring, Page 3.3-68, by adding the words "ACTIONS (continued)" to the header of the Actions table, and by formatting the footer with the Amendment number in the right margin.

TS Section 3.5.1, ECCS - Operating, Page 3.5-6, by formatting the footer with the Amendment number in the right margin.

TS Section 3.5.2, ECCS - Shutdown, Page 3.5-10, by formatting the footer with the Amendment number in the right margin.

NLS2011026 Page 3 of 6 TS Section 3.6.1.1, Primary Containment, Page 3.6-2, by formatting the footer with the Amendment number in the right margin.

TS Section 3.6.4.3, SGT System, Page 3.6-40, by formatting the footer with the Amendment number in the right margin.

TS Section 3.7.4, CREF System, Page 3.7-9, by removing the word "(continued)" from the bottom of the Actions table.

TS Section 3.8.1, AC Sources - Operating, Page 3.8-3, by capitalizing the word "Actions" in the header of the Actions table and formatting the footer with the Amendment number in the right margin.

TS Section 3.8.3, Diesel Fuel Oil, Lube Oil, and Starting Air, Page 3.8-13, by formatting the footer with the Amendment number in the right margin.

TS Section 5.2, Organization, Page 5.0-2, by adding the word "(continued)" to the bottom of the page and correcting double and single line format.

TS Section 5.5, Programs and Manuals, Page 5.0-6, by adding the word "(continued)" to the bottom of the page and correcting double and single line format.

TS Section 5.5, Programs and Manuals, Page 5.0-9, by adding the word "(continued)" to the bottom of the page and correcting double and single line format.

TS Section 5.5, Programs and Manuals, Page 5.0-10, by removing paragraph b.1 of Section 5.5.6, the One-Time exception, as the 90 days has expired.

TS Section 5.5, Programs and Manuals, Page 5.0-12, by adding a space after the "C" in "30oC(86 0 F)".

3.0 Technical Evaluation No technical changes are being made. Corrections are editorial or administrative.

4.0 Regulatory Analysis 4.1 Precedence The corrections are editorial or administrative and stand alone; therefore, no precedence is needed.

NLS2011026 Page 4 of 6 4.2 No Significant Hazards Consideration Nebraska Public Power District (NPPD) is requesting a revision to the Facility Operating License No. DPR-46 for Cooper Nuclear Station. The requested changes are corrections to formatting and typographical errors, and also removes an expired one-time exception.

NPPD has evaluated whether or not a significant hazards consideration is involved with the proposed amendment by focusing on the three standards set forth in 10 CFR 50.92, "Issuance of amendment," as discussed below.

1. Does the proposed amendment involve a significant increase in the probability or consequences of an accident previously evaluated?

Response: No.

The proposed changes correct formatting and typographical errors and removes an expired one-time exception. Administrative and editorial changes such as these are not an initiator of any accident previously evaluated. As a result, the probability of an accident previously evaluated is not affected. The consequences of an accident with the incorporation of these administrative and editorial changes are not different than the consequences of the same accident without these changes. As a result, the consequences of an accident previously evaluated are not affected by these changes.

Based on the above, it is concluded that the proposed change does not involve a significant increase in the probability or consequences of an accident previously evaluated.

2. Does the proposed amendment create the possibility of a new or different kind of accident from any accident previously evaluated?

Response: No.

The proposed changes do not modify the plant design, nor do the proposed changes alter the operation of the plant or equipment involved in either routine plant operation or in the mitigation of the design basis accidents. The proposed changes are editorial or administrative only.

Based on the above, it is concluded that the proposed changes do not create the possibility of a new or different kind of accident from any accident previously evaluated.

NLS2011026 Page 5 of 6

3. Does the proposed amendment involve a significant reduction in a margin of safety?

Response: No.

The proposed changes consist of administrative and editorial changes to correct formatting and typographical errors and to remove an expired one-time exception. The changes do not alter the manner in which safety limits, limiting safety system settings or limiting conditions for operation are determined. The safety analysis acceptance criteria are not affected by these changes. The proposed changes will not result in plant operation in a configuration outside of the design basis. Therefore, the proposed changes do not involve a significant reduction in a margin of safety.

Based on the above, NPPD concludes that the proposed amendment presents no significant hazards consideration under the standards set forth in 10 CFR 50.92, paragraph (c), and, accordingly, a finding of no significant hazards consideration is justified.

4.3 Conclusion The proposed change has been evaluated to determine whether applicable regulations and requirements continue to be met. Applicable regulatory requirements continue to be met, adequate defense-in-depth is maintained, and sufficient safety margins are maintained.

In conclusion, based on the considerations discussed above, (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner, (2) such activities will be conducted in compliance with the Commission's regulations, and (3) the issuance of the amendment will not be inimical to the common defense and security or to the health and safety of the public.

5.0 Environmental Consideration 10 CFR 51.22(c) provides categories of actions which are categorical exclusions from performing an environmental assessment. An action which is a categorical exclusion does not require an environmental assessment or an environmental impact statement. 10 CFR 51.22(c)(9) allows as a categorical exclusion issuance of an amendment to a license for a reactor pursuant to 10 CFR Part 50 which changes a requirement with respect to installation or use of a facility component located within a restricted area as defined in 10 CFR Part 20, or which changes an inspection or a surveillance requirement, provided that (1) the amendment involves no significant hazards consideration, (2) there is no significant change in the types or significant increase in the amounts of any effluents that

NLS2011026 Page 6 of 6 may be released off-site, and (3) there is no significant increase in individual or cumulative occupational radiation exposure.

NPPD has reviewed the proposed license amendment and concludes that it meets the eligibility criteria for categorical exclusion set forth in 10 CFR 51.22(c)(9). The basis for this determination is as follows:

1. The proposed license amendment does not involve significant hazards as described previously in the No Significant Hazards Consideration Evaluation.
2. The proposed license amendment does not introduce any new equipment, nor does it require any existing equipment or systems to perform a different type of function than they are presently designed to perform. NPPD has concluded that this proposed change does not result in a significant change in the types or significant increase in the amounts of any effluents that may be released off-site.
3. These changes do not adversely affect plant systems or operation and therefore, do not significantly increase individual or cumulative occupational radiation exposure beyond that already associated with normal operation.

Therefore, pursuant to 10 CFR 51.22(c), no environmental impact statement or environmental assessment needs to be prepared in connection with issuance of the proposed license changes.

6.0 References Letter from Carl F. Lyon, U.S. Nuclear Regulatory Commission, to Stewart B. Minahan, Nebraska Public Power District, dated December 4, 2007, "Cooper Nuclear Station -

Issuance of Amendment Re: One-Time Exception to the 5-Year Test Frequency for a Single Safety Valve (TAC No. MD6580)"

NLS2011026 Page 1 of 22 ATTACHMENT 2 LICENSE AMENDMENT REQUEST FOR ADMINISTRATIVE REVISIONS TO TECHNICAL SPECIFICATIONS AND TO REMOVE AN EXPIRED ONE-TIME EXCEPTION TO THE FIVE-YEAR TEST FREQUENCY FOR A SINGLE SAFETY VALVE COOPER NUCLEAR STATION DOCKET NO. 50-298, DPR-46 Revised Technical Specification Pages - Markup Format 3.1-9 3.1-12 3.1-13 3.3-4 3.3-36 3.3-51 3.3-57 3.3-65 3.3-68 3.5-6 3.5-10 3.6-2 3.6-40 3.7-9 3.8-3 3.8-13 5.0-2 5.0-6 5.0-9 5.0-10 5.0-12

Control Rod OPERABILITY ACTIONSI 3.1.3 Aetiens (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. - ------------ NOTE ------------- 0D.1 Restore compliance with 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Not applicable when BPWS.

THERMAL POWER

> 9.85% RTP. OR D.2 Restore control rod to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Two or more inoperable OPERABLE status.

control rods not in compliance with banked position withdrawal sequence (BPWS) and not separated by two or more OPERABLE control rods.

E. Required Action and E.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A, C, or D not met.

OR Nine or more control rods inoperable.

Cooper 3.1-9 Amendment No. 2-3J

Control Rod Scram Ti'nes S.l1.4..

3.1 REACTIVITY CONTROL SYSTEMS 3.1.4 Control Rod Scram imnes LCO 3.1.4 a. No more than 10 OPERABLE control rods shall be "slow," In accordance with Table 3.1.4-1; and

b. No more then 2 OPERABLE control rods that are "slow" shall occupy adjacent locations.

APPLICABILITY: MODES I and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the LCO A.1 Be InMODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> n )tmet.

SURVEILLANCE REQUIREMENTS During single control rod scram time Surveillances, the control rod drive (CRD) pumps shall be Isolated from the associated scram accumulator.

SURVEILLANCE FREQUENCY SR 3.1.4.1 Verify each control rod scram time is within the limits Prior to exceeding of Table 3.1.4-1 with reactor steam dome pressure 40% RTP after

> 800 pslg. each reactor shutdown

>120 days 8R 3.1.4.2 Verify, for a representative sample, each tested 200 days control rod scram time Iswithin the limits of cumulative Table 3.1.4-1 with reactor steam dome pressure operation In

?> 800 psig. MODE 1

<-Ae nnttinuedN)

Amendment No. 2*

Cooper 3.1-12

~ ft. ~.I' orrcvrc ~ ~ ) ~r'

~ ~

= *

  • I ='

'I -1II.- F] F V-~- -VI.- -.

Control Rod Scram Times 3.1.4 SURVEILLANCE REQUIREMENTS _(__ntinued__

SURVEILLANCE FREQUENCY SR 3.1.4.3 Verify each affected control rod scram time is within Prior to declaring the limits of Table 3.1.4-1 with any reactor steam controt rod dome pressure. OPERABLE after work on control rod or CRD System that could affect scram time SR 3.1.4.4 Verify each affected control rod scram time is within Prior to exceeding the limits of Table 3.1.4-1. with reactor steam dome 40% RTP after pressure > 800 psig. fuel movement within the affected core cell AND Prior to exceeding 40% RTP after work on control rod or CRD System that could aflect scram time Cooper 3.1-13 Amendment No. 2--4

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY K)

SR 3.3.1.1.5 Verify the source range monitor (SRM) and Prior to Intermediate range monitor (IRM) channels withdrawing SRMs overlap, from the fully Inserted position SR 3.3.1.1.6 OTE Only required to be met during entry into MODE 2 from MODE 1.

Verify the IRM and APRM channels overlap. 7 days SR 3.3.1.1.7 Adjust the channel to conform to a calibrated flow 31 days signal.

SR 3.3.1.1.8 Calibrate the local power range monitors. 1000 MWD/T average core exposure SR 3.3.1.1.9 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.1.1.10 NOTES

1. Neutron detectors and recirculation loop flow transmitters are excluded.
2. For Function 2.a, not required to be performed when entering MODE 2 from MODE I until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after entering MODE 2.

184 days Perform CHANNEL CALIBRATION.

N t(continued)

Cooper 3.3-4 K-)

Amendment No. I44 Coper "- 4~99&

.3-4JUL i

ECCS Instrumentation 3.3.5,1 SURVEILLANCE REQUIREMENTS

-- - NOTES -. .... . . .

1. Refer to Table 3.3.5.1-1 to determine which SRs apply for each ECCS Function.
2. When a channel Is placed. in an inoperable status solely for performance of required Surveillances, entry Into associated Conditions and*Required Actions may be delayed as follows: (a) for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for Functions 3.c and 3.f; and (b) for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for Functions other than 3.c and 3.f provided the associated Function or the redundant Function maintains ECCS initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.5.1.1 Perform.CHANNEL CHECK. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SR 3.3.5.1.2 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.5.1.3 Perform CHANNEL CALIBRATION. 92 days SR 3.3.5.1.4 Perform CHANNEL CALIBRATION. 18 months SR 3.3.5.1.5 Perform LOGIC.SYSTEM FUNCTIONAL TEST. 18 months 3Amendment No.

3.3-35 AFRORGIMBF4 214

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 1 of 3)

Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE

1. Main Steam Line Isolation
a. Reactor Vessel Water 1.2,3 2 D SR 3.3.6.1.1 2 -113 Inches Level - Low Low Low SR 3.3.6.1.2 (Level 1) SR 3.3.6.1.4 SR 3.3.6.1.6
b. Main Steam Line 2 E SR 3.3.8.1.2 a 835 psig Pressure - Low SR 3.3.6.1.3 123 SR 3.3.8.1.6
c. Main Steam Line 1.2.3 2 per D SR 3.3.6.1.2 < 142.7%

Flow - High MSL SR 3.3.6.1.4 rated steam SR 3.3.6.1.6 flow

d. Condenser 1, 2 D SR 3.3.6.1.2 > 8 Inches Vacuum - Low SR 3.3.6.1.3 Hg vacuum 2 (a), 3 (a) SR 3.3.6.1.6
e. Main Steam Tunnel 1.2.3 2 per D SR 3.3.6.1.2 < 195*F Temperature - High location SR 3.3.6.1.4 SR 3.3.6.1.6
2. Primary Conlainment Isolation
a. Reactor Vessel Water Level- Low (Level 3) 1,2.3 G SR 3.3.6.1.1 > 3 Inches SR 3.3.6.1.2 SR 3.3.6.1.4 SR 3.3.6.1.6
b. DryweD Pressure - High 1.2,3 G SR 3,3.6.1.2 < 1.84 psig SR 3.3.6.1.4 SR 3.3.6.1.6
c. Reactor Building Ventilation 1,2,3 F SR 3.3.6.1.1 < 49 mR/hr Exhaust Plenum SR 3.3.6.1.2 Radiation- High 1.2.3 SR 3.3.6.1.4 SR 3.3.6.1.6
d. Main Steam Line F SR 3.3.6.1.1 < 3 times Radiation - High SR 3.3.6.1.2 Tull power SR 3.3.6.1.4 background SR 3.3.6.1.5 SR 3.3.6.1.6 1,2,3
e. Reactor Vessel Water Level F SR 3.3.6.1.1 > -113 inches

-Low Low Low (Level 1) SR 3.3.6.1.2 SR 3.3.6.1.4 SR 3.3.6.1.6 (continued)

(a) With any turbine stop valve not closed.

Amendment No.

Am-endment 231 3.3-51 ISMGL9I8~

Secondary Containment Isolation Instrumentation 3.3.6.2 Table 3.3.6.2.1 (page I ol1)

Secondary Containment Isolation Instrumentation APPLICABLE MODES OR REOUIRED OTHER CHANNELS SPECIFIED PER SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS TRIP SYSTEM REQUIREMENTS VALUE

1. ReactorVessel Water 1.2.3. 2 SR 3.3.6.2.1 t.-42Inches Level - Low Low ILevel 2) (a) SR 3.3.6.22 SR 3.3.6.2.3 SR 3.3.6.2.4
2. Doywdl Pressure - -igh 1.2.3 2 SR 3.3.6.2.2 -C1.84 pslg SR 3.3.6.2.3 SR 3.3.6.2.4
3. Reactor Building Venltlalton 1.2.3. 2 SR 3.3.6.2.1 <49 mR/Ih Exhaust Plenum (a).(b) SR.3.3.6.2,2 Radialton -High SR 3.3.6.2.3 SR 3.3.62.4 f() During operations Wilha potential for dramng the reactor vesseL

.b) During movement of recently Irradiated fuel assembles In secondary containment.

3Amendment NO.

3.3-57 Amen~dmen! 22 I

LOP Instrumentation 3.3.8.1 fN SURVEILLANCE REQUIREMENTS L Ii-~rl~ . *

1. Refer to Table 3.3.8.1-1 to determine which SRs apply for each LOP Function.
2. When a channel is placed In an Inoperable status solely for performance of required Surveillances, entry Into associated Conditions and Required Actions may be delayed for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> provided the associated Function maintains DG initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.8.1.1 Perform CHANNEL FUNCTIONAL TEST. 31 days SR 3.3.8.1.2 Perform CHANNEL CALIBRATION. 18 months SR 3.3.8.1.3 Perform LOGIC SYSTEM- FUNCTIONAL TEST. 18 months Amendment No.

3.3-65 Amendmeooper

RPS Electric Power Monitoring 3.3.8.2 CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Initiate action to fully Insert Immediately associated Completion all Insertable control rods Time of Condition A or B in core cells containing not met in MODE 5 with one or more fuel any control rod withdrawn assemblies.

from a core cell containing one or more fuel assemblies.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.8.2.1 Perform CHANNEL CALIBRATION. The Allowable 18 months Values shall be:

/

a. Overvollage < 131 V with time delay set to

_3.8 seconds.

b. Undervoltage > 109 V, with time delay set to 5 3.8 seconds.
c. Underfrequency > 57.2 Hz, with time delay set to < 3.8 seconds.

SR 3.3.8.2.2 Perform a system functional test. 18 months

.v Am*i- i net 213 3.3-88

~m nt o.

ECCS - Operating 3.5.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.1.9

1. For HPCI only, not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> afterreactor steam pressure and flow are adequate to perform the test
2. Vessel injectionlspray may be excluded.

Verify each ECCS injection/spray subsystem actuates on an actual or simulated automatic 18 months Initiation signal.

SR 3.5.1.10 -- --NOTE-----.

Valve actuation may be excluded.

Verify the ADS actuates on an actual or simulated 18 months automatic Initiation signal.

SR 3.5.1.11 - -- NOTE -----

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam pressure and flow are adequate to perform the test.

Verify each ADS valve opens when manually 18 months actuated.

Cooper Amendme Arrendfnn&~.tj.Z13 3.5-6

ECCS - Shutdown 3.5.2

" SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY 1*

SR 3.5.2.4 Verify each required ECCS pump develops Ihe specified In accordance flow rate against a system head corresponding to the with the specified reactor pressure. Inservice SYSTEM HEAD Testing NO. CORRESPONDING Program OF TO A REACTOR SYSTEM FLOW RATE PUMPjS PRESSURE OF CS >_4720 gpm 1 ~113psig LPCI ?_7700 gpm 2psig 20 SR 3.5.2.5 .NOTE-Vessel InjectIon/spray may be excluded.

Verify each required ECCS Injection/spray subsystem 18 months actuates on an actual or simulated automatic Initiation signal.

leI -it-__..

IMI 1411J1011 -- 3.5-10

  • "Amendment No.I

Primary Containment 3.6.1,1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.1.1 Perform. required visual examinations and leakage In accordance rate tesling except for primary containment air lock with Ihe Primary testing, In accordance with the Primary Containment Containment Leakage Rate Testing Program. Leakage Rate Testing Program SR 3.6.1.1.2 Verify drywell to suppression chamber bypass 18 months leakage Is equivalent to a hole < 1.0 inch In diameter. AND

--- NOTE--

Only required after Iwo consecutive tests fall and continues until two consecutive tests pass 9 months Amendment No.

A1 .1nedmonenl1z36 3.6-2

SGT System 3.6.4.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. (continued) E.2 Initiate action to Immediately suspend OPDRVs.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.3.1 Operate each SGT subsystem for> 10 continuous 31 days hours with heaters operating.

SR 3.6.4.3.2 Perform required SGT filter testing Inaccordance In accordance with the Ventilation Filler Testing Program (VFTP). with the VFTP SR 3.6.4.3.3 Verify each SGT subsystem actuates on an actual 18 months or simulated Initiation signal.

SR 3.6.4.3.4 Verify the SGT units cross tie damper is in the 18 months correct position, and each SGT room air supply check valve and SGT dilution air shutoff valve can be opened.

Ariit~iJim3rt 222 3.6-40

~K~r

CREF System 3.7.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and ---------- NOTE-associated Completion LCO 3.0.3 is not applicable.

Time of Condition A not ------ . ... ..

met during movement of lately irradiated fuel D.1 Suspend movement of lately Immediately assemblies in the irradiated fuel assemblies in the secondary containment or secondary containment.

during OPDRVs.

AND OR D.2 Initiate action to Immediately CREF System inoperable suspend OPDRVs.

due to an inoperable CRE boundary during movement of lately irradiated fuel assemblies in the secondary containment or during OPDRVs.

(ee..ii.ed)

Cooper 3.7-9 Amendment No. 2-3 AC Sources - Operating 3.8.V

  • -------- ACTIONS _

CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.3.1 Determine OPERABLE 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> DG Is not Inoperable due to common cause failure.

OR B.3.2 Perform SR 3.8.1.2 for 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OPERABLE DG.

B.4 Restore DG to 7 days OPERABLE status.

AND 14 days from discovery of failure to meet LCO C. Two offslte circuits C.1 Declare required 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> from Inoperable. feature(s) inoperable discovery of when the redundant Condition C required feature(s) are concurrent with Inoperable. Inoperability of redundant required feature(s)

AND C.2 Restore one offslte 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> circuit to OPERABLE status.

(continued)

-Amendment No.

3.8-3

  • L%l ILI I* _ Cooper

Diesel Fuel Oil, Lube Oil, and Starting Air 3,8.3 3.8 ELECTRICAL POWER SYSTEMS 3.8.3 Diesel Fuel OiI, Lube Oil, and Starling Air LCO 3.8.3 The stored diesel fuel oil, lube oil, and starting air subsystem shall be within limits for each required diesel generator (DG).

APPLICABILITY: When associated DG Is required to be OPERABLE.

ACTIONS

. .... NOTE- -

Separate Condition entry Is allowed for each DG, except for Conditions A, C, and D.

CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel oil level , 49,500 gal A.1 Restore fuel oil level to within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> and > 42.800 gal In limits.

storage tanks.

B. One or more DGs with B.1 Restore lube oil Inventory to 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> lube oil Inventory < 504 gal within limits.

and > 432 gal.

C. Stored fuel oil total C.1 Restore stored fuel oil total 7 days particulates not within limit. particulates to within Omit.

(continued)

Amendment No.

~Amnendment 2 ~ 3.8-13

Organization 5.2 5.0 ADMINISTRATIVE CONTROLS 5.2 Organization.

5.2.1 Onsite and Offslte Orqanizations ý[extended double line]

Onsite and offeite organizations shall be established for unit operation and corporate management, respectively. The onsite and offsite organizations shall Include the positions for activities affecting safety of the nuclear power plant.

a. Lines of authority. responsibility, and communication shall be defined and established throughout highest management levels, Intermediate levels, and all operating organization positions. These relationships shall be documented and updated, as appropriate, Inorganization charts, functional descriptions of departmental responsibilities and relationships, and job descriptions for key personnel positions, or In equivalent forms of documentation. These requirements, Including the plant-specific titles ot those personnel fulfilling the responsibilities of the positions delineated In these Technical Specifications, shall be documented Inthe USAR.

, .b. The plant manager shall be responsible for overall safe operation of the plant and shall have control over those onsite activities necessary for safe operation and maintenance of the plant.

c. The corporate officer with direct responsibility for the plant shall have corporate responsibility for overall plant nuclear safety and shall take any measures needed to ensure acceptable performance of the staff in operating, maintaining, and providing technical support to the plant to ensure nuclear safety.
d. The Individuals who train the operating staff, carry out radiological protection functions, or perform quality assurance functions may report to the appropriate onsite manager, however, these Individuals shall have sufficient organizational freedom to ensure their Independence from operating pressures.

5.2.2 Unit Staff The unit staff organization shall include the following:

a. A non-licensed operator shall be assigned when the reactor contains fuel and two additional non-lIcensed operators shall be assigned when the reactor is (continued) operating in MODES 1, 2,or 3.

[added single line]

SOZUG-FZ n 0 A~f r~mat )Jr 4=

- LUUIJ*

Programs and Manuals 5.0 ADMINISTRATIVE CONTROLS 5.5 Programs and Manuals The following programs shall be established, implemented and maintained. e 5.5.1 Offsite Dose Assessment Manual (ODAM)

a. The ODAM shall contain the methodology and parameters used in the

.calculation ot offsite doses resulting from radioactive gaseous and liquid effluents, In the calculation of gaseous and liquid effluent monitoring alarm and trip setpolnts, and In the conduct of the radiological environmental "monitoring program; and

b. The ODAM shall also contain the radioactive effluent controls and radiological environmental monitoring activities, and descriptions of the information that should be Included in the Annual Radiological Environmental Operating and Radioactive Effluent Release reports required by Specification 5.6.2 and Specification 5.6.3.
c. Licensee initiated changes to the ODAM:
1. Shall be documented and records of reviews performed shall be retained. This documentation shall contain:
a. sufficient Information to support the change(s) together with the appropriate analyses or evaluations Justifying the change(s), and
b. a determination that the change(s) maintain the levels of radioactive effluent control required by 10 CFR 20.1302, 40 CFR 190, 10 CFR 50.36a, and 10 CFR 50, Appendix I. and do not adversely Impact the accuracy or reliability of effluent, dose, or setpoint calculations;
2. Shall become effective after review and acceptance by the Station Operations Review Committee (SORC) and the approval of the plant manager; and
3. Shall be submitted to the NRC in the form of a complete, legible copy of the entire ODAM as a part of or concurrent with the Radioactive Effluent Release Report for the period of the report In which any change In the ODAM was made. Each change shall be Identified by

[added single line]cntinued)

Cooper 5.0-6 Amendment No. +137 1

Programs and Manuals 5.5 5.5 Programns and Manuals 5.5.4 Radioactive Effluent Controls Program (continued) I ine]

g. Limitations on the dose rate resulfing from radioactive material released In gaseous effluents to areas beyond the she boundary shall be limited to the following:

I. For noble gases: less than or equal lo a dose rate of 500 mrem/yr to the total body and less than or equal to a dose rate of 3000 mrem/yr to the skin, and

2. For lodine-131, Iodine-133, tritium, and all radionuclides Inparticulate forrdwith half lives > 8 days: less than or equal to a dose rite of 1500 mremlyr to any organ;
h. Limitations on the annual and quarterly air doses resulting from noble gases released In gaseous effluents from the unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I;
1. Limitations on the annual and quarterly doses to a member of the public from lodine-131, iodine-1 33, tritium, and all radionudides In particulate form with half lives > 8 days in gaseous effluents released from the unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I;and
j. .Limitationson the annual dose or dose commitment to any member of the public due to releases of radioactivity and to radiation from uranlum fuel cycle sources, conforming to 40 CFR 190.

5.5.5 Component Cyclic or Transient Llmli This program provides controls to track the USAR Section 111-3.5, cyclic and transient occurrences to ensure that components are maintained within the design limits.

  • / [added single line] I
  • _ (continued)

Cooper 5.0-9 Amendment No.]ýýe

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.6 Inservice Testing Program This program provides controls for inservice testing of ASME Code Class 1, 2, and 3 pumps and valves:

a. Testing Frequencies applicable to the ASME Code for Operation and Maintenance of Nuclear Power Plants (ASME OM Code) and applicable Addenda are as follows:

ASME OM Code and applicable Addenda terminology for Required Frequencies inservice testing for performing inservice activities testing activities At least once per 7 days Weekly Monthly At least once per 31 days Quarterly or every 3 months At least once per 92 days Semiannually or every 6 months At least once per 184 days Every 9 months At least once per 276 days Yearly or annually At least once per 366 days Biennially or every 2 years At least once per 731 days

b. The provisions of SR 3.0.2 are applicable to the above required Frequencies and

-= deleted paragraphI to other normal and accelerated Frequencies specified as 2 years or less in the Inservice Testing Program for performing inservice testing activities;

.. .... -,,,,,e Ece an:......

Gep n valve......

MS RV 7GARV, as Feqkgueir by AIb1L Umi 69do MandatOFY ;AppcnASI 1,poror-ag~p 113-'Y, may be dolayed until start of Cycle 24 refueling ,outage,bu no later than juno 8, 2008 (90 days from exprataion of th@ 5 year IntepA1 on March 10,

c. The provisions of SR 3.0.3 are applicable to inservice testing activities; and
d. Nothing in the ASME OM Code shall be construed to supersede the requirements of any TS.

(continued)

Cooper 5.0-10 Amendment -

Programs and Manuals 5.5

/

5.5 Programs and Manuals K>

5.5.7 Ventilation Filter Testing Program (VFTP1 (continued)

c. Demonstrate for each of the ESF systems that a laboratory test of a sample of the charcoal adsorber, when obtained as described in Regulatory Guide 1.52.

Revision 2. Section C.6.b shows the methyl Iodide penetration less than or equal to the value specified below when tested in accordance with ASTM D3803-1989 at a lemperature of 30'C(86'F) and the relative humidity specified below.

q I 3 pce here ESF Ventilation System I Penetration: Relative Humidity:

2.5 SGT System 70 2.5 Control Room 95 Emergency Filter System

d. Demonstrate for each of the ESF systems that the pressure drop across the combined HEPA filters, the prefilters. and the charcoal adsorbers is less than the value specified below when tested at the system flowrate specified as follows:

ESF Ventilation System Della P (inches Wq) Flowrale (cfm)

SGT System 160201o1958 Control Room Emergency 810 to 990 Filter System (continued)

Cooper 5.0-12 Amendment No. TM

NLS2011026 Page 1 of 22 ATTACHMENT 3 LICENSE AMENDMENT REQUEST FOR ADMINISTRATIVE REVISIONS TO TECHNICAL SPECIFICATIONS AND TO REMOVE AN EXPIRED ONE-TIME EXCEPTION TO THE FIVE-YEAR TEST FREQUENCY FOR A SINGLE SAFETY VALVE COOPER NUCLEAR STATION DOCKET NO. 50-298, DPR-46 Revised Technical Specification Pages - Final Type Format 3.1-9 3.1-12 3.1-13 3.3-4 3.3-36 3.3-51 3.3-57 3.3-65 3.3-68 3.5-6 3.5-10 3.6-2 3.6-40 3.7-9 3.8-3 3.8-13 5.0-2 5.0-6 5.0-9 5.0-10 5.0-12

Control Rod OPERABILITY 3.1.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. -------- NOTE 1--------D Restore compliance with 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Not applicable when BPWS.

THERMAL POWER

> 9.85% RTP. OR D.2 Restore control rod to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Two or more inoperable OPERABLE status.

control rods not in compliance with banked position withdrawal sequence (BPWS) and not separated by two or more OPERABLE control rods.

E. Required Action and E.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A, C, or D not met.

OR Nine or more control rods inoperable.

Cooper 3.1-9 Amendment No.

Control Rod Scram Times 3.1.4 3.1 REACTIVITY CONTROL SYSTEMS 3.1.4 Control Rod Scram Times LCO 3.1.4 a. No more than 10 OPERABLE control rods shall be "slow," in accordance with Table 3.1.4-1; and

b. No more than 2 OPERABLE control rods that are "slow" shall occupy adjacent locations.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the A.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> LCO not met.

SURVEILLANCE REQUIREMENTS

NO r------------------------------------------------------------

During single control rod scram time Surveillances, the control rod drive (CRD) pumps shall be isolated from the associated scram accumulator.

SURVEILLANCE FREQUENCY SR 3.1.4.1 Verify each control rod scram time is within the limits Prior to exceeding of Table 3.1.4-1 with reactor steam dome pressure 40% RTP after

> 800 psig. each reactor shutdown

> 120 days (continued)

Cooper 3.1-12 Amendment No.

Control Rod Scram Times 3.1.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3,1.4.2 Verify, for a representative sample, each tested 200 days control rod scram time is within the limits of cumulative Table 3.1.4-1 with reactor steam dome pressure operation in

> 800 psig. MODE 1 SR 3,1.4.3 Verify each affected control rod scram time is within Prior to declaring the limits of Table 3.1.4-1 with any reactor steam control rod dome pressure. OPERABLE after work on control rod or CRD System that could affect scram time SR 3.1.4.4 Verify each affected control rod scram time is within Prior to exceeding the limits of Table 3.1.4-1 with reactor steam dome 40% RTP after pressure > 800 psig. fuel movement within the affected core cell AND Prior to exceeding 40% RTP after work on control rod or CRD System that could affect scram time Cooper 3.1-13 Amendment No.

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.5 Verify the source range monitor (SRM) and Prior to intermediate range monitor (IRM) channels withdrawing SRMs overlap. from the fully inserted position SR 3.3.1.1.6 --------------------- NOTE---------------

Only required to be met during entry into MODE 2 from MODE 1.

Verify the IRM and APRM channels overlap. 7 days SR 3.3.1.1.7 Adjust the channel to conform to a calibrated flow 31 days signal.

SR 3.3.1.1.8 Calibrate the local power range monitors. 1000 MWDIT average core exposure SR 3.3.1.1.9 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.1.1.10. ------------------- NOTES---------------

1. Neutron detectors and recirculation loop flow transmitters are excluded.
2. For Function 2.a, not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after entering MODE 2.

Perform CHANNEL CALIBRATION. 184 days (continued)

Cooper 3.3-4 Amendment No.

ECCS Instrumentation 3.3.5.1 SURVEILLANCE REQUIREMENTS

NOTES ------------------------------

1. Refer to Table 3.3.5.1-1 to determine which SRs apply for each ECCS Function.
2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed as follows: (a) for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for Functions 3.c and 3.f; and (b) for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for Functions other than 3.c and 3.f provided the associated Function or the redundant Function maintains ECCS initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.5.1.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SR 3.3.5.1.2 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.5.1.3 Perform CHANNEL CALIBRATION. 92 days SR 3.3.5.1.4 Perform CHANNEL CALIBRATION. 18 months SR 3.3.5.1.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. 18 months Cooper 3.3-36 Amendment No.

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 1 of 3)

Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS. FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE

1. Main Steam Line Isolation
a. Reactor Vessel Water 1,2,3 2 D SR 3.3.6.1.1 > -113 inches Level - Low Low Low SR 3.3.6.1.2 (Level 1) SR 3.3.6.1.4 SR 3.3.6.1.6
b. Main Steam Line 2 E SR 3.3.6.1.2 > 835 psig Pressure - Low SR 3.3.6.1.3 SR 3.3.6.1.6
c. Main Steam Line 1,2,3 2 per D SR 3.3.6.1.2 < 142.7%

Flow - High MSL SR 3.3.6.1.4 rated steam SR 3.3.6.1.6 flow 1,

d. Condenser 2 D SR 3.3.6.1.2 > 8 inches Vacuum - Low SR 3.3.6.1.3 Hg vacuum 2(a), 3 (a) SR 3.3.6.1.6
e. Main Steam Tunnel 1,2,3 2 per D SR 3.3.6.1.2 < 195°F Temperature - High location SR 3.3.6.1.4 SR 3.3.6.1.6
2. Primary Containment Isolation
a. Reactor Vessel Water Level - Low (Level 3) 1,2,3 2 G SR 3.3.6.1.1 > 3 inches SR 3.3.6.1.2 SR 3.3.6.1.4 SR 3.3.6.1.6
b. Drywell Pressure - High 1,2,3 2 G SR 3.3.6.1.2
c. Reactor Building Ventilation 1,2,3 2 F SR 3.3.6.1.1 < 49 mR/hr Exhaust Plenum SR 3.3.6.1.2 Radiation- High SR 3.3.6.1.4 SR 3.3.6.1.6
d. Main Steam Line 1,2,3 2 F SR 3.3.6.1.1 < 3 times Radiation - High SR 3.3.6.1.2 full power SR 3.3.6.1.4 background SR 3.3.6.1.5 SR 3.3.6.1.6
e. Reactor Vessel Water Level 1,2,3 2 F SR 3.3.6.1.1 > -113 inches

-Low Low Low (Level 1) SR 3.3.6.1.2 SR 3.3.6.1.4 SR 3.3.6.1.6 (continued)

(a) With any turbine stop valve not closed.

Cooper 3.3-51 Amendment No.

Secondary Containment Isolation Instrumentation 3.3.6.2 Table 3.3.6.2-1 (page 1 of 1)

Secondary Containment Isolation Instrumentation APPLICABLE MODES OR REQUIRED OTHER CHANNELS SPECIFIED PER SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS TRIP SYSTEM REQUIREMENTS VALUE

1. Reactor Vessel Water 1,2,3, 2 SR 3.3.6.2.1 > - 42 inches Level - Low Low (Level 2) (a) SR 3.3.6.2.2 SR 3.3.6.2.3 SR 3.3.6.2.4
2. Drywell Pressure - High 1,2,3 2 SR 3.3.6.2.2 < 1.84 psig SR 3.3.6.2.3 SR 3.3.6.2.4
3. Reactor Building Ventilation 1,2,3, 2 SR 3.3.6.2.1 < 49 mR/hr Exhaust Plenum (a),(b) SR 3.3.6.2.2 Radiation - High SR 3.3.6.2.3 SR 3.3.6.2.4 (a) During operations with a potential for draining the reactor vessel.

(b) During movement of recently irradiated fuel assemblies in secondary containment.

Cooper 3.3-57 Amendment No.

LOP Instrumentation 3.3.8.1 SURVEILLANCE REQUIREMENTS

NOTES ------------------------------

1. Refer to Table 3.3.8.1-1 to determine which SRs apply for each LOP Function.
2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> provided the associated Function maintains DG initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.8.1.1 Perform CHANNEL FUNCTIONAL TEST. 31 days SR 3.3.8.1.2 Perform CHANNEL CALIBRATION. 18 months SR 3.3.8.1.3 Perform LOGIC SYSTEM FUNCTIONAL TEST. 18 months Cooper 3.3-65 Amendment No.

RPS Electric Power Monitoring 3.3.8.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Initiate action to fully insert Immediately associated Completion all insertable control rods Time of Condition A in core cells containing or B not met in MODE 5 one or more fuel with any control rod assemblies.

withdrawn from a core cell containing one or more fuel assemblies.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.8.2.1 Perform CHANNEL CALIBRATION. The Allowable 18 months Values shall be:

a. Overvoltage < 131 V with time delay set to

< 3.8 seconds.

b. Undervoltage > 109 V, with time delay set to

< 3.8 seconds.

c. Underfrequency > 57.2 Hz, with time delay set to < 3.8 seconds.

SR 3.3.8.2.2 Perform a system functional test. 18 months Cooper 3.3-68 Amendment No.

ECCS - Operating 3.5.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.1.9 ------------------- NOTES ----------------

1. For HPCI only, not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam pressure and flow are adequate to perform the test.
2. Vessel injection/spray may be excluded.

Verify each ECCS injection/spray subsystem 18 months actuates on an actual or simulated automatic initiation signal.

SR 3.5.1.10 --------------------- NOTE----------------

Valve actuation may be excluded.

Verify the ADS actuates on an actual or simulated 18 months automatic initiation signal.

SR 3.5.1.11 --------------------- NOTE----------------

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam pressure and flow are adequate to perform the test.

Verify each ADS valve opens when manually 18 months actuated.

Cooper 3.5-6 Amendment No.

ECCS - Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.4 Verify each required ECCS pump develops the In accordance specified flow rate against a system head with the corresponding to the specified reactor pressure. Inservice SYSTEM HEAD Testing NO. CORRESPONDING Program OF TO A REACTOR SYSTEM FLOW RATE PUMPS PRESSURE OF CS > 4720 gpm 1

  • 113 psig LPCI > 7700 gpm 1
  • 20 psig SR 3.5.2.5 -- ------------------ NOTE -----------------

Vessel injection/spray may be excluded.

Verify each required ECCS injection/spray 18 months subsystem actuates on an actual or simulated automatic initiation signal.

Cooper 3.5-10 Amendment No.

Primary Containment 3.6.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.1.1 Perform required visual examinations and leakage In accordance rate testing except for primary containment air lock with the Primary testing, in accordance with the Primary Containment Containment Leakage Rate Testing Program. Leakage Rate Testing Program SR 3.6.1.1.2 Verify drywell to suppression chamber bypass 18 months leakage is equivalent to a hole < 1.0 inch in diameter. AND

NOTE --------

Only required after two consecutive tests fail and continues until two consecutive tests pass 9 months Cooper 3.6-2 Amendment No.

SGT System 3.6.4.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. (continued) E.2 Initiate action to Immediately suspend OPDRVs.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.3.1 Operate each SGT subsystem for > 10 continuous 31 days hours with heaters operating.

SR 3.6.4.3.2 Perform required SGT filter testing in accordance In accordance with the Ventilation Filter Testing Program (VFTP). with the VFTP SR 3.6.4.3.3 Verify each SGT subsystem actuates on an actual 18 months or simulated initiation signal.

SR 3.6.4.3.4 Verify the SGT units cross tie damper is in the 18 months correct position, and each SGT room air supply check valve and SGT dilution air shutoff valve can be opened.

Cooper 3.6-40 Amendment No.

CREF System 3.7.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and --------------- NOTE ----------

associated Completion LCO 3.0.3 is not applicable.

Time of Condition A not met during movement of lately irradiated fuel D.1 Suspend movement of lately Immediately assemblies in the irradiated fuel assemblies in secondary containment the secondary containment.

or during OPDRVs.

AND OR D.2 Initiate action to Immediately CREF System suspend OPDRVs.

inoperable due to an inoperable CRE boundary during movement of lately irradiated fuel assemblies in the secondary containment or during OPDRVs.

Cooper 3.7-9 Amendment No.

AC Sources - Operating 3.8.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.3.1 Determine OPERABLE 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> DG is not inoperable due to common cause failure.

OR B.3.2 Perform SR 3.8.1.2 for 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OPERABLE DG.

AND B.4 Restore DG to 7 days OPERABLE status.

AND 14 days from discovery of failure to meet LCO C. Two offsite circuits C.1 Declare required 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> from inoperable, feature(s) inoperable discovery of when the redundant Condition C required feature(s) are concurrent with inoperable. inoperability of redundant required feature(s)

AND C.2 Restore one offsite circuit 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> to OPERABLE status.

(continued)

Cooper 3.8-3 Amendment No.

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 3.8 ELECTRICAL POWER SYSTEMS 3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air LCO 3.8.3 The stored diesel fuel oil, lube oil, and starting air subsystem shall be within limits for each required diesel generator (DG).

APPLICABILITY: When associated DG is required to be OPERABLE.

ACTIONS

IJtj r---------------------------------------------------------

Separate Condition entry is allowed for each DG, except for Conditions A, C, and D.

CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel oil level A.1 Restore fuel oil level to within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />

  • 49,500 gal and limits.

> 42,800 gal in storage tanks.

B. One or more DGs with B.1 Restore lube oil inventory to 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> lube oil inventory within limits.

  • 504 gal and

> 432 gal.

C. Stored fuel oil total C.1 Restore stored fuel oil total 7 days particulates not within particulates to within limit.

limit.

(continued)

Cooper 3.8-13 Amendment No.

Organization 5.2 5.0 ADMINISTRATIVE CONTROLS 5.2 Organization 5.2.1 Onsite and Offsite Orqanizations Onsite and offsite organizations shall be established for unit operation and corporate management, respectively. The onsite and offsite organizations shall include the positions for activities affecting safety of the nuclear power plant.

a. Lines of authority, responsibility, and communication shall be defined and established throughout highest management levels, intermediate levels, and all operating organization positions. These relationships shall be documented and updated, as appropriate, in organization charts, functional descriptions of departmental responsibilities and relationships, and job descriptions for key personnel positions, or in equivalent forms of documentation. These requirements, including the plant-specific titles of those personnel fulfilling the responsibilities of the positions delineated in these Technical Specifications, shall be documented in the USAR.
b. The plant manager shall be responsible for overall safe operation of the plant and shall have control over those onsite activities necessary for safe operation and maintenance of the plant.
c. The corporate officer with direct responsibility for the plant shall have corporate responsibility for overall plant nuclear safety and shall take any measures needed to ensure acceptable performance of the staff in operating, maintaining, and providing technical support to the plant to ensure nuclear safety.
d. The individuals who train the operating staff, carry out radiological protection functions, or perform quality assurance functions may report to the appropriate onsite manager; however, these individuals shall have sufficient organizational freedom to ensure their independence from operating pressures.

5.2.2 Unit Staff The unit staff organization shall include the following:

a. A non-licensed operator shall be assigned when the reactor contains fuel and two additional non-licensed operators shall be assigned when the reactor is operating in MODES 1, 2, or 3.

(continued)

Cooper 5.0-2 Amendment No.

Programs and Manuals 5.5 5.0 ADMINISTRATIVE CONTROLS 5.5 Programs and Manuals The following programs shall be established, implemented and maintained.

5.5.1 Offsite Dose Assessment Manual (ODAM)

a. The ODAM shall contain the methodology and parameters used in the calculation of offsite doses resulting from radioactive gaseous and liquid effluents, in the calculation of gaseous and liquid effluent monitoring alarm and trip setpoints, and in the conduct of the radiological environmental monitoring program; and
b. The ODAM shall also contain the radioactive effluent controls and radiological environmental monitoring activities, and descriptions of the information that should be included in the Annual Radiological Environmental Operating and Radioactive Effluent Release reports required by Specification 5.6.2 and Specification 5.6.3.
c. Licensee initiated changes to the ODAM:
1. Shall be documented and records of reviews performed shall be retained. This documentation shall contain:
a. sufficient information to support the change(s) together with the appropriate analyses or evaluations justifying the change(s), and
b. a determination that the change(s) maintain the levels of radioactive effluent control required by 10 CFR 20.1302, 40 CFR 190, 10 CFR 50.36a, and 10 CFR 50, Appendix I, and do not adversely impact the accuracy or reliability of effluent, dose, or setpoint calculations;
2. Shall become effective after review and acceptance by the Station Operations Review Committee (SORC) and the approval of the plant manager; and
3. Shall be submitted to the NRC in the form of a complete, legible copy of the entire ODAM as a part of or concurrent with the Radioactive Effluent Release Report for the period of the report in which any change in the ODAM was made. Each change shall be identified by (continued)

Cooper 5.0-6 Amendment No.

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.4 Radioactive Effluent Controls Program (continued)

g. Limitations on the dose rate resulting from radioactive material released in gaseous effluents to areas beyond the site boundary shall be limited to the following:
1. For noble gases: less than or equal to a dose rate of 500 mrem/yr to the total body and less than or equal to a dose rate of 3000 mrem/yr to the skin, and
2. For iodine-131, iodine-133, tritium, and all radionuclides in particulate form with half lives > 8 days: less than or equal to a dose rate of 1500 mrem/yr to any organ;
h. Limitations on the annual and quarterly air doses resulting from noble gases released in gaseous effluents from the unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I; Limitations on the annual and quarterly doses to a member of the public from iodine-1 31, iodine-1 33, tritium, and all radionuclides in particulate form with half lives > 8 days in gaseous effluents released from the unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I; and
j. Limitations on the annual dose or dose commitment to any member of the public due to releases of radioactivity and to radiation from uranium fuel cycle sources, conforming to 40 CFR 190.

5.5.5 Component Cyclic or Transient Limit This program provides controls to track the USAR Section 111-3.5, cyclic and transient occurrences to ensure that components are maintained within the design limits.

(continued)

Cooper 5.0-9 Amendment No.

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.6 Inservice Testing Program This program provides controls for inservice testing of ASME Code Class 1, 2, and 3 pumps and valves:

a. Testing Frequencies applicable to the ASME Code for Operation and Maintenance of Nuclear Power Plants (ASME OM Code) and applicable Addenda are as follows:

ASME OM Code and applicable Addenda terminology for Required Frequencies inservice testing for performing inservice activities testing activities Weekly At least once per 7 days Monthly At least once per 31 days Quarterly or every 3 months At least once per 92 days Semiannually or every 6 months At least once per 184 days Every 9 months At least once per 276 days Yearly or annually At least once per 366 days Biennially or every 2 years At least once per 731 days

b. The provisions of SR 3.0.2 are applicable to the above required Frequencies and to other normal and accelerated Frequencies specified as 2 years or less in the Inservice Testing Program for performing inservice testing activities;
c. The provisions of SR 3.0.3 are applicable to inservice testing activities; and
d. Nothing in the ASME OM Code shall be construed to supersede the requirements of any TS.

(continued)

Cooper 5.0-10 Amendment No.

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 Ventilation Filter Testing Program (VFTP) (continued)

c. Demonstrate for each of the ESF systems that a laboratory test of a sample of the charcoal adsorber, when obtained as described in Regulatory Guide 1.52, Revision 2, Section C.6.b shows the methyl iodide penetration less than or equal to the value specified below when tested in accordance with ASTM D3803-1989 at a temperature of 300C (86 0 F) and the relative humidity specified below.

ESF Ventilation System Penetration: Relative Humidity:

SGT System 2.5 70 Control Room 2.5 95 Emergency Filter System

d. Demonstrate for each of the ESF systems that the pressure drop across the combined HEPA filters, the prefilters, and the charcoal adsorbers is less than the value specified below when tested at the system flowrate specified.as follows:

ESF Ventilation System Delta P (inches Wq) Flowrate (cfm)

SGT System <6 1602 to 1958 Control Room Emergency <6 810 to 990 Filter System (continued)

Cooper 5.0-12 Amendment No.

4 ATTACHMENT 3 LIST OF REGULATORY COMMITMENTS© ATTACHMENT 3 LIST OF REGULATORY COMMITMENTS©4 Correspondence Number: NLS2011026 The following table identifies those actions committed to by Nebraska Public Power District (NPPD) in this document. Any other actions discussed in the submittal represent intended or planned actions by NPPD. They are described for information only and are not regulatory commitments. Please notify the Licensing Manager at Cooper Nuclear Station of any questions regarding this document or any associated regulatory commitments.

COMMITMENT COMMITTED DATE COMMITMENT NUMBER OR OUTAGE None 4- 4 4- 4 1* I 1- I 4- 4 4 4 4- 4 4- 4 I

I I

PROCEDURE POERE04RESON2 0.42 REVISION 27 PAGE 18 OF 25 1 AE8F5I

Retrieved from "https://kanterella.com/w/index.php?title=NLS2011026,_License_Amendment_Request_for_Administrative_Revisions_to_Technical_Specifications_and_to_Remove_an_Expired_One-Time_Exception_to_the_Five-Year_Test_Frequency_for_a_Single_Safety_Valve&oldid=2119625"