Text

License Amendment Request for Adoption of Technical Specification Task Force (TSTF) Traveler TSTF-423, Revision 1, Using the Consolidated Line Item Improvement Process
	ML14234A457
Person / Time
Site:	Columbia
Issue date:	08/12/2014
From:	Hettel W; Energy Northwest
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	G02-14-112
	Download: ML14234A457 (121)
	v • d • e

Wmina G. HWel AL fimalkvim Prseknt~ Operad" Box 98%WA P.O.R~FAmhkl. Malgg3=4.og Drop PE23 Ph. 509-377-8311 F. 509-=774674 w=1Twgh9enmrgy-noflhwt.com AU6 12 2014 10 CFR 50.90 G02-14-112 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, D.C. 20555-0001

Subject:

COLUMBIA GENERATING STATION, DOCKET NO. 50-397 LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE (TSTF) TRAVELER TSTF-423, REVISION 1, USING THE CONSOLIDATED LINE ITEM IMPROVEMENT PROCESS

Dear Sir or Madam:

In accordance with the provisions of Title 10 of the Code of FederalRegulations (10 CFR) Section 50.90, Energy Northwest is submitting a request for an amendment to Columbia Generating Station (Columbia) Technical Specifications (TS) to incorporate the NRC-approved TSTF-423, Revision 1.

The proposed amendment would modify TS to risk-Inform requirements regarding selected Required Action end states by incorporating the boiling water reactor (BWR) owners' group (BWROG) approved Topical Report NEDC-32988-A, Revision 2,

'Technical Justification to Support Risk-Informed Modification to Selected Required Action End States for BWR Plants." Additionally, the proposed amendment would modify the TS Required Actions with a Note prohibiting the use of limiting condition for operation (LCO) 3.0.4.a when entering the preferred end state (Mode 3) on startup.

Attachment 1 provides a description and assessment of the proposed change, the requested confirmation of applicability, and plant-specific verifications.

Attachment 2 summarizes the regulatory commitments made in this submittal.

Attachment 3 provides markup pages of existing TS to show the proposed change.

Attachment 4 provides markup pages of existing TS Bases to show the proposed change.

Attachment 5 provides revised (clean) TS pages.

Energy Northwest requests approval of the proposed license amendment six months from the date of submittal, with the amendment being implemented within 60 days.

LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATMI TASK FORCE (TSTF) TRAVELER TSTF-423, REVISION 1, USING THE CONSOLIDATED LINE ITEM IMPROVEMENT PROCESS Page2of2 2 In accordance Wth 1.0 CFR 50.91 (a)(1), "Notice for public comment," the analysis about the issue of no significant hazards consideration (NSHC) using the standards in 10 CFR 50.92 is being provided to the Commission in accordance with the distribution requirements in 10 CFR 50.4.

In accordance with 10 CFR 50.91(b)(1), "State consultation," a copy of this application and the reasoned analysis about NSHC is being provided to the designated Washington State Official.

If you should have any questions regarding this submittal, please contact Ms. L. L.

Williams, Licensing Supervisor, at 509-377-8148.

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

Executed on P*xs.w'T 1\. Zsz%.

Respectfully, W. G. Hettel Vice President, Operations : Description and Assessment : Regulatory Commitments. : Proposed Technical Specification Changes : Proposed Technical Specification Bases Changes : Revised (clean) Technical Specification Pages cc: NRC Region IVAdministrator NRC NRR Project Manager NRC Sr. Resident Inspector - 988C MA Jones- BPA/1 399 (email)

WA Horin - Winston & Strawn (email)

RR Cowley - WDOH (email)

JO Luce - EFSEC (email)

ICENSE AMENDMENT REOUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE (TST1)TRAVELER TSTF-42S, REVISION 1, USING THE COWSO4DATED LINE ITEM IMPROVEMENT PROCESS - Description and Assessment Page1 of 13 1.0 DESCRIPnON The proposed amendment would modify Technical Specifications (TS) to rik-inform requirements regarding selected Required Action end states. Additionally, it would modify those TS Required Actions with a Note prohibiting the use of limiting condition for operation (LCO) 3.0.4.a when entering the preferred end state (Mode 3) on startup.

The changes are consistent with Nuclear Regulatory Commission (NRC)-approved Technical Specification Task Force (TSTF) traveler TSTF-423, Revision 1, "Technical Specifications End States, NEDC-32968-A," dated December 22, 2009 (ADAMS Accession Number ML093570241) (Reference 1). The FederaRegister notice published on February 18, 2011 (76 FR 9614) (Reference 2) announced the availability of this TS Improvement as part of"he consolidated line item Improvement process (CLIIP).

2.0 ASSESSENT 2.1 by of T"" R., omt NEDC4-S.A,, TSTF4, a"d Moe Sft Energy Northwest has reviewed boiling water reactor (BWR) owners' group (BWROG) topical report (TA) NEDC-32988-A (Reference 3), TSTF-423, Revision 1 (Reference 1),

and the NRC staff's model safety evaluation (SE) (Reference 4) as part of the CLIIP.

Energy Northwest has concluded that the Information in TA NEDC-32968-A, TSTF-423, and the NRC staffs model SE are generally applicable to Columbia Generating Station (Columbia) and justify this license amendment request (LAR) for the incorporation of the changes to Columbia's TS. Table I identifies differences between TSTF-423, the model SE, and the Columbia specific design and licensing basis.

2.2 Optional Changes and Varliosw1 Energy Northwest is not proposing any substantive variations or deviations from TR NEDC-32988.A, the TS changes described in the TSTF-423 Revision 1, or the NRC staff's model SE referenced in the FederalRegisteron February 18, 2011 (76 FR 9614) as part of the CLIlP Notice of Availability. The Model SE refers to Section 1I of NUMARC 93-01, Revision 3. However, in Regulatory Guide 1.160, Revision 3, the NRC has endorsed Revision 4A of NUMARC 93-01. As such, Energy Northwest will follow Section 11 of NUMARC 93-01, Revision 4A.

The proposed TS changes are consistent with TSTF-423, Revision 1. The TSTF traveler is based on NUREG-1433 Revision 3.0, "Standard Technical Specifications General Electric Plants, BWR/4," and NUREG-1434 Revision 3.0, "Standard Technical Specifications General Electric Plants, BWRIB." While Columbia's TS are based primarily on NUREG-1434, a few Columbia TS are based on NUREG-1433. Therefore,

LICENSE AMENQMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE (TSTF) TRAVELER TSTF423, REVISION 1, USING THE CONSOLIDATED UNE ITEM IMPROVEMENT PROCESS - Description and Assessment Page 2 of 13 adaption of the TS markups contained in TSTF-423, Revision 1 is required. The proposed variations/deviations are described in Table 1 of this document

3.0 REGULATORY ANALYSIS

&. No Signifint Hftads Conskkdeton (NSHC) Dtmmnation Energy Northwest has evaluated the proposed changes to the TS using the criteria in 10 CFR 50.92 and has determined that the proposed changes do not involve a significant hazards consideration.

Description of Amendment Request A change is proposed to Columbia's TS, consistent with TSTF-423, Revision 1, to allow, for some systems, entry into hot shutdown rather than cold shutdown to repair equipment, if risk is assessed and managed consistent with the program in place for complying with the requirements of 10 CFR 50.65(a)(4).

Changes proposed in TSTF-423 will be made to Columbia's TS for selected Required Action end states.

Basis for no significant hazards consideration determination: As required by 10 CFR 50.91(a), Energy Northwest's analysis of the issue of no significant hazards consideration is presented below:.

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

Response: No The proposed change allows a change to certain required end states when the TS Completion Times for remaining in power operation will be exceeded. Most of the requested technical specification (TS) changes are to permit an end state of hot shutdown (Mode 3) rather than an end state of cold shutdown (Mode 4) contained in the current TS. The request was limited to: (1) those end states where entry into the shutdown mode is for a short interval, (2) entry is initiated by inoperability of a single train of equipment or a restriction on a plant operational parameter, unless otherwise stated in the applicable TS, and (3) the primary purpose is to correct the initiating condition and return to power operation as soon as is practical. Risk insights from both the qualitative and quantitative risk assessments were used in specific TS assessments. Such assessments are documented in Section 6 of topical report NEDC-32988-A, Revision 2, "Technical Justification to Support Risk Informed Modification to Selected Required Action End States for BWR Plants." They provide an integrated discussion of deterministic and probabilistic Issues, focusing on specific TSs, which are used to support the proposed TS end state and associated restrictions. The risk insights support the conclusions of the specific TS assessments. Therefore, the

UCENSE AMeNDMWNT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION tAK FORCE (MSM) TRAVELER TSTF-423, REVIION 1, USING THE CONSOIDATED UNE ITEM IMPROVEMENT PROCESS Attachment I - Description and Assessment Page 3 of 13 probability of an accident previously evaluated is not significantly Increased, if at all. The consequences of an accident after adopting TSTF-423 are no different than the consequences of an accident prior to adopting TSTF-423. Therefore, the consequences of an accident previously evaluated are not significantly affected by this change. The addition of a requirement to assess and manage the risk introduced by this change will further minimize possible concerns.

-Therefore, the proposed change does not involve a significant Increase in the probability or consequences of an accident previously evaluated.

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

Response: No The proposed change does not Involve a physical alteration of the plant (no new or different type of equipment will be installed). If risk Is assessed and managed, allowing a change to certain required end states when the TS Completion Times for remaining in power operation are exceeded (i.e., entry Into hot shutdown rather than cold shutdown to repair equipment) will not introduce new failure modes or effects and will not, in the absence of other unrelated failures, lead to an accident whose consequences exceed the consequences of accidents previously evaluated. The addition of a requirement to assess and manage the risk introduced by this change and the commitment by Energy Northwest to adhere to the guidance InTSTF-IG-05-02, "Implementation Guidance for TSTF-423, Revision 1, 'Technical Specifications End States, NEDC-32988-A," will

-further minimize possible concerns.

Thus, based on the above, this change does not create the possibility of a new or different-kind of accident from an accident previously evaluated.

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

Response: No The proposed change allows, for some systems, entry into hot shutdown rather than cold shutdown to repair equipment, if risk is assessed and managed. The BWROG's risk assessment approach is comprehensive and follows NRC staff guidance as documented in Regulatory Guides (AG) 1.174 and 1.177. In addition, the analyses show that the criteria of the three-tiered approach for allowing TS changes are met. The risk impact of the proposed TS changes was assessed following the three-tiered approach recommended in RG 1.177. A risk assessment was performed to justify the proposed TS changes. The net change to the margin of safety Is insignificant.

LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE (TSTF) TRAVELER TSTF-423, REVISION I, USING THE CONSOLIDATED LINE ITEM IMPROVEMENT PROCESS Attachment I - Description and Assessment Page 4 of 13 Therefore, the proposed change does not involve a significant reduction in a margin of safety.

Based upon the reasoning presented above, Energy Northwest concludes that the requested change involves no significant hazards consideration, as set forth in 10 CFR 50.92(c), 1Issuance of Amendment."

3.2 Verlfkcatlon, Commctents and Additional Inf#matton Needed Energy Northwest commits to the regulatory commitments in Attachment 2. In addition, Energy Northwest has proposed TS Bases consistent with TSTF-423, Revision 1, which provide guidance and details on how to implement the new requirements.

Implementation of TSTF-423 requires that risk be managed and assessed, and Energy Northwest's configuration risk management program Is adequate to satisfy this requirement. The risk assessment need not be quantified, but may be a qualitative assessment of the vulnerability of systems and components when one or more systems are not able to perform their associated function. Finally, Energy Northwest has a Bases Control Program consistent with Section 5.5 of the Standard Technical Specifications (STS).

4.0 ENVIRONMENTAL EVALUATION The proposed change would change a requirement with respect to installation or use of a facility component located within the restricted area, as defined in 10 CFR Part 20, and would change an inspection or surveillance requirement. However, the proposed change does not involve (i) a significant hazards consideration, (ii)a significant change in the types or significant increase in the amounts of any effluents that may be released offsite, or (iii) a significant Increase in individual or cumulative occupational radiation exposure. Accordingly, the proposed change meets the eligibility criterion for categorical exclusion set forth In 10 CFR 51.22(c)(9). Therefore, pursuant to 10 CFR 51.22(b), no environmental Impact statement or environmental assessment need be prepared in connection with the proposed change.

S.0REFERENCES

1. Technical Specification Task Force (rSTF) traveler TSTF-423, Revision 1, "Technical Specifications End States, NEDC-32988-A," dated December 22, 2009. (ADAMS Accession Number ML093570241)

2. Federal Register, Vol. 76, No. 34, p.9614, "Notice of Availability of the Proposed Models for Plant-Specific Adoption of Technical Specifications Task Force (TSTF) Traveler TSTF-423, Revision 1, "Technical Specifications End States,

LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE (TSTF) TRAVELER TSTF42, REVISION 1, USING THE CONSOLIDATED UNE ITEM IMPROVEMENT PROCESS - Description and Assessment Page 5 of 13 NEDC-32988-A," for Soling Water Reactor Plants Using the Consolidated Line Item Improvement Process," February 18, 2011. (ADAMS Accession Number ML102730585)

3. NEDC-32988-A, Revision 2, "Technical Justification to Support Risk-Informed Modification to Selected Required Action End States for BWR Plants," December 2002. (ADAMS Accession Number ML030170090).

4 NRC Model Safety Evaluation of TSTF-423, Revision 1, dated February 3,2011 (ADAMS Accession No. ML102730688).

LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIRCATION TASK FORCE (1STF) TRAVELER TSTF-423, REVISION 1, USING THE CONSOLIDATED LINE ITEM IMPROVEMENT PROCESS Attachment I - Description and Assessment Page 6of 13 TABLE I Ts S (Md ) TS - Do.. fom TSTW-423 Oetons from MoM SE - * ,

NUREG-1434 No deviations Model SE section 3.2.5 - No deviations 3.3.8.2.C 3.3.8.2.C .,

Energy Northwest proposes to modiy the 3.2.1:

existing Condition A from "oneor more required

The model SE lists the number of SRVs to be SRVs [safety relief valves) inoperable" to -one operable for both the safety function and relief required SRV inoperable." The Required function. In NUREG-1434, the specific number is NUREG-1434 Action is to be in Mode 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , which bracketed. The Columbia TS require the safety 3.4.4.A 3.4.4.B is consistent with the TSTF-423 change to STS function of four SRVs be operable.

3.4.4.8 3.4.4.C Condition B. New Condition B for 'two or more

The Conditions and proposed modification for end required SRVs inoperable! is consistent-with state Required Actions are as described in this the TSTF-423 changeto Condition C and table. The model SE is based on the STS.

requires being in Mode 3.within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and Mode 4 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

3.2.2 - The model SE lists the number of SRVs NUREG-1434 required to be operable for the ADS [automatic 3.5.1.D 3.5.1.D No deviations depreswsuzation system] function. In NUREG-3.5.1.G 3.5.1.G 1434, the specific number is bracketed. The Columbia TS require the ADS function of six SRVs

.... _ be operable.

3.2.21 - The Columbia TS refer to this system as "RHR Drywall Spray System' rather than "RHR Containment Spray Systm. The Columbia-NUREG-1434 No deviations specific design described in the TS Bases diffem 3.6.1.5.C 3.6.1.7.C slightly from that described in the STS Bases (NUREG-1434 Volume 2) and the model SE.

UCENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNCAL SPECIFICATION TASK FORCE MM TRAVELER TSTF-423, REVISION 1, USING THE CONSOUOATED UNE ITEM IMPROVEMENT PROCESS Attachment I - Description and Assessment Page 7 of 13 TS TB4 "S".. Ow~latlons *rM154ST-.Dvdos*mod . . S NUREG-1433 3.6.1.6.D 3.6.1.7.D 3.2.10 - This Specification from the BWRI4 STS 3.6.1.6.E 3.6.1.7.E applies to Columbia.

3.6.1.6.F 3.6.1.7.F

TSTF-423 added a new Condition B and 3.2.11:

rnumbered the subsequent two Conditions

This So from the BWRf4 STS applies to (now Condition C and 0). Condition D is Codumbia.

wp~a*hen the Reuie Aei and assda~lCowp~wTkm h1eoIwt C is

The model SE lists the umdber of suppression ch-antw-*- vacuum breakers required to not met and requires being in Mode 3 within be operbe. In NUREG-1433, the specific 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and Mode 4 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . Energy number is brdmted. The C TS requir Northwe proposes to add the new Condition seven chamber-todrweU vacuum B consistent with TSTF-423. However, the breakers be operable for opening, Columbia TS contain three subsequent ,,The Conditions and proposed 1olcto for NUREG-1 433 C~ondtins and. Energy Nmrthwest proposes end state Required Actions are as described in 3.6.1.713 3.6.1 .82 to reunuber these to be Conditions C, D, and 3.6.61.7.C 3.8.1 .8.C this table. The model SE is based on the SE for 3.6.1.7.D 3.6.1 .8.D E. NEDC-3928S-A evson 2.

3.6.1 .7.E

TSTF423 moiied Condition D to apply only to Condition C. The Required Action is to be inMode 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and Mode 4 w"hin 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . Energy Northwest proposes to revise the analogous Columbia TS Condition E to apply to Conditions C and D. The Required Action is to be in Mode 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and Mode 4 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months , which is consistent with the existing Required Action and associated Completion Time and is not chanqed by TSTF-423.

UCENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE (TSTF) TRAVELER TSTF-423, REVISION 1, USING THE CONSOUDATED LINE ITEM IMPROVEMENT PROCESS - Description and Assessment Page 8 of 13 Columbla StandardeTS ations om T-.4 gvi -framft"SE TS -(S")3OV~U fo odlS In order to accommodate the TSTF-423 change to Condition B, Energy Northwest proposes to create NUREG-1434 new Condition C for "two RHR [residual heat 3.8.2.3.B 3.6.2.3.B remova pool cooling subsystems 3.6.2.3.C 3.6.2.3.C i rae. The Required "On$ are to be in 3.2.23 - No deviations 3.6.2-3.C 3.6.2.3.D Mode 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and Mode 4 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months , which is consistent with the existing Required Action and associated Completion Times and is not changed by TSTF-423.

NUREG-1434 No deviations 3.2.14 - No deviations 3.6.4.1.B 3.6.4.1.8 ,_._ _

NUREG-1434 3.6.4.3.B 3.6.4.3.8 No deviations 3.2.15 - No deviations 3.6.4.3.D 3.6.4.3.D1

TSTF-423 relocated the CondiWon for gone SSW 3.2.25:

[standby service water] subsystem inoperable'

The model SE discusses cooling towers and from Condition C to Condition B. This Condition UHS temperature. In NUREG-1434, these was already numbered as Condition B in the requirements ae bracketed. The Columbia TS NUREG-1434 Columbia TS. Thus, this change is not do not contain these requirements. The 3.7.1.8 proposed. Columbia TS contain requirements for 3.7.1.C 3.7.1.C 9 Energy Northwest proposes to add Condition C sediment depth in the spray ponds.

3.7.1.D 3.7.1.D for "Required Action and associated Completion

The Conditions and proposed modification for 3.7.1.E Time of Condition B not met,' which is consistent end state Required Actions are as described in with TSTF-423. However, TSTF-423 also this table. The model SE is based on the STS.

applies this new Condition to Condition A. In NUREG-1434, Condition A is for "one or more cooling towers with one cooling tower fan inoperable." This Condition is not applicable to Columbia and is not included in the Columbia

LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE (PSlF)TRAVELER TSTF-423, REVISION 1, USING THE CONSOLIDATED LINE ITEM IMPROVEMENT PROCESS Attachment I - Description and Assessment Page 9 of 13 Columbia TS.

1st~murd J!L 1 Des" sl~osfo bo

$F3 rMW 0sv! ofrom Mdel S TS. Thus, Energy Northwest prposes to only apply new Condition C to existing Condition B.

" TSTF-423 renumbered Condition B to Condition

0. In NUREG-1434 this Condition is related to water temperature in the ultimate heat sink (UHS). This Condition is not included in the Columbia TS. Thus, this change is not proposed.

" TSTF-423 renumbered Condition D to Condition E. This Condition is applicable to the following situatiori 1) Required Action and associated Completion Time of Condition D not met 2) Both SSW subsystems inoperable; or 3) UKS inoperable for reasons other tIha Condition A.

Energy Norutwet proposes to fenumber eisting Condition C to Condition 0 and modify it to be consistent with TSTF-428 but recognize the Co.umbia-specific Cond.os as follows: 1)

Required Acfion and associated Completio Time of Condition A not met-,2) both SW

[service water) subsystems inoperable; or 3)

UHS inoperable for reasons other than Condilton A. The Required Action is to be in Mode 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and Mode 4 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

Note that Condition A for Columbia is related to UHS water inventory. TSTF-423 provisions are not proposed to be applied to this Condition A.

LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE (TSTF) TRAVELER TSTF-423, REVISION 1, USING THE CONSOLIDATED LINE ITEM IMPROVEMENT PROCESS - Description and Assessment Page 10 of 13 CTkumbl isT Dhlato r mhm TSlTl-48 Dovle*tae fromn M dal SE 3.2.26:

The Columbia TS refer to this system as

""Coroml Room Emergency Filtration (CREF)

System" rather than "Control Room Fresh Air NUREG-1434 (CRFA) System". The Columbia-specific 3.7.3.C 3.7.3.C No deviations design descrbed in the TS Bases differs 3.7.3.E 3.7.3.E Ndeito slighy from #W described Inthe STS Bases 3.7.3.E 3.7.3.E (NUREG-1434 Volume 2) and the model SE.

Due to the adoption of TSTF-448 in the Coumbia TS, the Required Actions and associated Completion Times of Condition B differ from that described in the model SE.

The TS madkups in TSTF-423 preceded the 3.2.27:

issuance of TSTF-477, "Adding an Action

The Columbia-specific design described in the Statement for Two Inoperable Control Room Air TS Bases differs slightly from that described in Conditioning Subsystems." As such, TSTF-423 the STS Bases (NUREG-1434 Volume 2) and removes the requirement to go to Mode 4 from the model SE.

Condition B and Condition D. Condition B is for

Due to the adoption of TSTF-477, the the Required Action and associated Completion Conditions and proposed modification for end NUREG-1434 Time of Condition A not met in Mode 1, 2 or 3. state Required Actions are as described in this 3.7.4.C 3.7.4.8 Condition A is for one control room AC [air table and differ from the model SE.

3.7.4.D conditioning] subsystem inoperable. Condition D is for No control room AC subsystems inoperable in Mode 1, 2, or 3. Energy Northwest has adopted TSTF-477, which created a new Condition B for two control room AC subsystem inoperable and provided an allowed outage time of 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

Condition C is for the Required Action and associated Completion Time of Condition A or B

UCENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE (TSTM) TRAVELER TSTF-423, REVISION 1, USING THE CONSOUDATED LINE ITEM IMPROVEMENT PROCESS - Description and Assessment Page 11 of 13 CokSmbia Standard TS Deviations from TSF-423 Deviations from Model SE not met in Mode 1, 2, or 3. This Condition C encompasses the changes made to Conditions B and D in TSTF-423. Thus, Energy Northwest proposes to modify Condition C consistent with TSTF-423.

3.2.28 - The model SE contains the value for gross gamma activiy rate of the noble gases. In NUREG-1434 the specific number is bracketed.

The Columbia TS require the gross gamma NUREG-1434 activity rate of the noble gases be less than or 3.7.5.B 3.7.5.8 No deviations equal to 332 mCisecond. Additionally, the model SE contains the location for the measurement of the activity rate. In NUREG-1434 this information is bracketed. The Columbia TS require the activity rate be

,_,,measured at the main condenser air ejector.

3.2.6:

The Colunbia-specific design described inthe TS Bases differs slightly from that described NUREG-1434 Condition F is for one required in the STS Bases (NUREG-1434 Volume 2) automatic load sequencer inoperable. This and the model SE.

NUREG-1434 Condition is not induded In the Columbia TIS.

The model SE includes the requirement for 3.8.1.F 3.8.1.G NUREG-1434 Condition Columbia Condition F. Energy Northwestto G is analogous automatic this information Is bracketed. InThe load sequencers. NUREG-1434 Columbia proposed to modify Condition F consistent with TS do not contain this requirement TSTF-423.

The Conditions and proposed modification for end state Required Actions are as described in this table. The model SE is based on the STS.

UCENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE (TSTF) TRAVELER TSTF-423, REVISION 1, USING THE CONSOUDATED LINE ITEM IMPROVEMENT PROCESS - Description and Assessment Page 12 of 13 T.DTS(STS)SatdwdT8 Iro v, mT 1F.4k jI....ev aton from

.. SE

TSTF-423 created new Condition D for 3.2.7 - The Conditions and proposed

'Required Action and associated Completion modification for end state Required Actions are Time for Division 1 or 2 DC [direct currenti as descnrbed in this table. The model SE is electrical power subsystem for Condition A, B, or based on the STS.

C not met." Condition A for -one battery charger on one division inoperable" is analogous to Columbia's Condition A. Condition B for "one batery on one division inoperable', is analogous to Columbia's Condition D. Condition C for

'Division I or 2 DC electrical power subsystem inoperable for reasons other than Condition A or B" is analogous to Columbia's Condition G.

Thus, Columbia's existing Condition J is NUREG-1434 analogous to the TSTF-423 Condition D.

3.8.4.D Energy Northwest proposes-to modify Condition 3.8.4.J 3.8A.E J consistent with TSTF-423., -

3.8.4.F

TSTF-423 renumbered existing Condition D to Condition E. This condition is for "Division 3 DC electrical power subsystem inoperable for reasons other than Condition A or B." This change is not applicable to the Columbia TS.

TSTF-423 renumbered existing Condition E to Condition F. This Condition was modified to apply only when the Required Action and associated Completion Time for Division 3 DC electrical power subsystem for Condition A, B, or E not met." The Columbia TS already contain an existing Condition (H) that applies when the

-i A Reauired Action and associated Completion

UCENSE AMENDMEN REQUEST FOR ADOPTIO OF TECHNICAL SPECIFICATION TASK FORCE (TSTF) TRAVELER TSTF-423, REVISION 1, USING THE CONSOLlDATED LINE ITEM IMPROVEMENT PROCESS Atlachment 1- Description and Assessment Page 13 of 13 Columbia StaIdrdTS TBDovhMIon fromf TSTF-423 agates,MWWtSE tine of Dkiso 34elatd Conditions are not met. Thus, no changes are propos~dto existino Condition H. _._,_-_"

TSTF-423 modified Condition D. This Contio 3.2.9 for -Required Action and associated CTepibon *

The C,..design described in the Time of Condition A, B, or C not met" Energy TS Bases diem sligh from that described.

Northwest proposes to modify the analogous in the STS Bases (NUREG-1434 Volume 2)

Condition C for "Required Action and assocdiaed and the model SE.

Completion Time of Condition A or B not met'

The model SE includes the requirement for NUREG-1434 consistent with TSTF-423. NUREG-1434 contains vital AC buses. In NUREG-1434 this 3.8.7.C 3.8.9.D Condition B for one or more Division 1 and 2 AC requirement is bracketed. The Columbia TS

[alternating current] vital buses inoperable." The do not Contain this requirement Cokmbia TS do not contain this Condition. Thus, , The Ccdons and proposedmodification for for Columbia, the TSTF-423 provisions are only end state Acquired Actions are as described applied when Condition A or B (which is In this t . The model SE is based on the analogous to NUREG-1434 Condition C) are not STS.

met.

LIC SE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATIONS TASK FORCE (TWTF) TRAVELER TSTF-423, REVISION 1, USING THE CONSOLIDATED LINE ITEM IMPROVEMENT PROCESS Page 1of 1 LIST OF REGULATORY COMMITMENTS The following table identifies those actions committed to by Energy Northwest in this document. Any other statements in this submittal are provided for information purposes and are not considered to be regulatory commitments. Please direct questions regarding these commitments to Ms. L. L Williams, Licensing Supervisor, at 509-377-8148.

Energy Northwest will follow the guidance established in Im.. emon with Section 11 of NUMARC 93-01, "Industry Guidance for ImendWWn1 Monitoring the Effectiveness of Maintenance at Nuclear Power Plants," Nuclear Management and Resource Council (NUMARC), Revision 4A. A-&412011. -. ...... ... .......

Energy Northwest will follow the guidance established in !Implement with TSTF-IG-05-02, Revision 1, "Implementation Guidance and1eWt for TSTF-423, Revision 1, 'Technical Specifications End States, NEDC-32988-A.I"

LICENSE AMENDMENT REOUEST FOR ADOPTION OF TSTF-423, REVISION 1 PROPOSED TECHNICAL SPECIFICATIONS CHANGES (MARK-UPS)

RPS Electric Power Monitoring 3.3.8.2 3.3 INSTRUMENTATION 3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring LCO 3.3.8.2 Two RPS electric power monitoring assemblies shall be OPERABLE for each inservice RPS motor generator set or alternate power supply that supports equipment required to be OPERABLE.

APPLICABILITY: MODES 1,2, and 3, MODES 4 and 5 with both residual heat removal (RHR) shutdown cooling (SDC) suction Isolation valves open, MODE 5 with any control rod withdrawn from a core cell containing one or more fuel assemblies.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or both required A.1 Remove associated 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inservice power supplies inservice power supply(s) with one electric power from service.

monitoring assembly inoperable.

B. One or both requred B.1 Remove associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inservice power supplies inservice power supply(s) with both electric power from service.

monitoring assemblies inoperable.

C. Required Action and C.1 associated Completion Time of Condition A or B not met in MODE 1, 2, or 3.

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Columbia Generating Station 3.3.8.2-1 Amendment No. 440,46- 225 1

SRVs - < 25% RTP 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.4 Safety/Relief Valves (SRVs) - < 25% RTP LCO 3.4.4 The safety function of four SRVs shall be OPERABLE.

APPLICABILITY: MODE I with THERMAL POWER < 25% RTP, MODES 2 and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required A.1 SRV, inoperable.

Be In MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months B ** G3i I <'* hOuJ VNP Columbia Generating Station 3.4.4-1 Amendment No. 440,469 225 1

ECCS - Operat 3.5.1 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.1 ECCS - Operating LCO 3.5.1 Each ECCS Inject:on/spray subsystem and the Automatic Depessurtzaton System (ADS) functio of six safetyee valves Sh be OPERABLE.

APPLICABILITY: MODE 1, MODES 2 and 3, except ADS valves are not required to be OPERABLE with reactor stear dome pressureu 150 peig.

ACTIONS LCO 3.OA.b is not 4ppicable to HPCS.

CONDITION REQUIRED ACTION COMPLETION TIME A. One low pressure ECCS A.1 Restore low pressure 7 days injection/spray ECCS injecton/spray subsystem Inoperable. subsystem to OPERABLE statUs.

B High Presu Core 8.1 Verify by adm**Mstrtve Immedtely Spray (HPCS) System means RCIC System Is inoperable. OPERABLE when RCIC System is required to be OPERABLE.

8.2 Restore HPCS System to 14 days OPERABLE status.

Columbia Generaft Station 3.5.1-1 Amendment No. 40,48Z 225 1

ECCS - Operating 3.5.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Two ECCS injection C.1 Restore ECCS 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months subsystems inoperable. injectionspray subsystem to OPERABLE status.

QR One ECCS injection and one ECCS spray subsystem Inoperable.

D. Required Action and W.1 associated Completion Time of Condition A, B, or C not met.

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months E. One required ADS valve E.1 Restore ADS valve to 14 days inoperable. OPERABLE status.

F. One required ADS valve F.1 Restore ADS valve to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. OPERABLE status.

AND OR One low pressure ECCS F.2 Restore low pressure 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months injection/spray ECCS injection/spray subsystem inoperable, subsystem to OPERABLE status.

Columbia Generating Station 3.5.1-2 Amendment No. 440,4a0 225 1

ECCS - Operating 3.5.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME G. Required Action and (1 ) F associated Completion L 04 i Time of Condition E orFFp en rei not met.

BeIn MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Two or more required ADS valves inoperable.

H. HPCS and Low H.1 Enter LCO 3.0.3. Immediately Pressure Core Spray (LPCS) Systems Inoperable.

QO Three or more ECCS injection/spray subsystems inoperable.

OR HPCS System and one or more required ADS valves Inoperable.

OR Two or more ECCS injectiOn/spray subsystems and one or more required ADS valves inoperable.

Columbia Generating Station 3.5.1-3 Amendment No. 4.40,469 225 1

RHR Drywell Spray 3.6.1.5 3.6 CONTAINMENT SYSTEMS 3.6,1.5 Residual Heat Removal (RHR) Drywell Spray LCO 3.6.1.5 Two RHR drywell spray subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR drywell spray A.1 Restore RHR drywell spray 7 days subsystem inoperable, subsystem to OPERABLE status.

B. Two RHR drywell spray B.1 Restore one RHR drywell 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months subsystems inoperable, spray subsystem to OPERABLE status.

C. Required Action and C.1 associated Completion Time not met.

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.5.1 Verify each RHR drywell spray subsystem manual, 31 days power operated, and automatic valve In the flow path that is not locked, sealed, or otherwise secured In position, is in the correct position or can be aligned to the correct position.

Columbia Generating Station 3.6.1.5-1 Amendment No. 440,440 V5 I

Reactor Building-to-Suppression Chamber Vacuum Breakers 3.6.1.6 3.6 CONTAINMENT SYSTEMS 3.6.1.6 Reactor Building-to-Suppresslon Chamber Vacuum Breakers LOG 3.6.1.6 Each reactor buklding-to-suppression chamber vacuum breaker shall be OPERABLE.

APPLICABILITY: MODES 1,2, and 3.

ACTIONS at.-% I Separate Condition entry is allowed for each line.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more lines with A.1 Close the open vacuum 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months one reactor building-to- breaker.

suppression chamber vacuum breaker not closed.

B. One or more lines with B.1 Close one open vacuum 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months two reactor building-to- breaker.

suppression chamber vacuum breakers not closed.

C. One line with one or C.1 Restore the vacuum 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months more reactor building-to- breaker(s) to OPERABLE suppression chamber status.

vacuum breakers inoperable for opening.

DHi*Ž A U iNOT Bern MDE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

Columbia Generating Station 3.6.1.6-1 Amendment No. 449,469 225 1

Reactor Building-to-Suppression Chamber Vacuum Breakers 3.6.1.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME t .Two or more lines with 1. Restore all vacuum 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months one or more reactor breakers in two lines to buIlding-to-suppression OPERABLE status.

chamber vacuum breakers Inoperable for opening.

.Required Action and *.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time IAN not met.

.2 Be In MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.6.1 ....-- NOTES--

1. Not required to be met for vacuum breakers that are open during Surveillances.

2. Not required to be met for vacuum breakers open when performing their intended function.

Verify each vacuum breaker Is closed. 14 days SR 3.6.1.6.2 Perform a functional test of each vacuum breaker. In accordance with the Inservice Testing Program SR 3.6.1.6.3 Verify the full open setpoint of each vacuum breaker 24 months iss 0.5 psid.

Columbia Generating Station 3.6.1.6-2 Amendment No. 44,14.9 225 1

Suppression Chamber-to-Drywell Vacuum Breakers 3.6.1.7 3.6 CONTAINMENT SYSTEMS 3.6.1.7 Suppression Chamber-to-Drywell Vacuum Breakers LCO 3.6.1.7 Seven suppression chamber-to-drywell vacuum breakers shall be OPERABLE for opening.

Nine suppression chamber-to-drywll vacuum breakers shall be closed, except when performing their intended function.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required A.1 Restore one vacuum 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months suppression chamber-to- breaker to OPERABLE drywell vacuum breaker status.

inoperable for opening.

eet* MQ >dB*

-*} i h S-.NOTE- - .1 Close the open vacuum 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months I Separate Condition entry breaker disk.

Is allowed for each suppression chamber-to-drywell vacuum breaker.

One or more suppression chamber-to-drywell vacuum breakers with one disk not closed.

Columbia Generating Station 3.6.1.7-1 Amendment No. 440,-19 225 1

Suppression Chamber-to-Drywell Vacuum Breakers 3.6.1.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME L1 One or more -".1 Close one open vacuum 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months suppression chamber-to- breaker disk.

drywell vacuum breakers with two disks not dosed.

,.Required Action and -. 1 Be In MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Timec 4 t U not met.

3.2 Be In MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.7.1 NOTE--

Not required to be met for vacuum breakers that are open during Surveillances.

Verify each vacuum breaker is dosed. 14 days SR 3.6.1.7.2 Perform a functional test of each required vacuum 31 days breaker.

Within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after any discharge of steam to the suppression chamber from the safety/relief valves SR 3.6.1.7.3 Verify the full open setpoint of each required 24 months vacuum I I breaker EN IWN is < 0.5 psid. I Columbia Generating Station 3.6.1.7-2 Amendment No. 46-0,2W 225

RHR Suppression Pool Cooling 3.6.2.3 3.6 CONTAINMENT SYSTEMS 3.6.2.3 Residual Heat Removal (RHR) Suppression Pool Cooling LCO 3.6.2.3 Two RHR suppression pool cooling subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIO NS ..... .... .. . ...

CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR suppression A.1 Restore RHR suppression 7 days pool cooling subsystem pool coon subsystem to inoperable. OPERABLE status.

B. Required Action and B.1 N associated Completion a s Time of Condition A not a÷r met.

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (2 Be i!D 4*hours 3t Columbia Generating Station 3.6.2.3-1 Amendment No. 440,440 225 1

Secondary Containment 3.6.4.1 3.6 CONTAINMENT SYSTEMS 3.6.4.1 Secondary Containment LCO 3.6.4.1 The secondary containment shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, During operations with a potential for draining the reactor vessel (OPDRVs).

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Secondary containment A.1 Restore secondary 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months inoperable in MODE 1, containment to OPERABLE 2, or 3. status.

B. Required Action and B.1 associated Completion Tme of Condition A not met.

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months C. Secondary containment C.1 Initiate action to suspend Immediately inoperable during OPDRVs.

OPDRVs.

Columbia Generating Station 3.6.4.1-1 Amendment No. 460,4,9 225 1

SGT System 3.6.4.3 3.6 CONTAINMENT SYSTEMS 3.6.4.3 Standby Gas Treatment (SGT) System LCO 3.6.4.3 Two SGT subsystems shal be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, During operations with a potential for draining the reactor vessel (OPDRVs).

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SGT subsystem A.1 Restore SGT subsystem to 7 days inoperable. OPERABLE status.

B. Required Action and B.1 associated Completion Time of Condition A not met In MODE 1, 2, or 3.

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months C. Required Action and C.A Place OPERABLE SGT Immediately associated Completion subsystem in operation.

Time of Condition A not met during OPDRVs. OR C.2 Initiate action to suspend Immediately OPDRVs.

D. Two SGT subsystems D.1 OT -----

inoperable in MODE1, L, A no 2, or 3. appbcabke when entenn*

MOD)E3 Columbia Generating Station 3.6.4.3-1 Amendment No. 46g,4t0 225 I

SGT System 3.6.4.3 CONDITION REQUIRED ACTION COMPLETION TIME MO. LD Columbia Generating Station 3.6.4.3-2 Amendment No. 460,409 225 1

SW System and UHS 3.7.1 3.7 PLANT SYSTEMS 3.7.1 Standby Service Water (SW) System and Ultimate Heat Sink (UHS)

LCO 3.7.1 Division I ald 2 SW subsystems and UHS shal be OPERABLE.

APPLICABILITY: MODES 1,2, 2and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Average sediment depth A.1 Restor average sedIment 30 days in one or both spray depth to within mts.

ponds 2 0.5 ft and

< 1.0 ft.

B. One SW subsystem B.1 -NO TES-....

inoperabe. 1.- Enter applicabl Conditions and Required Actions of LCO 3.8.1,

'AC Sources -

Operatng," for dis

-natormade inaopea by SW System.

2. Enter applicable Conditions and Required Actions of LCO 3A.9, "Residual Heat Removal (RHR)

Shutdown Cooling System - Hot Shutdown," for RHR shutdown cooling subsystem made

noperable by SW System.

Restore SW subsystem to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE status.

S I Columbia Generaft Station 3.7.1-1 CAmendment No. 4"6, 225 1

SW System and UHS 3.7.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME

b. Required Action and .1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A not met. AN 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR <.2 Be in MODE 4. I Both SW subsystems inoperable.

QR UHS Inoperable for reasons other than Condition A.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1.1 Verify the water level of each UHS spray pond is 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

> 432 ft 9 Inches mean sea level.

SR 3.7.1.2 Verify the average water temperature of each UHS 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months spray pond is < 770 F.

Columbia Generating Station 3.7.1-2 Amendment No. 440,4I69 2 1

CREF System 3.7.3 3.7 PLANT SYSTEMS 3.7.3 Control Room Emergency Filfation (CREF) System LCO 3.7.3 Two CREF subsystems shal be OPERABLE.

I M-The cont room envelope (CRE) bmodary may be opened intermitently under administratve control.

APPLICABILITY: MODES 1, 2, and 3, Dudng operatons with a potential for draning the reactor vessel (OP)RVs).

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CREF subsystem A.1 Restore CREF subsystemn 7 days inoperable for reasons to OPERABLE status.

other than Condition B.

B. One or more CREF B.1 Iitiat action to inplement Immediately subsystems Inpra migatn actions.

due to inoperable CRE boundary in MODE 1, 2, M and 3.

8.2 Verify mitgatig actions ensure CRE occupant 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months exposures to radiological, chemical, and smoke hazards will not exceed limits.

90 days 8.3 Restr CRE boundary to OPERABLE status.

Columbia Generating Statlon 3.7.3-1 Amendment No. 404,2P 225 1

CREF System 3.7.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and CA associated Completion O 4a Time of Condition A or B not met in MODE 1, 2, or 3.

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months D. Required Action and D.1 Place OPERABLE CREF Immediately associated Completion subsystem In pressurization Time of Condition A not mode.

met during OPDRVs.

go D.2 Initiate action to suspend Immediately OPDRVs.

E. Two CREF subsystems E.1 inoperable in MODE 1, 2, or 3 for reasons other than Condition B.

F. Two CREF subsystems F.A Initiate action to suspend Immediately inoperable during OPDRVs.

OPDRVs.

OR One or more CREF subsystems inoperable due to inoperable CRE boundary during OPDRVs.

Columbia Generating Station 3.7.3-2 Amendment No. 20;,246 225 1

Control Room AC System 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Control Room Air Conditioning (AC) System LCO 3.7.4 Two control room AC subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, Durin operations with a potential for draining the reactor vessel (OPDRV$).

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One control room AC A.1 Restore control room AC 30 days subsystem inoperable, subsystem to OPERABLE status.

8. Two control room AC B.1 Verify control room area Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months subsystems inoperable, temperature < 900F.

B.2 Restore one control room 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AC subsystem to OPERABLE status.

C. Required Action and C.1 associated Completion Time of Condition A or B not met in MODE 1, 2, or 3.

Be nMODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Columbia Generating Station 3.7.4-1 Amendment No. 469,409 226-227

Main Condenser Offgas 3.7.5 3.7 PLANT SYSTEMS 3.7.5 Main Condenser Offgas LCO 3.7.5 The gross gamma activity rate of the noble gases measured at the main condenser air ejector shall be < 332 mCi/second after decay of 30 minutes.

APPLICABILITY: MODE 1, MODES 2 and 3 with any main steam line not isolated and steam jet air ejector (SJAE) in operation.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Gross gamma activity A.1 Restore gross gamma 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months rate of the noble gases activity rate of the noble not within limit, gases to within limit.

B. Required Action and 8.1 Isolate all main steam lines. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. QB B.2 Isolate SJAE. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months QR B.3.

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Columbia Generating Station 3.7.5-1 Amendment No. 440,4-. 225 1

AC Sources - Operating 3.8.1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 AC Sources - Operating LCO 3.8.1 The follwtng AC electrical power sources shalt be OPERABLE:

a. Two qualed ckuits between the offite transmission network and the onsle Class 1E AC Electric Power Distribution System; and

b. Three diesel generetors (0Gs).

APPLICABIKiTY: MODES 1, 2, and 3.

Division 3 AC electrical power sources we not requKed to be OPERABLE when High Pressure Core Spray System IsInoperable.

ACTIONS IP.-

LCO 3.O.4.b Is not applicable to DGs.

CONDITION REQUIRED ACTION COMPLETION TIME A. One offite circuit A.1 Perform SR 3.8.1.1 for I hour Inoperable. OPERABLE offslte circuit.

Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter Columbia Generating Station 3.8.1-1 Amendment No. 449,41 225 1

AC Sources - Operating 3.8.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continmed) A.2 Declare required feature(s) 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months from with no offslte power discovery of no ofisite available Inoperabe when power to one division the redundant required concurrent with feature(s) ae WOeb. inoperabwt of redundant required feature(s)

AND A.3 Restore offslte circuit to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE status.

6 dy from discovery of failure to meet LCO when not associated with Required Action B.4.2.2 17 days from discovery of failure to meet LCO S. OnerequiredOG 8.1 Perform SR 3.8.1.1 for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Inoperable. OPERABLE offsie arcgts).

Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter 8.2 Declare required featurs), 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from supported by the inoperabe discovery of DG, Inoperable when the Condition B redundant requird concurrent with feature(s) are inopere. inoperability of redundant required feature(s)

CclumWa Genmbng Station 3.8.1-2 Amendment No. 406,44 225 1

AC Sources - Operti 3.8.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.3.1 Detemi*ne OPERABLE 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months DO(s) wre not noperable due to common came failure.

8.3.2 Perform SR 3.8.1.2 for 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months If not OPERABLE DG(s). perbrmed wkhn the pest 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ANM 5.4.1 Restore required DG to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months from OPERABLE status. (tisovefy ofan inpeabe DO 6 days from discover of failure to meet LCO OR BA.2.1 Establish risk management 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months actions for the alternate AC sources.

0.4.2.2 Restore rquired DG to 14 days OPERABLE status.

17 days from discove of failure to meet LCO Columbia Gerveraft Statim 3.8.1-3 Amendment No. -1,4.. 225 1

AC Sources - Operat 3.8.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Two offs.e circuits C.1 Declare required feature(s) 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months from nerabe. inoerae when the dscovery of redMnd required Condition C feare(s) are inperable. concurrert with knpwsbft of redundant required C.2 Restore one oftste drcult to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE status.

D. One offse circuit -- NOTE OWe. Ente qPWabe Comdltions and Required Actions of LCO 3.8.7, AMstr&utlo System - Opratlg,"

when Condftion D is entered with no One required DG AC power source to any division.

0.1 Restore offsite circuit to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months OPERABLE status.

D.2 Restore required DG to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months OPERABLE status.

E. Two required DGs E.1 Restore one required OG to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months Ingeable. OPERABLE status.

OR 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months If DWvision 3 DG is inoerble Wumbla Generating Station 3.8.1-4 Anment No. 4.69,49Z 225

AC Sources - Operating 3.8.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME F. Required Action and F.1 associated Completion 4 Time of Condition A, B, a e e C, D, or E not met.

BeIn MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months G. Three or more required G.1 Enter LCO 3.0.3. Immediately AC sources inoperable.

SURVEILLANCE REQUIREMENTS, SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated 7 days power availability for each offsite circuit.

SR 3.8.1.2 ................. NOTE ----------- .---

1. All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.

2. A modified DG start involving idling and gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer. When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.7 must be met.

Verify each required DG starts from standby 31 days conditions and achieves steady state:

a. Voltage Ž 3910 V and < 4400 V and frequency

> 58.8 Hz and 5 61.2 Hz for DG-1 and DG-2; Columbia Generating Station 3.8.1-5 Amendment No. 460,444 225 1

DC Sources - Operaing 3.8.4 3,8 ELECTRICAL POWER SYSTEMS 3.8.4 DC Source- OperatDat LCO 3.8.4 The Division 1, Division 2, and Division 3 DC electrcal power subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS .. .. . . . . . . .. ..

CONDITION REQUIRED ACTION COMPLETION TIME A. One required Division I A.I Retore bary trm-na 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months or2 125 V DC battery voltage to greer than or cawe koperable. equal to the minimum

$W*1h0edloAt Vo e.

A.2 Verify beaery toat crent Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

2 amps.

A.3 Restore required battery 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months charger to OPERABLE status.

B. One required Division 3 B.1 Restore battery minal 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months 125 V DC battery votage to greter than or charger inoperable, equal to the minimum established loat voltage.

B.2 Verify battery float current Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

2 amps.

AMD 8.3 Restore required battery 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months dhwger to OPERABLE status.

Columbia Generating Station 3.8.4-1 Amendment 460,204 225 1

DC Sources - Operating 3.8.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. One required Division I C.1 Restore battery teminal 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months 250 V DC battery voltage to greater than or charger inoperable. equal to the minimum IsItshed float voltage.

C.2 Verify battery float current Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

52 amps.

C.3 Restore requied battery 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months charger to OPERABLE status.

D. One required Division I D.1 Restore batte to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months or 2 125 V DC battery OPERABLE status.

Inoperable.

E. One required Division 3 EA1 Restore battery to 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months 126 V DC battery OPERABLE status.

F. One required Division I F.1 Restore battery to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months 250 V DC battery OPERABLE status.

G. Divisionlor2125VDC G.1 RestoreDivisionland2 2hours electrical power 125 V DC electrical power subsystem inoperable subsystems to OPERABLE for reasons other than status.

Condition A or D.

Columbia Generating Station 3.8.4-2 Amendment 440,204 226 1

DC Sources - Operating 3.8.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME H. Required Action and H.1 Declare High Pressure Immediately associated Completion Core Spray System Time of Condition B or E inoperable.

not met.

QE Division 3 DC electrical power subsystem inoperable for reasons other than Condition B or E.

I. Required Action and 1.1 Declare associated Immediately associated Completion supported features Time of Condition C or F inoperable.

not met.

OR Division 1 250 V DC electrical power subsystem inoperable for reasons other than Condition C or F.

J. Required Action and J.1 associated Completion Time of Condition A or D not met.

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Required Action and associated Completion Time of Condition G not met.

Columbia Generating Station 3.8.4-3 CAmendment 46,2" 2 I

Distrui Systems - Operating 3.8.7 3.8 ELECTRICAL POWER SYSTEMS 3.8.7 Distribution System - Operaft LCO 3.8.7 The oNowin AC nd DC electrical power distributio subsystems shell be OPERABLE:

a. Division I and Division 2 AC electrical power distribution subsystem;

b. DMivson and Division 2 125 V DC electrial power distribution

c. Divioli 1250 V DC electc power distribon subsystem; and

d. Division 3 AC and DC electical power distribution subsystem.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS _____________ ________

CONDITION REQUIRED ACTION COMPLETION TIME A. Division I or 2 AC A.1 Restorevsion and 2 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months electrical power AC elocrical power diesftributi subsystem dtrtion subsystems to &6i inoperable. OPERABLE status.

16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months from discovery of failure to meet LCO 3.8.7.a or b

8. Dlvisionlor2l2SVDC 8.1 RestoreDivilsonland2 2hours electrical power 125 V DC elec l power distriuion subsystem distribution subsystems to MQ Inopera. OPERABLE status.

16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months from dikove.y of failure to meet LCO 3.8.7.a or b

Columbia Gerwra*V Station 3.8.7-1 Amendment 44.,440 225 J

Distribution Systems - Operating 3.8.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 NO associated Completion © 4 st Time of Condition A or B aicbie w eng not met.

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months D. Division 1250 V DC D.1 Declare associated Immediately electrical power supported feature(s) distribution subsystem Inoperable.

Inoperable.

E. One or more Division 3 E.A Declare High Pressure Immediately AC or DC electrical Core Spray System power distribution Inoperable.

subsystems inoperable.

F. Two or more divisions F.1 Enter LCO 3.0.3. Immediately with Inoperable electrical power distribution subsystems that result in a loss of function.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct breaker alignments and Indicated 7 days power availability to required AC and DC electrical power distribution subsystems.

Columbia Generating Station 3.8.7-2 Amendment 449,44W 225 1

LICENSE AMENDMENT REQUEST FOR ADOPTION OF TTP-423, REVISION 1 PROPOSED TECHNICAL SPECIFICATIONS BASES CHANGES (MARK-UPS)

RPS Electric Power Monitoring B 3.3.8.2 BASES ACTIONS (continued)

Alternatively, f it is rot desired to remove the power supply(s) from service (e.g., as in the case where removing the power supply(s) from service would result in a scram or Isolation), Condition C or D, as applicable, must be entered and its Required Actions taken.

DA If both power monitoring assemblies for an Inservice power supply (MG set or alternate) are inoperable, or both power monitoring assemblies In each inservice power supply are Inoperable, the system protective function Is lost. In this condition, 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months is allowed to restore one assembly to OPERABLE status for each Inservice power supply. If one inoperable assembly for each inservice power supply cannot be restored to OPERABLE status, the associated power supplies must be removed from service within I hour (Required Action B.1). An alternate power supply with OPERABLE a may then be used to power one RPS bus. The 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Completion Time is sufficient for the plant operations personnel to take corrective actions and is acceptable because it minimizes risk while allowing time for restoration or removal from service of the electric power monitoring assemblies.

Alternately, if it Is not desired to remove the power supply(s) from service (e.g., as in the case where removing the power supply(s) from service would result in a scram or isolation), Condition C or D, as applicable, must be entered and Its Required Actions taken.

If any Required Action and associated Completion Timne of Condition A or B are not met in MODE 1,2, or 3, e tm uto 4 *The plant shutdown is accomplished by placing the plant in MODE 3 within 12 hou Rein~nf the A~licabry ot te LCO

lbe *use he plant riMk*}*:*i O smia to **be thanth rask anMOD)E4 (Bre4)an us th ines~~ 3to orrrm ran r rpairst1o restore Irie systerr c OPERABLE status wall be shor. Htowever, vogrntary entry *to MODE 4ray b*ma as at sao an a~cepa bwk state RevisIon 73 Generating Station B 3.3.8.2-4 Columbia Generating Columbia Station B 3.3.8.2-4 Revision 73

RPS Electric Power Monitoring B 3.3.8.2 Req i~d Acrt C 1 smodh by aNFe at* tates tht LCO 304a is rTh a wf*le bwed Te 3reas None prbhases ton opert t)O O4a nter ?viE 3 dt~~trup wsih the LCO no met s:ever the÷ sniSr ecnant eusec$LGO 3O0b4o a~pphcbe L 0~uiO 4b requlr e* rnanof ariskassssen experiace, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.

Columbia Generating Station B 3.3.8.2-5 Revision 73

RPS Electric Power Monitoring B 3.3.8.2 BASES SURVEILLANCE REQUIREMENTS (continued)

The 24 month Frequency is based on Instrument drift analysis, the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient Ifthe Surveillance were performed with the reactor at power.

REFERENCES 1. FSAR, Section 8.3.1.1.6.

2. 10 CFR 50.36(cX2)(il).

3. NRC Generic Letter 91-09, "Modification of Surveillance Interval for the Electric Protective Assemblies In Power Supplies for the Reactor Protection System."

II IIII I I I IIIIIIII ie I 1 I s hn IIIr a Ju I tIca Io tu IIII I o I RIIIIIII Columbia Generating Station B 3.3.8.2-8 Revision 73

SRVs - < 25% RTP B 3.4.4 BASES LCO (continued)

The SRV safety set e estalished to ensur the ASME Code limit on peek reactor pressure is saifed. The ASME Code pM ill require the lowest safety valve be sd at or below vessl design pressure (1250 pW#) wid the highest sety valve be set so the O accumulated preseure does not exceed 110% of the design pressure for r conditions. The transient evaluationt in References 4 and 5 Wod g Oie safety mode are based on these saionts, but also Include the dditonl cetaint of *3% of the nominal selpoint to account for potential sepoint drift to provide an added degree of conservatism.

Operation with few vals OPERABLE #wthan eplled, or with setpoirs outside the ASKR liltA o e ki a more sre toactor "ons to a inwsl - asst6trsu inte ASME Gdod

on APPLICABILITY In MOPE I vUh THEFOAL PQWU 2$%RTP andOW ES 2 and 3, to spoci nwmw of SRVs must be OPERABLE shoo ther may be considerable energy inte reactor core ad the Wling design basis transients are assumed to occur. The SRVs may be required to limit peak reactor pressure.

The requirements for SRVs with THERMAL POWER > 25% RTP are discussed in LCO 3.4.3. In MODE 4, decay heat is low enough for the RHR System to povMde adequate ooing, and reactor pressure is low enough that twoevereure limit cannot be approached by assumed operatonal transients or aocdent In MODE 6, the reacor vessel head is unboked or removed and the reactor is at atmospheric pressure. The SRV function Is not needed during the condtons ACTIONS With less than the minimum number of required SRVs OPERABLE, a transient may result in the violation of the ASME Code limit on reactor pressure. $ r be te a ut be b to Saln*t isOa T ac etN saw ryt MODE 4may made*s itisaisoan Saio I 83.4.4.2 IRIeIIIIvI[ I _ s.Ion III73 ILI Ge CoI IIIlumia eatn II lIlIJl Columbia Generating Station B 3.4.4-2 Revision 73

SRVs - < 25% RTP B 3.4.4 t*i~ed Avoi A !sm4Ieby a otetha eth*atLCO304aiS

<J~V(V he* so etcmono Pre *n ThueiioLCO3 0b* tt apcbfe C 04 t rCeq04b res pe tomi nc o a tia e*sesm

i~ss S~e{ah! S/strse Iq omcnet ColKrmat on o1t he asus de tef iahorm ¢t th *abr~phly oi enterin MOL) 3 t o lM~suentu04 i*mangeantA ns atappropnak LCO 30,4 $s wt ACTN , cyth *eae f a 5ht Iowr #tt un; P a~ ompleteot ra~sotiab~ based or operatang

~e . I r~iac~ th fffItconrIItl si rduUpowe ii w pro withOut (. sheagirig lant systemso

~.

I~~* ~'+/-

4 P

>iM

~n enared IV a' eaaLAe ataarasinen arayres~ft I j eacto ~¶r. Ut' Ihepisiar usibe

~ ) /I~h hi (. does not aI~pIy To achie~ia lb J vWXiW 3'aul ar ~2hoorsar 'Ito A I pIflKin Timss~re ~g~n a'~

~ e rudpLrit addo ft d without ~r oaI~ 'ag~ ~ ~Ian Columbia Generating Station B83.4.4-3 Revision 73

SRVs - < 25% RTP B 3.4.4 BASES REFERENCES 1. FSAR, Section 15.2.4.

2. Columbia Generating Station Calculation NE-02-94-66, Revision 0, November 13, 1995.

3. ASME, Boiler and Pressure Vessel Code,Section III.

4. FSAR, Chapter 15.

5. GE-NE-187-24-O992, -WPPSS Nuclear Project 2 SRV Setpoint Tolerance and Out-of-Service Analysis," Revision 2, July 1993.

6. 10 CFR 50.36(c)(2)(0i).

7. ASME Code for Operation and Maintenance of Nuclear Power Plants.

Pla ei-2k SuppA*s Columbia Generating Station B 3.4.4-5 Revision 73

ECCS - Operating B 3.5.1 BASES ACTIONS (continued) information, to determine IIRCIC is out of service for maintenance or other reasons. It is not necessary to perform the Surveillances needed to demonstrate the OPERABILITY of the RCIC System. However, Ifthe OPERABILITY of the RCIC System cannot be inmnedlately verified and RCIC Is required to be OPERABLE, Condition D must be immediately entered. Ifa single active component fagls concurrent with a design basis LOCA, there is a potential, depending on the specific failure, that the minimum required ECCS equipment will not be available. A 14 day Completion Time Is based on the results of a reliability study (Ref. 13) and has been found to be acceptable through operating experience.

c-1 With two ECOS injection subsystems inoperable or one ECCS injection and one ECCS spray subsystem inoperable, at least one ECCS injection/spray subsystem must be restored to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . In this condition, the remaining OPERABLE subsystems provide adequate core cooling during a LOCA. However, overall ECCS reliability Is reduced in this Condition because a single failure Inone of the remaining OPERABLE subsystems concurrent with a design basis LOCA may result in the ECCS not being able to perform its intended safety function. Since the ECCS availability Is reduced relative to Condition A, a more restrictive Completion Time is imposed. The 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Completion Time is based on a reliability study, as provided in Reference 13.

Nfany Required Action and associated Completion Time of Condition A, B, or C are not met, the plant must be brought to a MODE in wich overall plant ri* mm goed. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

reainin9 n1the A* p: ac~ty , e L0

eptat*e b use the plant bisk in MO}DE 1 s s~miar to or toe* than the aisk an MODE 4 (~Re. 17) an beca~s the time spet In MODE~ 3~ pet necm the nees~sary repairs to restore tIhe ~smsm to OPERA1BL L statuis wil be short Howee, vokirn*ad'r ery nto MOUL 4 may be mole as it as also an ac24ptabie lowrsk stdate Hequu oeAtin D1ias ms i b aNNo S~t8s tha LODO304.a is not pi aiie whn ent ing MODE3 This *epr $kMeuse LCO03.0.4. to enterMODF3 durr st d p wh th LC©nrn*mt Columbia Generating Station B 3.5.1-6 Revision 73

EGGS - Operating B 3.5.1 exeinct reach the required pln conditi ons ,

f~rom ful power codtionsin an orerl aneerand wihufhlengingM i3 pantsytes Columbia Generating StationB351-Resin7 B 3.5.1-7 Revision 73

ECCS - Operating B 3.5.1 BASES ACTIONS (continued)

The LCO requires six ADS valves to be OPERABLE to provide the ADS function. Reference 14 contains the results of an analysis that evaluated the effect of two ADS valves being out of service. This analysis showed that assuming a failure of the HPCS System, operation of only five ADS valves wilt provide the required depressurization. However, overall reliability of the ADS is reduced because a single failure in the OPERABLE ADS valves could rel In a reduction in depressurization capability. Therefore, operation is only allowed for a limited time. The 14 day Completion Time is based on a reliabiity study (Ref. 13) and has been found to be acceptable through operating experience.

If any one low pressure ECCS injection/spray subsystem is inoperable in addition to one required ADS valve inoperable, adequate core cooling is ensured by the OPERABILITY of HPCS and the remaining low pressure ECCS injection/spray subsystems. However, the overall ECCS reliability is reduced because a single active component failure concurrent with a design basis LOCA could result in the minimum required ECCS equipment not being available. Since both a high pressure (ADS) and low pressure subsystem are Inoperable, a more restrictive Completion Time of 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months is required to restore either the low pressure ECCS injectlioVspray subsystem or the ADS valve to OPERABLE status. This Completion Time Is based on a reliability study (Ref. 13) and has been found to be acceptable through operating experience.

If any Required Action and associated Completion Time of Condition E or F are not met or Iftwo or more required ADS valves are inoperable, the plant must be brought to a - M ,iQE in which overa1I pant is irrur z d . To achieve this status, the plant must be brought to at least MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months He ~n, ngin *e*It I **t' LCO isa 10 b~use heplant rikunF*E3 iss lamtoor owe *n ae i} in MODE 4 (Ref 7) usebca t t~ma nM*OC 3 to *forntP n as ry airs to f~ v~th s OaOPERAI3LE uesw~tb h Hewerv vo[nary enry *gt FDE 4may be measa its also an a cptLe iow+l State, Columbia Generating Station B 3.5.1-8 Revision 73

ECCS - Operating B 3.5.1 Teqm AllowCom tion Tie by a Note r toa staes tt LCO 304tais

)3O 304a tOerierMQ d iDi qstaiiup wittheLCO nlre*

iw et theea *

rest c*- otheu* of CO 3X0.4.b tappii abe0 aeu'u LX)3 04b equ* per aiiocmaof a isk aesse~n~

I resn *peabte t requ pla corndons fro fatIo ower esbc onis Ina of r mamnner and t#o f allengngp LCa 3s0y4 t s o* app{ cabiet ant he *Nut~olesao*p dt* ch esan*ODESo oThei s pe lied coa i is in thAppba ily tht are toquiied to cc~yl 4v~ AC SoN 'ht retpa a' hu wnoffhounit The allowed Completion Tim& is reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.

Columbia Generating Station B 3.5.1-9 Revision 73

ECCS - Operating B 3.5.1 BASES REFERENCES 1. FSAR, Section 6.3.2.2.3.

2. FSAR, Section 6.3.2.2.4.

3. FSAR, Section 6.3.2.2.1.

4. FSAR, Section 6.3.2.2.2.

5. FSAR, Section 15.6.6.

6. FSAR, Section 15.6.4.

7. FSAR, Section 15.6.5.

8. 10 CFR 50, Appendx K.

9. FSAR, Section 6.3.3.

10. 10 CFR 50.46.

11. FSAR, Section 6.3.343.

12. 10 CFR 50.38(cX2)(ii).

13. Merandum from R.L e (NRC) to V. Stelo, Jr. (NRC),

MRoccmmd Interim Revisions to LCO* for ECCS Components,"

Deoemb# 1, 1975.

14. NEDC-321,15P, Columbia Generating Station, "SAFER/GESTR-LOCA Loss-of-Coolant Accident Analysis," Revision 2, July 1993.

15. Licensee Controlled Specifications Manual.

16. NEDO 32291-A, "System Analyses for the Elimination of Selected Response Time Testing Requirements," October 1995.

i N)C*32**A Revision 2 T bnua Jus*ti~ctn to Supr Risk~

t4orm* *d aior to eeed1Ru* End Stat* fI PR PRan, te*m ern2t J Columbia Generating Station B 3.5.1-15 Revision 73

RHR Drywell Spray 83.6.1.5 BASES ACTIONS (continued)

If any Required Action and associated Completion Time cannot be met, the plant must be brought to a MODE in wich ov i p* mr k men . To achieve this status, the plant must be brought to at least MODE 3 within 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Talnowe Co pet T he Lrasnable, baed on e e plant Vrifying the lioe s len en E 3 to pemoan alta noer opera rvpalrs to pore tsy wextoOP A Lsst wioT *owesntap vcnntrenttyi* MDE 4 my b m,*as i ao *n aclet tat Iware lstate R~ietr* Acton C !s* ei aNe hat#e h LC &03 4ae the aupicabde were eried tobeI etel corc3 Nostprohrbto the use of LCod 30 a b e tai gne t 3 ac cidert p with thi LtO ti met.

drysesCpraO mo0 i manuals peIiotianteo T a is assessment addres *r vve maipuoe la *yon;rs ahr, ciiolvets, cvrific ation t thoe ts d0:s nTeh1*air* of t e~ ac0eptab ofty lenrtedn MODE 2, and*

esta* ¶himt& o t5k m 0aem~ cions ppf a0~*se O3A.04 $s I:, :cbeio - ardt~ c, vo ro1rcu* chae ~in MODESo

< :*:f~i t*e*s in tr©* ppehca my tha ae [*ur cm witAUT\ O'S 7: 03 ar Oa~t of) 7tsutd(NO 01 the unit The allowed Completion Tim, ¢ s reasonable, based on operating experience, to reach the required plant conditions from full power assumr in conditions ~eed in an aciet

etk~in<r orderly thenls ands.hse manner is accpt without challenging4bfplantaablesnehH systems.

SURVEILLANCE cc vl. es.

REQUIREMENTS Verifying the correct alignment for manual and power operated valves in the RHR drywell spray mode flow path provides assurance that the proper flow paths will exist for system operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since these were verified to be in the correct position prior to locking, sealing, or securing. A valve Is also allowed to be in the nonaccident position, provided it can be aligned to the accident position within the time assumed in the accident analysis. This 1s acceptable, since the RHR drywell spray mode is manually initiated. This SR does not require any testing or valve manipulation; rather, it involves verification that those valves capable of being mtspositioned are in the correct position. This SR does not apply to valves that cannot be inadvertently misaligned, such as check valves.

Revision 73 Generating Station B 3.6.1.5-3 Columbia Generating Columbia Station B 3.6.1.5-3 Revision 73

RHR Drywell Spray B 3.6.1.5 BASES REFERENCES 1. FSAR, Section 6.2.1.1.5.4.

2. 10 CFR 50.36(c)(2)(B).

3. FSAR, Section 15.6.5.

4nf, M tc tO d P~quwe Lo S fr 3WR Columbia Generating Station B 3.6.1.5-5 Revision 73

Reactor Building-to-Suppression Chamber Vacuum Breakers B 3.6.1.6 BASES ACTIONS (continued) vac

nopeisahie vo pnnf adte not restoed whin theO{np 4*nT~me n(t> { t *naa g brea ers th e or i*udmorTi 4nt ro nemanirU- t* LCOsaiii is acvpable because th plnt a MODE mmsa*t o*/ae rn*e*ik* 4Ref3 a.

rest, e tr Aunstem OPEI3Ati. statis will be *iort Howvm

~o Aat D 4 sodfb a Nhate tat stdts that LCO 3 0 4 a is

,:t cae be*÷°t0* MO© <3 ts

eh @sthe Is at L :O 3 & 4a nto eaQe DL duper9 sktap with the LCO no! met o*,e t~e s n restrot*' m*e*e L ( 3{04 fapp~icbie b ue *CU 04b r~u e perom~aace o isk sesme

..... ... r .a

..... te *con',G 1app~:r~rats L$.O ?304 is wi uN IOSo mta ~ att sU o* nt urn Un v a a onoper

))~~~iFIC~. I i fltao it Sr aip tdi~rMt¶ a n r ijynvinno andwir~u i p 1 am t~

I WitE two or more lanes with one or more vacuum breakers inoperable for I

opening tas primary containment bounriary is intact However, in the Columbia Generating Station B 3.6.1.6-4 Revision 73

Reactor Building-to-Suppression Chamber Vacuum Breakers B 3.6.1.6 this stts thephmt be brohg he MODEn 3 wth i hourm anto~ed to M ERABEhin 3 status ho .s Completion Timear reasonta e, b ACTIONSp a o e 3n11c toreuh ereqt plmant m

b} met rtbedtQQo* PER :*L statusw thn 1 hou OPRAL srau .4kw~ t*e IIV Cornlpd Tjre* The pia* utr b*Ou~t t a MO9IE *n wh th LC ds not apply To achieve this status, the plant must be brought to at least MODE 3 withinwtos~dto codtion from*

ful poe conditionso In@ oann¢ orel mane ad u 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and to MODE 4 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . The alowed Completion Times are reasonable, based on operating experience, to reach the required plant fEahvacuum conditions frombreaker Is verW full power o bn~edos toesrnno sed t th a poteta conditions in an orderly manner and without challenging plant systems.

SURVEILLANCE SR .61.6.1 REQUIREMENTS Each vacuum breaker i veu to be closed to ensure that a potential breach in the primary containment boundary is not present. This Surveillance is performed by observing local or control room indications of vacuum breaker position or by verifying a differential pressure of

> 0.5 prid is maintained between the reactor building and suppression chamber. The 14 day Frequency is based on eniern judgment, is considered adequate in view of other Indications of vacuum breaker status available to operations personnel, and has been shown to be acceptable through operating experience.

Two Notes are added to this SR. The first Note allos reactor building-to-suppession chamber vacuum breakers opened in conjunction with the performance of a surveillance to not be considered as failing this SR.

These periods of opening vacuum breakers are controlled by plant procedures and do not represent inoperable vacuum breakers. The second Note is included to clarify that vacuum breakers ope due to an actual differential pressure, are not considered as failing this SR.

Columbia Generating Station B 3.6.1.6-5 Revision 73

Reactor Building.to-Suppression Chamber Vacuum Breakers B 3.6.1.6 BASES SURVEILLANCE REQUIREMENTS (continued)

Each vacuum breaker must be cycled to ensure that it opens property to perform its design function and returns to Its fully closed position. This ensures that the safety analysis assumptions are valid. The Frequency of this SR is in accordance with the Inservice Testing Program.

Demonstration of vacuum breaker opening setpoint is necessary to ensure that the safety analysis assumption regarding vacuum breaker full open differential pressure of S 0.5 psid Is valid. The 24 month Frequency is based on requirements associated with instruments that monitor differential pressure between the reactor building and suppression chamber. The 24 month Frequency has been shown to be acceptable, based on operating experience, and is further justified because of other surveillances performed at shorter Frequencies that convey the proper functioning status of each vacuum breaker.

REFERENCES I. FSAR, Section 6.2.1.1.4.

2. 10 CFR 50.36(c)(2)(H).

.IT n'Sd *b CC' .2 f2 I' ' I I I IIII I II [III]

I I I II III I Columbia Generating Station B 3.6.1.6-6 Revision 73

Suppression Chamber-to-Drywell Vacuum Breakers B 3.6.1.7 BASES APPLICABILITY (continued) of the drywell. The limiting pressure and temperature of the primary system prior to a DBA occur in MODES 1, 2, and 3. Excessive negative pressure inside the drywell could also occur due to inadvertent actuation of the Drywell Spray System.

In MODES 4 and 5, the probability and consequences of these events are reduced by the pressure and temperature limitations in these MODES; therefore, maintaining suppression chamber-to-drywell vacuum breakers OPERABLE is not required in MODE 4 or 5.

ACTIONS &I With one of the required vacuum breakers Inoperable for opening (e.g., a vacuum breaker disk is not open and may be stuck closed or not within its opening setpolnt limit, so that it would not function as designed during an event that depressurized the drywell), the remaining six OPERABLE vacuum breakers are capable of providing the vacuum relief function.

However, overall system reliability is reduced because a single failure in one of the remaining vacuum breakers could result in an excessive suppression chamber-to-drywell differential pressure during a DBA.

Therefore, with one of the seven required vacuum breakers inoperable, 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Is allowed to restore at least one of the inoperable vacuum breakers to OPERABLE status so that plant conditions are consistent with those assumed for the design basis analysis. The 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Completion Time is considered acceptable due to the low probability of an event in which the remaining vacuum breaker capability would not be adequate.

fa iUe iha up1 o* bUoodr~e Iv u bredke

pe ab for oix'an #a r ored toOP RABLE Statu w in

he ~u*Co~t *Tio the nt*musl bbo*ght to acooorton }n w£hi arena ! pat isk is n *imiized. To acheve this *Atu th ptant m.*4 bbr**ht*oatas MODE 3 w ith 2 h~ur i:*ma~I* i* the r~iicblyo LCD c acpi-abe becuse~the p~art

+skriMOC) 3 s* r to o ower P risk r MO* 4 (Rl 3) anr because th nims n L)* 3 to rf., riece q repairs t io*tapr entry .*to MODE 4 may be md as it is also an acc(:pi<ab3 l~wiisk Stae Rtouir I Actin B3. ts by a Note tha states that LCO 3X0 4.a i no~ appiate wh;en entering MO* 3. This Note prohibits the use cA LCD 30.4ai to enter MODE 3 during startup wit the LCD not met*

Columbia Generating Station B 3.6.1.7-3 Revision 73

Suppression Chamber-to-Drywell Vacuum Breakers B 3.6.1.7 Howe~e *÷e sno sti~t~ on theuse LGQO 304 h t*ipI~b~e*

W one or 3mor v e beaker anst e adrisk anose*,e com muslxtio b÷ syswen the swellaxesondepaeson cha ai sahe contas venltr r petion due to this ba letoakage 3I OCA waee to o hrfo the Mote nos cbreaker d is mu 4o ies 72 husIs aed to los the vpabcliuu tbrat are rtuo tredun doay wi aiNtC or thetothr vc hbreake d (the t the othe ardisk i Colpoet)an the low pSoba i base ofen thatwld prerize coul occur, primre cotaent.N ndasatreA vauum therpaisuthe nm fo4rmr pote~ntial is poitio iirfucpiwe With one or more vacuum breakers with one disk not closed, communicaedon between the drywenl and suppression chamber airspace could occur, and,ma a result, there Is the potential for primary containment overpressurization due to this bypass leakage ifa LOCA were to occur. Therefore, the open vacuum breaker disk must be closed.

72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months s Nalowed to closete vacuum breaker due to the redundant capability afforded by the other vacuum breaker disk, (the fact that the other disk Is closed), and the low probabilit of an event that would pressurze primary containment. Ifvauw brs poito indication is not reliable, en alune* mho of verifying that the vacuum breakers are closed is to verify that a differential pressure of > 0.5 psld between the suppression chamber and drywall is maintained for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months without makeup. As Noted, separate Condition entry is allowed for each vacuum breaker.

Columbia Generating Station B 3.6.1.7-4 Revision 73

Suppression Chamber-to-Drywefl Vacuum Breakers B 3.6.1.7 BASES ACTIONS (continued)

With one or more vacuum breakers with two disks not closed, this allows communication between the drywell and suppression chamber, and, as a result, there is the potential for primary containment overpressunizatlon due to this bypass leakage if a LOCA were to occur. Therefore, one open vacuum breaker disk must be closed. A short time Is allowed to close one of the vacuum breaker disks due to the low probability of an event that would pressurize primary containment. If vacuum breaker position indication is not reliable, an alternate method of verifying that the vacuum breaker disks are closed Is to verify that a differential pressure of

> 0.5 psid between the suppression chamber and drywell Is maintained for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months without makeup. The required 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months Completion Time is considered adequate to perform this test.

plant must be brought to a MODE In which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and to MODE 4 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . The allowed Completion Times are reasonable, based on oper at ene,.to reach the required plant conditions from full power conditions In an orderly manner and without challenging plant systems.

SURVEILLANCE SR 3.6.1.7,1 REQUIREMENTS Each vacuum breaker Is verified closed (except when the vacuum breaker is performing its intended design function) to ensure that this potential large bypass leakage path is not present. This Surveillance is peduemued byobserving4hl su"woreaker posWWisA kation or by verifying that a differential pressure of a 0.5 psid between the suppression chamber and drywell Is maintained for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months without makeup. The 14 day Frequency Is based on engineering judgment, Is considered adequate in view of other indications of vacuum breaker status available to operations personnel, and has been shown to be acceptable through operating experience.

A Note Is added to this SR which allows suppression chamber-to-drywell vacuum breakers opened in conjunction with the performance of a surveillance to not be considered as failing this SR. These periods of opening vacuum breakers are controlled by plant procedures and do not represent inoperable vacuum breakers.

Columbia Generating Station B 3.6.1.7-5 Revision 73

Suppression Chamber-to-Drywell Vacuum Breakers B 3.6.1.7 BASES SURVEILLANCE REQUIREMENTS (continued)

Each required vacuum breaker must be cycled to ensure that it opens adequtel to perform Its design function and relturn to the Afull closed posit-. This enmsres that the sakity analysis assumption are valid.

The 31 day Frequency of this SR was develop, based on Inservice Testing Program requirenment to perform valve testin at eat once every 92 days. A 31 day Frequency was chosen to provide additonal assurance that the vacuum breaker are OPERABLE, since they are Oced in a harsh envonrmet (the suppressio chamber airepace). In addition, this funtional test i required wfthin 12 hous after a discharge of steam to the suppression cwamber from the safety/rele valves.

Veriication of the vacuum breae opening setpoint is necessary to ensure that the safety analysis assumption regarding vacuum breaker full open differentiea pressure of %0.5 pstd Is valid. The 24 month Frequency is based on the need to perform this Survellnce under the conditions that apply during a plant outage and the potential for an unplanned tranent Ifthe Surveillance were performed with the reactor at power.

The 24 month Frequency has been shown to be acceptable, based on operating experence, and is further Jus*ie because of other surveillances performd at shorter Frequencies that convey the proper functioning status of each vacuum brealer.

REFERENCES 1. FSAR, Section 6.2.1.1.4.

2. 10 CFR 50.36(cX2Xt).

3NC.32')88 RevLsr'- 2, Tchni! -usti icatwv to Support Risk-

.III -. ... ... to SeIecied ReIIII1 r StateI. for W R n--

P~g~p Oocmiier2OWN Columbia Generating Station B 3.6.1.7-6 Revision 82

RHR Suppression Pool Cooling B 3.6.2.3 BASES LCO During a DBA, a minimum of one RHR suppression pool cooling subsystem Is required to maintain the primary containment peak pressure and tempersture below the design limits (Ref. 2). To ensure that these requirements are met, two RHR suppression pool cooling subsystems must be OPERABLE. Therefore, in the event of an accident, at least one subsystem IsOPERABLE, assuming the worst case single active failure.

An RHR suppression pool cooling subsystem Is OPERABLE when the pump, a he*t exchanger, and associated piping, valves, Instrumentation, and controls are OPERABLE.

APPLICABILITY In MODES 1, 2, and 3, a DBA could cause both a release of radioactive material to primary containment and a heatup and pressurization of primary containment. In MODES 4 and 5, the probability and consequences of these events are reduced due to the pressure and temperature limitations in these MODES. Therefore, the RHR Suppression Pool Cooling System is not required to be OPERABLE in MODE 4 or 5.

ACTIONS &1 With one RHR suppression pool cooling subsystem inoperable, the inoperable subsystem must be restored to OPERABLE status within 7 days. In this condition, the remaining RHR suppression pool cooling subsystem is adequate to peIrform the primary containment cooling function. However, the overall reliability Is reduced because a single failure in the OPERABLE subsystem could result in reduced primary containment cool capability. The 7 day Completion Time is acceptable in light of the redundant RHR suppression pool cooling capabilities afforded by the OPERABLE subsystem and the low probability of a DBA occurring during this period.

I

~. Qoitnq subsystem as ~noperabIe and is riot

<)3~ ~AA~ Wa in requt T4T1e an~A~'iachoveraU r s m~n~ ~¶. ,l ~i~a> ~rra ~iu~ eptanimustbe o ba I as

H MODE) s~ri o or ttwi '*h ri* MOO 4(R*,5 and basethe trespenot in M*t) 3 ir . 4orp m the necssr repair to re~** se n tj OP RBL stu be short Howe*

k

>rutary entyV ;i~to MODE 4 uT~av be mad as It is also an a( *Ttabe~ AowJkste Columbia Generating Station B 3.6.2.3-2 Revision 73

RHR Suppression Pool Cooling B 3.6.2.3 R* of tAo B ! nsu fby aNote thah atesthat~L 3.04a is

t~p~aot s*ente

< ng MODE 3 This Note prohibs Ih use oefc LCO 342 Ic rODE 3 duinnostasfup wth th LCOt niot set, os Now* *thee * *est~c~ ~'th

useof LGQ3O0b ff apphcabie

sa re LCO 304b requsrespdr a ue*ot a sds aesessrn

1 TIw alicry Completion Time, reasonable, based on operating experience, to reach fth required plant onditions from full power conditions in an orderly ramer and whoutohellng igplant systems.

p~n4;s b{br a O*O

h w LCO~ c tho *yO T rea ch required ithe ln odtosfofull*@e** power* con¢ditionse an orderly* mha**nner andwtot chaliengn lntsses Columbia Generating Station B 3.6.2.3-3 Revision 73

RHR Suppression Pool Cooling B 3.6.2.3 BASES SURVEILLANCE §R 3.6.2.2.1 REQUIREMENTS Verifying the correct alignment for manual, power operated, and automatic valves, in the RHR suppression pool cooling mode flow path provides assurance that the proper flow path exists for system operation.

This SR does not apply to valves that are locked, sealed, or otherwise secured in position since these valves were verified to be in the correct position prior to being locked, sealed, or secured. A valve is also allowed to be in the nonaccident position, provided it can be aligned to the accident position within the time assumed in the accident analysis. This is acceptable, since the RHR suppression pool cooling mode is manually initiated. This SR does not require any testing or valve manipulation; rather, it Involves verification that those valves capable of being mispositioned are in the correct position. This SR does not apply to valves that cannot be inadvertently misaligned, such as check valves.

The Frequency of 31 days is justified because the valves are operated under procedural control, improper valve position would affect only a single subsystem, the probability of an event requiring initiation of the system is low, and the system is a manually initiated system. This Frequency has been shown to be acceptable, based on operating experience.

SR 3,6.2.3-2 Verifying each RHR pump develops a flow rate > 7100 gpm, while operating in the suppression pool cooling mode with flow through the associated heat exchanger, ensures that the primary containment peak pressure and temperature can be maintained below the design limits during a DBA (Ref. 2). The normal test of centrifugal pump performance required by the ASME OM Code (Ref. 4) is covered by the requirements of LCO 3.5.1, "ECCS - Operating." Such inservice tests confirm component OPERABILITY, and detect Incipient failures by indicating abnormal performance. The Frequency of this SR is In accordance with the Inservice Testing Program.

REFERENCES 1. FSAR, Section 6.2.1.1.3.3.

2. FSAR, Section 6.2.2.3.

3. 10 CFR 50.36(c)(2)(ii).

4. ASME Code for Operation and Maintenance of Nuclear Power Plants.

Columbia Generating Station B 3.6.2.3-4 Revision 73

RHR Suppression Pool Cooling B 3.6.2.3 Columbia Generating Station B 3.6.2.3-5 Revision 73

Secondary Containment B 3.6.4.1 BASES LCO An OPERABLE secondary containment provides a control volume into which fission products that bypass or leak from primary containment, or are released from the reactor coolant pressure boundary components located in secondary containment can be diluted and processed prior to release to the environment. For the secondary containment to be considered OPERABLE, it must have adequate leak tightness to ensure that the required vacuum can be e and maintained.

APPLICABILITY In MODES 1, 2, and 3, a LOCA could lead to a fission product release to primary containment that leaks to secondary containment. Therefore, secondary containment OPERABILITY is required during the same operating conditions that require primary containment OPERABILITY.

In MODES 4 and 5, the probability and consequences of the LOCA are reduced due to the pressure and temperature limitations In these MODES. Therefore, maintaining secondary containment OPERABLE Is not required in MODE 4 or 5 to ensure a control volume, except for other situations for which significant releases of radioactive material can be postulated, such as during operations with a potential for draining the reactor vessel (OPDRVs).

ACTIONS A-1 If secondary containment is inoperable, it must be restored to OPERABLE status within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . The 4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Completion Time provides a period of time to correct the problem that is commensurate with the importance of maintaining secondary containment during MODES 1,2, and 3. This time period ensures that the probability of an accident (requiring secondary containment OPERABILITY) occurring during periods where secondary containment is inoperable Is minimal.

I I

Ifthe secondary containment cannot be restored to OPERABLE status within the required Completion Time, the plant must be brought to a MODE In which

overa pt ri m~nmized.

To achieve this status, the plant must be brought to at least MODE 3 I

within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

&u~a~un~ ~fl tt~P A p~ic~u~Itty ~A ~r~o LO a aceabe beause the pnt

<~ ~S s~mdai ~o or ~ow~u thrit ris in *DE 4P(e 3}and

~re p. ~nM0U to peiorn* the necssar repairsto

~tY~iIorE~ th~ ~4orn w~ QPEHAI3Lfi sitatis wd Hw. yweve

~bn y ritry~uMOt) m uta eow ~s Columbia Generating Station B 3.6.4.1-2 Revision 73

Secondary Containment B 3.6.4.1 R~u~dA:t *r* B1

dfaby a No* ha1 sta~ ha L(0 O04a s The&#owed eiTne reasonable, probasied optheruteg n

Ho:eIen tgeope reach th eir pla nt cnditions f0r fullapow e conditions

ete~

I of tr e aner abnd ty oent calng plant sysemd es efistm r s* rlnayeme a4isr apprprte LCO 3.04 r~ot abl* e to. an th Nte doe XA pr cld haqes ir MODES or wt ACT )ONS o thta pe toa $huSlk~n o th nr The allowed Completion Time r,r xts based on operating expeiec, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.

Columbia Generating Station B 3.6.4.1-3 Revision 73

Secondary Containment B 3.6.4.1 BASES SURVEILLANCE REQUIREMENTS (continued)

Therefore, these two tests are used to assess secondary containment boundary Integrity. Since these SRs are secondary containment tests, they need not be performed with each SOT subsystem. The SGT subsystems are tested on a STAGGERED TEST BASIS, however, to ensure that In addition to the requirements of LCO 3.6.4.3, either SGT subsystem will perform this test. Operating experience has shown these components usually pass the Surveillance when performed at the 24 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

REFERENCES 1. FSAR, Sections 15.6.5.

2. 10 CFR 50.36(c)(2)(ii).

Infcmno Mo* c*t:

RqI* Sta~te* for3WR P~ars i *cenbs 30t2.

Columbia Generating Station B 3.6.4.1-.6 Revision73

SGT System B 3.6.4.3 BASES APPLICABILITY In MODES 1,2, and 3, a DBA could lead to a fission product release to primary ontainment that leaks to secondary containment. Therefore, SGT System OPERABILITY is required during these MODES.

In MODES 4 and 5, the probability and consequences of these events are reduced due to the pressure and temperature limitations In these MODES. Therefore, maintaining the SGT System OPERABLE Is not required in MODE 4 or 5, except for other situations under which significant releases of radioactive material can be postulated, such as during operations with a potential for draining the reactor vessel (OPDRVs).

ACTIONS A.1 With one SGT subsystem inoperable, the inoperable subsystem must be restored to OPERABLE status within 7 days. In this condition, the remaining OPERABLE SGT subsystem Is adequate to perform the required radioactivity release control function. However, the overall system reliability Is reduced because a single failure in the OPERABLE subsystem could result in the radioactivity release control function not being adequately performed. The 7 day Completion Time Is based on consideration of such factors as the availability of the OPERABLE redundant SGT subsystem and the low probability of a DBA occurring during this period.

Ifthe SGT subsystem cannot be restored to OPERABLE status within the required Completion Time in MODE 1, 2, or 3, the plant must be brought to a MODE in which o i t is rmi n*. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

4*yaitHg Uh# Appic,. tyiJ L(f 0h CO is ab* U thei plant

,ir*"}E3 itm~a too *wrk *Ithe ik i*E 4 (R, 5) an e te*e time spet in MO©EI 3 to perorm the necessar repairs to retAore the s~ysLem to OPERAFBL* staus wii} bo shcort However, oe*qan er~ty rieMOOE 4 ay madas}t is aiso an FRh~ui~d oricB3 1 uos m~ y a t. tht states that LeoQ30.4a

app3lcbe wa eintrg fv1DE 3, This Notet prohibits the us of (1)° 43*,,a eto er I)D durn starlup wh the LCO no me Ho~ve there is no rest lction on the use of LC0 3 0 4ob, if applksable, b~ause LCO 3,0,4, requ ues perfomance of a risk assesment a ess* i *# e systems and *s, consideratio of the resul, iena tooftie acceptabui of nteringMODlE 3, nd Revision 73 Generating Station Columbia Generating B3.6.4.3-3 Revision 73 Columbia Station B 3.6.4.3-3

SGT System B 3.6.4.3 propriate ~o ~J 4 is

) appb. C) dP~A (4edee$ etpei io changes n MO~S 0; I ~ ted ~oriditsc~n~ tn the App~ ~. i~ a e ~OQLit G( c trnrA~

1K )N~orI[a~ar pat~ t~at owr A ~te urn!

The allowed Completion Tiro reasonable, based on operating experience, to reach the required plant conditions from full power conditions In an orderly manner and without challenging plant systems.

RevisIon 73 Generating Station B 3.6.4.3-4 Columbia Generating Columbia Station B 3.6.4.3-4 Revision 73

SGT System B 3.6.4.3 BASES ACTIONS (continued)

C.1 and C.2 During OPDRV9, when Required Action A.1 cannot be completed within the required Completion Time, the OPERABLE SGT subsystem should be immediately placed in operation. This Required Action ensures that the remaining subsystem Is OPERABLE, that no failures that could prevent automatic actuation will occur, and that any other failure would be readily detected.

An alternative to Required Action C.1 is to immediately suspend activities that represent a potential for releasing radioactive material to the secondary containment, thus placing the unit in a condition that minimizes risk. Action must be immediately initiated to suspend OPDRVs to minimize the probability of a vessel draindown and subsequent potential for fission product release. Action must continue until OPDRVs are suspended.

P.1 Ifboth SGT subsystems are inoperable in MODE 1, 2, or 3, the SGT System may not be capable of supporting the required radioactive release control function.

a i i rn ka o heve tmust

m n+#*- thA o

LC a blae * *the pint fish i MO 3 imsai to rw ban rk M DE 4 (Ref 6}

4s he in

3to *o* n* y a to Iit *r v~

sytm OPER fLE statue wil be she er, voAu +t y eu~y +nto OI 4 may a made as it is also an A~do Rc* A~io is

!o+id* by a N~ote tht sates that LCO 3OA a i no ap

aC)wen r TfD Note D ~boos S te of i1CO 0 4 a *tueMOrDE ~3 duong startup with the LCO not met

AOeve the~e+ no loe o* e ri o LCO3X)A4b, apf ble au~sadresiq no~ab~e syses and opoents. consideation o the esat s enon o kris g mnt ions, a* LCO 3.0.4 rflut *ptab~e ,oa+Je at ae pr , i+s+n MODES or othersci *tions in thVtlm arerequtred to with ACTiONS o1- that aie part of a shutdown of the uni Columbia Generating Station B 3.6.4.3-5 Revision 73

SGT System B 3.6.4.3 When two SGT subsystems are inoperable, actions must be Immediately Initiated to suspend OPDRVs to minimize the probability of a vessel draindown and subsequent potential for fission product release. Action must continue until OPDRVs are suspended.

SURVEILLANCE §R 3.6.4.3.1 REQUIREMENTS Operating (from the control room) each SGT subsystem for > 10 continuous hours ensures that both subsystems are OPERABLE and that all associated controls are functioning properly. It also ensures that blockage, fan or motor failure, or excessive vibration can be detected for corrective action. Operation with the heaters on (automatic heater cycling to maintain temperature) for k 10 cortinuou hours every 31 days eliminates moisture on the adsorbers and HEPA filters. The 31 day Frequency was developed in consideration of the known reliability of fan motors and controls and the redundancy available in the system.

Columbia Generating Station B 3.6.4.3-6 Revision 73

SGT System B 3.6.4.3 BASES SURVEILANCE REQUIREMENTS (continued)

SR -3.6,4.,22 This SR verifies that the required SGT filter testing Is performed in accordance with the Ventilation Filter Testing Program (VFTP). The SGT System filter tests are in accordance with Regulatory Guide 1.52 (Ref. 5).

The VFTP includes testing HEPA filter performance, charcoal adsorber efficiency, minimum system flow rate, and the physical properties of the activated charcoal (general use and following specific operations).

Specified test frequencies and additional information are discussed in detail in the VFTP.

SR 3.6.4.3.3 This SR requires verification that each SGT subsystem starts upon receipt of an actual or simulated initiation signal. The LOGIC SYSTEM FUNCTIONAL TEST In LCO 3.3.6.2, "Secondary Containment Isolation Instrumentation," overlaps this SR to provide complete testing of the safety function. While this Surveillance can be performed with the reactor at power, operating experience has shown these components usually pass the Surveillance when performed at the 24 month Frequency, which Is based on the refueling cycle. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

SR 3.6.4.3.4 This SR requires verification that the primary SGT filter cooling recirculation valve can be opened and the primary fan started. This ensures that the ventilation mode of SGT System operation Is available.

While this Surveillance can be performed with the reactor at power, operating experience has shown these components usually pass the Surveillance when performed at the 24 month Frequency, which Is based on the refueling cycle. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

REFERENCES 1. 10 CFR 50, Appendix A, GDC 41.

2. FSAR, Section 6.5.1.2.

3. FSAR, Section 15.6.5.

4. 10 CFR 50.36(c)(2)(ii).

5. Regulatory Guide 1.52, Rev. 2.

Columbia Generating Station B 3.6.4.3-7 Revision 73

SGT System B 3.6.4.3

~L ?9~3&-A Kev~ :* *n2 T Se*c ustIhGatIon 10 Support Risk niormed Mo~it.ca~ E d St~ite¶~ for ~H

~ ~ant~ J >e*0ke 2U~.

Columbia Generating Station B 3.6.4.3-8 Revision 73

SW System and UHS B 3.7.1 BASES ACTIONS (continued)

I n SW S4 di;) )GA( \; ( pG piE4iOr 1Th~

)tCl~; 0V~ 4 1~A P~ ~ ~¶~W* 3 ~1hIG I~ 1)i A i~r~n~ ir )W~ CUSP p Muu~ ~dI0WOl M(414 4m yheP1eA~At ~4G~

u ~ d)~I~ ~ i~. ~htit LGO ~ 4 ~

~ P 1

~)k~4d in r pw~1i~ Q~ m

~ 1< ~ GI 0. 3 34b 4&t~ANt~

~D 4P ~ ~)~4orrn~nce ol ~. ~essnaan1

4. del> ~v ~ ac~. ep~a0iIu~ ol entering MODE 3, and A g ~ 14044 ~ i;aons, A dppnpraate LCQ 3 C 4 as

~)i t)JIO~lA0J eli$~d NSA. U U ki e ~rMO~,i Sea

~'fl~ *~> U '4 pel1/4#thel ~re ~'equared tG Ccfflpiy

~ po ~~hu1dow~ol thW huvV~u C )U~ ~s reasunable denop a

'3/4 edp3o~ ;Grw a~oras hum fu~ poser ad W4~ '$~u) haUengn ig plant syst~n ~s naIaaoi~ A ~ao no b~c ~*s y temsdreano~urab UH~ ~; deteamanee anopet able 1ui~ reasons other than Condltbon A, the unit rau Pe ~a ~n DEanwra eLCOdoesnotapply. T ieve ha L 1 ian rn p ma MQ&E3w l2hours

~ dM0) 4 thin hours Th al Comp ionWnesare Columbia Generating Station B 3.7.1-5 Revision 73

SW System and UHS B 3.7.1 sal.ae

, on oprtm*,pene to iec the reqwed plan SURVEILLANCE 3..11 REQUIREMENTS Verfication of the UHS spray pond level ensures adequate long term (30 days) cooling can be maintained. The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency Is based on operating experience related to trending of the parameter variations during the applicable MODES.

Verification of the UHS spray pond temperatureensures that the heat removal capability of the SW System I within the assumptions of the DBA analysis. The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency Is based on operating experience related to trending of the parameter variations during the applicable MODES.

Verifying the correct alignment for each manual, power operated, and automatic valve Ineach SW subsystem flow path provides assurance that the proper flow paths will exist for SW operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since these valves were verified to be in the correct position prior to locking, sealing, or securing. A valve is also allowed to be Inthe nonaccident position and yet considered Inthe correct position, provided it can be automatically realigned to its accident position within the required time.

This SR does not require any testing or valve manipulation; rather, it involves verification that those valves capable of potentially being mispositioned are Inthe correct position. This SR does not apply to valves that cannot be Inadvertently misaligned, such as check valves.

Columbia Generating Station B 3.7.1-6 Revision 73

SW System and UHS B 3.7.1 BASES REFERENCES 1. Regulatory GUld f.27, Revision 1, March 1974.

2. FSAR, Sections 9.2.5 and 9.2.7.

3. FSAR, Table 9.2-5.

4. FSAR, Section 6.2.2.3.

5. FSAR, Chapter 15.

6. FSAR, Table 6.2-2.

7. 10 CFR 50.36(c)(2)(i).

0 NEDC32 A* Rson 2I T *Ju e o pgrRsk, Columbia Generating Station B 3.7.1-8 Revision 73

CREF System B 3.7.3 BASES ACTIONS (continued)

Ifthe unfltered 4dbilsk of potentially contaminated air pas the CRE boundwy ad Into the ORE can result InGRE occupant radiological dose geater than Ihe aflcltd dose of do len*i basis anas of OBA conseuences (allowd fobe up W6 mm TEDE). or inaxMr bs p t d CRofoccupesfm tazardos chemicals or smoke, Oie GRE boundayiIs inpre Actions must e taken to restore an OPERABLE CRE boundary wi0hin 90 dys.

During the period OW lhe CRE bounday Isco.sideredinopeftbie action must be Initiated to implement mitiga actions to lhsn dS esct on CRE occupants fom the potea hazards of

radogc or dchmical event or a challenge fom smoke. Actions must be tkem wIthin 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months to verify that in the event of a DOA, the mitga actions will ensure that CRE occupW diologica expos will not exceed the Calulated dose of the licensing bess analyses of DBA comequences, end that CRE occupants a protected torn hazardous chemicals nd smok. These mitigating actions (i.e., actions Wt are tamn to offset the onsequences of the inoperable CRE boundary) should be preplanned for Imptnelmnaion upon entry into the condition, regardless ofwhether entry Is intentlonal or unintentional. The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Compli Time Is reasonable based on the low probability of a DBA occunig durking this tme period, and the use of nitat actions. The 90 day Completion Time is reasonable based on the determineaon that the mitigating actions will ensure protection of CRE occupanis within ansayzed limits while limiting the probability that CRE occupants will have to irplement protective measures Ott may adversely affect their ability to control the reactor mnd maintain It in a safe shutdown condition in the event of a DBA. In addition, the 90 day Completion Time is a reasonable time to diagnose, plan and possibly repair, and test most problems with the CRE boundary.

In MODE 1, 2, or 3, if the inoperable CREF subsystem or CRE boundary cannot be restored to OPERABLE status within the required Completion Time, the unit must be placed In a MODE that minizs.

piant risk. To achieve this stafus, the unit must be placed In at least MODE 3 within 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months s-- -

Remsaing inthe Apphclity of #e LCO is accptale because fe plant in MODE 3iito o r ta e riskeInMOOE 4 (Re. 10) and because the fi-me spent in MOVE 3 to perform the necessary repais, RevIsion 73 Columbia Generating Station B 3.7.3-4 Revision 73 Columbia Ganerating SUrtion B 3.7.3-4

CREF System B 3.7.3 BASES ACTIONS (continued) tosre the sy ' to P E stus wit be However, Mu na y tnWOF'O 4 may be ma ad is also an Required A-o Ca (i is modified by a Note tha ts that, 1Ot LCO 3 0,4 a 1s wen ~~ngMOO 3.This Note proýhAAs the use of not pplcabe CL) .0A.4a to ent MOD 3 di wi t LCO not met H~cev- there f,- nores c on tt* use of LCD' 30b,4h ifappliable, becaus CD 3.0.4 b requiLms erfomrs of a uisk assment ng lstomp ts, conaleng i of tle s, d vnion -f the acceIty of d torfn MODE 3, and lshmen of nsk nm en aeo", if apmprats. LLC( 3.0.4 is rno app*W to~, aid ft t~4of:des =o pmdude, cw~es in MODES or ofth sedfld aonddkm In. to fihj&tat are required to cowi~y wMt CTfONS or OWam Ea st of vno #efl unit.

The* dowed Com tiT e. am iseeonftle, based on operatn ewxeli.'e, to reach the requkrd urn conditions from f power nMiWIS Wan otdey mnmwr Wd wthou"*Inn junlt systems.

Durng OPORVs, ifthe inoperable CREF sbstem cannt be resored to OPERABLE status win the required Competon Time, the OPERABLE CREF subsystem may be placed inthe p mode.

This action ensures that the remaining subsystem Is OPERABLE, that no faures tht would prevent automatic actuation wil occur, and that any ctive failure will be readily detecd.

An alternative to Required Action D.A Is to immediately suspend OPDRVs to minimize the probability of a vessel dreindon and subsequent

....* dr fission prodWrelease. Actions must continue until the OPDRVs are suspended.

Ifboth CREF subsystems are inoperable In MODE 1, 2, or 3, for reasons other than an inoperable CRE boundary (i.e., Condition B) the CREF System may not be capable of performing the intended function and the unit is in a condition outside of the accident analyses.

4440~~ Therefore, the plant must be brought o MODE* t$wcibh the overai Plant risk I-s mirkmized To ach;ev t'his sths, t pant must be bro*ght to at least MODE 3 whiin 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

.3-5 .. e...sion...73 C lumbi GeneraItInI .

Stat*JioB ...

Columbia Generating Station B 3.7.3-6 Revision 73

CREF System B 3.7.3 BASES ACTIONS (continued)

Remel rig in te Aplabky of the LCO is accptebe bauae tie plant skMO In 3 is fn toor thente sk in MW 4 (Ref. 10) arid because th bin sp*et in MODE 3 to peufm tie necissary repa*s toretos hesystem to OPERABLf. stas w;,M be ~-Hout er, tary mo OE 4 mbemaes0 s also an

-cetatlow fAk state ReuredAcbmE I mmodifed by aNotp thaltMtesthat LCO 304.i IC30A* to enter MODE 3 durng stý ttwi v1h the 100 not met.l Hee, tir is no rmo onth use of LC 3~0A4b, if sp *,

~LCO 3.0 4*b requ*ss pefomance of a 4s assessment adc~ssou4 vlnoperabl system~s andA c-won&onms, ronslderoo' of the res~I, dtemiatin f te ccptabiity of wierig MO 3,and

-xet na risk appropte LCO 3 CA is no ~cb~c o, ti Not d noprecude, changes, in M~OMS or oith Aer spelleý cond areit- A cabiwty htaerqr ocml Thie aloe Coleion Tim is b*e on

,esnbe *w*rg s an O Sd y maie andthut chlegigpat syStes.

During OPDRV*, with two CREF subsystems inoperable or with one or more CREF subsystems inoperable due to an Inoperable CRE boundary, action must be taken Immedatly to suspend OPORVs to minimize the probability of a vese drslndov and subsequent potential for fson product release. Action must continue until the OPDRVs are suspended.

SURVEILLANCE 3J.1 REQUIREMENTS Opera*n* (from the control room) each CREF subsystem for Ž10 continuous hours ensures that both subsystems are OPERABLE and that all associated controls are functioni property. It also ensures that

-t*elta, fan Winotor Miure, or excessive vibration can be detected for corrective action. Operation with the heaters on (automatic heater cycling to maintain humidity) for LŽ 10 continuous hours every 31 days reduces moisture on the adsorbers and HEPA filters. The 31 day Frequency was developed in consideration of the known reliability of fan motors and controls and the redundancy available in the system.

Staton 1 IIII 3.7.31 IRI II " Il IInI 82 Columbia enerating Columbia Generating Station B83.7.3-6 Revision 82

CREF System 83.7.3 BASES SURVEILLANCE REQUIREMENTS (continued) compenmtoy measures may also be used as mitgating actions as required by Required Action 8.2., Temporary analyt methods may also be used as comlpensatoy* measures to restore OPERABILITY (Ref. 9).

Options for restoing the CRE boundary to OPERABLE status Include chaging the bases oBA onu analysis, repairing the CRE boundary, or S combination of thes actions. Depending upon the nature of the problem and the cwecdve action, a ful scope inleekage test may not be necessary to establish tWt the CRE boundary has been restored to OPERABLE status.

REFERENCES 1. FSAR, Section 6.4.1.

2. FSAR, Section 9.4.1.

3. FSAR, Chapter 6.

4. FSAR, Chapter 15.

5. FSARI Section 6.4.

6. FSAR, Section 0.5:

7. ReguiatoryaG~we 1.196, May 2003.

8. NE1 99-03, "Control Room Habitability Assessment," June 2001.

9. Letter from Eric J. Leeds (NRC) to James W. Davis (NEI) daled January 30,2004, "NEI Draft White Paper, Use of Generic Letter 91-18 Process and Alternatis Souros Terms in we Context of Control Room Habitability.- (ADAMS Accession No.,

ML04030069).8ASES L1..... .. - A R vis... 2,ITec-ý-JCal

.k.a.... to ..& 4 . Risl-jodfwcaln to Saected Requwed krifrrne End Stabs for 13R P~arf~ December2002 37.-8Re .II IJIIII l iso 73-Coum i GeneratII I Sttin ingI llllllllllll!!!llIJI Columbia Generating Station B 3.7.3-8 Revision 73

Control Room AC System 83.7.4 BASES ACTIONS .1 With one contr room AC siumperabe, thoInoperable control room AC subsystem must be restored to OPERABLE stmus within 30 days. With the unit inthio condition, the remaining OPERABLE control room AC subsystem isadequate to pefom the control room air cooxnditnn function. However, the overall reliability Isreduced because a single fabr in Ve OPERABLE subsystem could result in loss of the conrol room air condltioning function. The 30 day Completion Time Is based on Oi low probability of an event occurring requiring conrol room Isolation, the = nsIderation tW the remaining subsystem can provde the required protection, and 1he availabIlity of alternate cooling methods.

If both conrol room AC subsystems we ino , the Control Room AC System may not be capable of performing Its ftended function.

Therefore, the ontrol rom area temperakure is required to be monitored to ensure Ot temperature Is being maintainsd low enough that equipment inthe omtol room is not adversely affected. With the control room temperature being maintained Wiin te temperature limit, 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Is allowed to restore a Control Room AC subsystem to OPERABLE status. This Co mp Time is eo eonslerg that the control room temperature Is being mintained within limits and the low probability of an event occurring requiring control room lslation.

In MODE 1, 2, or 3, Nfthe inoperable control room AC subsystem(s) cannot be restored to OPERABLE status within the associated Completion Tim, the unit must be placed In a MODE that minimies risk. To.adve this status the unit must be placed In at least MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

t beus te t~rne spen in M~)3 to pelorhe neessy repr to systeni to OPERA&E sttu w be shr. Hcsetr,

&~ioete vunAy inMiEýabmds, a a not

~ e ~er1gMODE- 3.T')otpoiblsteueo ea 104 re e 1resfa Columbia Generating Station B 3.7.4-3 Revision a81

Control Room AC System 83.7.4 BASES ACTIONS (continued) 1 **

LXO 3,04 T~wallwedCoy~leon t ad reas)Oon", bxas*ed ton of tera everience, to reach the required unit conditons from full pow conditions inan orderly mnner and wio challenging unk systems.

During OPORVs, NRequired Action A.1 cannot be oompieed withi the requ- d Coneition Time, the OPERABLE contor room AC subystem may be paeWd immediately in operation. This action ensuresthat the remaining subsystem IsOPERABLE, that no failures that would prevent actuation wi occur, and that any active failure will be readily detected.

An alternative to Required Action D.A Is to irmmediately suspend OPDRVs to minimize the probability of a vessel draindown and subsequent potential for fission product release. Action must continue until the OPDRVs are suspended.

Ell During OPDRVs INRequired Actions B.1 and 8.2 cannot be met within the required Completion Times, action must be taken to immediately suspend OPDRVs to minimize the probability of a vessel draindown and subsequent potential for fission product release. Action must continue until the OPDRVs are suspended.

SURVEILLANCE SR3...1 REQUIREMENTS This SR verifies that the heat removal capability of the system is sufficient to remove the control room heat load assumed In the safety analyses.

The SR consists of a combination of testing and calculation. The 24 month Frequency Is appropriate since significant degradation of the Control Room AC System Is not expected over this time period.

Columbia Generating Station B 3.7.4-4 Revision 81 I

Control Room AC System 83.7.4 BASES REFERENCES I. FSAR, Section 6.4.

2. FSAR, Section 9.4.1.

3. 10 CFR 50.36(c)(2X)().

4 I BI 3.7.4 l I lil II Rev i o 8 CI lumbiag I netig Ii Stat n Columbia Generating Station B 3.7.4-5 Revision 81

Main Condenser Offgas B 3.7.5 BASES ACTIONS Al Ifthe offgas radioactivity rate limit Is exceeded, 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Is allowed to restore the gross gamma activity rate to within the limit. The 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Completion Time Isreasonai*e, basd on engineering udgment considering the time e#red to complete Ne ReuiW Action, the large margins associated with permissfb dose and exposure limis, and the low probability of a Main Condenser Offgas System failure occurng.

Ifthe gross gamma acty rate is not restored to within the limits within the associated Completio Time, all main steam lines or the SJAE must be Isolated. This isolas theMain Condenser Offgas System from significant sources of radioactive steam. The main sterm lines are consdered isolated If it least one main steam Isolation valve in each main steanm ine Is closed, and at least one main steam line drain valve In each drain fine Is closed. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Completion Time is reasonable, based on operating experience, to perform the actions from full power conditions Inan ordeuly manner and without challenging unit systems.

An alternative to Required Actions 0.1 and B.2 Is to place the unit in a MODE in which a'i p1nr ik ts rr z.

P.... To achieve this status, the unit must be placed Inat least MODE 3 within 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months si 4 H~ete

ze~r o te4 )L

c O 3 0a4b #eath~t becauae4 C ruin rf~o~a~ mf 11 r vddunayervr nn OL*ye ri a*tecr p as s alo sean~

(I~t1rO 4cepta E ýti p~lt 40 teoe

,hea *Mi *3 Flequtin *u No* yhal ates LCO1o4 Columbia Generating Station B 3.7.5-2 Revision 73 I

Main Condenser Offgas B 3.7.5 The allowed Completion Time reasonable, based on operating experience, to reach the required unit conditions from full power conditions Inan orderly manner and without challenging unit systems.

SURVEILLANCE SR 3.7.5.1 REQUIREMENTS This SR, on a 31 day Frequency, requires an Isotopic analysis of an offgas sample (taken at the discharge of the main condenser air ejector prior to dilution) to ensure that the required limits are satisfied. The noble gases to be sampled are Xe-133, Xe-135, Xe-138, Kr-85, Kr-87, and Kr-88. Ifthe measured rate of radioactivity increases significantly (by k 50% after correcting for expected increases due to changes in THERMAL POWER), an isotopic analysis Is also performed within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after the increase Is noted, to ensure that the increase is not indicative of a sustained increase in the radioactivity rate. The 31 day Frequency is adequate in view of other insftumentatlon that continuously monitor the offgas, and is acceptable based on operating experience.

This SR is modified by a Note indicating that the SR is not required to be performed until 31 days after any main steam fine Is not Isolated and the SJAE is in operation. Only in this condition can radioactive fission gases be in the Main Condenser Offgas System at significant rates.

Columbia Generating Station B 3.7.5-3 Revision 73

Main Condenser Oftgas B 3.7.5 BASES REFERENCES I. FSAR, Section 11.3.

2. NUREG-0800.

3. 10 CFR 50.67, "Accident Source Term.-

4. 10 CFR 50.36(c)(2)(ii).

4 ~3 oA R*vJc m T na* Ju ai 'o orevR i

Columbia Generating Station B 3.7.5-4 Revision 73

AC Sources - Operating B 3.8.1 BASES ACTIONS (continued)

F.1 I If the inoperable AC electrical power sources cannot be restored to OPERABLE status within the associated Completion Time, the unit must be brought to a MODE In which ovoII nt r To achieve this status, the unit must be brought to MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months v*# a enuy*oMO 4a tmay

i* as s o an ca ds a.f

o* I 1aK& 0sesi*SMO 3 oepctstes*o ab LCO3.4

- oe** M[}: e*st* up w iC n@ .e Howa.va.~ t!e~e r ms wt*:c the te ot CC 3~0A b it *4)adbe auausa aLrO 3.04 tb eq<r-s p1ortance~ d ~a isk4 a::sessrt ae**

O a n -* cetabr~ o

rie

03 4as esta ento. *s 'S> ret a~os*p pa aye LCOn304 w ACt ofa KN fasuto*d ÷u l The allowed Completion Time reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.

G.1 Condition 0 corresponds to a level of degradation in which all redundancy In the AC electrical power supplies has been lost. At this severely degraded level, any further losses In the AC electrical power system will cause a loss of function. Therefore, no additional time is justified for continued operation. The unit is required by LCO 3.0.3 to commence a controlled shutdown.

SURVEILLANCE The AC sources are designed to permit inspection and testing of all REQUIREMENTS Important areas and features, especially those that have a standby function, in accordance with 10 CFR 50, GDC 18 (Ref. 11). Periodic component tests are supplemented by extensive functional tests during refueling outages under simulated accident conditions. The SRs for Revision 73 Columbia Generating Station B 3.8.1-15 Columbia Generating Station B 3.8.1-15 Revision 73

AC Sources - Operating B 3.8.1 BASES REFERENCES 10 CFR 50, Appendix A, GDC 17.

2. FSAR, Chapter 8.

3. Deleted.

4. FSAR, Tables 8.3-1, 8.3-2, and 8.3-3.

5. Safety Guide 9, Revision 0, March 1971.

6. FSAR, Chapter 6.

7. FSAR, Chapter 15.

8. 10 CFR 50.36(c)(2)(l1).

9. Regulatory Guide 1.93, Revision 0, December 1974.

10. Generic Letter 84-15, July 2,1964.

11. 10 CFR 50, Appendix A, GDC 18.

12. Regulatory Guide 1.9, July 1993.

13. Regulatory Guide 1.108, Revision 1, August 1977.

14. Regulatory Guide 1.137, Revision 1, October 1979.

15. Calculations Nos. E/I-02-87-07 and 2-12-58.

16. ASME Code for Operation and Maintenance of Nuclear Power Plants.

17. IEEE Stndard 308-1974.

18. ANSI C84.1, 1982.

19. Letter, G02-13-043, "Request for Technical Specification Interpretation Regarding the Offsite Power Supplies to the Onsite Class I E AC Power Distribution System."

NES oA Rvsi 2, hnc Jus iat* to S rt Rsk*

rdm&r *{n to t Reugre

Sta fog B3WR Columbia Generating Station B 3.8.1-36 Revision 76

DC Sources - Operating B83.8.4 BASES ACTIONS (continued)

Ifthe Inoperable Division 1or Division 2 125 VOC electrical power subsystem cannot be restored to OPERABLE status within the associated Completion Tine, the unit must be brought to a MODE Inwhich the 4 ovra

~ p~ minrn~ ~.To achieve this status, the plant must be brought to at least MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Thenallowed Com~plect2ioTim ro:teaIO s soanable, baed onhoerpatng axeine to reac the reqire plan codtin frm ful power SURVEOLLANCE SR 3.8.4.1 theff ctiveness of the battery chrgers, whic supporttheabiit L of th04e In wic thechrger Is iorsupplying the continuous3charge rqire spltoe ovrom h internallssso a batr and maintai othebteyi te asoiae DCsbytm n flatcare bter clls 04lreev adeuat curre nat e to oprarty charg h batteory.

oTheunltag Thuiee nt Cmlion thme noiesna allowaed bldesig bolased on operbatieyng Vrercnifyint batter therminalu voltage whiltaeonelotcargeshelpsy toeensuere Revision 73 B3.8.4-8 Generating Station Columbia Generating Columbia Station B 3.8.4-8 Revision 73

DC Sources - Operating B 3.8.4 BASES REFERENCES I. 10 CFR 50, Appendix A, GDC 17.

2. Regulatory Guide 1.6, Revision 0, March 10, 1971.

3. IEEE Standard 308, 1974.

4. FSAR, Chapter 8.

5. Columbia Generating Station Calculation 2.05.01, Rev. 8, February 1990.

6. Columbia Generating Station Calculation EM 02-85-02, Rev. 1, April 1989.

7. FSAR, Chapter 6.

8. FSAR, Chapter 15.

9. 10 CFR 50.36(c)(2)(i).

10. Regulatory Guide 1.93, December 1974.

11. IEEE Standard 450,2002.

12. Regulatory Guide 1.32, February 1977.

NE*C A, eA o+ ca Just¢at to SuAe

+h '***+t a:e Re4+end Sat. o BWR ai+ +b {

Columbia Generating Station B 3.8.4-11 Rev. 73

Distribution Systems - Operating B 3.8.7 BASES ACTIONS (continued)

c. The potential for an event in conjunction with a single failure of a redundant component.

The 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months Completion Time for DC electrical power distribution subsystems is consistent with Regulatory Guide 1.93 (Ref. 4).

The second Completion Time for Required Action B. 1 establishes a limit on the maximum time allowed for any combination of required distribution subsystems to be inoperable during any single contiguous occurrence of failing to meet the LCO. IfCondition B is entered while, for instance, an AC bus is inoperable and subsequently returned OPERABLE, the LCO may already have been not met for up to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . This situation could lead to a total duration of 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months , since initial failure of the LCO, to restore the DC electrical power distribution system. At this time, an AC bus could again become inoperable, and DC electrical power distribution could be restored OPERABLE. This could continue indefinitely.

This Completion Time allows for an exception to the normal "time zero" for beginning the allowed outage time "clock." This allowance results in establishing the "time zero" at the time the LCO was initially not met, instead of the time Condition B was entered. The 16 hour1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months Completion Time is an acceptable limitation on this potential of failing to meet the LCO indefinitely.

I If the inoperable electrical power distribution system cannot be restored to OPERABLE status within the associated Completion Times, the plant must be brought to a MODE in which eaH plan ied. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 4 the A~Aicabdty ~i the I is acceptable becau~>~ the plani I in iA 3 is ~t~aku to Of ~ Ii the rist~ in ~<AOL)L~ 4 ij~hiI 5~i and

<i( ~ t~i~ ~n~e sp~r#t in MQ~J& I ~~torm the necessary repairs to a to& sy~;l~ io is wd~ be shuti Howevc~,

i~iTh1fy ~ ~ .~t ~v~0OE 4 ma be ri~e as it ~s J~o an I~qLdre~> Actior~ Cu ~'i moditied b~1 a N(~to that states that LCO 3~OA a is

~ 2. 0 3 Thi eproh~ the o Q~ ~ o~reM0DE3 ~ rt 100 m how. r in ur~duon u~> LOO OAb Icab b u~e Q304 ii ci n~ a an k e~ merit al as in no r I ystem a co cm s nat.ono#the RevIsion 73 Columbia Generating Station B 3.8.7-6 Columbia Generating Station B 3.8.7-6 Revision 73

Distribution Systems - Operating B 3.8.7

e:sts*Jt*rmflat otuh ac~i tybof entermn* !*AO 3, and e~ >snTab emotnrsk mi*a*g nt a¢*{ t*apro tae. LC&) 304ri not *: iea*to anth Note dces ho*

ci-e0 chan~es qir*DOES

<:t6 C*Iido*t ** t* *Apphcb tytyiat areqruiredt ou~pt, SATION-S of hat ars pal a~ htt wnoltheunit The allowed Completion Time - reasonable, based on operating experience, to reach the required plant conditions from full power conditions inan orderly manner and without challenging plant systems.

Q1d With the Division 1250 VDC electrical power distribution subsystem Inoperable, the RCIC System and other associated supported features are not capable of performing their Intended functions. Immediately declaring the RCIC System and other associated supported features Inoperable allows the ACTIONS of the associated LCOs to apply appropriate limitations on continued reactor operation.

Columbia Generating Station B 3.8.7-7 Revision 73

Distribution Systems - Operating B 3.8.7 BASES ACTIONS (continued)

L.

With the Division 3 electrical power distribution system inoperable, the Division 3 powered systems are not capable of performing their intended functions. Immediately declaring the High Pressure Core Spray System inoperable allows the ACTIONS of LCO 3.5.1, "ECCS - Operating, to apply appropriate limitations on continued reactor operation.

F.1 Condition F corresponds to a level of degradation in the electrical power distribution system that causes a required safety function to be lost.

When more than one Condition Is entered and this results in the loss of a required function, the plant is In a condition outside the accident analysis.

Therefore, no additional time Is justified for continued operation.

LCO 3.0.3 must be entered immediately to commence a controlled shutdown.

SURVEILLANCE SR 3&8,1I REQUIREMENTS This Surveillance verifies that the AC and DC electrical power distribution systems are functioning properly, with the correct circuit breaker alignment. The correct breaker alignment ensures the appropriate separation and Independence of the electrical divisions is maintained, and power is available to each required bus. The verification of energization of the buses ensures that the required power is readily available for motive as well as control functions for critical system loads connected to these buses. This may be performed by verification of absence of low voltage alarms or by verifying a load powered from the bus Is operating.

The 7 day Frequency takes into account the redundant capability of the AC and DC electrical power distribution subsystems, and other indications available in the control room that alert the operator to subsystem malfunctions.

REFERENCES 1. FSAR, Chapter 6.

2. FSAR, Chapter 15.

3. 10 CFR 50.36(cX2)(ii).

4. Regulatory Guide 1.93, December 1974.

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Columbia Generating Station B 3.8.7-8 Revision 73

LICENSE AMENDMENT REQUEST FOR ADOPTION OF TSTF-423, REVISION I PROPOSED TECHNICAL SPECIFICATION PAGES (CLEAN)

RPS Electric Power Monitoring 3.3.8.2 3.3 INSTRUMENTATION 3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring LCO 3.3.8.2 Two RPS electric power monitoring assemblies shall be OPERABLE for each inservice RPS motor generator set or alternate power supply that supports equipment required to be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, MODES 4 and 5 with both residual heat removal (RHR) shutdown cooling (SDC) suction isolation valves open, MODE 5 with any control rod withdrawn from a core cell containing one or more fuel assemblies.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or both required A.1 Remove associated 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inservice power supplies Inservice power supply(s) with one electric power from service.

monitoring assembly inoperable.

B. One or both required B.1 Remove associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Inservice power supplies Inservice power supply(s) with both electric power from service.

monitoring assemblies Inoperable.

C. Required Action and C.1 -...-------- NOTE ............

associated Completion LCO 3.0.4.a is not Time of Condition A or B applicable when entering not met in MODE 1, 2, MODE 3.

or 3. .. ..

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months I

Columbia Generating Station 3.3.8.2-1 Amendment No. 440,440 225 1

SRVs - < 25% RTP 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.4 Safety/Relief Valves (SRVs) - < 25% RTP LCO 3.4.4 The safety function of four SRVs shall be OPERABLE.

APPLICABILITY: MODE I with THERMAL POWER < 25% RTP, MODES 2 and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required SRV AL ...-- NOTE ---........

n------

inoperable. LCO 3.0.4.a Is not applicable when entering MODE 3.

Be In MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months B. Two or more required 8.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SRVs Inoperable.

AND B.2 Be in MODE 4 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Columbia Generating Station 3.4.4-1 Amendment No. 440,460 225 1

ECCS - Operating 3.5.1 ACTIONS _-

CONDITION REQUIRED ACTION COMPLETION TIME C. Two ECOS injection C.1 Restore ECCS 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months subsystems inoperable, injection/spray subsystem to OPERABLE status.

98 One ECCS Injection and one ECCS spray subsystem inoperable.

D. Required Action and D.1 ...........

ANOTE-.........-

associated Completion LCO 3.0.4.a is not Time of Condition A, B, applicable when entering or C not met. MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months E. One required ADS valve EA Restore ADS valve to 14 days inoperable. OPERABLE status.

F. One required ADS valve F.1 Restore ADS valve to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. OPERABLE status.

AND OR One low pressure ECCS F.2 Restore low pressure 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months injection/spray ECCS injection/spray subsystem inoperable, subsystem to OPERABLE status.

Columbia Generating Station 3.5.1-2 Amendment No. 449,469 225 1

ECCS - Operating 3.5.1 ACTIONS __

CONDITION REQUIRED ACTION COMPLETION TIME G. Required Action and GA.1 ............NOTE------.-

associated Completion LCO 3.0.4.a is not Time of Condition E or F applicable when entering not met. MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Two or more required ADS valves Inoperable.

H. HPCS and Low H1A Enter LCO 3.0.3. Immediately Pressure Core Spray (LPCS) Systems Inoperable.

QR Three or more ECCS Injection/spray subsystems inoperable.

HPCS System and one or more required ADS valves inoperable.

Two or more ECCS injection/spray subsystems and one or more required ADS valves inoperable.

Columbia Generating Station 3.5.1-3 Amendment No. ..440,44 225 1

RHR Drywell Spray 3.6.1.5 3.6 CONTAINMENT SYSTEMS 3.6.1.5 Residual Heat Removal (RHR) Drywell Spray LCO 3.6.1.5 Two RHR drywetl spray subsystems shall be OPERABLE.

APPLICABILITY: MODES 1,2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR drywefl spray A.1 Restore RHR drywell spray 7 days subsystem inoperable, subsystem to OPERABLE status.

B. Two RHR drywell spray 8.1 Restore one RHR drywell 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months subsystems Inoperable, spray subsystem to OPERABLE status.

C. Required Action and C.1 -------- NOTE-.-----....

associated Completion LCO 3.0.4.a Is not Time not met. applicable when entering MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.61.5.1 Verify each RHR drywell spray subsystem manual, 31 days power operated, and automatic valve In the flow path that is not locked, sealed, or otherwise secured In position, is in the correct position or can be aligned to the correct position.

Columbia Generating Station 3.6.1.5-1 Amendment No. 449,469 225 1

Reactor Building-to-Suppression Chamber Vacuum Breakers 3.6.1.6 3.6 CONTAINMENT SYSTEMS 3.6.1.6 Reactor Building-to-Suppression Chamber Vacuum Breakers LCO 3.6.1.6 Each reactor building-to-suppression chamber vacuum breaker shall be OPERABLE.

APPLICABILITY: MODES 1,2, and 3.

ACTIONS a'.qlt-

^

s.... -. .. nj~LJ I I Separate Condition entry Is allowed for each line.

. . ..... ee-

. . . . . .II

.- .- . .. II II I. . .I I .

CONDITION REQUIRED ACTION COMPLETION TIME A. One or-more lines with A.1 Close the open vacuum 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months one reactor building-to- breaker.

suppression chamber vacuum breaker not closed.

B. One or more lines with B.1 Close one open vacuum 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months two reactor building-to- breaker.

suppression chamber vacuum breakers not closed.

C. One line with one or C.1 Restore the vacuum 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months more reactor building-to- breaker(s) to OPERABLE suppression chamber status.

vacuum breakers inoperable for opening.

D. Required Action and .1 ------..----- NOTE --....-----

associated Completion LCO 3.0.4.a is not Time of Condition C applicable when entering not met. MODE 3.

Be In MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

Columbia Generating Station 3.6.1.6-1 Amendment No. 449,460 225 1

Reactor Building-to-Suppression Chamber Vacuum Breakers 3.6.1.6 ACTIONS '__

CONDITION REQUIRED ACTION COMPLETION TIME E. Two or more lines with E.1 Restore all vacuum 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months one or more reactor breakers in two lines to building-to-suppression OPERABLE status.

chamber vacuum breakers inoperable for opening.

F. Required Action and F.1 Be In MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A, B AN or E not met.

F.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.6.1 ------ ------ ....... NOTES-----

1. Not required to be met for vacuum breakers that are open during Surveillances.

2. Not required to be met for vacuum breakers open when performing their intended function.

Verify each vacuum breaker is closed. 14 days SR 3.6.1.6.2 Perform a functional test of each vacuum breaker. In accordance with the Inservice Testing Program SR 3.6.1.6.3 Verify the full open setpoint of each vacuum breaker 24 months Is < 0.5 psid.

Columbia Generating Station 3.6.1.6-2 Amendment No. ..44,46. 225 1

Suppression Chamber-to-Drywell Vacuum Breakers 3.6.1.7 3.6 CONTAINMENT SYSTEMS 3.6.1.7 Suppression Chamber-to-Drywell Vacuum Breakers LCO 3.6.1.7 Seven suppression chamber-to-drywell vacuum breakers shall be OPERABLE for opening.

Nine suppression chamber-to-drywell vacuum breakers shall be closed, except when performing their intended function.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required A.1 Restore one vacuum 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months suppression chamber-to- breaker to OPERABLE drywell vacuum breaker status.

inoperable for opening.

B. Required Action and B.1 ------- ----- NOTE-------------

associated Completion LCO 3.0.4.a is not Time of Condition A applicable when entering not met. MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months C. ............ NOTE ----.-.-- C.1 Close the open vacuum 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months I Separate Condition entry breaker disk.

is allowed for each suppression chamber-to-drywell vacuum breaker.

One or more suppression chamber-to-drywell vacuum breakers with one disk not closed.

Columbia Generating Station 3.6.1.7-1 Amendment No. 40,4-0A 225 1

Suppression Chamber-to-Drywell Vacuum Breakers 3.6.1.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. One or more D.1 Close one open vacuum 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months suppression chamber-to- breaker disk.

drywell vacuum breakers with two disks not closed.

E. Required Action and E.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition C orDD not met.

E.2 Be In MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months I SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.7.1 .- NOTE Not required to be met for vacuum breakers that are open during Surveillances.

Verify each vacuum breaker is closed. 14 days SR 3.6.1.7.2 Perform a functional test of each required vacuum 31 days breaker.

Within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after any discharge of steam to the suppression chamber from the safety/relief valves SR 3.6.1.7.3 Verify the full open setpoint of each required 24 months I II I vacuum II breaker is_< 0.5 psid. I I IN Columbia Generating Station 3.6.1.7-2 Amendment No. 460,202 225

RHR Suppression Pool Cooling 3.6.2.3 3.6 CONTAINMENT SYSTEMS 3.6.2.3 Residual Heat Removal (RHR) Suppression Pool Cooling LCO 3.6.2.3 Two RHR suppression pool cooling subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

. CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR suppression A.1 Restore RHR suppression 7 days pool cooling subsystem pool cooling subsystem to inoperable. OPERABLE status.

B. Required Action and B.1 .-----.-.-- NOTE -............

associated Completion LCO 3.0.4.a is not Time of Condition A not applicable when entering met. MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months C. Two RHR suppression C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months pool cooling subsystems inoperable. AND C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Columbia Generating Station 3.6.2.3-1 Amendment No. 440,4.69 225 1

Secondary Containment 3.6.4.1 3.6 CONTAINMENT SYSTEMS 3.6.4.1 Secondary Containment LCO 3.6.4.1 The secondary containment shall be OPERABLE.

APPLICABILITY: MODES 1,2, and 3, During operations with a potential for draining the reactor vessel (OPDRVs).

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Secondary containment A.1 Restore secondary 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months inoperable in MODE 1, containment to OPERABLE 2, or 3. status.

B. Required Action and, B1. --.... .NOTE------.

associated Completion LCO 3.0.4.a is not Time of Condition A not applicable when entering met. MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months C. Secondary containment CA Initiate action to suspend Immediately Inoperable during OPDRVs.

OPDRVs.

Columbia Generating Station 3.6.4.1-1 Amendment No. 46Q.194 225 1

SGT System 3.6.4.3 3.6 CONTAINMENT SYSTEMS 3.6.4.3 Standby Gas Treatment (SGT) System LCO 3.6.4.3 Two SGT subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, During operations with a potential for draining the reactor vessel (OPDRVs)..

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SGT subsystem A.1 Restore SGT subsystem to 7 days Inoperable. OPERABLE status.

B. Required Action and B.1 --.....------ NOTE----------

associated Completion LCO 3.0.4.a Is not Time of Condition A not applicable when entering met In MODE 1, 2, or 3. MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months C, Required Action and C.1 Place OPERABLE SGT Immediately associated Completion subsystem In operation.

Time of Condition A not met during OPDRVs. OR C.2 Initiate action to suspend Immediately OPDRVs.

D. Two SGT subsystems D.1 ------------ NOTE ...............

Inoperable in MODE 1, LCO 3.0.4.a is not 2, or 3. applicable when entering MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Columbia Generating Station 3.6.4.3-1 Amendment No. 4-69,49 225 1

SW System and UHS 3.7.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 .....-........ NOTE -.....-----

associated Completion LCO 3.0.4.a Is not Time of Condition B not applicable when entering met. MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months D. Required Action and D.1 Be In MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A not met. AM 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR D.2 Be in MODE 4. I Both SW subsystems inoperable.

OB UHS inoperable for reasons other than Condition A.

SURVEILLANCE REQUIREMENTS *___,__.

SURVEILLANCE FREQUENCY SR 3.7.1.1 Verify the water level of each UHS spray pond Is 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

> 432 ft 9 Inches mean sea level.

SR 3.7.1.2 'Verify the average water temperature of each UHS 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months spray pond is < 77 0 F.

Columbia Generating Station 3.7.1-2 Amendment No. 449,4.8 225 1

CREF System 3.7.3 ACTIONS ....

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 -A....NOTE---..-

associated Completion LCO 3.0.4.a is not Time of Condition A or B applicable when entering not met in MODE 1, 2, MODE 3.

or 3.

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months D. Required Action and DA Place OPERABLE CREF Immediately associated Completion subsystem In pressurization Time of Condition A not mode.

met during OPDRVs.

OR D.2 Initiate action to suspend Immediately OPDRVs.

E. Two CREF subsystems E.1 ........--- NOTE-........

inoperable In MODE 1, LCO 3.0.4.a is not 2, or 3 for reasons other applicable when entering than Condition B. MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months F. Two CREF subsystems F.1 Initiate action to suspend Immediately inoperable during OPDRVs.

OPDRVs.

OR One or more CREF subsystems Inoperable due to Inoperable CRE boundary during OPDRVs.

Columbia Generating Station 3.7.3-2 Amendment No. 07,2.146 225 1

Control Room AC System 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Control Room Air Conditioning (AC) System LCO 3.7.4 Two control room AC subsystems shall be OPERABLE.

APPUCABILITY: MODES 1, 2, and 3, During operations with a potential for draining the reactor vessel (OPORVs).

ACTIONS

-CONDITION REQUIRED ACTION COMPLETION TIME A. One control room AC AI1 Restore control room AC 30 days subsystem inoperable, subsystem to OPERABLE status..

B. Two control room AC 5.1 Verify control room area Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months subsystems Inoperable. temperature c 90"F.

8.2 Restore one control room 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AC subsystem to OPERABLE status.

C. Required Action and C.1 ------- NOTE -....------

associated Completion LCO 3.0.4.a Is not Time of Condition A or B applicable when entering not met In MODE 1, 2, or MODE 3.

3.

Be InMODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Columbia Generating Station 3.7.4-1 Amendment No. 46,,409 2*6-227

Main Condenser Offgas 3.7.5 3.7 PLANT SYSTEMS 3.7.5 Main,Condenser Offgas LCO 3.7.5 The gross gamma activity rate of the noble gases measured at the main

-condenser air ejector shall be < 332 mCi/second after decay of 30 minutes.

APPUCABIUTY: MODE 1, MODES 2 and 3 with any main steam tine not Isolated and steam jet air ejector (SJAE) in operation.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Gross gamma actity A.1 Restore gross gamma 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months rate of the noble gases activity rate of the noble not within limit. gases to within limit.

B. Required Action and 6.1 Isolate all main steam Oines. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met.

B.2 Isolate SJAE. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 8.3 ............ NOTE ..-..........

LCO 3.0.4.a is not applicable when entering MODE 3 Be InMODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Columbia Generating Station 3.7.5-1 Amendment No. 44,,409 225 1

AC Sources - Operating 3.8.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME F. Required Action and F.1 .......... NOTE-associated Completion LCO 3.0.4.a is not Time of Condition A, B, applicable when entering C, D, or Enot met. MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months G. Three or more required G.1 Enter LCO 3.0.3. Immediately AC sources Inoperable.

SURVEILLANCE REQUIREMENTS "

SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and Indicated 7 days power availability for each offsite circuit.

SR 3.8.1.2 -------- ....

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

1. All DG starts may be preceded by an engine prelube period and followed by a warmup period pr!or to loading.

2. A modified DG start involving idling and gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer. When modifled start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.7 must be met.

Verify each required DG starts from standby 31 days conditions and achieves steady state:

a. Voltage > 3910 V and <4400 V and frequency

> 58.8 Hz and < 61.2 Hz for DG-I and DG-2; and

b. Voltage > 3910 V and <4400 V and frequency Columbia Generating Station 3.8.1-5 Amendment No. 4W9,484. 225 1

DC Sources - Operating 3.8.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME H. Required Action and H.1 Declare High Pressure Immediately associated Completion Core Spray System Time of Condition B or E Inoperable.

not met.

Division 3 DC electrical power subsystem inoperable for reasons other than Condition B or E.

1. Required Action and 1.1 Declare associated Immediately associated Completion supported features Time of Condition C or F Inoperable.

not met.

Division 1 250 V DC electrical power subsystem inoperable for reasons other than Condition C or F.

J. Required Action and J. ............... NOTE --....------

associated Completion LCO 3.0.4.a is not Time of Condition A or D applicable when entering not met. MODE 3.

OR Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Required Action and associated Completion Time of Condition G not met.

Columbia Generating Station 3.8.4-3 Amendment 460,2G4 225 1

Distribution Systems - Operating 3.8.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and CA -N --NOTE associated Completion LCO 3.0.4.a Is not Time of Condition A or 8 applicable when entering not met. MODE 3.

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months D. Division 1250 V DC 0.1 Declare assocated Immediately electrical power supported fature(s) distribution subsystem inoperable.

inoperable.

E. One or more Division 3 E.1 Declare High Pressure Immediately AC or DC electrical Core Spray System power distribution Inoperable.

subsystems Inoperable.

F. Two or more divisions F.A Enter LCO 3.0.3. Immediately with inoperable electrical power distribution subsystems that result in a loss of function.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct breaker alignments and indicated 7 days power availability to required AC and DC electrical power distribution subsystems.

Columbia Generating Station 3.8.7-2 Amendment 440,460 226 1

v t e Letter Sequence Request
TAC:MF4616, Technical Specifications End States, NEDC-32988-A (Open)
Initiation Request Acceptance... Administration Questions 9 March 2015 Answers 3 April 2015 Results Approval... Other:
MONTHYEAR2015-03-09 [Table View]

ML14234A457

Text

Subject:

Dear Sir or Madam:

3.0 REGULATORY ANALYSIS

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