Text

Issuance of Renewed Facility Operating License No. NPF-21 for Columbia Generating Station. Columbia Lr Ltr to Applicant
	ML12089A043
Person / Time
Site:	Columbia
Issue date:	05/22/2012
From:	Cunanan A; License Renewal Projects Branch 1
To:	Reddemann M; Energy Northwest
	Cunanan A, NRR/DLR, 415-3897
Shared Package
ML12089A042	List: ML12089A043; ML12089A090;
References
	Download: ML12089A043 (409)
	v • d • e

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 May 22,2012 Mr. Mark E. Reddemann Chief Executive Officer Energy Northwest P.O. Box 968 (Mail Drop 1023)

Richland, WA 99352-0968

SUBJECT:

ISSUANCE OF RENEWED FACILITY OPERATING LICENSE NO. NPF-21 FOR COLUMBIA GENERATING STATION

Dear Mr. Reddemann:

The U.S. Nuclear Regulatory Commission (NRC or the staff) has issued Renewed Facility Operating License No. NPF-21 for the Columbia Generating Station (Columbia). The NRC issued the renewed facility operating license based on the staff's review of your application dated January 19, 2010, as supplemented by letters submitted to the NRC through April 23, 2012. The technical specifications for Columbia were not amended as a result of the NRC's review.

Renewed Facility Operating License No. NPF-21 expires at midnight on December 20, 2043.

The technical basis for issuing the renewed operating license is set forth in NUREG-2123, "Safety Evaluation Report Related to the License Renewal of the Columbia Generating Station,"

May 2012. The results of the environmental review related to the issuance of the renewed license are given in NUREG-1437, Supplement 47, "Generic Environmental Impact Statement for License Renewal of Nuclear Plants, Regarding Columbia Generating Station," April 2012. contains Renewed Facility Operating License No. NPF-21 with attachments, Appendix A, "Technical Specifications," and Appendix B, "Environmental Protection Plan," and Appendix C, "Additional Conditions." is a copy of the related Federal Register notice of issuance of the renewed license.

The staff has sent the original to the Office of the Federal Register for publication.

M. Reddemann -2 If you have any questions regarding this issue, please feel free to contact me at 301-415-3897 or bye-mail at Arthur.Cunanan@nrc.gov.

Sincerely, Arthur Cunanan, Project Manager Projects Branch 1 Division of License Renewal Office of Nuclear Reactor Regulation Docket No. 50-397

Enclosures:

1. Columbia Generating Station Renewed Facility Operating License

2. Federal Register Notice of Renewed Facility Operating License cc: Listserv

Letter to Mark Reddemann from A. Cunanan dated May 22,2012

SUBJECT:

ISSUANCE OF RENEWED FACILITY OPERATING LICENSE NO. NPF-21 FOR COLUMBIA GENERATING STATION DISTRIBUTION:

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Enclosure 1 Columbia Generation Station Renewed Facility Operating License ML12089A090

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 ENERGY NORTHWEST DOCKET 50-397 COLUMBIA GENERATING STATION RENEWED FACILITY OPERATING LICENSE Renewed License No. NPF-21

1. The Nuclear Regulatory Commission (the Commission or the NRC) has found that:

A. The application for renewed license filed by Energy Northwest (also the licensee), complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's regulations set forth in 10 CFR Chapter I, and all required notifications to other agencies or bodies have been duly made; B. Construction of Energy Northwest, Columbia Generating Station (the facility) has been substantially completed in conformity with Construction Permit No.

CPPR-93 and the application, as amended, the provisions of the Act, and the regulations of the Commission; C. The facility will operate in conformity with the application, as amended, the provisions of the Act, and the regulations of the Commission (except as exempted from compliance in Section 2.0. below);

D. There is reasonable assurance: (i) that the activities authorized by this renewed operating license can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations set forth in 10 CFR Chapter I (except as exempted from compliance in Section 2.0. below);

E. Energy Northwest is technically qualified to engage in the activities authorized by this renewed license in accordance with the Commission's regulations set forth in 10 CFR Chapter I; F. Energy Northwest has satisfied the applicable provisions of 10 CFR Part 140, "Financial Protection Requirements and Indemnity Agreements," of the Commission's regulations; Renewed License No. NPF-21

-2 G. The issuance of this renewed license will not be inimical to the common defense and security or to the health and safety of the public; H. After weighing the environmental, economic, technical, and other benefits of the facility against environmental and other costs and considering available alternatives, the issuance of this Renewed Facility Operating License No.

NPF-21, subject to the conditions for protection of the environment set forth in the Environmental Protection Plan attached as Appendix B, is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied; and I. The receipt, possession, and use of source, byproduct and special nuclear material as authorized by this renewed license will be in accordance with the Commission's regulations in 10 CFR Parts 30, 40 and 70.

J. Actions have been identified and have been or will be taken with respect to (1) managing the effects of aging during the period of extended operation on the functionality of structures and components that have been identified to require review under 10 CFR 54.21 (a)(1), and (2) time-limited aging analyses that have been identified to require review under 10 CFR 54.21 (c), such that there is reasonable assurance that the activities authorized by the renewed operating license will continue to be conducted in accordance with the current licensing basis, as defined in 10 CFR 54.3, for the facility, and that any changes made to the facility's current licensing basis in order to comply with 10 CFR 54.29(a) are in accordance with the Act and the Commission's regulations.

2. Based on the foregoing findings regarding this facility, Renewed Facility Operating License NPF-21 is hereby issued to Energy Northwest (the licensee) to read as follows:

A. This renewed operating license applies to Columbia Generating Station, a boiling water nuclear reactor and associated equipment, owned by Energy Northwest.

The facility is located on Hanford Reservation in Benton County near Richland, Washington, and is described in the licensee's "Final Safety Analysis Report", as supplemented and amended, and in the licensee's Environmental Report, as supplemented and amended.

B. Subject to the conditions and requirements incorporated herein, the Commission hereby licenses Energy Northwest:

(1) Pursuantto Section 103 of the Act and 10 CFR Part 50, to possess, use, and operate the facility at the designated location on Hanford Reservation, Benton County, Washington, in accordance with the procedures and limitations set forth in this renewed license; Renewed License No. NPF-21

-3 (2) Pursuant to the Act and 10 CFR Part 70, to receive, possess and use at any time special nuclear material as reactor fuel, in accordance with the limitations for storage and amounts required for reactor operation, as described in the Final Safety Analysis Report, as supplemented and amended; (3) Pursuant to the Act and 10 CFR Parts 30, 40 and 70, to receive, possess, and use at any time any byproduct, source and special nuclear material as sealed neutron sources for reactor startup, sealed sources for reactor instrumentation and radiation monitoring equipment calibration, and as fission detectors in amounts as required; (4) Pursuant to the Act and 10 CFR Parts 30, 40 and 70, to receive, possess, and use in amounts as required any byproduct, source of special nuclear material without restriction to chemical or physical form, for sample analysis or instrument calibration or associated with radioactive apparatus or components; and (5) Pursuant to the Act and 10 CFR Parts 30, 40 and 70, to possess, but not separate, such byproduct and special nuclear materials as may be produced by the operation of the facility.

(6) Pursuant to the Act and 10 CFR Parts 30, 40 and 70, to store byproduct, source and special nuclear materials not intended for use at Columbia Generating Station. The materials shall be no more than 9 sealed neutron radiation sources designed for insertion into pressurized water reactors and no more than 40 sealed beta radiation sources designed for use in area radiation monitors. The total inventory shall not exceed 24 microcuries of strontium-90, 20 microcuries of uranium-235, 30 curies of plutonium-238, and 3 curies of americium-241.

C. This renewed license shall be deemed to contain and is subject to the conditions specified in the Commission's regulations set forth in 10 CFR Chapter I and is subject to all applicable provisions of the Act and to the rules, regulations, and orders of the Commission now or hereafter in effect; and is subject to the additional conditions specified or incorporated below:

(1) Maximum Power Level The licensee is authorized to operate the facility at reactor core power levels not in excess of full power (3486 megawatts thermal).

Renewed License No. NPF-21

-4 (2) Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No. 224 and the Environmental Protection Plan contained in Appendix B, are hereby incorporated in the renewed license. The licensee shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

(a) For Surveillance Requirements (SRs) not previously performed by existing SRs or other plant tests, the requirement will be considered met on the implementation date and the next required test will be at the interval specified in the Technical Specifications as revised in Amendment No. 149.

(3) Deleted.

(4) Deleted.

(5) Deleted.

(6) Deleted.

(7) Deleted.

(8) Deleted.

(9) Deleted.

(10) Deleted.

(11) Shield Wall Deferral (Section 12.3.2. SSER#4, License Amendment #7)

The licensee shall complete construction of the deferred shield walls and window as identified in Attachment 3, as amended by this license amendment.

(12) Deleted.

(13) Deleted.

The parenthetical notation following the title of many license conditions denotes the section of the Safety Evaluation Report and/or its supplements wherein the license condition is discussed.

Renewed License No. NPF-21

- 5 (14) Fire Protection Program (Generic Letter 86-10)

The licensee shall implement and maintain in effect all provisions of the approved fire protection program as described in Section 9.5.1 and Appendix F of the Final Safety Analysis Report (FSAR) for the facility thru Amendment #39 and as described in subsequent letters to the staff through November 30, 1988, referenced in the May 22, 1989 safety evaluation and in other pertinent sections of the FSAR referenced in either Section 9.5.1 or Appendix F and as approved in the Safety Evaluation Report issued in March 1982 (NUREG 0892) and in Supplements 3, issued in May 1983, and 4, issued in December 1983, and in safety evaluations issued with letters dated November 11, 1987 and May 22, 1989 subject to the following provision:

The licensee may make changes to the approved fire protection program without prior approval of the Commission only if those changes would not adversely affect the ability to achieve and maintain safe shutdown in the event of a fire.

(15) Deleted.

(16) Deleted.

(17) Deleted.

(18) Deleted.

(19) Deleted.

(20) Deleted.

(21 ) Deleted.

(22) Deleted.

(23) Deleted.

(24) Deleted.

(25) Deleted.

(26) Deleted.

(27) Deleted.

(28) Deleted.

Renewed License No. NPF-21

- 6 (29) Protection of the Environment (FES)

Before engaging in additional construction or operational activities which may result in a significant adverse environmental impact that was not evaluated or that is significantly greater than the evaluation in the Final Environmental Statement the licensee shall provide a written notification to the Director of the Office of Nuclear Reactor Regulation and receive written approval from that office before proceeding with such activities, (30) Deleted.

(31) Mitlgation Strategy License Condition Develop and maintain strategies for addressing large fires and explosions and that include the following key areas:

(a) Fire fighting response strategy with the following elements:

1. Pre-defined coordinated fire response strategy and guidance

2. Assessment of mutual aid fire fighting assets

3. Designated staging areas for equipment and materials

4. Command and control

5. Training of response personnel (b) Operations to mitigate fuel damage considering the following:

1. Protection and use of personnel assets

2. Communications

3. Minimizing fire spread 4, Procedures for implementing integrated fire response strategy

5. Identification of readily-available pre-staged equipment

6. Training on integrated fire response strategy

7. Spent fuel pool mitigation measures (c) Actions to minimize release to include consideration of:

1. Water spray scrubbing

2. Dose to onsite responders (32) The licensee shall implement and maintain all Actions required by Attachment 2 to NRC Order EA-06-137, issued June 20,2006, except the last action that requires incorporation of the strategies into the site security plan, contingency plan, emergency plan and/or guard training and qualification plan, as appropriate.

Renewed License No. NPF-21

-7 (33) Control Room Envelope Habitability Program (CRE)

Upon implementation of Amendment No.207 adopting TSTF-448, Revision 3, the determination of CRE unfiltered air inleakage as required by SR 3.7.3.4, in accordance with TS S.S.14.c.(i), the assessment of CRE habitability as required by Specification S.S.14.c.(ii), and the measurement of CRE pressure as required by Specification S.S.14.d, shall be considered met. Following implementation:

(a) The first performance of SR 3.7.3.4, in accordance with Specification S.S.14.c.(i), shall be within the specified Frequency of 6 years, plus the 18-month allowance of SR 3.0.2, as measured from November 6, 2003, the date of the most recent successful tracer gas test, or within the next 18 months if the time period since the most recent successful tracer gas test is greater than 6 years.

(b) The first performance of the periodic assessment of CRE habitability, Specification S.S.14.c.(ii), shall be within 3 years, plus the 9-month allowance of SR 3.0.2, as measured from November 6, 2003, the date of the most recent successful tracer gas test, or within the next 9 months if the time period since the most recent successful tracer gas test is greater than 3 years.

(c) The first performance of the periodic measurement of CRE pressure, Specification S.S.14.d, shall be within 24 months, plus the 184 days allowed by SR 3.0.2, as measured from March 23, 2006, the date of the most recent successful pressure measurement test, or within 184 days if not performed previously.

Renewed License No. NPF-21

-8 (34) The information in the FSAR supplement, submitted pursuant to 10 CFR 54.21 (d), as supplemented by Commitment Nos. 1, 5, 13, 14, 17, 18, 23, 24,26,27,28,32,36,38,40,41,42,43,48,49,50,53,55, 58, 59, 60, 61, 63, 64, 65, 66, 67, 68, 69, and 70 of Appendix A of NUREG-2123, "Safety Evaluation Report Related to the License Renewal of Columbia Generating Station" dated May 2012, is henceforth part of the FSAR which will be updated in accordance with 10 CFR 50.71 (e). As such, the licensee may make changes to the programs and activities described in the UFSAR supplement and Commitment Nos. 1,5,13,14,17,18,23, 24,26,27,28,32,36,38,40,41,42,43,48,49,50,53,55, 58, 59, 60, 61,63,64,65,66,67,68,69, and 70 of Appendix A of NUREG-2123 provided the licensee evaluates such changes pursuant to the criteria set forth in 10 CFR 50.59 and otherwise complies with the requirements in that section.

(35) The licensee's FSAR supplement submitted pursuant to 10 CFR 54.21 (d),

as revised during the license renewal application review process, and as supplemented by Commitment Nos. 1, 5, 13, 14, 17, 18, 23, 24, 26, 27, 28,32,36,38,40,41,42,43,48,49,50,53,55,58,59,60, 61, 63, 64, 65,66,67,68,69, and 70 of Appendix A of NUREG-2123, describes certain future programs and activities to be completed before the period of extended operation. Energy Northwest shall complete these activities no later than June 20, 2023, and shall notify the NRC in writing when implementation of these activities is complete.

(36) To prevent lateral motion of the core plate, the licensee shall install core plate weqges around the periphery of the core plate within the shroud on or before December 20,2021. Upon completion of the core plate wedge installation, the licensee shall submit a written report to the NRC staff summarizing the results of the installation. The licensee shall also submit a written report regarding any corrective action taken related to core plate rim hold-down bolts or core plate wedges and the results of extent of condition reviews on or before December 20,2021.

Renewed License No. NPF-21

-9 D. Exemptions from certain requirements of Appendices G, Hand J to 10 CFR Part 50, are described in the Safety Evaluation Report. These exemptions are authorized by law and will not endanger life or property or the common defense and security and are otherwise in the public interest. Therefore, these exemptions are hereby granted pursuant to 10 CFR 50.12. With the granting of this exemption the facility will operate, to the extent authorized herein, in conformity with the application, as amended, the provisions of the Act, and the rules and regulations of the Commission.

E. The licensee shall fully implement and maintain in effect all provisions of the Commission-approved physical security, training and qualification, and safeguards contingency plans including amendments made pursuant to provisions of the Miscellaneous Amendments and Search Requirements revisions to 10 CFR 73.55 (51 FR 27817 and 27822) and to the authority of 10 CFR 50.90 and 10 CFR 50.54(p). The plan, which contains Safeguards Information protected under 10 CFR 73.21, is entitled: "Columbia Generating Station Physical Security Plan, Training and Qualification Plan, Safeguards Contingency Plan, and Independent Spent Fuel Storage Installation Plan, Revision 3" submitted May 18, 2006. Energy Northwest shall fully implement and maintain in effect all provisions of the Commission-approved cyber security plan (CSP), including changes made pursuant to the authority of 10 CFR 50.90 and 10 CFR 50.54(p). The Energy Northwest CSP was approved by License Amendment No. 222.

F. Deleted.

G. The licensee shall notify the Commission, as soon as possible but not later than one hour, of any accident at this facility which could result in an unplanned release of quantities of fission products in excess of allowable limits for normal operation established by the Commission.

H. The licensee shall have and maintain financial protection of such type and in such amounts as the Commission shall require in accordance with Section 170 of the Atomic Energy Act of 1954, as amended, to cover public liability claims.

Renewed License No. NPF-21

- 10 I. This renewed license is effective as of the date of issuance and shall expire at midnight December 20, 2043.

FOR THE NUCLEAR REGULATORY COMMISSION

~/06 Eric J. Leeds, Director Office of Nuclear Reactor Regulation

Enclosures:

1. Appendix A Technical Specifications

2. Appendix B Environmental Protection Plan

3. Appendix C Additional Conditions Date of Issuance: May 22, 2012 Renewed License No. NPF-21

ATTACHMENT 1 TO OPERATING LICENSE NPF-21 Deleted Amendment No. 4&7 223

ATTACHMENT 2 Deleted Amendment No. 25, 60, 162223

ATTACHMENT 3 LIST OF SHIELD WALLS

1. Deleted.

2. Deleted.

3. Deleted.

4. Deleted.

- 5. FSAR Figure 12.3"12, Zone G The access blockout to the duplicate centrifuge room.

- 6. FSAR Figure 12.3-12. Zone F Same as above for the duplicate centrifuge.

- 7. FSAR Figure 12.3-13, Zone J The blockout for one of the two decon concentrators.

- 8. FSAR Figure 12.3-11. Zone 0"8 - The two block walls at the north end of the truck loading bay.

- 9. FSAR Figure 12.3-11. Zone E The leaded glass viewing window in the radwaste area.

- Shield walls and window identified in items 5, 6, 7, 8, and 9 will be installed if the associated radiation levels at these locations exceed 2.5mRlhr as dictated by the ongoing ALARA reviews.

Amendment No. +- 223

LICENSE AUfliOITYXFll COaGU DPINOI U, APPENDIX A TECHNICAL SPECIFICATIONS FOR COLUMBIA GENERATING STATION

TABLE OF CONTENTS 1.0 USE AND APPLICATION 1.1 Definitions . . . . . . . . . . . . . . . . . . . . 1.1-1 1.2 Logical Connectors . . . . . . . . . . . . . . . . . 1.2-1 1.3 Completion Times . . . . . . . . . . . . . . . . . . 1.3-1 1.4 Frequency . . . . . . . . . . . . . . . . . . . . . 1.4-1 2.0 SAFETY LIMITS (SLs) 2.1 SLs 2.0-1 2.2 SL Violations 2.0-1 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY 3.0-1 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY . . . . . . 3.0-4 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM) . . . . . . . . . . . . . . . 3.1.1-1 3.1.2 Reactivity Anomalies . . . . . . . . . . . . . . . . 3.1.2-1 3.1.3 Control Rod OPERABILITY . . . . . . . . . . . . . . 3.1.3-1 3.1.4 Control Rod Scram Times . . . . . . . . . . . . . . 3.1.4-1 3.1.5 Control Rod Scram Accumulators . . . . . . . . . . . 3.1.5-1 3.1.6 Rod Pattern Control ................ 3.1.6-1 3.1.7 Standby Liquid Control (SLC) System . . . . . . . . 3.1.7-1 3.1.8 Scram Discharge Volume (SDV) Vent and Drain Valves . . . . . . . . . . . . . . . . . . 3.1 .8-1 3.2 POWER DISTRIBUTION LIMITS 3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR) . . . . . . . . . . . . . . . . 3.2.1-1 3.2.2 MINIMUM CRITICAL POWER RATIO (MCPR) . . . . 3.2.2-1 3.2.3 LINEAR HEAT GENERATION RATE (LHGR) . . . . . 3.2.3-1 3.2.4 Average Power Range Monitor (APRM) Gain and Setpoint . . . . . . . . . . . . . . . . 3.2.4-1 3.3 INSTRUMENTATION 3.3.1.1 Reactor Protection System (RPS) Instrumentation 3.3.1.1-1 3.3.1.2 Source Range Monitor (SRM) Instrumentation . . . . . 3.3. 1.2-1 3.3.1.3 Oscillation Power Range Monitor (OPRM)

Instrumentation . . . . . . . . . . . . . . . . 3.3.1.3-1 I 3.3.2.1 Control Rod Block Instrumentation . . . . . . . . . 3.3.2.1-1 3.3.2.2 Feedwater and Main Turbine High Water Level Trip Instrumentation . . . . . . . . . . . 3.3.2.2-1 3.3.3.1 Post Accident Monitoring (PAM) Instrumentation . 3.3.3.1-1 3.3.3.2 Remote Shutdown System . . . . . . . . ... . . . . . 3.3.3.2-1 3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT)

Instrumentation . . . . . . . . . . . . . . . . 3.3.4.1-1 3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) Instrumentation . . . . . . 3.3.4.2-1 3.3.5.1 Emergency Core Cooling System (ECCS)

Instrumentation . . . . . . . . . . . . . . . . 3.3. 5 .1-1 (continued)

Columbia Generating Station i Amendment I 149,169,171 Ao.

APR 0 r- 2001

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& O N dT pQ T t ~ i Ast~ v L~ IS

TABLE OF CONTENTS 3.3 INSTRUMENTATION (continued) 3.3.5.2 Reactor Core Isolation Cooling (RCIC) System Instrumentation . . . . . . . . . . . . . . 3.3.5.2-1 3.3.6.1 Primary Containment Isolation Instrumentation 3.3.6.1-1 3.3.6.2 Secondary Containment Isolation Instrumentation 3.3.6.2-1 3.3.7.1 Control Room Emergency Filtration (CREF) System Instrumentation . . . . . . . . . . . . . . 3.3.7.1-1 3.3.8.1 Loss of Power (LOP) Instrumentation ...... 3.3.8.1-1 3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring ........ ................. 3.3.8.2-1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 Recirculation Loops Operating .......... 3.4.1-1 3.4.2 Jet Pumps . . . . . . . . . . . . . . . . . . . . 3.4.2-1 3.4.3 Safety/Relief Valves (SRVs) - > 25% RTP 3.4.3-1 3.4.4 Safety/Relief Valves (SRVs) - < 25% RTP ..... 3.4.4-1 3.4.5 RCS Operational LEAKAGE ............. 3.4.5-1 3.4.6 RCS Pressure Isolation Valve (PIV) Leakage .... 3.4.6-1 3.4.7 RCS Leakage Detection Instrumentation ...... 3.4.7-1 3.4.8 RCS Specific Activity . . . . . . . . . . . . . . 3.4.8-1 3.4.9 Residual Heat Removal (RHR) Shutdown Cooling System-Hot Shutdown ..................... 3.4.9-1 3.4.10 Residual Heat Removal (RHR) Shutdown Cooling System-Cold Shutdown ............ 3.4.10-1 3.4.11 RCS Pressure and Temperature (P/T) Limits .... 3.4.11-1 3.4.12 Reactor Steam Dome Pressure ........... 3.4.12-1 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.1 ECCS-Operating . . . . . . . . . . . . . . . . . 3.5.1-1 3.5.2 ECCS- Shutdown ........ .................. 3.5.2-1 3.5.3 RCIC System . . . . . . . . . . . . . . . . . . . 3.5.3-1 3.6 CONTAINMENT SYSTEMS 3.6.1.1 Primary Containment . . . . . . . . . . . . . . . 3.6.1.1-1 3.6.1.2 Primary Containment Air Lock ... ............. 3.6.1.2-1 3.6.1.3 Primary Containment Isolation Valves (PCIVs) . . . 3.6.1.3-1 3.6.1.4 Drywell Air Temperature ............. 3.6.1.4-1 3.6.1.5 Residual Heat Removal (RHR) Drywell Spray .. 3.6.1.5-1 3.6.1.6 Reactor Building-to-Suppression Chamber Vacuum Breakers . . . . . . . . . . . . . . . 3.6.1.6-1 3.6.1.7 Suppression Chamber-to-Drywell Vacuum Breakers 3.6.1.7-1 3.6.2.1 3.6.2.2 Suppression Pool Average Temperature ..........

Suppression Pool Water Level .... ............

3.6.2.1-1 3.6.2.2-1 I 3.6.2.3 Residual Heat Removal (RHR) Suppression Pool Cooling . . . . . . . . . . . . . . . . . . . 3.6.2.3-1 (continued)

Columbia Generating Station ii Amendment No. 149,IS0,I9-6 199

TABLE OF CONTENTS 3.6 CONTAINMENT SYSTEMS (continued) 3.6.3.1 Deleted 3.6.3.2 Primary Containment Atmosphere Mixing System . . .. 3.6.3.2-1 3.6.3.3 Primary Containment Oxygen Concentration ........ .. 3.6.3.3-1 3.6.4.1 Secondary Containment .. ............... 3.6.4.1-1 3.6.4.2 Secondary Containment Isolation Valves (SCIVs) 3.6.4.2-1 3.6.4.3 Standby Gas Treatment (SGT) System ............ ... 3.6.4.3-1 3.7 PLANT SYSTEMS 3.7.1 Standby Service Water (SW) System and Ultimate Heat Sink (UHS) ............. 3.7.1-1 3.7.2 High Pressure Core Spray (HPCS) Service Water (SW) System ............................. 3.7.2-1 3.7.3 Control Room Emergency Filtration (CREF) System . 3.7.3-1 3.7.4 Control Room Air Conditioning (AC) System ..... ... 3.7.4-1 3.7.5 MainCondenser Offgas ....... ............... ... 3.7.5-1 3.7.6 Main Turbine Bypass System .... ............. ... 3.7.6-1 3.7.7 Spent Fuel Storage Pool Water Level ..... ........ 3.7.7-1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 AC Sources-Operating ........ .... ........ ... 3.8.1-1 3.8.2 AC Sources-Shutdown ............................ 3.8.2-1 3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air . . . 3.8.3-1 3.8.4 DC Sources-Operating ....... ............... ... 3.8.4-1 3.8.5 DC Sources-Shutdown ...... ................ ... 3.8.5-1 3.8.6 Battery Parameters ...... ................. ... 3.8.6-1 3.8.7 Distribution Systems-Operating ....... .......... 3.8.7-1 3.8.8 Distribution Systems-Shutdown ...... ........... 3.8.8-1 3.9 REFUELING OPERATIONS 3.9.1 Refueling Equipment Interlocks . ....... .......... 3.9.1-1 3.9.2 Refuel Position One-Rod-Out Interlock .... ....... 3.9.2-1 3.9.3 Control Rod Position ........ ................. 3.9.3-1 3.9.4 Control Rod Position Indication ....... .......... 3.9.4-1 3.9.5 Control Rod OPERABILITY-Refueling .......... 3.9.5-1 3.9.6 Reactor Pressure Vessel (RPV) Water Level -Irradiated Fuel ..... ............. ... 3.9.6-1 3.9.7 Reactor Pressure Vessel (RPV) Water Level-New Fuel or Control Rods .......... . .. 3.9.7-1 3.9.8 Residual Heat Removal (RHR)-High Water Level . . 3.9.8-1 3.9.9 Residual. Heat Removal (RHR)-Low Water Level . . . 3.9.9-1 3.9.10 Decay Time ......................... ........ 3.9.10-1 3.10 SPECIAL OPERATIONS 3.10.1 Inservice Leak and Hydrostatic Testing Operation 3.10.1-1 3.10.2 Reactor Mode Switch Interlock Testing ...... ..... 3.10.2-1 3.10.3 Single Control Rod Withdrawal-Hot Shutdown . . . . 3.10.3-1 (continued)

Columbia Generating Station ii i Amendment No. 149;169,189,199 204

I11.1-TABLE OF CONTENTS 3.10 SPECIAL OPERATIONS (continued) 3.10.4 Single Control Rod Withdrawal - Cold Shutdown . . . . 3.10.4-1 3.10.5 Single Control Rod Drive (CRD)

Removal- Refueling . . . . . . . . 3.10.5-1 3.10.6 Multiple Control Rod Withdrawal - Refueling. 3.10.6-1 3.10.7 Control Rod Testing -Operating . . . . . . . . . . . 3.10.7-1 3.10.8 SHUTDOWN MARGIN (SDM) Test-Refueling .3.10.8-1 4.0 DESIGN FEATURES 4.1 Site Location .4.0-1 4.2 Reactor Core . . . . . . . . . . . . . . . . . . . . 4.0-1 4.3 Fuel Storage ......... . 4.0-2 5.0 ADMINISTRATIVE CONTROLS 5.1 Responsibility . . . . . . . . . ... . . . . . . . . 5.1-1 5.2 Organization . . . 5.2-1 5.3 Unit Staff Qualifications . . . . . . . . . . . .. 5.3-1 5.4 Procedures . . . . . . . . . . . . . . . . . . .. . 5.4-1 5.5 Programs and Manuals . . . . . . . . . . . . .. . . 5.5-1 5.6 Reporting Requirements . . .. . . . . . . . .. . . 5.6-1 5.7 High Radiation Area . . . . . .. . . . . . .. . . 5.7-1 Columbia Generating Station iv Amendment. No. 14-41691

Definitions 1.1 1.0 USE AND APPLICATION 1.1 Definitions

NOTE------------------------------------

The defined terms of this section appear in capitalized type and are applicable throughout these Technical Specifications and Bases.

Term Definition ACTIONS ACTIONS shall be that part of a Specification that prescribes Required Actions to be taken under designated Conditions within specified Completion Times.

AVERAGE PLANAR LINEAR The APLHGR shall be applicable to a specific HEAT GENERATION RATE planar height and is equal to the sum of the (APLHGR) LHGRs for all the fuel rods in the specified bundle at the specified height divided by the number of fuel rods in the fuel bundle at the height.

CHANNEL CALIBRATION A CHANNEL CALIBRATION shall be the adjustment, as necessary, of the channel output such that it responds within the necessary range and accuracy to known values of the parameter that the channel monitors. The CHANNEL CALIBRATION shall encompass the entire-channel, including the required sensor, alarm, display, and trip functions, and shall include the CHANNEL FUNCTIONAL TEST. Calibration of instrument channels with resistance temperature detector (RTD) or thermocouple sensors may consist of an inplace qualitative assessment of sensor behavior-and~normal calibration of the remaining adjustable devices in the channel. The CHANNEL CALIBRATION may be performed by means of any series of sequential, overlapping, or total channel steps so that the entire channel is

-calibrated.

CHANNEL CHECK A CHANNEL CHECK shall be the qualitative assessment, by observation, of channel behavior during operation. This determination shall include, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter.

(continued)

Columbia Generating Station 1.1 -1 Amendment No. +44 1691

Definitions 1.1 1.1 Definitions (continued)

CHANNEL FUNCTIONAL TEST A CHANNEL FUNCTIONAL TEST shall be the injection of a simulated or actual signal into the channel as close to the sensor as practicable to verify OPERABILITY, including required alarm, interlock, display, and trip functions, and channel failure trips. The CHANNEL FUNCTIONAL TEST may be performed by means of any series of sequential, overlapping, or total channel steps so that the entire channel is tested.

CORE ALTERATION CORE ALTERATION shall be the movement of any fuel, sources, or reactivity control components within the reactor vessel with the vessel head removed and fuel in the vessel. The following exceptions are not considered to be CORE ALTERATIONS:

a. Movement of source range monitors, local power range monitors, intermediate range monitors, traversing incore probes, or special movable detectors (including undervessel replacement);

and

b. Control rod movement, provided there are no fuel assemblies in the associated core cell.

Suspension of CORE ALTERATIONS shall not preclude completion of movement of a component to a safe position.

CORE OPERATING LIMITS The COLR is the unit specific document that REPORT (COLR) provides cycle specific parameter limits for the current reload cycle. These cycle specific limits shall be determined for each reload cycle in accordance with Specification 5.6.3. Plant operation within these limits is addressed in individual Specifications.

DOSE EQUIVALENT 1-131 DOSE EQUIVALENT 1-131 shall be that concentration of 1-131 (microcuries/gram) that alone would produce the same Total Effective Dose Equivalent (TEDE) dose as the quantity and isotopic mixture of 1-131, 1-132, 1-133, 1-134. and 1-135 actually present. The dose conversion factors used for this calculation shall be those listed in Federal Guidance Report (FGR) 11, "Limiting Values of (continued)

Columbia Generating Station 1.1-2 Amendment No. 149,169,19G 199

Definitions 1.1 1.1 Definitions (continued)

DOSE EQUIVALENT 1-131 Radionuclide Intake and Air Concentration and (continued) Dose Conversion Factors for Inhalation, Submersion, and Ingestion," 1988.

EMERGENCY CORE COOLING The ECCS RESPONSE TIME shall be that time interval SYSTEM (ECCS) RESPONSE from when the monitored parameter exceeds its ECCS TIME initiation setpoint at the channel sensor until the ECCS equipment is capable of performing its safety function (i.e., the valves travel to their required positions, pump discharge pressures reach their required values, etc.). Times shall include diesel generator starting and sequence loading delays, where applicable. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

END OF CYCLE The EOC-RPT SYSTEM RESPONSE TIME shall be that RECIRCULATION PUMP TRIP time interval from initial signal generation by (EOC-RPT) SYSTEM RESPONSE the associated turbine throttle valve limit switch TIME or from when the turbine governor valve hydraulic control oil pressure drops below the pressure switch setpoint to complete suppression of the electric arc between the fully open contacts of the recirculation pump circuit breaker. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

ISOLATION SYSTEM The ISOLATION SYSTEM RESPONSE TIME shall be that RESPONSE TIME time interval from when the monitored parameter exceeds its isolation initiation setpoint at the channel sensor until the isolation valves travel to their required positions. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

(continued)

Columbia Generating Station 1.1-3 Amendment No. 149,169 199

Definitions 1.1 1.1 Definitions (continued)

LEAKAGE LEAKAGE shall be:

a. Identified LEAKAGE

1. LEAKAGE into the drywell such as that from pump seals or valve packing. that is captured and conducted to a sump or collecting tank; or

2. LEAKAGE into the drywell atmosphere from sources that are both specifically located and known either not to interfere with the operation of leakage detection systems or not to be pressure boundary LEAKAGE:

b. Unidentified LEAKAGE All LEAKAGE into the drywell that is not identified LEAKAGE:

c. Total LEAKAGE Sum of the identified and unidentified LEAKAGE: and

d. Pressure Boundary LEAKAGE LEAKAGE through a nonisolable fault in a Reactor Coolant System (RCS) component body, pipe wall, or vessel wall.

LINEAR HEAT GENERATION The LHGR shall be the heat generation rate per RATE (LHGR) unit length of fuel rod. It is the integral of the heat flux over the heat transfer area associated with the unit length.

LOGIC SYSTEM FUNCTIONAL A LOGIC SYSTEM FUNCTIONAL TEST shall be a test TEST of all required logic components (i.e., all required relays and contacts, trip units, solid state logic elements, etc.) of a logic circuit, from as close to the sensor as practicable up to.

but not including, the actuated device, to verify OPERABILITY. The LOGIC SYSTEM FUNCTIONAL TEST may be performed by means of any series of sequential, overlapping, or total system steps so that the entire logic system is tested.

(continued)

Columbia Generating Station 1.1 -4 A Amendment No. +44 1691

Definitions 1.1 1.1 Definitions (continued)

MAXIMUM FRACTION The MFLPD shall be the largest value of the OF LIMITING fraction of limiting power density (FLPD) in the POWER DENSITY (MFLPD) core. The FLPD shall be the LHGR existing at a given location divided by the specified LHGR limit for that bundle type.

MINIMUM CRITICAL POWER The MCPR shall be the smallest critical power RATIO (MCPR) ratio (CPR) that exists in the core for each class of fuel. The CPR is that power in the assembly that is calculated by application of the appropriate correlation(s) to cause some point in the assembly to experience boiling transition.

divided by the actual assembly operating power.

MODE A MODE shall correspond to any one inclusive combination of mode switch position, average reactor coolant temperature, and reactor vessel head closure bolt tensioning specified in Table 1.1-1 with fuel in the reactor vessel.

OPERABLE -OPERABILITY A system, subsystem, division, component., or device shall be OPERABLE or have OPERABILITY when it is capable of performing its specified safety function(s) and when all necessary attendant instrumentation, controls, normal or emergency electrical power, cooling and seal water, lubrication, and other auxiliary equipment that are required for the system, subsystem, division, component.-or device to perform its specified safety function(s) are also capable of performing their relatedsupport function(s).

PHYSICS TESTS PHYSICS TESTS shall be those tests performed to measure the fundamental nuclear characteristics of the reactor core and related instrumentation.

These tests are:

a. .Described in Chapter 14, Initial Test Program of the FSAR:

b. Authorized under the provisions of 10OCFR 50.59; or

c. Otherwise approved by the Nuclear Regulatory Commission.

(continued)

Columbia Generating Station 1.1I- 5 A Amendment No. A449 1691

111Mt_

Definitions 1.1 1.1 Definitions (continued)

RATED THERMAL POWER RTP shall be a total reactor core heat transfer (RTP) rate to the reactor coolant of 3486 MWt.

REACTOR PROTECTION The RPS RESPONSE TIME shall be that time interval SYSTEM (RPS) RESPONSE from when the monitored parameter exceeds its RPS TIME trip setpoint at the channel sensor until de-energization of the scram pilot valve solenoids. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

SHUTDOWN MARGIN (SDM) SDM shall be the amount of reactivity by which the reactor is subcritical or would be subcritical assuming that:

a. The reactor is xenon free:

b. The moderator temperature is 680 F: and

c. All control rods are fully inserted except for the single control rod of highest reactivity worth, which is assumed to be fully withdrawn.

With control rods not capable of being fully inserted, the reactivity worth of these control rods must be accounted for in the determination of SDM.

STAGGERED TEST BASIS A STAGGERED TEST BASIS shall consist of the testing of one of the systems, subsystems.

channels, or other designated components during the interval specified by the Surveillance Frequency, so that all systems, subsystems.

channels, or other designated components are tested during n Surveillance Frequency intervals.

where n is the total number of systems, subsystems, channels, or other designated components in the associated function.

THERMAL POWER THERMAL POWER shall be the total reactor core heat transfer rate to the reactor coolant.

(continued)

Columbia Generating Station 1.1-6 Amendment No. +44 1691

Definitions 1.1 1.1 Definitions (continued)

TURBINE BYPASS SYSTEM The TURBINE BYPASS SYSTEM RESPONSE TIME shall be RESPONSE TIME the time from when the turbine bypass control unit generates a turbine bypass valve flow signal until 80Z of the turbine bypass capacity is established.

The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

Columbia Generating Station 1.1-7 Amendment No. 44-9 1691

Definitions 1.1 Table 1.1-1 (page 1 of 1)

MODES.

REACTOR MODE AVERAGE REACTOR MODE TITLE SWITCH POSITION COOLANT TEMPERATURE

(.F) 1 Power Operation Run NA 2 Startup Refuel(a) or Startup/Hot NA Standby 3 Hot Shutdown(a) Shutdown > 200 4 Cold Shutdown(a) Shutdown S 200 5 Refueling(b) Shutdown or Refuel NA (a) All reactor vessel head closure bolts fully tensioned.

(b) One or more reactor vessel head closure bolts less than fully tensioned.

Columbia Generating Station 1.1-8 Amendment No. +4-4 1691

Logical Connectors 1.2 1.0 USE AND APPLICATION 1.2 Logical Connectors PURPOSE The purpose of this section is to explain the meaning of logical connectors.

Logical connectors are used in Technical Specifications (TS) to discriminate between, and yet connect, discrete Conditions. Required Actions, Completion Times.

Surveillances, and Frequencies. The only logical connectors that appear in TS are AND and OR. The physical arrangement of these connectors constitutes logical conventions with specific meanings.

BACKGROUND Several levels of logic may be used to state Required Actions. These levels are identified by the placement (or nesting) of the logical connectors and by the number assigned to each Required Action. The first level of logic is identified by the first digit of the number assigned to a Required Action and the placement of the logical connector in the first level of nesting (i.e., left justified with the number of the Required Action). The successive levels of logic are identified by additional digits of the Required Action number and by successive indentions of the logical connectors.

When logical connectors are used to state a Condition, Completion Time, Surveillance, or Frequency, only the first level of logic is used, and the logical connector is left justified with the statement of the Condition, Completion Time, Surveillance, or Frequency.

EXAMPLES The following examples illustrate the use of logical connectors.

(continued)

Columbia Generating Station 1 .2 -1 Amendment No. 4-49 1691

_~~~~1111-Logical Connectors 1.2 1.2 Logical Connectors EXAMPLES EXAMPLE 1.2-1 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LCO not met. A.1 Verify . . .

AND A.2 Restore . . .

In this example, the logical connector AND is used to indicate that, when in Condition A, both Required Actions A.1 and A.2 must be completed.

(continued)

Columbia Generating Station 1.2- 2 Amendment No. 4-4-4 1691

Logical Connectors 1.2 1.2 Logical Connectors EXAMPLES EXAMPLE 1.2-2 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LCO not met. A.1 Trip . . .

OR A.2.1 Verify . . .

AND A.2.2.1 Reduce . . .

OR A.2.2.2 Perform . . .

OR A.3 Align . . .

This example represents a more complicated use of logical connectors. Required Actions A.1, A.2. and A.3 are alternative choices, only one of which must be performed as indicated by the use of the logical connector OR and the left justified placement. Any one of these three Actions may be chosen. If A.2 is chosen, then both A.2.1 and A.2.2 must be performed as indicated by the logical connector AND.

Required Action A.2.2 is met by performing A.2.2.1 or A.2.2.2. The indented position of the logical connector OR indicates that A.2.2.1 and A.2.2.2 are alternative choices, only one of which must be performed.

Columbia Generating Station 1.2-3 Amendment No. i4-9 1691

Completion Times 1.3 1.0 USE AND APPLICATION 1.3 Completion Times '

PURPOSE The purpose of this section is to establish the Completion Time convention and to provide guidance for its use.

BACKGROUND Limiting Conditions for Operation (LCOs) specify minimum requirements for ensuring safe operation of the unit. The ACTIONS associated'with an LCO state Conditions that typically describe the ways in which the requirements of the LCO can fail to be met. Specified with each stated Condition are Required Action(s) and Completion Time(s).

DESCRIPTION The Completion Time is the amount of time allowed for completing a Required Action. It is referenced to the time of discovery of a situation (e.g.. inoperable equipment or variable not within limits) that-requires entering an ACTIONS Condition unless btherwise'specified, providing the unit is in a MODE or specified condition stated in the Applicability of the LCO. Required Actions must be completed prior to the expiration of the specified Completion Time. -An ACTIONS Condition remains in effect and the Required Actions apply until the Condition no longer exists or the unit is not within the LCO Applicability.

If situations are discovered that require entry into more than one Condition at a time within a single LCO (multiple Conditions), the Required Actions for each Condition must be performed within the associated Completion Time. When in multiple Conditions, separate Completion Times are tracked for each Condition starting from the'time of discovery of the situation that required entry into the Condition.

Once a Condition has been entered, subsequent divisions, subsystems..components, or variables expressed in the Condition, discovered to be inoperable or not within limits, will not result in separate entry into the Condition unless specifically stated. The Required Actions of the Condition continue to apply to-each additional failure, with Completion Times based on initial entry into the Condition.

However, when a subsequent division, subsystem, component, or variable expressed in the Condition is discovered to be inoperable or not within limits, the Completion Time(s) may be extended. To apply this Completion Time extension, two criteria must first be met. The subsequent inoperability:

(continued)

Columbia Generating Station 3 1.3-1 Amendment No.' -149.1691

- EIILA_

Completion Times 1.3 1.3 Completion Times DESCRIPTION a. Must exist concurrent with the first inoperability; (continued) and

b. Must remain inoperable or not within limits after the first inoperability is resolved.

The total Completion Time allowed for completing a Required Action to address the subsequent inoperability shall be limited to the more restrictive of either:

a. The stated Completion Time, as measured from the initial entry into the Condition, plus an additional 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ; or

b. The stated Completion Time as measured from discovery of the subsequent inoperability.

The above Completion Time extension does not apply to those Specifications that have exceptions that allow completely separate re-entry into the Condition (for each division.

subsystem, component, or variable expressed in the Condition) and separate tracking of Completion Times based on this re-entry. These exceptions are stated in individual Specifications.

The above Completion Time extension does not apply to a Completion Time with a modified "time zero." This modified "time zero" may be expressed as a repetitive time (i.e.,

"once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ," where the Completion Time is referenced from a previous completion of the Required Action versus the time of Condition entry) or as a time modified by the phrase "from discovery . . ." Example 1.3-3 illustrates one use of this type of Completion Time. The 10 day Completion Time specified for Conditions A and B in Example 1.3-3 may not be extended.

(continued)

Columbia Generating Station 1.3- 2 Amendment No. 4-44 1691

Completion Times 1.3 1.3 Completion Times (continued)

EXAMPLES The following examples illustrate the use of Completion Times with different types of Conditions and changing Conditions.

EXAMPLE 1.3-1 ACTIONS CONDITION REQUIRED ACTION J COMPLETION TIME B. Required B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Action and associated AND Completion Time not B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months met.

Condition B has two Required Actions. Each Required Action has its own separate Completion Time. Each Completion Time is referenced to the time that Condition B is entered.

The Required Actions of Condition B are to be i-n MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND in'MODE 4 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . A total of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is allowed for reaching MODE 3 and a total of 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (not 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months ) is allowed for reaching MODE 4 from the time that Condition B was entered. If MODE 3 is reached within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , the> time allowed for reaching MODE 4 is the next 30'hours because the total time allowed for reaching MODE 4 is 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

If Condition B is entered while in'MODE 3. the time allowed for reaching MODE 4 -is the next 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

(continued)

Columbia Generating Station 1.3~-3 Amendment No. 444 1691

_ _ _ _ _ I'I :L Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-2 (continued)

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

B. Required B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Action and associated AND Completion Time not B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months met.

When a pump is declared inoperable. Condition A is entered.

if the pump is not restored to OPERABLE status within 7 days, Condition B is also entered and the Completion Time clocks for Required Actions B.1 and B.2 start. If the inoperable pump is restored to OPERABLE status'after Condition B is entered, Conditions A and B are exited, and therefore, the Required Actions of Condition B may be terminated.

When a second pump is declared inoperable while the first pump is still inoperable. Condition A is not re-entered for the second pump. LCO 3.0.3 is entered, since the ACTIONS do not include a Condition for more than one inoperable pump.

The Completion Time clock for Condition A does not stop after LCO 3.0.3 is entered, but continues to be tracked from the time Condition A was initially entered.

While in LCO 3.0.3. if one of the inoperable pumps is restored to OPERABLE status and the Completion Time for Condition A has not expired, LCO 3.0.3 may be exited and operation continued in accordance with Condition A.

(continued)

Columbia Generating Station 1.3 -4 Amendment No. +49 1691

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-2 (continued)

While in LCO 3.0.3, if one of the inoperable pumps is restored to OPERABLE status and the Completion Time for Condition A has expired. LCO 3.0.3 may be exited and operation continued in accordance with Condition B. The Completion Time for Condition B is tracked from the time the Condition A Completion Time expired.

On restoring one of the pumps to OPERABLE status, the Condition A Completion Time is not reset, but continues from the time the first pump was declared inoperable. This Completion Time may be extended if the pump restored to OPERABLE status was the first inoperable pump. A 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months extension to the stated 7 days is allowed, provided this does not result in the second pump being inoperable for

> 7 days.

(continued)

Columbia Generating Station 1.3- 5 Amendment No. 449 1691

_ _ __ __ __ _ _ ___ ___ __ __ _ __ _ I IL L.

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-3 (continued)

ACTIONS CONDITION REOUIRED ACTION COMPLETION TIME A. One A.1 Restore 7 days Function X Function X subsystem subsystem to AND inoperable. OPERABLE status.

10 days from discovery of failure to meet the LCO B. One B.1 Restore 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Function Y Function Y subsystem subsystem to AND inoperable. OPERABLE status.

10 days from discovery of failure to meet the LCO C. One C.1 Restore 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Function X Function X subsystem subsystem to inoperable. OPERABLE status.

AND OR One C.2 Restore 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Function Y Function Y subsystem subsystem to inoperable. OPERABLE status.

(continued)

Columbia Generating Station 1.3 -6 Amendment No. +4-41691

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-3 (continued)

When one Function X subsystem and one Function Y subsystem are inoperable. Condition A and Condition B are concurrently applicable. The Completion Times for Condition A and Condition B are tracked separately for each subsystem, starting from the time each subsystem was declared inoperable and the Condition was entered. A separate Completion Time is established for Condition C and tracked from the time the second subsystem was declared inoperable (i.e.. the time the situation described in Condition C was discovered).

If Required Action C.2 is completed within the specified Completion Time. Conditions B and C are exited. If the Completion Time for Required Action A.1 has not expired.

operation may continue in accordance with Condition A. The remaining Completion Time in Condition A is measured from the time the affected subsystem was declared inoperable (i.e., initial entry into Condition A).

The Completion Times of Conditions A and B are modified by a logical connector, with a separate 10 day Completion Time measured from the time it was discovered the LCO was not met. In this example.-without the separate Completion Time.

it would be possible to alternate between Conditions A. B.

and C in such a manner that operation could continue indefinitely without ever restoring systems to meet the LCO.

The separate Completion Time modified by the phrase "from discovery of failure to meet the LCO" is designed to prevent indefinite continued operation while not meeting the LCO.

This Completion Time allows for an exception to the normal

'time zero" for beginning the Completion Time "clock". In this instance, the Completion Time "time zero' is specified as commencing at the time the LCO was initially not met, instead of-at the-time the associated Condition was entered.

- .(continued)

Columbia Generating Station -1.3-7 Amendment No. +44 1691

I l;L.-

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-4 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore valve(s) 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months valves to OPERABLE inoperable. status.

B. Required B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Action and associated AND Completion Time not B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months met.

A single Completion Time is used for any number of valves inoperable at the same time. The Completion Time associated with Condition A is based on the initial entry into Condition A and is not tracked on a per valve basis.

Declaring subsequent valves inoperable, while Condition A is still in effect, does not trigger the tracking of separate Completion Times.

Once one of the valves has been restored to OPERABLE status, the Condition A Completion Time is not reset, but continues from the time the first valve was declared inoperable. The Completion Time may be extended if the valve restored to OPERABLE status was the first inoperable valve. The Condition A Completion Time may be extended for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months provided this does not result in any subsequent valve being inoperable for > 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

If the Completion Time of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months (plus the extension) expires while one or more valves are still inoperable, Condition B is entered.

(continued)

Columbia Generating Station 1.3 -8 Amendment No. 4-4g 1691

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-5 (continued)

ACTIONS

NOTE--------------------------

Separate Condition entry is allowed for each inoperable valve.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore valve to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months valves OPERABLE status.

inoperable.

B. Required B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Action and associated AND Completion Time not B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months met.

The Note above the ACTIONS Table is a method of modifying how the Completion Time is tracked. If this method of modifying how the Completion Time is tracked was applicable only to a specific-Condition. the Note would appear in that Condition rather than at the top of the ACTIONS Table.

The Note allows Condition A to be entered separately for each inoperable valve, and Completion Times tracked on a per valve basis. When a valve is declared inoperable, Condition A is entered and its Completion Time starts. If subsequent valves are declared inoperable, Condition A is entered for each valve and separate Completion Times start and are tracked for each valve. -

(continued)

Columbia Generating Station 1.3 -9 Amendment No. 4-4-9 1691

lIvLa Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-5 (continued)

If the Completion Time associated with a valve in Condition A expires. Condition B is entered for that valve.

If the Completion Times associated with subsequent valves in Condition A expire. Condition B is entered separately for each valve and separate Completion Times start and are tracked for each valve. If a valve that caused entry into Condition B is restored to OPERABLE status, Condition B is exited for that valve.

Since the Note in this example allows multiple Condition entry and tracking of separate Completion Times. Completion Time extensions do not apply.

EXAMPLE 1.3-6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One channel A.1 Perform Once per inoperable. SR 3.x.x.x. 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months OR A.2 Reduce THERMAL 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months POWER to

< 50% RTP.

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

(continued)

Columbia Generating Station 1 .3-10 Amendment No. +44 1691

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-6 (continued)

Entry into Condition A offers a choice between Required Action A.1 or A.2. Required Action A.1 has a "once per" Completion Time, which qualifies for the 25Z extension, per SR 3.0.2. to each performance after the initial performance.

The initial 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months interval of Required Action A.1 begins when Condition A is entered and the initial performance of Required Action A.1 must be completed within the first 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months interval. If Required Action .A.1 is followed and the Required Action is not met within the Completion Time (plus the extension allowed by SR 3.0.2). Condition B is entered.

If Required Action A.2 is followed and the Completion Time of 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months is not met. Condition B is entered.

If after entry into Condition B. Required Action A.1 or A.2 is met, Condition B is exited and operation may then continue in Condition A.

(continued)

Columbia Generating Station 1.3 -I1 Amendment No. 4-49 1691

Cilue-Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-7 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One A.1 Verify affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months subsystem subsystem inoperable. isolated. AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND A.2 Restore subsystem 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months to OPERABLE status.

B. Required B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Action and associated AND Completion Time not B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months met.

Required Action A.1 has two Completion Times. The 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Completion Time begins at the time the Condition is entered and each "Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter" interval begins upon performance of Required Action A.1.

If after Condition A is entered, Required Action A.1 is not met within either the initial 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or any subsequent 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months interval from the previous performance (plus the extension allowed by SR 3.0.2), Condition B is entered. The Completion Time clock for Condition A does not stop after Condition B is entered, but continues from the time Condition A was initially entered. If Required Action A.1 (continued)

Columbia Generating Station 1.3 -12 Amendment No. +4-4 1691

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-7 (continued) is met after Condition B is entered. Condition B is exited and operation may continue in accordance with Condition A.

provided the Completion Time for Required Action A.2 has not expired.

IMMEDIATE When 'Immediately" is used as a Completion Time, the COMPLETION TIME Required Action should be pursued without delay and in a controlled manner.

Columbia Generating Station 1.3-13 Amendment No. -149 1691

Frequency 1.4 1.0 USE AND APPLICATION 1.4 Frequency PURPOSE The purpose of this section is to define the proper use and application of Frequency requirements.

DESCRIPTION Each Surveillance Requirement (SR) has a specified Frequency in which the Surveillance must be met in order to meet the associated Limiting Conditions for Operation (LCO). An understanding of the correct application of the specified Frequency is necessary for compliance with the SR.

The "specified Frequency" is referred to throughout this section and each of the Specifications of Section 3.0, "Surveillance Requirement (SR) Applicability." The "specified Frequency" consists of the requirements of the Frequency column of each SR, as well as certain Notes in the Surveillance column that modify performance requirements.

Sometimes special situations dictate when the requirements of a Surveillance are to be met. They are "otherwise stated" conditions allowed by SR 3.0.1. They may be stated as clarifying Notes in the Surveillance, as part of the Surveillance, or both.

Situations where a Surveillance could be required (i.e., its Frequency could expire), but where it is not possible or not desired that it be performed until sometime after the associated LCO is within its Applicability, represent potential SR 3.0.4 conflicts. To avoid these conflicts, the SR (i.e., the Surveillance or the Frequency) is stated such that it is only "required" when it can be and should be performed. With an SR satisfied, SR 3.0.4 imposes no restriction.

The use of "met" or "performed" in these instances conveys specified meanings. A Surveillance is "met" only when the acceptance criteria are satisfied. Known failure of the requirements of a Surveillance, even without a Surveillance specifically being "performed," constitutes a Surveillance not "met." "Performance" refers only to the requirement to specifically determine the ability to meet the acceptance criteria. Some Surveillances contain notes that modify the Frequency of performance or the conditions during which the (continued)

Columbia Generating Station 1.4-1 Amendment No. 149,169 205

Frequency 1.4 1.4 Frequency DESCRIPTION acceptance criteria must be satisfied. For these (continued) Surveillances, the MODE-entry restrictions of SR 3.0.4 may not apply. Such a Surveillance is not required to be performed prior to entering a MODE or other specified condition in the Applicability of the associated LCO if any of the following three conditions are satisfied:

a. The Surveillance is not required to be met in the MODE or other specified condition to be entered; or

b. The Surveillance is required to be met in the MODE or other specified condition to be entered, but has been performed within the specified Frequency (i.e., it is current) and is known not to be failed; or

c. The Surveillance is required to be met, but not performed, in the MODE or other specified condition to be entered, and is known not to be failed.

Examples 1.4-3, 1.4-4, 1.4-5, and 1.4-6 discuss these special situations.

EXAMPLES The following examples illustrate the various ways that Frequencies are specified. In these examples, the Applicability of the LCO (LCO not shown) is MODES 1, 2, and 3.

EXAMPLE 1.4-1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Example 1.4-1 contains the type of SR most often encountered in the Technical Specifications (TS). The Frequency specifies an interval (12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ) during which the associated Surveillance must be performed at least one time.

(continued)

Columbia Generating Station 1.4-2 Amendment No. 149,169 205

Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4-1 (continued)

Performance of the Surveillance initiates the subsequent interval. Although the Frequency is stated as 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , an extension of the time interval to 1.25 times the interval specified in the Frequency is allowed by SR 3.0.2 for operational flexibility. The measurement of this interval continues at all times, even when the SR is not required to be met per SR 3.0.1 (such as when the equipment is inoperable, a variable is outside specified limits, or the unit is outside the Applicability of the LCO). If the interval specified by SR 3.0.2 is exceeded while the unit is in a MODE or other specified condition in the Applicability of the LCO, and the performance of the Surveillance is not otherwise modified (refer to Examples 1.4-3 and 1.4-4), then SR 3.0.3 becomes applicable.

If the interval as specified by SR 3.0.2 is exceeded while the unit is not in a MODE or other specified condition in the Applicability of the LCO for which performance of the SR is required, then SR 3.0.4 becomes applicable. The Surveillance must be performed within the Frequency requirements of SR 3.0.2, as modified by SR 3.0.3, prior to entry into the MODE or other specified condition or the LCO is considered not met (in accordance with SR 3.0.1) and LCO 3.0.4 becomes applicable.

EXAMPLE 1.4-2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Verify flow is within limits. Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after

> 25% RTP AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter (continued)

Columbia Generating Station 1.4-3 Amendment No. 149,169 205

Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4-2 (continued)

Example 1.4-2 has two Frequencies. The first is a one time performance Frequency, and the second is of the type shown in Example 1.4-1. The logical connector "AND" indicates that both Frequency requirements must be met. Each time reactor power is increased from a power level < 25% RTP to

> 25% RTP, the Surveillance must be performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

The use of "once" indicates a single performance will satisfy the specified Frequency (assuming no other Frequencies are connected by "AND"). This type of Frequency does not qualify for the extension allowed by SR 3.0.2.

"Thereafter" indicates future performances must be established per SR 3.0.2, but only after a specified condition is first met (i.e., the "once" performance in this example). If reactor power decreases to < 25% RTP, the measurement of both intervals stops. New intervals start upon reactor power reaching 25% RTP.

EXAMPLE 1.4-3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

NOTE------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after > 25% RTP.

Perform channel adjustment. 7 days The interval continues whether or not the unit operation is

< 25% RTP between performances.

(continued)

Columbia Generating Station 1.4-4 Amendment No. 149,169 205

Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4-3 (continued)

As the Note modifies the required performance of the Surveillance, it is construed to be part of the "specified Frequency." Should the 7 day interval be exceeded while operation is < 25% RTP, this Note allows 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after power reaches L 25% RTP to perform the Surveillance. The Surveillance is still considered to be within the "specified Frequency." Therefore. if the Surveillance were not performed within the 7 day interval (plus the extension allowed by SR 3.0.2), but operation was < 25% RTP, it would not constitute a failure of the SR or failure to meet the LCO. Also. no violation of SR 3.0.4 occurs when changing MODES. even with the 7 day Frequency not met, provided operation does not exceed 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (plus the extension allowed by SR 3.0.2) with power L 25% RTP.

Once the unit reaches 25% RTP, 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months would be allowed for completing the Surveillance. If the Surveillance were not performed within this 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months interval (plus the extension allowed by SR 3.0.2), there would then be a failure to perform a Surveillance within the specified Frequency, and the provisions of SR 3.0.3 would apply.

EXAMPLE 1.4-4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

- - - - - - - - - - - - - - - - - NOTE - - - - - - - - - - - - - - - -

Only required to be met in MODE 1.

Verify leakage rates are within limits. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Example 1.4-4 specifies that the requirements of this Surveillance do not have to be met until the unit is in MODE 1. The interval measurement for the Frequency of this Surveillance continues at all times, as described in (continued)

Columbia Generating Station 1.4-5 Amendment No. 149,169,205 212

Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4-4 (continued)

Example 1.4-1. However, the Note constitutes an "otherwise stated" exception to the Applicability of this Surveillance.

Therefore, if the Surveillance were not performed within the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months interval (plus the extension allowed by SR 3.0.2),

but the unit was not in MODE I, there would be no failure of the SR nor failure to meet the LCO. Therefore. no violation of SR 3.0.4 occurs when changing MODES. even with the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency exceeded, provided the MODE change was not made into MODE 1. Prior to entering MODE 1 (assuming again that the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency were not met): SR 3.0.4 would require satisfying the SR.

EXA,MPLE 1.4-5 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY

- - - - - - - - - - - - - - - - - . NOT E- - - - - - - . - - - - - - - - - -

Only required to be performed in MODE 1.

Perform complete cycle of the valve. 7 days The interval continues. whether or not the unit operation is in MODE I, 2. or 3 (the assumed Applicability of the associated LCOj between performances.

As the Note modlfies the required performance of the Surveillance, the Note is construed to be part of the "specified Frequency." Should tne 7 day interval be exceeded while operation is not in MODE I, this Note allows entry into and operation in MODES 2 and 3 to perform the Surveillance. The Sur'veillance is still considered to be per'formed wi thi n the "speci fi ed Frequency" if compl eted prior to entering MODE 1.

(continued)

Columbia Generating Station 1 .4 - 6 Amendment No. 9-& 212

Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4-5 (continued)

Therefore, if the Surveillance were not performed within the 7 day (plus the extension allowed by SR 3.0.2) interval. but operation was not in MODE 1. it would not constitute a failure of the SR or failure to meet the LCO. Also no violation of SR 3.0.4 occurs when changing MODES. even with the 7 day Frequency not met, provided operation does not result in entry into MODE 1.

Once the unit reaches MODE 1. the requirement for the Surveillance to be performed within its specified Frequency applies and would require that the Surveillance had been performed. If the Surveillance were not performed prior to entering MODE 1. there would then be a failure to perform a Surveillance within the specified Frequency, and the provisions of SR 3.0.3 would apply.

EXAMPLE 1.4-6 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY

- - - - - - - - - - - - - - - - - - NOT E- - - - - - - - - - - - - - - - - -

Not required to be met in MODE 3.

Verify parameter is within limits. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Example 1.4-6 specifies that the requirements of this Surveillance do not have to be met while the un~t is in MODE 3 (the assumed Applicability of the associated LCO is MODES

1. 2, and 3). The interval measurement for the Frequency of this Surveillance continues at all times. as described in Example 1.4-1. However, the Note constitutes an "otherwise stated" exception to the Applicability of this Surveillance.

Therefore. if the Surveillance were not performed within the (continued)

Columbia Generating Station 1. 4 - 7 Amendment No. ~ 212

Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4-6 (continued) 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months interval (plus the extension allowed by SR 3.0.2).

and the unit was in MODE 3, there would be no failure of the SR nor failure to meet the LCO. Therefore. no violation of SR 3.0.4 occurs when changing MODES to enter MODE 3, even with the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency exceeded. provided the MODE change does not result in entry into MODE 2. Prior to entering MODE 2 (assuming agin that the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency were not met), SR 3.0.4 would require satisfying the SR.

Columbia Generating Station 1.4-8 Amendment No. ~ 212

SLs 2.0 K) 2.0 SAFETY LIMITS (SLs) 2.1 SLs 2.1.1 Reactor Core SLs 2.1.1.1 With the reactor steam dome pressure < 785 psig or core flow < 10% rated core flow:

THERMAL POWER shall be < 25% RTP.

2.1.1.2 With the reactor steam dome pressure > 785 psig and core flow > 10% rated core flow:

The MCPR shall be > 1.09 for two recirculation loop operation or > 1.10 for single recirculation loop operation.

I 2.1.1.3 Reactor vessel water level shall be greater than the top of active irradiated fuel.

2.1.2 Reactor Coolant System Pressure SL Reactor steam dome pressure shall be <,1325 psig.

2.2 SL Violations With any SL violation, the f.ollowing actions shall be completed within 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months s:

2.2.1 Restore compliance with all SLs; and 2.2.2 Insert all insertable control rods.

Columbia Generating Station 2.0-1 Amendment No. +69 186 14 , 5.. 4 . .

LU!J rnPIJILdU1IILY 3.0 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY LCO 3.0.1 LCOs shall be met during the MODES or other specified conditions in the Applicability, except as provided in LCO 3.0.2, LCO 3.0.7, and LCO 3.0.8.

I LCO 3.0.2 Upon discovery of a failure to meet an LCO, the Required AcLions of the associated Conditions shall be met, except as provided in LCO 3.0.5 and LCO 3.0.6.

If the LCO is met or is no longer applicable prior to expiration of the specified Completion Time(s), completion of the Required Action(s) is not required, Unless otherwise stated.

LCO 3.0.3 When an LCO is not met and the associated ACTIONS are not met, an associated ACTION is not provided, or if directed by the associated ACTIONS, the unit shall be placed in a MODE or other specified condition in which the LCO is not applicable. Action shall be initiated within I hour to place the unit, as applicable, in:

a. MODE 2 within 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months ;

b. MODE 3 within 13 hours1.50463e-4 days 0.00361 hours 2.149471e-5 weeks 4.9465e-6 months ; and

c. MODE 4 within 37 hours4.282407e-4 days 0.0103 hours 6.117725e-5 weeks 1.40785e-5 months .

Exceptions to this Specification are stated in the individual Specifications.

Where corrective measures are completed that permit operation in accordance with. the LCO or ACTIONS, completion of the actions required by LCO 3.0.3 is not required.

LCO 3.0.3 is only applicable in MODES 1., 2, and 3.

LCO 3.0.4 When an LCO is not met, entry -into a MODE or other specified condition in the Applicability shall only be made:

a. When the associated ACTIONSto be entered permit continued operation in the MODE or other specified condition in the Applicability for an unlimited period of time; (continued)

Columbia Generating Station 3.0-1 Amendment No. 14.+/-1 691817, 198

LCO Applicability 3.0 3.0 LCO APPLICABILITY LCO 3.0.4 b. After performance of a risk assessment addressing (continued) inoperable systems and components, consideration of the results, determination of the acceptability of entering the MODE or other specified condition in the Applicability, and establishment of risk management actions, if appropriate; exceptions to this Specification are stated in the individual Specifications, or

c. When an allowance is stated in the individual value, parameter, or other Specification.

This Specification shall not prevent changes in MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.

LCO 3.0.5 Equipment removed from service or declared inoperable to comply with ACTIONS may be returned to service under administrative control solely to perform testing required to demonstrate its OPERABILITY or the OPERABILITY of other equipment. This is an exception to LCO 3.0.2 for the system returned to service under administrative control to perform the testing required to demonstrate OPERABILITY.

LCO 3.0.6 When a supported system LCO is not met solely due to a support system LCO not being met, the Conditions and Required Actions associated with this supported system are not required to be entered. Only the support system LCO ACTIONS are required to be entered. This is an exception to LCO 3.0.2 for the supported system. In this event.

additional evaluations and limitations may be required in accordance with Specification 5.5.11, "Safety Function Determination Program (SFDP)." If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered.

When a support system's Required Action directs a supported system to be declared inoperable or directs entry into Conditions and Required Actions for a supported system, the applicable Conditions and Required Actions shall be entered in accordance with LCO 3.0.2.

(continued)

Columbia Generating Station 3.0-2 Amendment No. 149.169,187

3.0 3.0 LCO APPLICABILITY (continued)

LCO 3.0.7 Special Operations LCOs in Section 3.10 allow specified Technical Specifications (TS) requirements to be changed to permit performance of special tests and operations. Unless otherwise specified, all other TS requirements remain unchanged. Compliance with Special Operations LCOs is optional. When a Special Operations LCO is desired to be met buL is not met, the ACTIONS of the Special Operations LCO shall be met. When a Special Operations LCO is not desired to be met, entry into a MODE or other specified condition in the Applicability shall only be made in accordance with the other applicable Specifications.

LCO 3.0.8 When one or more required snubbers are unable to perform their associated support function(s), any affected supported LCO(s) are not required to be declared not met solely for this reason if risk is assessed and managed, and:

a. The snubbers not able to perform their associated support function(s) are associated with only one train or subsystem of a multiple train or subsystem supported system or are associated with a single train or subsystem supported system and are able to perform their associated support function within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months ; or

b. The snubbers not able to perform their associated support function(s) are associated with more than one train or subsystem of a multiple train or subsystem supported system and are able to perform their associated support function within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

At the end of the specified period the required snubbers must be able to perform their associated support function(s), or the affected supported system LCO(s) shall be declared 'not met.

Columbia Generating Station 3.0-3 Amendment No. 149,69,18G , 198

Uiji-SR Applicability.

3.0 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY 11 SR 3.0.1 SRs shall be met during the MODES or other specified conditions in the Applicability for individual LCOs, unless otherwise stated in the SR. Failure to meet a Surveillance, whether such failure is experienced during the performance of the Surveillance or between performances of the.-

Surveillance, shall be failure to meet the LCO. Failure to perform a Surveillance within the specified Frequency shall be failure to meet the LCO except as provided in SR 3.0.3.

Surveillances do not have to be performed on inoperable equipment or variables outside specified limits.

SR 3.0.2 The specified Frequency for each SR is met if the Surveillance is performed within 1.25 times the interval specified in the Frequency, as measured from the previous performance or as measured from the time a specified condition of the Frequency is met.

For Frequencies specified as "once," the above interval extension does not apply.

If a Completion Time requires periodic performance on a "once per . . ." basis, the above Frequency extension applies to each performance after the initial performance.

Exceptions to this Specification are stated in the individual Specifications.

SR 3.0.3 If it is discovered that a Surveillance was not performed within its specified Frequency, then compliance with the requirement to declare the LCO not met may be delayed, from the time of discovery, up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or up to the limit of the specified Frequency, whichever is greater. This delay period is permitted to allow performance of the Surveillance. A risk evaluation shall be performed for any Surveillance delayed greater than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and the risk impact shall be managed.

If the Surveillance is not performed within the delay period. the LCO must immediately be declared not met, and the applicable Condition(s) must be entered.

- (continued)

Columbia Generating Station 3.0-4 Amendment No. 149-169,180 OCT 08 2002

SR Applicability 3.0 3.0 SR APPLICABILITY ,;.

SR 3.0.3 When the Surveillance is performed within the delay period (continued) and the Surveillance is not met, the LCO must immediately be declared not met, and the applicable Condition(s) must be entered.

SR 3.0.4 Entry into a MODE or other specified condition in the Applicability of an LCO shall only be made when the LCO's Surveillances have been met within their specified Frequency, except as provided by SR 3.0.3. When an LCO is not met due to Surveillances not having been met, entry into a MODE or other specified condition in the Applicability shall only be made in accordance with LCO 3.0.4.

This provision shall not prevent entry into MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.

Columbia Generating Station 3.0- 5 Amendment No. 149,169,18G,187

SDM 3.1.1 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM)

LCO 3.1.1 SDM shall be:

a. > 0.38% Ak/k, with the highest worth control rod analytically determined: or

b. > 0.28% Ak/k. with the highest worth control rod determined by test.

APPLICABILITY: MODES 1, 2. 3. 4, and 5.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SDM not within limits A.1 Restore SDM to within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months in MODE 1 or 2. --limits.

B. Required Action-and B.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.

C. SDM not within limits C.1 Initiate action to Immediately in MODE 3. fully insert all insertable control rods.

D. SDM not within limits D.1 Initiate action to Immediately in MODE 4. fully insert all insertable control rods.

AND (continued)

Columbia Generating Station 3.1. 1-1 Amendment No. +4-9 1691

__ _ _ _ _ _ lI I SDM 3.1.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. (continued) D.2 Initiate action to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore secondary containment to OPERABLE status.

AND D.3 Initiate action to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore one standby gas treatment (SGT) subsystem to OPERABLE status.

AND D.4 Initiate action to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore isolation capability in each required secondary containment penetration flow path not isolated.

E. SDM not within limits E.1 Suspend CORE Immediately in MODE 5. ALTERATIONS except for control rod insertion and fuel assembly removal.

AND E.2 Initiate action to Immediately fully insert all insertable control rods in core cells containing one or more fuel assemblies.

AND (continued)

Columbia Generating Station 3.}. 1-2 Amendment No. +4-41691

SDM 3.1.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. (continued) E.3 Initiate action to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore secondary containment to OPERABLE status.

AND E.4 Initiate action to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore one SGT subsystem to OPERABLE status.

AND E.5 Initiate action to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore isolation capability in each required secondary containment penetration flow path not isolated.

Columbia Generating Station 3.1.1 -3 Amendment No. +4-9 1691

l ii -

SDM 3.1.1 SURVEILLANCE REOUIREMENTS SURVEILLANCE FREOUENCY SR 3.1.1.1 Verify SDM is: Prior to each in vessel fuel a > 0.38% Ak/k with the highest worth movement during control rod analytically determined; fuel loading or sequence

b. > 0.28% AMkk with the highest worth AND control rod determined by test.

Once within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after criticality following fuel movement within the reactor pressure vessel or control rod replacement Columbia Generating Station 3. 1.1-4 Amendment No. +4-4 1691

Reactivity Anomalies 3.1.2 3.1 REACTIVITY CONTROL SYSTEMS 3.1.2 Reactivity Anomalies LCO 3.1.2 The reactivity difference between the monitored core keff and the predicted core keff shall be within + 1% Ak/k.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Core reactivity A.1 Restore core 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months difference not within reactivity difference limit. to within limit.

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

Columbia Generating Station 3.1.2-1 Amendment No. 49 1691

_111X_.

Reactivity Anomalies 3.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

+

SR 3.1.2.1 Verify core reactivity difference between Once within the monitored core keff and the predicted 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after core keff is within +/- 1% Ak/k. reaching equilibrium conditions following startup after fuel movement within the reactor pressure vessel or control rod replacement AND 1000 MWD/T thereafter during operations in MODE 1 V

Columbia Generating Station 3.1. 2-2 Amendment No. 4-49 1691

Control Rod OPERABILITY 3.1.3 3.1 REACTIVITY CONTROL SYSTEMS 3.1.3 Control Rod OPERABILITY LCO 3.1.3 Each control rod shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each control rod.

CONDITION REQUIRED ACTION COMPLETION TIME A. One withdrawn control ------------ NOTE-------------

rod stuck. Rod Worth Minimizer (RWM) may be bypassed as allowed by LCO 3.3.2.1. "Control Rod Block Instrumentation," if required, to allow continued operation.

A.1 Verify stuck control Immediately rod separation criteria are met.

AND A.2 Disarm the associated 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months control rod drive (CRD).

AND (continued)

Columbia Generating Station 3.1.3 -1 Amendment No. i4-4 1691

Control Rod OPERABILITY 3.1. 3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3 Perform SR 3.1.3.2 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months from for each withdrawn discovery of OPERABLE control rod. Condition A concurrent with THERMAL POWER greater than the low power setpoint (LPSP) of the RWM A.4 Perform SR 3.1.1.1. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months B. Two or more withdrawn B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months control rods stuck.

C. One or more control C.1 - - - - - - - - NOTE - - - - - - - -

rods inoperable for RWM may be bypassed reasons other than as allowed by Condition A or B. LCO 3.3.2.1, if required, to allow insertion of inoperable control rod and continued operation.

Fully insert 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months inoperable control rod.

C.2 Disarm the associated 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months CRD.

(continued)

Columbia Generating Station 3.1.3-2 Amendment No. 149,169,212216

Control Rod OPERABI LITY 3.1.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. ---------NOTE-------- D.1 Restore compliance 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Not applicable when with BPWS.

THERMAL POWER

> 10% RTP. OR D.2 Restore control rod 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Two or more inoperable to OPERABLE status.

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

E. ---------NOTE-------- E.1 Restore the control 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Not applicable when rod to OPERABLE THERMAL POWER status.

> 10% RTP.

One or more groups with four or more inoperable control rods.

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, C, D, or E not met.

Nine or more control rods inoperable.

Columbia Generating Station 3.1.3-3 Amendment No. 149.169216

Control Rod OPERABI LITY 3.1. 3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.3.1 Determine the position of each control rod. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SR 3.1.3.2 - - - - - - - - - - - - - - - - - - - NOT E- - - - - - - - - - - - - - - - - - - -

Not required to be performed unti? 31 days after the control rod is withdrawn and THERMAL POWER is greater than the LPSP of the RWM.

Insert each withdrawn control rod at least 31 days one notch.

SR 3.1.3.3 Verify each control rod scram time from In accordance fully withdrawn to notch position 5 is with

7 seconds. SR 3.1.4.l, SR 3.1.4.2, SR 3.1.4.3, and SR 3.1.4.4 SR 3:1.3.4 Verify each contro? rod does not go to the Each time the withdrawn overtravel position. control rod is withdrawn to "full out" position Prior to declaring control rod OPERABLE after work on control rod or CRD System that could affect coupling Columbia Generating Station 3.1.3-4 Amendment No. 149,169,212216

Control Rod Scram Times 3.1 .4 3.1 REACTIVITY CONTROL SYSTEMS 3.1.4 Control Rod Scram Times LCO 3.1.4 a. No more than 13 OPERABLE control rods shall be "slow,"

in accordance with Tabl~ 3.1.4-1, and

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

APPLICABILITY: MODES 1 and 2.

ACT IONS CONDITION REOUIRED ACTION COMPLETION TIME A. Requi rements of the A.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months LCO not met.

Columbia Generating Station 3.1.4-1 Amendment No. 149,169 211

Control Rod Scram Times 3.1. 4 SURVEILLANCE REQUIREMENTS

- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - -NOTE - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - -

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

SURVEI LLANCE FREQUENCY SR 3.1.4.1 Verify each control rod scram time is Prior to within the limits of Table 3.1.4-1 with exceeding reactor steam dome pressure L 800 psig. 40% RTP after each reactor shutdown L 120 days SR 3.1.4.2 Verify. for a representative sample. each 200 days tested control rod scram time is within the cumulative limits of Table 3.1.4-1 with reactor steam operation in dome pressure L 800 psig. MODE 1 SR 3.1.4.3 Verify each affected control rod scram time Prior to is within the limits of Table 3.1.4-1 with declaring any reactor steam dome pressure. control rod OPERABLE after work on control rod or CRD System that could affect scram time (continued)

Columbia Generating Station 3.1.4-2 Amendment No. 149.169.194211

Control Rod Scram Times 3.1. 4 SURVEILLANCE REQUIRtMENTS SURVEILLANCE FREOUENCY SR 3.1.4.4 Verify each affected control rod scram time Prior to is within the limits of Table 3.1.4-1 with exceeding reactor steam dome pressure L 800 psig. 40% RTP after fuel movement withi n the affected core ce 11 Prior to exceeding 40%

RTP a fter work on control rod or CRD System that cou1d affect scram time Columbia Generating Station 3.1.4-3 Amendment No. 149.169. 194 211

Control Rod Scram Times 3.1. 4 Table 3.1.4-1 Control Rod Scram Times

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

1. OPERABLE control rods with scram times not within the limits of this Table are considered "slow."

2. Enter applicable Conditions and Required Actions of LCO 3.1.3, "Control Rod OPERABILITY," for control rods with scram times> 7 seconds to notch position 5. These control rods are inoperable, in accordance with SR 3.1.3.3, and are not considered "slow."

SCRAM TIMES(al(bl (secondsl WHEN REACTOR STEAM DOME PRESSURE NOTCH POS IT ION L 800 psig 45 0.528 39 0.866 25 1.917 5 3.437 (al Maximum scram time from fully withdrawn position, based on de-energization of scram pilot valve solenoids at time zero.

(bl Scram times as a function of reactor steam dome pressure, when

< 800 psig, are within established limits.

Columbia Generating Station 3. ] .4- 4 Amendment No. 149,169,211 212

Control Rod Scram Accumul ators 3.1. 5 3.1 REACTIVITY CONTROL SYSTEMS 3.1.5 Control Rod Scram Accumulators LCD 3.1. 5 Each control rod scram accumul ator shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTI ONS

- - - - - - - - - - . - - - - - - - - - - - - - - . - - - - . - - - - .'- NOT E- - - - - . - - - - - - - - - - - - - . - - . - - ... - - - - - - - -

Separate Condition entry is allowed for each control rod scram accumulator.

CONDITION REQUIRED ACTION COMPLETI ON TIME A. One control rod scram A.1 - - - - - . -NOTE - - - - - - - -

accumulator inoperable Only applicable if, with reactor steam the associated dome pressure control rod scram

900 psig. time was within the limits of Table 3.1.4-1 during the 1 ast scram time Surveillance.

Declare the 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months associated control rod scram time "slow."

OR A.2 Declare the 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months associated control rod inoperable.

(continued)

Columbia Generating Station 3.1.5-1 Amendment No. 149,169,205 216

Control Rod Scram Accumul ators 3.1. 5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. Two or more control B.1 Restore charging 20 minutes from rod scram accumulators wa~er header pressure discovery of i noperabl e with to ~ 940 psig. Conditi on B reactor steam dome concurrent with pressure ~ 900 psig. chargi ng water header pressure

< 940 psig B.2.1 - . - . - - - - NOTE - - - - - - - -

Only applicable if the associated control rod scram time was within the limits of Table 3.1.4-1 during the last scram time Surveillance.

Declare the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated control rod scram time "s 1ow. "

8.2.2 Declare the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated control rod inoperable.

(continued)

Columbia Generating Station 3.1.5-2 Amendment No. 149,169,205 216

Control Rod Scram Accumul ators 3.1. 5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. One or more cont rol C.1 Verify the associated Immediately upon rod scram accumulators control rod is fully discovery of i noperabl e with inserted. charging water reactor steam dome header pressure pressure < 900 psig. < 940 psig C.2 Declare the 1 hour*

associated control rod inoperable.

D. Required Action B.1 or D.1 - - - - - - - - NOTE - - - - - - - -

C.1 and associated Not applicable if all Completion Time not inoperable control met. rod scram accumulators are associated with fully inserted control rods.

Place the reactor Immediately mode switch in the shutdown position.

Columbia Generating Station 3.1.5-3 Amendment No. 149,169 216

_ _ 11:11 Control Rod Scram Accumulators 3.1.5 SURVEILLANCE REOUiREMENTS __

SURVEILLANCE I FREQUENCY SR 3.1.5.1 Verify each control rod scram accumulator 7 days pressure is > 940 psig.

. /

Columbia Generating Station 3.1.5 -4 Amendment No. +44 1691

Rod Pattern Control 3.1.6 3.1 REACTIVITY CONTROL SYSTEMS 3.1.6 Rod Pattern Control LCO 3.1.6 OPERABLE control rods shall comply with the requirements of the banked position withdrawal sequence (BPWS).

APPLICABILITY: MODES 1 and 2 with THERMAL POWER < 10% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more OPERABLE A.1 - -------- NOTE---------

control rods not in Rod Worth Minimizer compliance with BPWS. (RWM) may be bypassed as allowed by LCO 3.3.2.1, "Control Rod Block Instrumentation."

Move associated 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months control rod(s) to correct position.

OR A.2 Declare associated 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months control rod(s) inoperable.

(continued)

Columbia Generating Station 3.1.6 -1 Amendment No. 4-49 1691

'lnlI -

Rod Pattern Control 3.1.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. Nine or more OPERABLE B.1 ---- NOTE---------

control rods not in RWM may be bypassed compliance with BPWS. as allowed by LCO 3.3.2.1.

Suspend withdrawal of Immediately control rods.

AND B.2 Place the reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months mode switch in the shutdown position.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.1 Verify all OPERABLE control rods comply 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months with BPWS.

Columbia Generating Station 3.1.6- 2 Amendment No. +4-9 1691

SLC System 3.1.7 3.1 REACTIVITY CONTROL SYSTEMS 3.1.7 Standby Liquid Control (SLC) System LCO 3.1.7 Two SLC subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3. I ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SLC subsystem A.1 Restore SLC subsystem 7 days inoperable, to OPERABLE status.

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

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

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 3.1.7-1 Amendment No. 149,169 199

SLC System 3.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.1 Verify available volume of sodium 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months pentaborate solution is > 4587 gallons.

SR 3.1.7.2 Verify temperature of sodium pentaborate 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months solution is within the limits of Figure 3.1.7-1.

SR 3.1.7.3 Verify continuity of explosive charge. 31 days SR 3.1.7.4 Verify the concentration of boron in 31 days solution is within the limits of Figure 3.1.7-1. AND Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after water or boron is added to solution AND Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after solution temperature is restored within the limits of Figure 3.1.7-1 (continued)

Columbia Generating Station 3.1.7-2 Amendment No. 149,169 199

SlC System 3.1. 7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1. 7.5 Verify each SLC subsystem manual and power 31 days operated 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.

SR 3.1. 7 .6 Verify each pump develops a flow rate In accordance

~ 41.2 gpm at a discharge pressure with the

> 1220 psig. tnservice Testing Program SR 3.1. 7.7 Verify flow through one SLC subsystem from 24 months on a pump into reactor pressure vessel. STAGGERED TEST BASIS SR 3.1.7.8 Verify all heat traced plplng between 24 months storage tank and pump suction valve is unblocked.

Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after solution temperature is restored within the 1 imits of Figure 3.1.7-1 SR 3.1. 7. 9 Verify sodium penta borate enrichment is Pri or to

~ 44.0 atom percent B-IO. addition to SLC Tank Columbia Generating Station 3.1.7-3 Amendment No. 149.169,199221

11.11_

SLC System 3.1.7 150 140 130 120 LL.

0 110 a)

L.

100 Q

90 E -80 C) 70 60 50 40 10.8 12.2 13.6 15 16.4 17.8 Tank Concentration (% by weight)

Figure 3.1.7-1 (Page 1 of 1)

Sodium Pentaborate Solution Temperature/Concentration Requirements Columbia Generating Station 3.1.7- 4 Amendment No. +4G9 169l1

SDV Vent and Drain Valves 3.1.8 3.1 REACTIVITY CONTROL SYSTEMS 3.1.8 Scram Discharge Volume (SDV) Vent and Drain Valves-LCO 3.1.8 Each SDV vent and drain valve shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS

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

1. Separate Condition entry is allowed for each SDV vent and drain line.

2. An isolated line may be unisolated under administrative control to allow draining and venting of the SDV.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more SDV vent A.1 Isolate the 7 days or drain lines with associated line.

one valve inoperable.

B. One or more SDV vent B.1 Isolate the 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or drain lines with associated line.

both valves inoperable.

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

Columbia Generating Station 3.1.8-1 Amendment No. i4-9 1691

__ ____ ___ ____ ___ ii1A SDV Vent and Drain Valves 3.1.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.8.1 ---- -NOTE-----------------

Not required to be met on vent and drain valves closed during performance of SR 3.1.8.2.

Verify each SDV vent and drain valve is 31 days open.

SR 3.1.8.2 Cycle each SDV vent and drain valve to the 92 days fully closed and fully open position.

SR 3.1.8.3 Verify each SDV vent and drain valve: 24 months

a. Closes in < 30 seconds after receipt of an actual or simulated scram signal; and

b. Opens when the actual or simulated scram signal is reset.

Columbia Generating Station 3.1.8-2 Amendment No. A4g41691

APLHGR 3.2.1 3.2 POWER DISTRIBUTION LIMITS 3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR)

LCO 3.2.1 All APLHGRs shall be less than or equal to the limits specified in the COLR.

APPLICABILITY: THERMAL POWER > 25% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Any APLHGR not within A.1 Restore APLHGR(s) to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months limits. within limits.

B. Reqvired Action and B.1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion to < 25% RTP.

Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.1 Verify all APLHGRs are less than or equal Once within to the limits specified in the COLR. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after

> 25% RTP AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter Columbia Generating Station 3 3.2.1 -1 Amendment No. +4-9 1691

MCPR 3.2.2 3.2 POWER DISTRIBUTION LIMITS 3.2.2 MINIMUM CRITICAL POWER RATIO (MCPR)

LCO 3.2.2 All MCPRs shall be greater than or equal to the MCPR operating limits specified in the COLR.

APPLICABILITY: THERMAL POWER 2 25% RTP.

ACTIONS COND IT ION REQUIRED ACTION COMPLETION TIME A. Any MCPR not within A.1 Restore MCPR(s) to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months limits. within limits.

B. Required Action and B.1 Reduce THERMAL POWER to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion < 25% RTP.

Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify all MCPRs are greater than or equal Once within 12 to the limits specified in the COLR. hours after 2 25% RTP 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter (continued)

Columbia Generating Station 3.2.2-1 Amendment No. 149.169 211

MCPR 3.2.2 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREOUENCY SR 3.2.2.2 Determine the MCPR limits. Once within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after each completion of SR 3.1.4.1 Once with-in 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after each completion of SR 3.1.4.2 Once withi n 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after each completion of SR 3.1.4.4 Columbia Generating Station 3.2.2-2 Amendment No. 211 r

LHGR 3.2.3 3.2 POWER DISTRIBUTION LIMITS 3.2.3 LINEAR HEAT GENERATION RATE (LHGR)

LCO 3.,2.3 All LHGRs shall be less than or equal to the limits specified in the COLR.

APPLICABILITY: THERMAL POWER > 25% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Any LHGR not within A.1 Restore LHGR(s) to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months limits. within limits.

B. Required Action and B.1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion to < 25% RTP.

Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 Verify all LHGRs are less than or equal to Once within the limits specified in the COLR. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after

> 25% RTP AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter Columbia Generating Station 3.2.3 -1 Amendment No. 4-49 1691

APRM Gain and Setpoint 3.2.4 3.2 POWER DISTRIBUTION LIMITS 3.2.4 Average Power Range Monitor (APRM) Gain and Setpoint LCO 3.2.4 a. MFLPD shall be less than or equal to Fraction of RTP (FRTP): or

b. Each required APRM Flow Biased Simulated Thermal Power-High Function Allowable Value shall be modified by greater than or equal to the ratio of FRTP and the MFLPD: or

c. Each required APRM gain shall be adjusted such that the APRM readings are > 100% times MFLPD.

APPLICABILITY: THERMAL POWER > 25% RTP.

ACTIONS

-CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the A.1 Satisfy the 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months LCO not met. requirements of the LCO.

B. Required Action and B.1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion to < 25% RTP.

Time not met..

Columbia Generating Station 3.2.4 -1 Amendment No. -149 1691

. lu.

APRM Gain and Setpoint 3.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE . FREOUENCY SR 3.2.4.1 ------------------ NOTE--------------------

Not required to be met if SR 3.2.4.2 is satisfied for LCO 3.2.4.b or LCO 3.2.4.c requirements.

Verify MFLPD is within limits. Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after

> 25% RTP AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter SR 3.2.4.2 ------------------ NOTE--------------------

Not required to be met if SR 3.2.4.1 is satisfied for LCO 3.2.4.a requirements.

Verify each required: 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

a. APRM Flow Biased Simulated Thermal Power-High Function Allowable Value is modified by greater than or equal to the ratio of FRTP and the MFLPD; or

b. APRM gain is adjusted such that the APRM reading is > 100% times MFLPD.

Columbia Generating Station 3.2.4- 2 Amendment No. i4-9 1691

RPS Instrumentation 3.3.1.1 3.3 INSTRUMENTATION 3.3.1.1 'Reactor Protection System (RPS) Instrumentation-LCO 3.3.1.1 The RPS instrumentation for each Function in Table 3.3.1.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.1.1-1. -

ACTIONS

NOTE--------------------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Place channel in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months channels inoperable. trip.

OR A.2 Place associated trip 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months system in trip.

B. One or more Functions B.1. Place channel in one 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months with one or more trip system in trip.

required channels inoperable in both OR trip systems.

B.2 Place one trip system 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months in trip.

C. One or more Functions C.1 Restore RPS trip 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with RPS trip capability.

capability not maintained.

(continued)

Columbia Generating Station 3.3.1 .1-1 Amendment No. +4-9 1691

I1!11-RPS Instrumentation 3.3.1.1 ACTIONS CONDITION REQUIRED ACTION . COMPLETION TIME D. Required Action and D.1 Enter the Condition Immediately associated Completion referenced in Time of Condition A, Table 3.3.1.1-1 for B. or C not met. the channel.

E. As required by E.1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Required Action D.1 to < 30Z RTP.

and referenced in Table 3.3.1.1-1.

F. As required by F.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Required Action D.1 and referenced in Table 3.3.1.1-1.

G. As required by G.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Required Action D.1 and referenced in Table 3.3.1.1-1.

H. As required by H.1 Initiate action to Immediately Required Action D.1 fully insert all and referenced in insertable control Table 3.3.1.1-1. rods in core cells containing one or more fuel assemblies.

Columbia Generatinig Station 3.3. 1.1- 2 Amendment No. +449 1691

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS

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

1. Refer to Table 3.3.1.1-1 to determine which SRs apply for each RPS Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains RPS trip capability.

SURVEILLANCE FREQUENCY SR 3.3.1.1.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.1.1.2 ------------------NOTE-------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER > 25% RTP.

Verify the absolute difference between 7 days the average power range monitor (APRM) channels and the calculated power

< 2% RTP plus any gain adjustment required by LCO 3.2.4. "Average Power Range Monitor (APRM) Gain and Setpoint.'

while operating at > 25% RTP.

SR 3.3.1.1.3 ------------------NOTE-------------------

Not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2.

Perform CHANNEL FUNCTIONAL TEST. 7 days SR 3.3.1.1.4 Perform CHANNEL FUNCTIONAL TEST. 7 days (continued)

Columbia Generating Station 3.3.1.1-3 3 Amendment No. 4-49 1691

_ - _- I :11 RPS Instrumentation 3.3.1.1 SURVEILLANCE REOUIREMENTS SURVEILLANCE FREOUENCY SR 3.3.1.1.5 Verify the source range monitor (SRM) and Prior to intermediate range monitor (IRM) channels withdrawing overlap. SRMs from the fully inserted position SR 3.3.1.1.6 ------------------ NOTE-------------------

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

Verify the IRM and APRM channels overlap. 7 days SR 3.3.1.1.7 Calibrate the local power range monitors. 1130 MWD/T average core exposure SR 3.3.1.1.8 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.1.1.9 ------------------ NOTES------------------

1. Neutron detectors are excluded.

2. For Function 2.a. not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2.

Perform CHANNEL CALIBRATION. 184 days (continued)

Columbia Generating Station 3.3.1 .1-4 Amendment No. +49 1691

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.1.10 -NOTES------------------

1. Neutron detectors:are excluded.

2. For Function 1. not required to be performed when entering MODE 2 from MODE I until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2.

Perform CHANNEL CALIBRATION. 18 months for Functions 1 through 4. 6.

7, and 9 through 11 AND 24 months for Functions 5 and 8

SR 3.3.1.1.11 Verify the APRM Flow Biased Simulated 18 months Thermal Power-High Function time constant is < 7 seconds.

SR 3.3.1.1.12 Verify Turbine Throttle Valve-Closure. 18 months and Turbine Governor Valve Fast Closure Trip Oil Pressure -Low Functions are not bypassed when THERMAL POWER is > 30% RTP.

SR 3.3.1.1.13 Perform CHANNEL FUNCTIONAL TEST. 24 months SR 3.3.1.1.14 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months (continued)

Columbia Generating Station 3.3.1.1-5. Amendment No. 44-168-164,179 SEP 2 0 2A2

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY 1.

SR 3.3.1.1.15 ------------------ NOTES------------------

1. Neutron detectors are excluded.

2. Channel sensors for Functions 3 and 4 are excluded. I

3. For Function 5. 'n' equals 4 channels for the purpose of determining the STAGGERED TEST BASIS Frequency.

Verify the RPS RESPONSE TIME is within 24 months on a limits. STAGGERED TEST BASIS Columbia Generating Station 3.3.1.1-6 Amendment No. 149.1'0 1691 I!, A.

RPS Instrumentation 3.3.1.1 Table 3.3.1.1-1 (page 1 of 3)

Reactor Protection system Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

1. Intermediate Range Monitors

a. Neutron 2 3 G SR 3.3.1.1.1 < 122/125 Flux - High SR 3.3.1.1.3 divisions of full SR 3.3.1.1.5 scale SR 3.3.1.1.6 SR 3.3.1.1.10 SR 3.3.1.1.14 5(a) 3 H SR 3.3.1.1.1 < 122/125 SR 3.3.1.1.4 divisions of full SR 3.3.1.1.10 scale SR 3.3.1.1.14

b. Inop 2 3 G SR 3.3.1.1.3 NA SR 3.3.1.1.14 5 (a) 3 H SR 3.3.1.1.4 NA SR 3.3.1.1.14

2. Average Power Range Monitors

a. Neutron 2 2 G SR 3.3.1.1.1 < 20% RTP Flux - High, SR 3.3.1.1.3 Setdown SR 3.3.1.1.6

- SR 3.3.1.1.7 SR. 3.3.1.1.9 SR 3.3.1.1.14

b. Flow Biased 2 F SR 3.3.1.1.1 < 0.58W + 62% RTP Simulated Thermal SR 3.3.1.1.2 and < 114.9% RTP Power - High SR 3.3.1.1.7 SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.11 SR 3.3.1.1.14

c. Fixed Neutron 1 2 F SR 3.3.1.1.1 < 120% RTP Flux - High SR 3.3.1.1.2 SR 3.3.1.1.7 SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.14 SR 3.3.1.1.15

d. Inop 1,2 2 G SR 3.3.1.1.7 NA SR 3.3.1.1.8 SR 3.3.1.1.14

3. Reactor Vessel Steam 1,2 2 G SR 3.3.1.1.8 < 1079 psig Dome Pressure -High SR 3.3.1.1.10 SR 3.3.1.1.14 SR 3.3.1.1.15 (continued) ta) With any control rod withdrawn from a core cell containing one or more fuel assemblies.

Columbia Generating Station 3.3.1.1- 7 Amendment No. 49 1691

II.I-RPS Instrumentation 3.3.1.1 Table 3.3.1.1-1 (page 2 of 3)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

4. Reactor Vessel Water 1,2 2 G SR 3.3.1.1.1 > 9.5 inches Level - Low, Level 3 SR 3.3.1.1.8 SR 3.3.1.1.10 SR 3.3.1.1.14 SR 3.3.1.1.15

5. Main Steam Isolation 1 F SR 3.3.1.1.8 < 12.5% closed Valve - Closure SR 3.3.1.1.10 SR 3.3.1.1.14 SR 3.3.1.1.15

6. Primary Containment 1,2 2 G SR 3.3.1.1.8 < 1.88 psig Pressure - High SR 3.3.1.1.10 SR 3.3.1.1.14

7. Scram Discharge Volume Water Level - High

a. Transmitter/Trip 1,2 2 G SR 3.3.1.1.8 < 529 ft 9 inches Unit SR 3.3.1.1.10 elevation SR 3.3.1.1.14 5 (a) 2 H SR 3.3.1.1.8 c 529 ft 9 inches SR 3.3.1.1.10 elevation SR 3.3.1.1.14

b. Float Switch 1,2 2 G SR 3.3.1.1.8 < 529 ft 9 inches SR 3.3.1.1.10 elevation SR 3.3.1.1.14 5(a) 2 H SR 3.3.1.1.8 < 529 ft 9 inches SR 3.3.1.1.10 elevation SR 3.3.1.1.14

8. Turbine Throttle > 30% RTP 4 E SR 3.3.1.1.8 < 7% closed Valve - Closure SR 3.3.1.1.10 SR 3.3.1.1.12 SR 3.3.1.1.14 SR 3.3.1.1.15

9. Turbine Governor > 30% RTP 2 E SR 3.3.1.1.8 > 1000 psig Valve Fast Closure, SR 3.3.1.1.10 Trip Oil SR 3.3.1.1.12 Pressure - Low SR 3.3.1.1.14 SR 3.3.1.1.15

10. Reactor Mode 1,2 2 G SR 3.3.1.1.13 NA

-Switch - Shutdown SR 3.3.1.1.14 Position 5 (a) 2 H SR 3.3.1.1.13 NA SR 3.3.1.1.14 (continued)

(a) With any control rod withdrawn from a core cell containing one or more fuel assemblies.

Columbia Generating Station 3.3. 1.1- 8 Amendment No. +49 1691

RPS Instrumentation 3.3.1.1 Table 3.3.1.1-1 (page 3 of 3)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

11. Manual Scram 1,2 2 G SR 3.3.1.1.4 NA SR 3.3.1.1.14 5(a) 2 H SR 3.3.1.1.4 NA SR 3.3.1.1.14 (a) With any control rod withdrawn from a core cell containing one or more fuel assemblies.

Columbia Generating Station 3.3.1.1-9 Amendment No. +49 1691

SRM Instrumentation 3.3.1.2 3.3 INSTRUMENTATION 3.3.1.2 Source Range Monitor (SRM) Instrumentation LCO 3.3.1.2 The SRM instrumentation in Table 3.3.1.2-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.1.2-1.

ACTIONS CONDITION -REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Restore required SRMs 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months SRMs inoperable in to OPERABLE status.

MODE 2 with intermediate range monitors (IRMs) on Rang-e 2 or below.

B. Three required SRMs B.1 Suspend control rod Immediately inoperable in MODE 2 withdrawal.

with IRMs on Range 2 or below.

C. Required Action and C.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 or B not met.

(continued)

Columbia Generating Station 3.3.1.2-1 Amendment No. 44.9 1691

& l zl . -

SRM Instrumentation 3.3.1.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. One or more required D.1 Fully insert all 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SRMs inoperable in insertable control MODE 3 or 4. rods.

AND D.2 Place reactor mode 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months switch in the shutdown position.

E. One or more required E.1 Suspend CORE Immediately SRMs inoperable in ALTERATIONS except MODE 5. for control rod insertion.

AND E.2 Initiate action to Immediately fully insert all insertable control rods in core cells containing one or more fuel assemblies.

Columbia Generating Station 3.3. 1.2-2 Amendment No. +4-4169l

SRM Instrumentation 3.3.1.2 SURVEILLANCE REOUIREMENTS

NOTE-----------------------------------

Refer to Table 3.3.1.2-1 to determine which SRs apply for each applicable MODE or other specified condition.

SURVEILLANCE FREOUENCY SR 3.3.1.2.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.1.2.2 ------------------ NOTES------------------

1. Only required to be met during CORE ALTERATIONS.

2. One SRM may be used to satisfy more than one of the following.

Verify an OPERABLE SRM detector is 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months located in:

a. The fueled region;

b. The core quadrant where CORE ALTERATIONS are being performed when the associated SRM is included in the fueled region: and

c. A core quadrant adjacent to where CORE ALTERATIONS are being performed.

when the associated SRM is included in the fueled region.

SR 3.3.1.2.3 Perform CHANNEL CHECK. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (continued)

Columbia Generating Station 3.3.1.2-3 Amendment No. i44g 1691

I1ill SRM Instrumentation 3.3.1.2 SURVEILLANCE REOUIREMENTS SURVEILLANCE FREOUENCY SR 3.3.1.2.4 ------------------ NOTE-------------------

Not required to be met with less than or equal to four fuel assemblies adjacent to the SRM and no other fuel assemblies in the associated core quadrant.

Verify count rate is: 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months during CORE

a. > 3.0 cps with a signal to noise ALTERATIONS ratio > 2:1, or AND

b. > 0.7 cps with a signal to noise ratio > 20:1. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SR 3.3.1.2.5 ------------------ NOTE-------------------

The determination of signal to noise ratio is not required to be met with less than or equal to four fuel assemblies adjacent to the SRM and no other fuel assemblies in the associated core quadrant.

Perform CHANNEL FUNCTIONAL TEST and 7 days determination of signal to noise ratio.

SR 3.3.1.2.6 ------------------ NOTE------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after IRMs on Range 2 or below.

Perform CHANNEL FUNCTIONAL TEST and 31 days determination of signal to noise ratio.

(continued)

Columbia Generating Station 3.3. 1.2-4 Amendment No. A4-4 1691

SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS -

SURVEILLANCE FREQUENCY SR 3.3.1.2.7 ------------------ NOTES------------------

1. Neutron detectors are excluded.

2. Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after IRMs on Range 2 or below.

Perform CHANNEL CALIBRATION. 18 months Columbia Generating Station 3.3. 1.2 -5 Amendment No. 4-4-9 1691

1:11 SRM Instrumentation 3.3.1.2 Table 3.3.1.2-1 (page 1 of 1)

Source Range Monitor Instrumentation APPLICABLE MODES OR OTHER REQUIRED SURVEILLANCE FUNCTION SPECIFIED CONDITIONS CHANNELS REQUIREMENTS

1. Source Range Monitor 2 (a) 3 SR 3.3.1.2.1 SR 3.3.1.2.4 SR 3.3.1.2.6 SR 3.3.1.Z.7 3,4 2 SR 3.3.1.2.3 SR 3.3.1.2.4 SR 3.3.1.2.6 SR 3.3.1.2.7 5 SR 3.3.1.2.1 SR 3.3.1.2.2 SR 3.3.1.2.4 SR 3.3.1.2.5 SR 3.3.1.2.7 (a) With IRMs on Range 2 or below.

(b) Only one SRM channel is required to be OPERABLE during spiral offload or reload when the fueled region includes only that SRM detector.

(c) Special movable detectors may be used in place of SRMs if connected to normal SRM circuits.

Columbia Generating Station 3.3. 1.2-6 Amendment No. i4-41691

OPRM Instrumentation 3.3.2.3 3.3 INSTRUMENTATION 3.3.1.3 Oscillation Power Range Monitor (OPRM) Instrumentation LCO 3.3.1.3 Four channels of the OPRM instrumentation shall be OPERABLE within the limits as specified in the COLR.

APPLICABILITY: THERMAL POWER > 25% RTP.

ACTIONS

-.------------------------- NOTE-------------------------------------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Place channel in 30 days channels inoperable. trip.

OR A.2 Place associated RPS 30 days trip system in trip.

OR A.3 Initiate alternate 30 days method to detect and suppress thermal hydraulic instability oscillations.

(continued)

Columbia Generating Station 3.3.1 .3-1 Amendment No. 171 APR 0 5 20601

_zhaL 1o wltQi L pIL I &54a-46 4w &* 6

11.1I_

-~~~ . . . . .:s ACT IOS CONDITION RECUIRED ACTION COMPLETION TIME

3. OPRM trip capability B.1 Initiate alternate 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months not maintained. method to detect and suppress thermal hydraulic instability oscillations.

C. Required Action and C.1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion < 25% RTP.

Time not met.

SURVEILLANCE REQUIREMENTS

NOTE-----------------------------------

When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . provided the OPRM System maintains trip capability.

SURVEIL'.ANCE FREQUENCY SR 3.3.1.3.1 Perform CHANNEL FUNCTIONAL TEST. 184 days (continued)

umbia Generating Station 3.3.1.3-2 Amendment No. 171 A ,..

-saf &t kf//ne6 P&wl 1z /pshz A 4 t B /5

OPRM Instrumentation 3.3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.3.2 Calibrate the local power range monitors. 1130 MWD/T average core I exposure SR 3.3.1.3.3 ------------------NOTE-------------------

Neutron detectors are excluded.

Perform CHANNEL CALIBRATION. 24 months SR 3.3.1.3.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months SR 3.3.1.3.5 Verify OPRM is not bypassed when THERMAL 24 months POWER is > 30X RTP and core flow < 60X rated core flow.

SR 3.3.1.3.6 ------------------ NOTE-------------------

Neutron detectors are excluded.

Verify the RPS RESPONSE TIME is within 24 months on a limits. STAGGERED TEST BASIS Columbia Generating Station 3.3.1.3-3 Amendment No. 44+ 186

Control Rod Block Instrumentation 3.3.2.1 3.3 INSTRUMENTATION 3.3.2.1 Control Rod Block Instrumentation LCO 3.3.2.1 The control rod block instrumentation for each Function in Table 3.3.2.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.2.1-1.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One rod block monitor A.1 Restore RBM channel 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (RBM) channel to OPERABLE status.

inoperable.

B. Required Action and B.1 -Place one RBM channel 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated Completion in trip.

Time of Condition A not met.

OR Two RBM channels inoperable.

C. Rod worth minimizer C.1 Suspend control rod Immediately (RWM) inoperable movement except by during reactor -scram.

startup.

OR (continued)

Columbia Generating Station 3.3.2. 1-1 Amendment No. 449 1691

I1IAI-Control Rod Block Instrumentation 3.3.2.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.2.1.1 Verify > 12 rods Immediately withdrawn.

OR C.2.1.2 Verify by Immediately administrative methods that startup with RWM inoperable has not been performed in the last calendar year.

AND C.2.2 Verify movement of During control control rods is in rod movement compliance with banked position withdrawal sequence (BPWS) by a second licensed operator or other qualified member of the technical staff.

D. RWM inoperable during D.1 Verify movement of During control reactor shutdown. control rods is in rod movement compliance with BPWs by a second licensed operator or other qualified member of the technical staff.

(continued)

Columbia Generating Station 3.3.2. 1-2 Amendment No. +44g 1691

Control Rod Block Instrumentation 3.3.2.1 ACTIONS -

CONDITION REQUIRED ACTION - COMPLETION TIME E. One or more Reactor E.1 Suspend control rod Immediately Mode Switch -Shutdown withdrawal.

Position channels inoperable. AND E.2 Initiate action to Immediately fully insert all insertable control rods in core cells containing one or more fuel assemblies.

SURVEILLANCE REQUIREMENTS

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

1. Refer to Table 3.3.2.1-1 to determine which SRs apply for each Control Rod Block Function.

2. When an RBM channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated.Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains control rod block capability.

SURVEILLANCE FREQUENCY SR 3.3.2.1.1 Perform CHANNEL FUNCTIONAL TEST. 92 days

.Io . t--nue (continued)

Columbia Generating Station 3.3.2.1-3 Amendment No. i4-4 1691

Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS - -'.

SURVEILLANCE FREQUENCY SR 3.3.2.1.2 ------------ NOTE-------------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after any control rod is withdrawn at

< 10% RTP in MODE 2.

Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.2.1.3 ------------------ NOTE-------------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after THERMAL POWER is < 10% RTP in MODE 1.

Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.2.1.4 ------------------ NOTE-------------------

Neutron detectors are excluded.

Verify the RBM is not bypassed: 92 days

a. When THERMAL POWER is > 30% RTP: and

b. When a peripheral control rod is not selected.

SR 3.3.2.1.5 ------------------ NOTE-------------------

Neutron detectors are excluded.

Perform CHANNEL CALIBRATION. 92 days (continued)

Columbia Generating Station 3.3.2. 1-4 Amendment No. +49 1691

Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REOUIREMENTS -_-

SURVEILLANCE FREQUENCY SR 3.3.2.1.6 Verify the RWM is not bypassed when 24 months THERMAL POWER is < 10 RTP. I SR 3.3.2.1.7 -NOTE-------------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after reactor mode switch is in the shutdown position.

Perform CHANNEL FUNCTIONAL TEST. 24 months SR 3.3.2.1.8 Verify control rod sequences input to the Prior to RWM are in conformance with BPWS. declaring RWM OPERABLE following loading of sequence into RWM

<.Žolumbia Generating Station 3.3.2.1-5 Amendment No. 149.S-9,179 SEP 2 0 200

Control Rod Block Instrumentation 3.3.2.1 Table 3.3.2.1-1 (page 1 of 1)

Control Rod Block Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REOUIREO SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS REOUIREMENTS VALUE

1. Rod Block Monitor

a. Upscale (a) 2 SR 3.3.2.1.1 < 0.58W + 51S SR 3.3.2.1.4 RTP SR 3.3.2.1.5

b. Inop (a) 2 SR 3.3.2.1.1 NA SR 3.3.2.1.4

c. Downscale (a) 2 SR 3.3.2.1.1 > 3S RTP SR 3.3.2.1.4 SR 3.3.2.1.5

2. Rod Worth Minimizer 1 (b).2 (b) 1 SR 3.3.2.1.2 HA SR 3.3.2.1.3 SR 3.3.2.1.6 SR 3.3.2.1.8

3. Reactor Mode Switch- (c) 2 SR 3.3.2.1.7 NA Shutdown Position (a) THERMAL POWER > 30S RTP and no peripheral control rod selected.

(b) With THERMAL POWER < 10S RTP.

(c) Reactor mode switch in the shutdown position.

aJ Columbia Generating Station 3.3.2.1-6 Amendment No. +4Y 1691

Feedwater and Main Turbine High Water Level Trip Instrumentation 3.3.2.2 T,.-;

3.3 INSTRUMENTATION 3.3.2.2 Feedwater and Main Turbine High Water Level Trip Instrumentation LCO 3.3.2.2 Three channels of feedwater and main turbine high water level trip instrumentation shall be OPERABLE.

APPLICABILITY: THERMAL POWER > 25% RTP.

ACTIONS

NOTE----------------------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One feedwater and main A.1 Place channel in 7 days turbine high water trip.

level trip channel inoperable.

B. Two or more feedwater B.1 Restore feedwater and 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and main turbine high main turbine high water level trip water level trip channels inoperable. capability.

C. Required Action and C.1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion to < 25% RTP.

Time not met.

Columbia Generating Station 3.3.2.-1 Amendment No. 4-49 1691

Feedwater and Main Turbine High Water Level Trip Instrumentation 3.3.2.2

_ s SURVEILLANCE REQUIREMENTS

NOTE-----------------------------..

When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided feedwater and main turbine high water level trip capability is maintained.

SURVEILLANCE FREQUENCY SR 3.3.2.2.1 Perform CHANNEL CHECK. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SR 3.3.2.2.2 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.2.2.3 Perform CHANNEL CALIBRATION. The 24 months Allowable Value shall be < 56.0 inches.

SR 3.3.2.2.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months including valve actuation:

Columbia Generating Station 3.3.2.2- 2 Amendment No. +4-9 1691

PAM Instrumentation 3.3.3.1

. 3.3 INSTRUMENTATION 3.3.3.1 Post Accident Monitoring (PAM) Instrumentation LCO 3.3.3.1 The PAM instrumentation for each Function in Table 3.3.3.1-1 shall be OPERABLE.

APPLICABILITY: MODES 1 and 2. -

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each Function.

- - - - - - 7 - - - - - - - - - - - - - - - - --. - - - - --. - - - --. - - - - -

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions A.1 Restore required 30 days with one required channel to OPERABLE channel inoperable. status.

B. Required Action and B.1 Initiate action in Immediately associated Completion accordance with Time of Condition A Specification 5.6.4.

not met. I C. One or more Functions C.1 Restore all but one 7 days with two or more required channel to required channels OPERABLE status.

inoperable.

(continued)

Columbia Generating Station 3.3.3 .1-1 Amendment No. 149,169,187, 190

PAM Instrumentation 3.3.3.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Enter the Condition Immediately associated Completion referenced in Time of Condition C Table 3.3.3.1-1 for not met. the channel.

E. As required by E.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Required Action D.1 and referenced in Table 3.3.3.1-1.

F. As required by F.1 Initiate action in Immediately Required Action D.1 accordance with and referenced in Specification 5.6.4.

Table 3.3.3.1-1. I Columbia Generating Station 3.3.3.1 -2 Amendment No. 149,169, 190

PAM Instrumentation 3.3.3.1 SURVEILLANCE REOUIREMENTS

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

1. These SRs apply to each Function in Table 3.3.3.1-1.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the other required channel(s) in the associated Function is OPERABLE.

SURVEILLANCE FREQUENCY SR 3.3.3.1.1 Perform CHANNEL CHECK. 31 days SR 3.3.3.1.2 Deleted I

SR 3.3.3.1.3 Perform CHANNEL CALIBRATION for 18 months, Functions 1, 2, 4, 5, and 10. I SR 3.3.3.1.4 Perform CHANNEL CALIBRATION for 24 months Functions 3, 6, and 7.

Columbia Generating Station 3.3.3.1-3 Amendment No. 149,169,17 , 189

PAM Instrumentation 3.3.3. 1 Table 3.3.3.1-] (page 1 of ])

Post Accident Monitoring Instrumentation UHWiTIONS REFERENCED REOUIRED FRIiM REQUIRED FUNCTION ::HAN~ELS ACTrON D.]

I. Reactor Vessel Pressure 2 Z. Reactor Vessel Water level

a. -150 inches to .. 60 inches 2 E

b. -310 inches to -]10 :nches 2

3. Suppresslon Pool Water Level

a. -25 inches to +25 inches 2

b. 2 ft to 52 ft 2

~. Suppression Chamber Pressure 2

5. Drywell Pressure

a. -5 psig to +3 psig 2

b. 0 psig to 25 pSlg 2

. 0 psig to ]80 psig ? E

6. PrimMY Containment Area Rad'ation 2

7. Penetration Flow Path PCIV POSltion 2 per penetration flow path (a)(bJ B. Deleted

9. Deleted

]0. EeeS Pump Room Flood Level 5 (a) Not required for isolation valves whose associated penetrat'on flew path is isolated by a~ least one closed and de-activated automatic valve. closed manual valve. blind flange. or cheCk valve wlth flow through the valve secured.

(bl Only one position indication channel is required for penetration flow paths with only one installed control room indication channel.

Columbia Ge~erating Statinn 3.3.3.1'4 Amendment No. 149,169.189,208

I Remote Shutdown System 3.3.3.2 3.3 INSTRUMENTATION 3.3.3.2 Remote Shutdown System LCO 3.3.3.2 The Remote Shutdown System Functions shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each Function.

- - -- - -- W-- - - - - - - -- - - - - - --- - - - - - - - - - - - - - - - - - - - - - - - - - - - - I CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Restore required 30 days Functions inoperable. Function to OPERABLE status.

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

Columbia Generating Station 3.3.3.2 -1 Amendment No. 149,169,187

Remote Shutdown System 3.3.3.2 SURVEILLANCE REQUIREMENTS

NOTE-------------------------------------

When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

SURVEILLANCE FREQUENCY SR 3.3.3.2.1 Perform CHANNEL CHECK for each required 31 days instrumentation channel that is normally energized.

SR 3.3.3.2.2 Perform CHANNEL CALIBRATION for.each 18 months required instrumentation channel, except the suppression pool water level instrumentation channel.

SR 3.3.3.2.3 Perform CHANNEL CALIBRATION for the 24 months suppression pool water level instrumentation channel.

SR 3.3.3.2.4 Verify each required control circuit and 24 months transfer switch is capable of performing the intended functions.

Columbia Generating Station 3.3.3.2 -2 Amendment No. +449 169

EOC-RPT Instrumentation 3.3.4.1 3.3 INSTRUMENTATION 3.3.4.1 *End of Cycle Recirculation Pump Trip (EOC-RPT) Instrumentation LCO 3.3.4.1 a. Two channels per trip system for each EOC-RPT instrumentation Function listed below shall be OPERABLE:

1. Turbine Throttle Valve (TTV) -Closure: and

2. Turbine Governor Valve (TGV) Fast Closure, Trip Oil Pressure- Low.

OR

b. LCO 3.2.2. 'MINIMUM CRITICAL POWER RATIO (MCPR)."

limits for inoperable EOC-RPT as specified in the COLR are made applicable.

APPLICABILITY: THERMAL POWER > 30Z RTP.

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Restore channel to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months channels inoperable. OPERABLE status.

OR (continued)

Columbia Generating Station 3.3.4.1-1 Amendm-ent No. 4-49 169l

EOC-RPT Instrumentation 3.3.4.1 ACTIONS

.CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 -------- NOTE---------

Not applicable if inoperable channel is the result of an inoperable breaker.

Place channel in 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months trip.

B. One or more Functions B.1 Restore EOC-RPT trip 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months with EOC-RPT trip capability.

capability not maintained. OR AND B.2 Apply the MCPR limit 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for inoperable MCPR limit for EOC-RPT as specified inoperable EOC-RPT not in the COLR.

made applicable.

C. Required Action and C.1 Remove the associated 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion recirculation pump Time not met. from service.

OR C.2 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months to < 30% RTP.

Columbia Generating Station 3.3.4. 1-2 Amendment No. A+4@ 1691

EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS

NOTE------------------------------------

When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains EOC-RPT trip capability.

SURVEILLANCE FREQUENCY SR 3.3.4.1.1 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.4.1.2.a Perform CHANNEL CALIBRATION. The Allowable Value shall be:

TTV- Closure: < 7% closed. 24 months SR 3.3.4.1.2.b Perform CHANNEL CALIBRATION. The Allowable Value shall be:

TGV Fast Closure. Trip Oil Pressure- Low: 18 months

> 1000 psig.

SR 3.3.4.1.3 Verify TTV -Closure and TGV Fast Closure. 18 months Trip Oil Pressure -Low Functions are not bypassed when THERMAL POWER is 2 30% RTP.

SR 3.3.4.1.4 Perform LOGIC SYSTEM FUNCTIONAL TEST, 24 months including breaker actuation.

(continued)

Columbia Generating Station 3.3 .4 .1-3 Amendment No. 149.168 1691

EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY K..

SR 3.3.4.1.5 ------------------ NOTE-------------------

Breaker arc suppression time may be assumed from the most recent performance of SR 3.3.4.1.6.

Verify the EOC-RPT SYSTEM RESPONSE TIME 24 months on a is within limits. STAGGERED TEST BASIS SR 3.3.4.1.6 Determine RPT breaker arc suppression 60 months time.

Columbia Generating Station 3.3.4.1-4 Amendment 149,168 1691

ATWS-RPT Instrumentation 3.3.4.2 3.3 INSTRUMENTATION 3.3.4.2 Anticipated Transient Without Scram Recirculatibh Pump Trip (ATWS-RPT) Instrumentation -

LCO 3.3.4.2 Two channels per trip system for each ATWS-RPT instrumentation Function listed below shall be OPERABLE:

a. Reactor Vessel Water Level -Low Low. Level 2: and

b. Reactor Vessel Steam Dome Pressure -High.

APPLICABILITY: MODE 1.

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each channel.

CONDITION REOUIRED ACTION COMPLETION TIME A. One or more channels A.1 Restore channel to 7 days inoperable. OPERABLE status.

OR A.2 -------- NOTE---------

Not applicable if -

inoperable channel is the result of an inoperable breaker.

Place channel in 7 days trip.

(continued)

Columbia Generating Station 3.3 .4 .2- 1 Amendment No. 4-44 1691

ATWS-RPT Instrumentation 3.3.4.2 ACTIONS CONDITION REQUIRED ACTION . COMPLETION TIME B. One Function with B.1 Restore ATWS-RPT trip 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months ATWS-RPT trip capability.

capability not maintained.

C. Both Functions with CA Restore ATWS-RPT trip 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ATWS-RPT trip capability for one capability not Function.

maintained.

D. Required Action and D.1 Remove the associated 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion recirculation pump Time not met. from service.

OR D.2 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SURVEILLANCE REQUIREMENTS

NOTE-------------------------------------

When a channel is placed in an inoperable status solely for performance of required Surveillances. entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains ATWS-RPT trip capability.

SURVEILLANCE FREQUENCY SR 3.3.4.2.1 Perform CHANNEL CHECK for Reactor Vessel 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Water Level - Low Low. Level 2 Function.

(continued)

Columbia Generating Station 3.3.4.2- 2 Amendment No. A4g41691

ATWS-RPT Instrumentation 3.3.4.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE - FREQUENCY SR 3.3.4.2.2 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.4.2.3 Perform CHANNEL CALIBRATION. The 18 months Allowable Values shall be:

a. Reactor Vessel Water Level -Low Low, Level 2: > -58 inches: and

b. Reactor Vessel Steam Dome Pressure -High: < 1143 psig.

SR 3.3.4.2.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months including breaker actuation.

Columbia Generating Station 3.3.4.2- 3 Amendment No. i449 1691

ECCS Instrumentation 3.3.5.1 3.3 INSTRUMENTATION 3.3.5.1 Emergency Core Cooling System (ECCS) Instrumentation LCO 3.3.5.1 The ECCS instrumentation for each Function in Table 3.3.5.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.5.1-1.

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable. referenced in Table 3.3.5.1-1 for the channel.

B. As required by B.1 --------NOTES - --

Required Action A.1 1. Only applicable and referenced in in MODES 1, 2.

Table 3.3.5.1-1. and 3.

2. Only applicable for Functions l.a. 1.b. 2.a.

and 2.b.

Declare supported 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from feature(s) inoperable discovery of when its redundant loss of

feature ECCS initiation initiation capability capability for is inoperable. feature(s) in both divisions AND (continued)

Columbia Generating Station 3.3.5.1-1 Amendment No. 4-4-9 1691

ECCS Instrumentation 3.3.5.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2 -------- NOTES--------

1. Only applicable in MODES 1. 2.

and 3.

2. Only applicable for Functions 3.a and 3.b.

Declare High Pressure 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Core Spray (HPCS) discovery of System inoperable. loss of HPCS initiation capability AND B.3 Place channel in 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months trip.

C. As required by C.1 -------- NOTES--------

Required Action A.1 1. Only applicable and referenced in in MODES 1, 2.

Table 3.3.5.1-1. and 3.

2. Only applicable for Functions 1.c. 1.d. 1.e.

1.f. 2.c, 2.d.

2.e, and 2.f.

Declare supported 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from feature(s) inoperable discovery of when its redundant loss of feature ECCS initiation initiation capability capability for is inoperable. feature(s) in both divisions AND (continued)

Columbia Generating Station 3.3.5. 1-2 Amendment No. 449 1691

ECCS Instrumentation 3.3.5.1 ACTIONS -

-CONDITION REQUIRED ACTION -- COMPLETION TIME C. (continued) C.2 Restore channel to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE status.

D. As required by D.1 -------- NOTE-----

Required Action A.1 Only applicable if and referenced in HPCS pump suction is Table 3.3.5.1-1. not aligned to the suppression pool.

Declare HPCS System 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from inoperable. discovery of loss of HPCS initiation capability AND D.2.1 Place channel in 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months trip.

OR D.2.2 Align the HPCS pump 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

suction to the

-suppression pool.

(continued)

Columbia Generating Station 3.3.5.1- 3 Amendment No. +4-9 1691

Mj-I--

ECCS Instrumentation 3.3.5.1 ACTIONS

'CONDITION REQUIRED ACTION . COMPLETION TIME E. As required by E.1 -------- NOTES--------

Required Action A.1 1. Only applicable and referenced in in MODES 1. 2.

Table 3.3.5.1-1. and 3.

2. Only applicable for Functions 1.g. 1.h, and 2.g.

Declare supported 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from feature(s) inoperable discovery of when its redundant loss of feature ECCS initiation initiation capability capability for is inoperable. feature(s) in both divisions AND E.2 Restore channel to 7 days OPERABLE status.

F. As required by F.1 Declare Automatic 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Required Action A.1 Depressurization discovery of and referenced in System (ADS) valves loss of ADS Table 3.3.5.1-1. inoperable. initiation capability in both trip systems AND (continued)

K>

Columbia Generating Station 3.3.5. 1-4 Amendment No. A4-4 1691

ECCS Instrumentation 3.3.5.1 ACTIONS -

CONDITION REQUIRED ACTION l COMPLETION TIME F. (continued) F.2 Place channel in 96 hours0.00111 days 0.0267 hours 1.587302e-4 weeks 3.6528e-5 months from trip. discovery of inoperable channel concurrent with HPCS or reactor core isolation cooling (RCIC) inoperable AND 8 days G. As required by G.1 -------- NOTE---------

Required Action A.1 Only applicable for and referenced in Functions 4.b. 4.d.

Table 3.3.5.1-1. 4.e. 5.b. and S.d.

Declare ADS valves 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from inoperable. discovery of loss of ADS initiation capability in both trip systems AND (continued)

Columbia Generating Station 3.3.5. i-5 Amendment No. A4-4 1691

ECCS Instrumentation 3.3.5.1 ACTIONS

-CONDITION REQUIRED ACTION COMPLETION TIME G. (continued) G.2 Restore channel to 96 hours0.00111 days 0.0267 hours 1.587302e-4 weeks 3.6528e-5 months from OPERABLE status. discovery of inoperable channel concurrent with HPCS or RCIC inoperable AND 8 days H. Required Action and H.1 Declare associated Immediately associated Completion supported feature(s)

Time of Condition B. inoperable.

C. D. E. F, or G not met. -

K>

Columbia Generating Station 3.3.5. 1-6 Amendment No. 4-44 1691

ECCS Instrumentation 3.3.5.1 SURVEILLANCE REOUIREMENTS

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

1. Refer to Table 3.3.5.1-1 to determine which SRs apply for each ECCS Function.

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

SURVEILLANCE FREOUENCY SR 3.3.5.1.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.5.1.2 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.5.1.3 Perform CHANNEL CALIBRATION. 92 days SR 3.3.5.1.4 Perform CHANNEL CALIBRATION. 18 months SR 3.3.5.1.5 Perform CHANNEL CALIBRATION. 24 months SR 3.3.5.1.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months Columbia Generating Station 3.3.5.1 -7 Amendment No. 149,1'0 1691

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 1 of 4)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REOUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER REOUIREO SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REOUIREMENTS VALUE

1. Low Pressure Coolant Injection-A (LPCI) and Low Pressure Core Spray (LPCS) Subsystems I-

a. Reactor Vessel Water 1.2.3. 2 (b) B SR 3.3.5.1.1 > -142.3 Level - Low Low Low. SR 3.3.5.1.2 Inches Level I 4 (a) 5(a) SR 3.3.5.1.4 SR 3.3.5.1.6

b. Drywell 1.2.3 2 (b) B SR 3.3.5.1.2 < 1.88 psig.

Pressure- High SR 3.3.5.1.4 SR 3.3.5.1.6

c. LPCS Pump Start-LOCA 1.2.3. i(e) C SR 3.3.5.1.5 > 8.53 seconds Time Delay Relay SR 3.3.5.1.6 and 4 (a) 5 (a) < 10.64 seconds

d. LPCI Pump A 1.2.3. 1 (e) C SR 3.3.5.1.5 > 17.24 Start-LOCA Time SR 3.3.5.1.6 seconds and Delay Relay 4 (a). 5 (a) < 21.53 seconds

e. LPCI Pump A 1.2.3. 1 C SR 3.3.5.1.2 > 3.04 seconds Start- LOCA/LOOP Time SR 3.3.5.1.3 and Delay Relay 4 (a). 5 (a) SR 3.3.5.1.6 < 6.00 seconds

f. Reactor Vessel 1.2.3 1 per C SR 3.3.5.1.2 > 448 psig Pressure- Low valve SR 3.3.5.1.4 and (Injection SR 3.3.5.1.6 < 492 psig Permissive) 1 per B SR 3.3.5.1.2 > 448 psig 4 (a). 5 (a) valve SR 3.3.5.1.4 and SR 3.3.5.1.6 < 492 psig

g. LPCS Pump Discharge 1.2.3. 1 E SR 3.3.5.1.2 > 668 gpm Flow- Low (Minimum SR 3.3.5.1.4 and Flow) 4 (a), 5 (3) SR 3.3.5.1.6 < 1067 gpm

h. LPCI Pump A Discharge 1.2.3. 1 E SR 3.3.5.1.2 > 605 gpm Flow - Low (Minimum SR 3.3.5.1.4 and Flow) 4 (a). 5 (a) SR 3.3.5.1.6 < 984 gpm Manual Initiation 1,2.3. 2 C SR 3.3.5.1.6 NA 4 (a) 5 (a)

(continued)

(a) When associated subsystem(s) are required to be OPERABLE.

(b) Also required to Initiate the associated diesel generator (OG).

(e) Also supports OPERABILITY of 230 kV offsite power circuit pursuant to LCO 3.8.1 and LCO 3.8.2 I'

Columbia Generating Station 3.3. 5.1-8 Amendment No. 14.169,1O66.169,172 AMP 10Q XMsI

ECCS Instrumentation 3.3.5.1

- Table 3.3.5.1-1 (page 2 of 4) ,

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REOUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER REOUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REOUIREMENTS ALUE V-

2. LPCI 8 and LPCI C Subsystems

a. Reactor Vessel Water 1.2.3. 2 (b) B SR 3.3.5.1.1 > -142.3 Level - Low Low Low. SR 3.3.5.1.2 Inches Level 1 4 (a)' 5 (a) SR 3.3.5.1.4 SR 3.3.5.1.6

b. Drywell Pressure- High 1.2.3 2 (b) B SR 3.3.5.1.2 < 1.88 psig SR 3.3.5.1.4 SR 3.3.5.1.6

c. LPCI Pump B 1.2.3. I(e) C SR 3.3.5.1.5 > 17.24 Start - LOCA Time Delay I SR 3.3.5.1.6 seconds and Relay 4 (a). 5 (a) < 21.53 seconds

d. LPCI Pump C 1.2.3. 1 (e) C SR 3.3.5.1.5 > 8.53 seconds I

Start- LOCA Time Delay SR 3.3.5.1.6 and Relay 4 (a).5Ca) < 10.64 seconds

e. LPCI Pump B 1.2.3. 1 C SR 3.3.5.1.2 > 3.04 seconds Start- LOCA/LOOP Time SR 3.3.5.1.3 and Delay Relay 4 (a).5(a) SR 3.3.5.1.6 < 6.00 seconds

f. Reactor Vessel 1.2.3 1 per C SR 3.3.5.1.2 > 448 psig Pressure- Low valve SR 3.3.5.1.4 and (Injection Permissive) SR 3.3.5.1.6 <;492 psig 4 (a).5Ca) 1 per B SR 3.3.5.1.2 > 448 psig valve SR 3.3.5.1.4 and SR 3.3.5.1.6 < 492 psig

9. LPCI Pumps B & C 1.2.3. 1 per E SR 3.3.5.1.2 > 6D5 gpm Discharge Flow- Low pump SR 3.3.5.1.4 and (Minimum Flow) 4 (a)' 5 (a) SR 3.3.5.1.6 < 984 gpm

h. Manual Initiation 1.2.3. 2 C SR 3.3.5.1.6 NA 4 (a), 5 (a)

3. High Pressure Core Spray (HPCS) System

a. Reactor Vessel Water 1.2.3. 4 (b) B SR 3.3.5.1.1 > -58 inches Level - Low Low. SR 3.3.5.1.2 Level 2 4 (a). 5 (a) SR 3.3.5.1.4.

SR 3.3.5.1.6 (continued)

(a) When associated subsystem(s) are required to'be OPERABLE.

(b) Also required to initiate the associated DG.

(e) Also supports OPERABILITY of 230 kV offslte power circuit pursuant to LCO 3.8.1 and LCO 3.B.2 I

Columbia Generating Station 3.3.5.1 -9 Amendment No.- 142,'.IO1GG6G9,172 APR 3 0 2so1

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 3 of 4)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REOUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER REOUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

3. HPCS System (continued)

b. Drywell 1.2.3 4 (b) B SR 3.3.5.1.2 < 1.88 psig Pressure - High SR 3.3.5.1.4 SR 3.3.5.1.6

c. Reactor Vessel 1.2.3. 2 C SR 3.3.5.1.1 < 56.0 inches Water SR 3.3.5.1.2 Level - High. 4 (a), 5 (a) SR 3.3.5.1.4 Level 8 SR 3.3.5.1.6

d. Condensate 1.2.3. 2 D SR 3.3.5.1.2 > 448 ft 1 inch Storage Tank SR 3.3.5.1.4 elevation Level - Low 4(").5(C) SR 3.3.5.1.6

e. Suppression Pool 1.2.3 2 D SR 3.3.5.1.2 < 466 ft Water Level - High SR 3.3.5.1.4 11 Inches SR 3.3.5.1.6 elevation

f. HPCS System Flow 1.2.3. 1 E SR 3.3.5.1.2 > 1200 gpm Rate - Low SR 3.3.5.1.4 and < 1512 gpm (Minimum Flow) 4 (a) 5(a) SR 3.3.5.1.6

g. Manual Initiation 1.2.3. 2 C SR 3.3.5.1.6 NA 4(a) 5(a)

4. Automatic Depressurization System (ADS) Trip System A

a. Reactor Vessel 1.2(0) 3(d) 2 F SR 3.3.5.1.1 > *142.3 inches Water Level - Low SR 3.3.5.1.2 Low Low, Level 1 SR 3.3.5.1.4 SR 3.3.5.1.6

b. ADS Initiation 1 G SR 3.3.5.1.2 < 115.0 seconds Timer SR 3.3.5.1.3 SR 3.3.5.1.6

c. Reactor Vessel 1.2(d) 3(d) I F SR 3.3.5.1.1 > 9.5 inches Water Level - Low. SR 3.3.5.1.2 Level 3 SR 3.3.5.1.4 (Permissive) SR 3.3.5.1.6

d. LPCS Pump 1.2(d) ,3(d) 2 G SR 3.3.5.1.2 > 119 psig Discharge SR 3.3.5.1.4 and Pressure - High SR 3.3.5.1.6 < 171 psig (continued)

(a) When associated subsystem(s) are required to be OPERABLE.

(b) Also required to initiate the associated DOG.

(c) When HPCS is OPERABLE for compliance with LCO 3.5.2. *ECCS-Shutdown., and aligned to the condensate storage tank while tank water level is not within the limit of SR 3.5.2.2.

(d) With reactor steam dome pressure > 150 psig.

Columbia Generating Station 3.3.53.1-10 Amendment No. 149,1'0,16GG 1691

ECCS Instrumentation 3;3.5.1 Table 3.3.5.1-1 (page 4 of 4)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MOOES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

4. ADS Trip System A (continued)

e. LPCI Pump A Discharge 1 ,2(d),3(d) 2 G 'SR 3.3.5.1.2 > 116 psig and Pressure-High SR 3.3.5.1.4 7 134 psig SR 3.3.5.1.6

f. Accumulator Backup 1 ,2(d), 3 (d) 3 F SR 3.3.5.1.2 > 151.4 psig Compressed Gas System SR 3.3.5.1.4 Pressure-Low SR 3.3.5.1.6

9. Manual Initiation 1 2 (d),3(d) 4 G SR 3.3.5.1.6 NA

5. ADS Trip System B

a. Reactor Vessel Water 1 ,2 (d),3(d) 2 F SR 3.3.5.1.1 > -142.3 inches Level -Low Low Low, SR 3.3.5.1.2 Level 1 SR 3.3.5.1.4 SR 3.3.5.1.6

b. ADS Initiation Timer 1 , 2 (d), 3 (d) 1 G SR 3.3.5.1.2 < 115.0 seconds SR 3.3.5.1.3 SR 3.3.5.1.6

c. Reactor Vessel Water 1 , 2 (d), 3 (d) 1 F SR 3.3.5.1.1 > 9.5 inches Level - Low, Level 3 SR 3.3.5.1.2 (Permissive) SR 3.3.5.1.4 SR 3.3.5.1.6

d. LPCI Pumps 8 & C 1 ,2(d) 3(d) 2 per pump G SR 3.3.5.1.2 > 116 psig Discharge SR 3.3.5.1.4 and Pressure -High SR 3.3.5.1.6 < 134 psig

e. Accumulator Backup 1 ,2(d), 3 (d) 3 F SR 3.3.5.1.2. 2 151.4 psig Compressed Gas System SR 3.3.5.1.4 Pressure-Low SR 3.3.5.1.6

f. Manual Initiation 1 , 2 (d). 3 (d) 4 G SR 3.3.5.1.6 NA (d) With reactor steam dome pressure > 150 psig.

Columbia Generating Station 3.3.5.1 -11 Amendment No. 149.16G 1691

RCIC System Instrumentation 3.3.5.2 3.3 INSTRUMENTATION -

3.3.5.2 Reactor Core Isolation Cooling (RCIC) System Instrumentation LCO 3.3.5.2 rhe RCIC System instrumentation for each Function in Table 3.3.5.2-1 shall be OPERABLE.

APPLICABILITY: MODE 1, MODES 2 and 3 with reactor steam dome pressure > 150 psig.

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable. referenced in Table 3.3.5.2-1 for the channel.

B. As required by B.1 Declare RCIC System 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Required Action A.1 inoperable. discovery of and referenced in loss of RCIC Table 3.3.5.2-1. initiation capability AND B.2 Place channel in 24hours trip.

(continued)

Columbia Generating Station 3.3; 5.2-1 Amendment No. A44 1691

HERID RCIC System Instrumentation 3.3.5.2 ACTIONS

-CONDITION REQUIRED ACTION COMPLETION TIME C. As required by C.1 Restore channel to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Required Action A.1 OPERABLE status.

and referenced in Table 3.3.5.2-1.

D. As required by D.1 -------- NOTE---------

Required Action A.1 Only applicable if and referenced in RCIC pump suction is Table 3.3.5.2-1. not aligned to the suppression pool.

Declare RCIC System 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from inoperable. discovery of loss of RCIC initiation capability AND D.2.1 Place channel in 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months trip.

OR D.2.2 Align RCIC pump 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months suction to the suppression pool.

E. Required Action and E.1 Declare RCIC System Immediately associated Completion inoperable.

Time of Condition B.

C. or D not met.

K>

Columbia Generating Station 3.3.5.2- 2 Amendment No. +4-9 1691

Table 3.3.5.2-1 (page 1 of 1)

React'.1r Core I'i0lati,)n Cooling System Instrulncr.tation CONDITIONS REr}U IRED REFEREnCED CHANNELS FROM PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION FUNCT 19N ACTION.A.l REQUIREMUH5 VALUE

l. Reactor Vessel Water 4 B 5R 3.3.5.2.1 > -58 inches Level - Low Low. SR 3.3.5.2.2 Level 2 SR 3.3.5.2.3 SR 3.3.5.2.4

2. Reactor Vessel Water 2 C SR 3.3.5.2.1 ~ 56 inches Level - High. Level 8 SR 3.3.5.2.2 SR 3.3.5.2.3 SR 3.3.5.2.4

3. Condensote Storage 2 D SR 3.3.5.2.1 ~ 447 ft 7 Tank Level - Low 5R 3.3.5.2.2 i I1ches SR 3.3.5.2.3 elevatiDn SR 3.3.5.2.4

4. t~anual Initiation 2 C SR 3.3.5.2.4 NA t: I) 1 1/111 b i,] Gi? ne r ,J till IJ S t r1 t i rj n AmL'willH'nt 1\10. 1'19,169,210

t1L1L RCIC System Instrumentation 3.3.5.2 Table 3.3.5.2-1 (page 1 of 1)

Reactor Core Isolation Cooling System Instrumentation CONDITIONS REQUIRED REFERENCED CHANNELS PER FROM REQUIRED SURVEILLANCE ALLOWABLE FUNCTION FUNCTION ACTION A.1 REQUIREMENTS VALUE

1. Reactor Vessel Water 4 B SR 3.3.5.2.1 > -58 inches Level - Low Low, Level 2 SR 3.3.5.2.2 SR 3.3.5.2.3 SR 3.3.5.2.4

2. Reactor Vessel Water 2 C SR 3.3.5.2.1 c 56 inches Level - High, Level 8 SR 3.3.5.2.2 SR 3.3.5.2.3 SR 3.3.5.2.4

3. Condensate Storage Tank 2 D SR 3.3.5.2.1 > 446 ft 0 inches Level - Low SR 3.3.5.2.2 elevation SR 3.3.5.2.3 SR 3.3.5.2.4

4. Manual Initiation 2 C SR 3.3.5.2.4 NA Columbia Generating Station 3.3.5.2 -4 Amendment No. +44 1691

Primary Containment Isolation Instrumentation 3.3.6.1 3.3 INSTRUMENTATION 3.3.6.1 Primary Containment IsolaLion Instrumentation LCO 3.3.6.1 The primary containment isolation instrumentation for each Function in Table 3.3.6.1-1 shall be OPERABLE.

APPLICABILlTY: According to Table 3.3.6.1-1.

ACTIONS

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

1. Penetration flow paths may be unisolated intermittently under administrative controls.

2. Separate Condition entry is allowed for each channel.

COND IT ION REOUIRED ACT ION COMPLETION T1 ME A. One or more required A.l Place channel in ] 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for channels inoperable. t r' i p . Functions 2. a .

2.c, 5.d, 6.a and 6.b AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for Functions other than Functions 2. a, Z.c. 5. d , 6.a and 6.b R. One or more automatic B. 1 Restore isolation 1 hour Functions with crJpability, isolation capability not maintained.

(continued)

Columbia GeneraLing Station 3.3.6.1-1 Amendment No. 149.169,208

I'll*

Primary Containment Isolation Instrumentation 3.3.6.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Enter the Condition Immediately associated Completion referenced in Time of Condition A Table 3.3.6.1-1 for or B not met. the channel.

D. As required by D.1 Isolate associated 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Required Action C.1 main steam line and referenced in (MSL).

Table 3.3.6.1-1.

OR D.2.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND D.2.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E. As required by E.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Required Action C.1 and referenced in Table 3.3.6.1-1.

F. As required by F.1 Isolate the affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Required Action C.1 penetration flow and referenced in path(s).

Table 3.3.6.1-1.

G. As required by G.1 Isolate the affected 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Required Action C.1 penetration flow and referenced in path(s).

Table 3.3.6.1-1.

(continued)

Columbia Generating Station 3.3.6. 1-2 Amendment No. +44 1691

Primary Containment Isolation Instrumentation 3.3.6.1 ACTIONS _ -

CONDITION REQUIRED ACTION - COMPLETION TIME H. Required Action and H.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 F AND or G not met.

H.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR As required by Required Action C.1 and referenced in Table 3.3.6.1-1.

I. As required by 1.1 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Required Action C.1 standby liquid and referenced in control (SLC)

Table 3.3.6.1-1. subsystem inoperable.

OR 1.2 Isolate the Reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Water Cleanup (RWCU)

System.

J. As required by J.1 Initiate action to Immediately Required Action C.1 restore channel to and referenced in OPERABLE status.

Table 3.3.6.1-1.

OR J.2 Initiate action to Immediately isolate-the Residual Heat Removal (RHR)

-- Shutdown Cooling

-(SDC) System.

Columbia Generating Station 3.3t6.1-3 Amendment No: 4-49 1691l

Primary Containment Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS

- -- :--------------------------NOTES------------------------------------

1. Refer to Table 3.3.6.1-1 to determine which SRs apply for each Primary Containment Isolation Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains isolation capability.

I- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -

SURVEILLANCE FREQUENCY SR 3.3.6.1.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.6.1.2 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.6.1.3 Perform CHANNEL FUNCTIONAL TEST. 184 days SR 3.3.6.1.4 Perform CHANNEL CALIBRATION. 18 months SR 3.3.6.1.5 Perform CHANNEL CALIBRATION. 24 months SR 3.3.6.1.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months SR 3.3.6.1.7 ------------------ NOTE-------------------

Channel sensors for Functions l.a. 1.b.

and 1.c are excluded.

Verify the ISOLATION SYSTEM RESPONSE TIME 24 months on a is within limits. STAGGERED TEST BASIS I

Columbia Generating Station 3.3.6 .1-4 Amendment No. 149,159 1691

Columbia Generating Station 3.3.6.1-5 Amendment No.

149.169.172.214 219

Primary Containment. Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 2 of 4)

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

2. Primary Containment Isolation (continued)

d. Reactor Building 1.2.3 2 F SR 3. 3.6.1.1 < 16.0 mR/hr Vent Exhaust SR 3.3.6.1.2 Plenum SR 3.3.6.1.4 Radiation - High SR 3.3.6.1.6

e. Manual Initiation 1 2.3 4 G SR 3.3.6.1.6 NA

3. Reactor Core Isolation Cooling (RCIC) System Isolation

a. RCIC Steam Line 1.2.3 I F SR 3.3.6.1.1 < 250 inches wg Flow - High SR 3.3.6.1.2 SR 3.3.6.1.4 SR 3.3.6.1.6

b. RCIC Steam Line 1.2.3 1 F SR 3.3.6.1.2 < 3.00 seconds Flow- Time Delay SR 3.3.6.1.4 SR 3.3.6.1.6

c. RCIC Steam Supply 1.2.3 2 F SR 3.3.6.1.2 > 61 psig Pressure - Low SR 3.3.6.1.4 SR 3.3.6.1.6

d. RCIC Turbine 1.2.3 2 F SR 3.3.6.1.2 < 20 psig Exhaust Diaphragm SR 3.3.6.1.4 Pressure - High SR 3.3.6.1.6

e. RCIC Equipment 1 F SR 3.3.6.1.3 < 180F Room Area SR 3.3.6.1.4 Temperature - High SR 3.3.6.1.6

f. RCIC Equipment 1.2.3 1 F SR 3.3.6.1.3 < 60F Room Area SR 3.3.6.1.4 Differential SR 3.3.6.1.6 Temperature - High

g. RWCU/RCIC Steam 1.2.3 1 F SR 3.3.6.1.3 ' 180F Line Routing Area SR 3.3.6.1.4 Temperature - High SR 3.3.6.1.6

h. Manual Initiation 1.2.3 1(b) G SR 3.3.6.1.6 HA

4. RWCU System Isolation

a. Differential 1.2.3 I F SR 3.3.6.1.1 < 67.4 gpm Flow - High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 (continued)

(b) RCIC Manual Initiation only inputs into one of the two trip systems.

Columbia Generating Station 3.3.6.1- 6 Amendment No. 149,169,172 APRD 9 n02S

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 3 of 4)

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

4. RWCU System Isolation (continued)

b. Differential 1.2.3 1 F SR 3.3.6.1.2 < 46.5 seconds Flow-Time Delay SR 3.3.6.1.5 SR 3.3.6.1.6 1 F SR 3.3.6.1.1 < 271.7 gpm

c. Blowdown Flow- 1.2.3 High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7 1 F SR 3.3.6.1.3 < 160°F

d. Heat Exchanger 1.2.3 Room Area SR 3.3.6.1.4 Temperature - High SR 3.3.6.1.6 1.2,3 1 F SR 3.3.6.1.3 < 70°F

e. Heat Exchanger Room Area SR 3.3.6.1.4 Ventilation SR 3.3.6.1.6 Differential Temperature - High 1.2.3 1 per room F SR 3.3.6.1.3 < 1801F

f. Pump Room Area Temperature - High SR 3.3.6.1.4 SR 3.3.6.1.6

g. Pump Room Area 1.2.3 1 per room F SR 3.3.6.1.3 100DF Ventilation SR 3.3.6.1.4 Differential SR 3.3.6.1.6 Temperature - High

h. RWCU/RCIC Line 1.2.3 1 F SR 3.3.6.1.3 < 180*F Routing Area SR 3.3.6.1.4 Temperature- High SR 3.3.6.1.6

i. RWCU Line Routing 1,2.3 1 per room F SR 3.3.6.1.3 Area SR 3.3.6.1.4 Temperature - High SR 3.3.6.1.6 Room 409. 509 <~ 175*F Areas Room 408. 511 <. 180*F Areas J. Reactor Vessel 1.2.3 2 F SR 3.3.6.1.2 > -58 inches Water Level - Low SR 3.3.6.1.4 Low, Level 2 SR 3.3.6.1.6

k. SLC System Initiation 1.2.3 2 (c) I SR 3.3.6.1.6 NA I

1. Manual Initiation 1.2.3 2 G SR 3.3.6.1.6 NA (continued)

(c) SLC System Initiation only inputs Into one of the two trip systems.

Columbia Generating Station 3.3.6.1-7 Amendment No. 149,-9 ,!&+/-l 199

Pr i illd r'y Con trJ i nllH~n t Isolation lnstruillentar,ion 3.3.6.1

",[)!e 3.3. h. 1-) (page 4 of 4)

Pr1 Jr." ry Containment Isoldl;Ofl Ifl:; t r,lme ~ t d t IOn APPL reMILE CONDITIONS MonfS Cil ilEOUiRED RE'~REN(£D OThER r;HAN~tLS -ROM SPEClflEQ PER TRIP REOUIREO SURVi:ILLANCr ALLOWAiH E FIJ~C r I ON COND:TIONS SYSTE'~ Act I o~ C.l REQUIREMENTS VALUE

~. R"',R :,DC 51' tf,o' Iso1atiofl

d. Pump Roo'11 Area 3 I oer r'oom SR 3.3,6.1.3 S. tSO"F Temperilture tl; ~r; SR 3.3.6.1.4 SR 3.3.5.1.6

b. ;>ump Room Area I per room SR 3.3.6. I .3 S 70" F VEntllation SR 3,3,5, l ,4 Oifferenti 31 SR 3.3.6.1.5 7e,ppef'Qture - r.i'jh

c. Heilt fxc!'Jn<jer J I per room F SR 3. J. 6 ..1. J Area :ill L3.6. \.4 Temperature- High SR 3,3.6. I .6 Room ')0:' Ar'"d ( 140"F ROO1i 501 Ari!o .s. [60*F R'Jom 60':1 ArQa S. 150" Room 606 Ar!'4 ~ 140*'

2( d) SR C. ReactO" Ve$sc~ 3.4. ') J 3.3.n.!.l L 9.5 inches

\/dtfl I.e'l e 1 lOw, SR J.3.6.1.2

.. eyel 3 S~ 3.3.5,1.4 SR 3.3,6.1.6 fl. Rerlctor IJ es s.e 1 J .2. J SR 3,),6.1.2 ~ 135 p~ig PrC*5sure High SR 3,1,6,1.~

SR },).6.1.6

f. ~laNI<ll 1'11tldtion : ,2. J C, 5R 3 ), r,. 1. 6 NA 6 Tr.)verS1flg lnco,e ProOe Isolatl0n fleactor '1essel ! .2.:3 1

~ G SR 3.3.6 "

d. L *~8 l:1cneS I-iat!'r t evel Low 5R 3.3.(1, .4 low. Leve! 2 SR 3, J, 6. .6 IL Dry'",,, 11 F r,:!:;) ;)l_re \ .2.3 2 (i SR 3 j ,r,) , .: of.- i ! . liB p5;g rtlc;tl SR ) J 6 4 SR ),3 6.1.6 (dl Only one trip 5y5te~ regYirQd In HOCES 4 dnJ 5 wllh QHA Shutdown C0011n9 System integ"ity

!1ldWU ned.

Columbia Generating Station 3.3,6, [*8 Amendment No. 220 149,161,169,209

Secondary Containment Isolation Instrumentation 3.3.6.2 3.3 INSTRUMENTATION K-) 3.3.6.2 Secondary Contaihment Isolation Instrumentation LCO 3.3.6.2 The secondary containment isolation instrumentation for each Function in Table 3.3.6.2-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.6.2-1.

ACTIONS

----------------------------- NOTE ------------------------------------

Separate Condition entry is allowed-for each channel.

CONDITION REQUIRED ACTION, COMPLETION TIME A. One or more channels A.1 Piace channel in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for inoperable. trip. Function 2 I I AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for Functions other

- than Function 2 B. One or more automatic B.1 Restore isolation 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Functions with capability.

isolation capability not maintained.

C. Required Action and C1.1 --Isolate the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated Completion associated Time not met. penetration flow path(s).

OR (continued)

Columbia Generating Station 3.3.6.2-1 Amendment No. 4-49 1691

III' Secondary Containment Isolation Instrumentation 3.3.6.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.1.2 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months secondary containment isolation valve(s) inoperable.

AND C.2.1 Place the associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months standby gas treatment (SGT) subsystem in operation.

OR C.2.2 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SGT subsystem inoperable.

SURVEILLANCE REQUIREMENTS

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

1. Refer to Table 3.3.6.2-1 to determine which SRs apply for each Secondary Containment Isolation Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains isolation capability.

SURVEILLANCE FREQUENCY SR 3.3.6.2.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

Columbia Generating Station 3.3.6. 2-2 Amendment No. +44 1691

Secondary Containment.Isolation Instrumentation I 3.3.6.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.6.2.2 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.6.2.3 Perform CHANNEL CALIBRATION. 18 months SR 3.3.6.2.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months Columbia Generating Station 3.3.6.2 -3 Amendment No. +4-9 1691

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

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

1. Reactor Vessel Water 1.2.3.(a) 2 (c) SR 3.3.6.2.2 > -58 inches Level - Low Low, Level 2 SR 3.3.6.2.3 SR 3.3.6.2.4

2. Drywell Pressure-High 1.2.3 2 (c) SR 3.3.6.2.2 ( 1.88 psig SR 3.3.6.2.3 SR 3.3.6.2.4

3. Reactor Building Vent 1.2,3. 2 SR 3.3.6.2.1 < 16.0 mR/hr Exhaust Plenum Radiation - High (a) SR SR SR 3.3.6.2.2 3.3.6.2.3 3.3.6.2.4 I

4. Manual Initiation 1.2.3. 4 SR 3.3.6.2.4 NA (a)

I (a)

(b)

During operations with a potential Deleted for draining the reactor vessel.

I (c) Also required to initiate the associated LOCA Time Delay Relay Function pursuant to LCO 3.3.5.1.

Columbia Generating Station 3.3.6.2-4 Amendment No. 149,169,1721 199

CREF System Instrumentation 3.3.7.1 3.3 INSTRUMENTATION 3.3.7.1 ~Filtration

~~ ~ (CREF)

Control Room EmergencyThe~~~~~~ CRE System-Instrumentation ucini Sytmisrmnainfrec LCO 3.3.7.1 The CREF System instrumentation for each Function in Table 3.3.7.1-1 shall be. OPERABLE.

APPLICABILITY: According to Table 3.3.7.1-1.

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each channel.

CONDITION REOUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable. referenced in Table 3.3.7.1-1 for the channel.

B. As required by B.1 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Required Action A.l CREF subsystem discovery of and referenced in inoperable. loss of CREF Table 3.3.7.1-1. initiation capability in both trip systems AND B.2 Place channel in 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months trip.

(continued)

Columbia Generating Station 3.3.7.1 -1 Amendment No.-4-49 1691

CREF System Instrumentation 3.3.7.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. As required by C.1 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Required Action A.1 CREF subsystem discovery of and referenced in inoperable, loss of CREF Table 3.3.7.1-1. initiation capability in both trip systems AND C.2 Place channel in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months trip.

D. Required Action and D.1 Place associated CREF I hour associated Completion subsystem in the Time of Condition B or pressurization mode C not met. of operation.

OR 0.2 Declare associated I hour CREF subsystem inoperable.

I Columbia Generating Station 3.3.7.1-2 Amendment No. 149,169 199

CREF System Instrumentation 3.3.7.1 SURVEILLANCE REQUIREMENTS

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

1. Refer to Table 3.3.7.1-1 to determine which SRs apply for each CREF System Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains CREF initiation capability.

I SURVEILLANCE FREQUENCY SR 3.3.7.1.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.7.1.2 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.7.1.3 Perform CHANNEL CALIBRATION. 18 months SR 3.3.7.1.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months Columbia Generating Station 3.3.7.1-3 Amendment No. 149,169,187z 199

CREF System Instrumentation 3.3.7.1 Table 3.3.7.1-1 (page 1 of 1)

Control Room Emergency Filtration System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION A.1 REQUIREMENTS VALUE

1. Reactor Vessel 1,2.3. 2 B SR 3.3.7.1.1 > -58 inches Water Level-Low (a) SR 3.3.7.1.2 Low. Level 2 SR 3.3.7.1.3 SR 3.3.7.1.4

2. Drywell 1.2,3 2 C SR 3.3.7.1.1 < 1.88 psig Pressure -High SR 3.3.7.1.2 SR 3.3.7.1.3 SR 3.3.7.1.4

3. Reactor Building 1.2,3, 2 B SR 3.3.7.1.1 < 16.0 mR/hr SR 3.3.7.1.2 Vent Exhaust Plenum Radiation -High (a)

SR SR 3.3.7.1.3 3.3.7.1.4 I

(a) During operations with a potential for draining the reactor vessel.

I Columbia Generating Station 3.3.7.1-4 Amendment No. 149,169 199

LOP Instrumentation 3.3.8.1 3.3 INSTRUMENTATION 3.3.8.1 Loss of Power (LOP) Instrumentation LCO 3.3.8.1 The LOP instrumentation for each Function in Table 3.3.8.1-1 shall be OPERABLE.

APPLICABILITY: MODES 1, 2. and 3.. -

When the associated diesel generator (DG) is required to be OPERABLE by LCO 3.8.2, "AC Sources- Shutdown."

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed-for each channel.

CONDITION l REOUIRED ACTION COMPLETION TIME A. One or more required A.1 Enter the Condition Immediately channels inoperable. referenced in Table 3.3.8.1-1 for the channel.

B. As required by 8.1 Declare associated DG 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Required Action A.1 inoperable. discovery of and referenced in loss of Table 3.3.8.1-1. initiation capability for the associated DG AND

B.2 Restore channel to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE status.

(continued)

Columbia Generating Station 3.3.8.1i- 1 -Amendment No. 4-49 1691

awL-LOP Instrumentation 3.3.8.1 ACTIONS

.CONDITION REOUIRED ACTION COMPLETION TIME C. As required by C.1 Place channel in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Required Action A.1 trip.

and referenced in Table 3.3.8.1-1.

D. Required Action and D.1 Declare associated OG Immediately associated Completion inoperable.

Time of Condition B or C not met. OR

NOTE-------------

Only applicable for Functions 1.c and 1.d.

D.2.1 Open offsite circuit Immediately supply breaker to associated 4.16 kV ESF bus.

AND D.2.2 Declare associated Immediately offsite circuit inoperable.

Columbia Generating Station 3.3.8. 1-2 Amendment No. 4-4-9 1691

LOP Instrumentation 3.3.8.1 SURVEILLANCE REOUIREMENTS

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

1. Refer to Table 3.3.8.1-1 to determine which SRs apply for each LOP Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months provided the associated Function maintains initiation capability.

SURVEILLANCE FREOUENCY SR 3.3.8.1.1 Perform CHANNEL FUNCTIONAL TEST. 31 days SR 3.3.8.1.2 Perform CHANNEL CALIBRATION. 18 months SR 3.3.8.1.3 Perform CHANNEL CALIBRATION. 24 months SR 3.3.8.1.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 *months Columbia Generating Station 3.3.8. 3 Amendment No. '4-49 169l

LOP Instrumentation 3.3.8.1 Table 3.3.8.1-1 (page 1 of 1)

Loss of Power Instrumentation CONDITIONS REQUIRED REFERENCED CHANNELS FRO4 PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION DIVISION ACTION A.1 REQUIREMENTS VALUE

1. Divisions 1 and 2 - 4.16 kV Emergency Bus Undervoltage

a. TR-S Loss of Voltage - 4.16 kV 2 8 SR 3.3.8.1.2 > 2450 V and < 3135 V Basis SR 3.3.8.1.4

b. TR-S Loss of Voltage - Time 2 B SR 3.3.8.1.3 > 2.95 seconds and Delay SR 3.3.8.1.4 7.1 seconds

c. TR-B Loss of Voltage - 4.16 kV 1 C SR 3.3.8.1.3 > 2450 V and < 3135 V Basis SR 3.3.8.1.4

d. TR-B Loss of Voltage - Time 1 C SR 3.3.8.1.3 3.06 seconds and Delay SR 3.3.8.1.4 7 9.28 seconds

e. Degraded Voltage - 4.16 kV 2 (a) C SR 3.3.8.1.1 3685 V and < 3755 V Basis SR 3.3.8.1.2 SR 3.3.8.1.4

f. Degraded Voltage - Primary 2 (a) C SR 3.3.8.1.1 > 5.0 seconds and Time Delay SR 3.3.8.1.2 ; 5.3 seconds SR 3.3.8.1.4

9. Degraded Voltage - Secondary 1 C SR 3.3.8.1.2 ' 2.63 seconds and Time Delay SR 3.3.8.1.4 < 3.39 seconds

2. Division 3 - 4.16 kV Emergency Bus Undervottage

a. Loss of Voltage - 4.16 kV Basis 2 B SR 3.3.8.1.2 > 2450 V and < 3135 V SR 3.3.8.1.4

b. Loss of Voltage -Time Delay 2 B SR 3.3.8.1.3 > 1.87 seconds and SR 3.3.8.1.4 7 3.73 seconds

c. Degraded Voltage - 4.16 kV 2 C SR 3.3.8.1.2 > 3685 V and < 3755 V Basis SR 3.3.8.1.4

d. Degraded Voltage - Time Delay 2 C SR 3.3.8.1.2 > 7.36 seconds and SR 3.3.8.1.4 c 8.34 seconds (a) The Degraded Voltage - 4.16 kV Basis and -Primary Time Delay Functions must be associated with one another.

U Columbia Generating Station 3.3.8. 1-4 Amendment No. +-49 1691

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 REOUIRED 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 inservice power supplies with one supply(s) from II electric power 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 inservice power supplies with both supply(s) from electric power service.

monitoring assemblies inoperable.

C. Required Action and C.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 AND or B not met in MODE 1. 2, or 3. C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued)

Columbia Generating Station 3.3.8.2- 1 Amendment No. +449 1691

3II*U RPS Electric Power Monitoring 3.3.8.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME

0. Required Action and D.1 Initiate action to Immediately associated Completion restore one electric Time of Condition A or power monitoring B not met in MODE 4 or assembly to OPERABLE 5 with both RHR SDC status for inservice suction isoldtion power supply(s) valves open. supplying required instrumentation.

OR D.2 Initiate action to Immediately isolate the RHR SDC System.

E. Required Action and E.1 Initiate action to Immediately assoc-iated Completion fully insert all Time of Condition A or insertable control B not met in MODE 5 rods in core cells with any control rod containing one or withdrawn from a core more fuel assemblies.

cell containing one or more fuel assemblies.

Columbia Generating Station 3.3.8. 2-2 Amendment No. +4i 1691

RPS Electric Power Monitoring 3.3.8.2 SURVEILLANCE REOUIREMENTS When an RPS electric power monitoring assembly is placed in an inoperable status solely for performance of required Surveillances. entry into the associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the other RPS electric power monitoring assembly for the associated power supply maintains trip capability.

SURVEILLANCE FREOUENCY SR 3.3.8.2.1 ------------------NOTE------------------

Only required to be performed prior to entering MODE 2 or 3 from MODE 4, when in MODE 4 for > 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

Perform CHANNEL FUNCTIONAL TEST. 184 days SR 3.3.8.2.2 Perform CHANNEL CALIBRATION. The 24 months Allowable Values shall be: I

a. Overvoltage < 133.8 V. with time delay < 3.46 seconds;

b. Undervoltage 2 110.8 V. with time delay < 3.46 seconds; and

c. Underfrequency > 57 Hz, with time delay < 3.46 seconds.

SR 3.3.8.2.3 Perform a system functional test. 24 months I

-u Columbia Generating Station 3.3.8.2-3 Amendment No. 149.9,179 SEP 2 0 2a32

Recirculation LoOOpS Operating 3.4. 1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 Recirculation Loops Operating LCO 3.4.1 Two recirculation loops with matched flows shall be in operation.

I OR One recirculation loop shall be in operation provided that the following limits are applied when the associated LCO is I applicable:

a. LCO 3.2.1. "AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR)," single loop operation limits specified in the COLR; and

b. LCO 3.2.2. "MINIMUM CRITICAL POWER RATIO (MCPR)," single loop operation limits specified in the COLR.

APPLICABILITY: MODES 1 and 2.

K) ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Recirculation loop A.1 Declare the 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months flow mismatch not recirculation loop within limits. with lower flow to be "not in operation."

B. Requirements of the B.1 Satisfy the 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months LCO not met for requirements of the reasons other than LCO.

Condition A.

(continued)

Columbia Generating Station 3.4.1-1 Amendment No. 149.169,171

~ wa APR 0 5 2001

205 Jet Pumps 3.4.2 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.2 Jdt Pumps LCO 3.4.2 All jet pumps shall be-OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS - -_-_ _

CONDITION REOUIRED ACTION -COMPLETION TIME A. One or more jet pumps A.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months inoperable.

Columbia Generating Station 3.~4.-2-1 Amendment No. +4-9 1691

Jet Pumps 3.4.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE - FREQUENCY SR 3.4.2.1 ------------------ NOTES-------------------

1. Not required to be performed until 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after associated recirculation loop is in operation.

2. Not required to be performed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after > 25% RTP.

Verify at least two of the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months criteria (a. b. and c) are satisfied for each operating recirculation loop:

a. Recirculation loop drive flow versus recirculation pump speed differs by

< 10% from established patterns.

b. Recirculation loop drive flow versus total core flow differs by < 10% from established patterns.

c. Each jet pump diffuser to lower plenum A_,/

differential pressure differs by < 20%

from established patterns, or each jet pump flow differs by < 10% from established patterns.

Columbia Generating Station 3.4 .2-2 Amend~ment No. +4g4169l

SRVs - > 25% RTP 3.4.3 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.3 Safety/Relief Valves (SRVs) - > 25% RTP LCO 3.4.3 The safety function of 12 SRVs shall be OPERABLE, with two SRVs in the lowest two lift setpoint groups OPERABLE.

APPLICABILITY: THERMAL POWER > 25% RTP.

ACTIONS CONDITION REOUIRED ACTION COMPLETION TIME A. One or more required A.1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months SRVs inoperable. to < 25% RTP.

SURVEILLANCE REOUIREMENTS SURVEILLANCE FREOUENCY SR 3.4.3.1 Verify the safety function lift setpoints In accordance of the required SRVs are as follows: with the Inservice Number of Setpoint Testing Program SRVs (Dsiq) 2 1165 +/- 34.9 4 1175 i 35.2 4 1185 i 35.5 4 1195 + 35.8 4 1205 +/- 36.1 SR 3.4.3.2 Verify each required SRV opens when 24 months manually actuated.

Columbia Generating Station 3.4.3 -1 Amendment No. +49 1691

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 1 with THERMAL POWER < 25% RTP.

MODES 2 and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SRVs inoperable.

AND A.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REOUIREMENTS _

SURVEILLANCE FREQUENCY SR 3.4.4.1 Verify the safety function lift setpoints In accordance of the required SRVs are as follows: with the Inservice Number of Setpoint Testing Program SRVs (vsia) 2 1165 i 34.9 4 1175 i 35.2 4 1185 +/- 35.5 4 1195 +/- 35.8 4 1205 +/- 36.1 (continued)

Columbia Generating Station 3.4.4-1 Amendment No. 4-49 1691

SRVs - < 25% RTP 3.4.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREOUENCY SR 3.4.4.2- NOTE---------------------

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

Verify each required SRV opens when 24 months manually actuated.

Columbia Generating Station 3.4 .4-2 Amendment No. i44 1691

RCS Operational LEAKAGE 3.4.5 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.5 RCS Operational LEAKAGE LCO 3.4.5 RCS operational LEAKAGE shall be limited to:

a. No pressure boundary LEAKAGE;

b. < 5 gpm unidentified LEAKAGE:

c. < 25 gpm total LEAKAGE averaged over the previous 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period; and

d. < 2 gpm increase in unidentified LEAKAGE within the previous 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period in MODE 1.

APPLICABILITY: MODES 1, 2. and 3.

ACTIONS - _ ____-

CONDITION REQUIRED ACTION COMPLETION TIME A. Unidentified LEAKAGE A.1 Reduce LEAKAGE to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months not within limit. within limits.

OR Total LEAKAGE not -

within limit.

B. Unidentified LEAKAGE B.1 Reduce unidentified 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months increase not within LEAKAGE increase to limit. - - within limit.

OR (continued)

Columbia Generating Station 3.4.5 -1 Amendment No. 4 1691

RCS Operational LEAKAGE 3.4.5

- N ACTIONS

-CONDITION REQUIRED ACTION .; COMPLETION TIME B. (continued) B.2 Verify source of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months unidentified LEAKAGE increase is not service sensitive type 304 or type 316 austenitic stainless steel.

C. Required Action and C.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 AND or B not met.

C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR Pressure boundary LEAKAGE exists.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.5.1 Verify RCS unidentified and total LEAKAGE 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and unidentified LEAKAGE increase are within limits.

Columbia Generating Station 3 3.4.5- 2 Amendment No. 4-44 1691

RCS PIV Leakage 3.4.6 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.6 RCS Pressure Isolation Valve-(PIV) Leakage LCO 3.4.6 The leakage from each RCS PIV shall be within limit.:

APPLICABILITY: MODES 1 and 2.

MODE 3. except valves in the residual heat removal shutdown cooling flowpath when in. or during transition to or from, the shutdown cooling mode of operation.

ACTIONS

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

1. Separate Condition entry is allowed for each flow path.

2. Enter applicable Conditions and Required Actions for systems made inoperable by PIVs.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more flow paths ----------- NOTE---

with leakage from one Each check valve'used toi or more RCS PIVs not satisfy Required Action A.1' within limit, shall have been verified to meet SR 3.4.6.1 and be in the reactor coolant pressure boundary.

A.1 Isolate the high 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months pressure portion of the affected system from the low pressure portion by use of one closed manual, de-activated automatic.

or check valve.

(continued)

Columbia Generating Station 3.4.6 -1 i.Amendment No.-+44 1691

____ ______ ___ ___ _l1 11LL RCS PIV Leakage 3.4.6 ACTIONS CONDITION REOUIRED ACTION . COMPLETION TIME B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REOUIREMENTS SURVEILLANCE FREOUENCY SR 3.4.6.1 -------------- NOTE--------------------

Only required to be performed in MODES 1

- and 2.

Verify equivalent leakage of each RCS PIV In accordance is < 0.5 gpm per nominal inch of valve size with Inservice up to a maximum of 5 gpm, at an RCS Testing Program pressure of 1035 psig. The actual test pressure shall be > 935 psig.

Columbia Generating Station 3.4. 6-2 Amendment No. +4g4 1691

1I- RCS Leakage Detection Instrumentation 3.4.7 I

3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.7 RCS Leakage Detection Instrumentation LCO 3.4.7 The following RCS leakage detection instrumentation shall be OPERABLE:

a. Drywell floor drain sump flow monitoring system; and

b. One channel of either drywell atmospheric particulate or atmospheric gaseous monitoring system.

APPLICABILITY: MODES 1. 2, and 3.

-ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Drywell floor drain A.1 Restore drywell floor 30 days sump flow monitoring drain sump flow I system inoperable. monitoring system to OPERABLE status.

B. Required drywell B.1 Analyze grab samples Once per I

atmospheric monitoring of drywell 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months system inoperable. atmosphere.

AND B.2 Restore required 30 days drywell atmospheric monitoring system to OPERABLE status.

(continued)

Columbia Generating Station 3.4.7-1 Amendment No.-'149,1'69,187

RCS Leakage Detection Instrumentation 3.4.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME

NOTE --------- C.1 Analyze grab samples Once per 12 Only applicable when the of the drywell hours drywell atmospheri c atmosphere.

gaseous monitoring system is the only OPERABLE monitor.

C.2 Monitor RCS LEAKAGE by Once per 12 administrative means. hours C. Drywell floor drain sump flow monitoring AND system inoperable.

C.3 Restore drywell floor 7 days drain sump flow monitori ng system to OPERABLE status.

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 AND Condition A, B, or C not met. D.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E. All required E.1 Enter LCO 3.0.3. Immediately leakage detection systems inoperable.

Columbia Generating Station 3.4.7-2 Amendment No. 149,169 187 224

RCS Leakage Detection Instrumentation 3.4.7 SURVEILLANCE REQUIREMENTS

NOTE------------------------------------

When a channel is placed in ah inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the other required leakage detection instrumentation is OPERABLE.

SURVEILLANCE FREQUENCY SR 3.4.7.1 Perform CHANNEL CHECK of required drywell 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months atmospheric monitoring system.

SR 3.4.7.2 Perform CHANNEL FUNCTIONAL TEST of required 31 days leakage detection instrumentation.

SR 3.4.7.3 Perform CHANNEL CALIBRATION of required 18 months leakage detection instrumentation.

Columbia Generating Station 33.4.7 -3 Amendment No. 444 1691

RCS Specific Activity 3.4.8 3.4 REACTOR COOLANT-SYSTEM (RCS) 3.4.8 RCS Specific Activity LCO 3.4.8 The specific activity of the reactor coolant shall be limited to DOSE EQUIVALENT 1-131 specific activity

< 0.2 yCi/gm. -

APPLICABILITY: MODE 1.

MODES 2 and 3 with any main steam line not isolated.

ACTIONS :

CONDITION REQUIRED ACTION COMPLETION TIME A. Reactor coolant ------------ NOTE------------

specific activity :LCO 3.0.4.c is applicable.,

> 0.2 pCi/gm and I

< 4.0 yCi/gm DOSE EQUIVALENT I-131. A.1 Determine DOSE Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months EQUIVALENT 1-131. -

AND A.2 Restore DOSE 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months EQUIVALENT I-131 to within limits.

B. Required Action and B.1 Determine DOSE Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion EQUIVALENT 1-131.

Time of Condition A not met. AND OR B.2.1 Isolate all main 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months steam lines.

Reactor coolant specific activity OR

> 4.0 pCi/gm DOSE EQUIVALENT I-131.

(continued)

Columbia Generating Station 3 .4.8-1 Amendment No.- 149.169,187

RCS Specific Activity 3.4.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2.2.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND B.2.2.2 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 3.4.8.1 ------------------ NOTE--------------------

Only required to be performed in MODE 1.

Verify reactor coolant DOSE 7 days EQUIVALENT I-131 specific activity is

< 0.2 pCi/gm.

Columbia Generating Station 3.4.8- 2 Amendment No. +4g9 169

RHR Shutdown Cooling System - Hot Shutdown 3.4.9 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.9 Residual1 Heat Removal (RHR) Shutdown Cooling System - Hot Shutdown LCO 3.4.9 Two RHR shutdown cooling subsystems shall be OPERABLE, and, with no recirculation pump in operation, at least one RHR shutdown coolingsubsystem shall be in operation.

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

1. Both RHR shutdown cooling subsystems and recirculation pumps may be removed from operation for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period.

2. One RHR shutdown cooling subsystem may be inoperable for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for performance of Surveillances.

APPLICABILITY: MODE 3 with reactor steam dome pressure less than 48 psig.

ACTIONS

NOTE------------------------------------

& ) Separate Condition entry is allowed for each RHR shutdown cooling subsystem.

I CONDITION REQUIRED ACTION COMPLETION TIME A. One or two RHR A.1 Initiate action to Immediately shutdown cooling restore RHR shutdown subsystems inoperable. cooling subsystem to OPERABLE status.

AND (continued)

Columbia Gener'ating'Station . 1. . --

3.4'.9-1 Amendment No. 449,164,16E1187

RHR Shutdown Cooling System - Hot Shutdown 3.4.9 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 Verify an alternate 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months method of decay heat removal is available for each inoperable RHR shutdown cooling subsystem.

AND A.3 Be in MODE 4. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months B. No RHR shutdown B.1 Initiate action to Immediately cooling subsystem in restore one RHR operation. shutdown cooling subsystem or one AND recirculation pump to operation.

No recirculation pump in operation. AND B.2 Verify reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from coolant circulation discovery of no by an alternate reactor coolant method. circulation AND Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter AND B.3 Monitor reactor Once per hour coolant temperature and pressure.

J, Columbia Generating Station 3.4.9-2 Amendment No. 1494169

RHR Shutdown Cooling System - Hot Shutdown 3.4.9 SURVEILLANCE REQUIREMENTS _

SURVEILLANCE FREQUENCY SR 3.4.9.1 --- - -------- NOTE--------------------

Not required to be met until 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after reactor steam dome pressure is less than 48 psi g.

Verify one RHR shutdown cooling subsystem 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months or recirculation pump is operating.

Columbia Generating Station 3.4.9 -3 Amendment No. 149.164 1691

RHR Shutdown Cooling System - Cold Shutdown 3.4.10 3.4 REACTOR COOLANT SYSTEM (RCS),, - .

3.4.10 Residual Heat Removal (RHR) Shutdown Cooling System - Cold Shutdown LCO 3.4.10 Two RHR shutdown cooling subsystems shall be OPERABLE, and, with no recirculation pump in operationat least one RHR shutdown cooling'subsystem shall be in operation.

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

1. Both RHR shutdown cooling subsystems and recirculation pumps may be removed from operation for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period.

2. One RHR shutdown cooling subsystem may be inoperable for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for the performance of Surveillances.

APPLICABILITY: MODE 4.

ACTIONS -

NOTE-------------------------------------

> Separate Condition entry is allowed for each RHR shutdown cooling subsystem.

.~~~~ ........

CONDITION - ----REOUIRED ACTION COMPLETION TIME A. One or two RHR A.1 Verify an alternate 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months shutdown cooling method of decay heat subsystems inoperable. - removal is available AND for each inoperable RHR shutdown cooling Once per subsystem. 24'hours thereafter (continued).

Columbia Generating Station 3.4. 10- 1 _..Amendment No. 4-4.9'1691

1l1fL RHR Shutdown Cooling System - Cold Shutdown 3.4.10 ACTIONS CONDITION REQUIRED ACTION - COMPLETION TIME B. No RHR shutdown B.1 Verify reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from cooling subsystem in coolant circulating discovery of.no operation. by an alternate reactor coolant method. circulation AND AND No recirculation pump in operation. Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter AND B.2 Monitor reactor Once per hour coolant temperature and pressure.

SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.4.10.1 Verify one RHR shutdown cooling subsystem 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months or recirculation pump is operating.

Columbia Generating Station 3.4. 10-2 Amendment No. +4g 1691

RCS PIT Limits 3.4.11 3.4 REACTOR COOLANT SYSTEM (RCS)

J 3.4.11 RCS Pressure and Temperature (P/T) Limits LCO 3.4.11 RCS pressure.: RCS temperature. RCS heatup and cooldown rates, and the recirculation loop temperature requirements shall be maintained within limits.

APPLICABILITY: At all times.

ACTIONS _

CONDITION REQUIRED ACTION COMPLETION TIME A. --------- NOTE--------- A.1 Restore parameter(s) 30 minutes Required Action A.2 to within limits.

shall be completed if this Condition is AND ente-red.

A.2 Determine RCS is 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months acceptable for Requirements of the continued operation.

LCO not met in MODE 1,

2. or 3.

B. Required Action and B.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 AND not met.

B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued)

Columbia Generating Station 3.4.11-1 Amendment No.,449 1691

RCS P/T Limits 3.4.11 ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME C. --------- NOTE--------- C.1 Initiate action to Immediately Required Action C.2 restore parameters shall be completed if to within limits.

this Condition is entered. AND C.2 Determine RCS is Prior to Requirements of the acceptable for entering MODE 2 LCO not met in other operation. or 3 than MODES 1. 2.

and 3.

Columbia Generating Station 3.4 .11 -2 Amendment No. +4-9 1691

RCS P/T Limits 3.4.11 SURVEILLANCEREOUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 ------------------- NOTE--------------------

Only required to be performed during RCS heatup and cooldown operations. and RCS inservice leak and hydrostatic testing.

Verify: 30 minutes

a. RCS pressure and RCS temperature are within the applicable limits specified in Figures 3.4.11-1. 3.4.11-2, and 3.4.11-3;

b. -RCS heatup and-cooldown rates are

< 100 0 F in any 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period; and

c. RCS temperature -change during inservice leak and hydrostatic testing is < 200 F in any 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period when the RCS-pressure and RCS temperature are not within the limits of Figure 3.4.11-2.

SR 3.4.11.2 Verify RCS pressure and RCS temperature are Once within-within the criticality limits specified in 15 minutes Figure 3.4.11-3. - prior to control rod

- ~ withdrawal for

-I the purpose of achieving criticality tcontinueo)

Columbia Generating Station 3.4'.11 -3 Amendment No'. -4.9'169l

-IIL -

RCS P/T Limits 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE . FREQUENCY SR 3.4.11.3 ------------------- NOTE--------------------

Only required to be met in MODES 1. 2. 3.

and 4 during recirculation pump startup.

Verify the difference between the bottom Once within head coolant temperature and the reactor 15 minutes pressure vessel (RPV) coolant temperature prior to each is < 1450F. startup of a recirculation pump SR 3.4.11.4 ------------------- NOTE--------------------

Only required to be met in MODES 1. 2. 3, and 4 during recirculation pump startup.

Verify the difference between the reactor Once within coolant temperature in the recirculation 15 minutes loop to be started and the RPV coolant prior to each temperature is < 500F. startup of a recirculation pump SR 3.4.11.5 -------------------NOTE--------------------

Only required to be met in single loop operation with THERMAL POWER < 25% RTP or the operating recirculation loop flow < 10%

rated loop flow.

Verify the difference between the bottom Once within head coolant temperature and the RPV 15 minutes coolant temperature is < 145 0F. prior to an increase in THERMAL POWER or an increase in loop flow (continued)

Columbia Generating Station 3.4. 11-4 Amendment No. +4g 1691

RCS P/T Limits 3.4.11 SURVEILLANCE REOUIREMENTS SURVEILLANCE - FREOUENCY SR 3.4.11.6 ------------------- NOTE--------------------

Only required to be met in single loop operation when the idle recirculation loop is not isolated from-the RPV. and with THERMAL POWER < 25% RTP or the operating recirculation loop flow < 10% rated loop flow.

Verify the difference between the reactor Once within coolant temperature in the recirculation 15 minutes loop not in operation and the RPV coolant prior to an temperature is < 500F. increase in THERMAL POWER or an increase

in loop flow SR 3.4.11.7 ------------------- NOTE--------------------

Only required to be performed when tensioning the reactor vessel head bolting studs.

Verify reactor vessel flange and head 30 minutes flange temperatures are > 800F.

SR 3.4.11.8 -------------------NOTE--------------------

Not required to be performed until 30 minutes after RCS temperature < 900 F in MODE 4.

Verify reactor vessel flange and head 30 minutes flange temperatures are > 800F.

(continued)

Columbia Generating-Station 3.4.11- 5 :.Amendment No. 4-49 .1691

_111:

RCS P/T Limits 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.9 -.-----------------NOTE--------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after RCS temperature < 1000 F in MODE 4.

Verify reactor vessel flange and head 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months flange temperatures are > 800F.

Columbia Generating Station 3.4. 11-6 Amendment No. +44 1691

RCS P/T Limits 3.4.11

'1400 INITIAL RTndt VALUES ARE 28F FOR BELT1INE, 1300 34F FOR UPPER VESSEL, AND.

34F FOR BOTTOM HEAD 1200 BELTLINE CURVES 1100 ADJUSTED AS SHOWN:

EFPY SHIFT (-F)-

33.1 35 2L

a. 1000 W HEATUPICOOLDOWN 900 9 RATE OF COOLANT z < 20"F/HR

.j w

U)800 o 700 I,]

cc 600 ACCEPTABLE AREA OF Fl- OPERATION TO THE RIGHT OF THIS CURVE 500

- 400 300

.- UPPER VESSEL 200 AND BELTLINE LIMITS

.... BOTTOM HEAD .

100 . CURVE 0

0 25 50 75 100 125 150 175 200 MINIMUM REACTOR VESSEL METAL TEMPERATURE

('F)

Figure 3.4.11-1 (Page 1 of 1)

Inservice Leak and Hydrostatic Testing Curve Columbia Generdling Station 3.4 .11 -7 Amendment lab. 149*G9.-169, 193

RCS P/T Limits 3.4.11 1400 INITIAL RTndl VALUES ARE

_ F FOR BELTLINE,

.1300 34OF FOR UPPER VESSEL.

1300 -AND 20 34F FOR BOTTOM HEAD BELTLINE CURVES

. ADJUSTED AS SHOWN:

1100 _PS19 _ --- -EFPY ; SHIFT('F) 1 109.303 PS. 33.1 35 HEATUPICOOLDOWN a 900 RATE OF COOLANT RA I 00TFHR LU l 790P'IG u800 140F e 700 < t I li l 6COPSIG l *I'l

° 600 < - - --- - I - - - ACCEPTABLEAREAOF OPERATION TO THE

!IRIGHT OF THIS CURVE 400 tu 400 ----

SoTTOm -~ -= - - -2+

300I 200 - UPPER VESSEL AND BELTLINE FLANGE LIMITS REGICNBOflOM HEAD 100 80F -- 1 -- < .............. UV

CURVE o !- { 1 -j I -

0 25 50 75 100 125 150 175 200 225 250 MINIMUM REACTOR VESSEL METAL TEMPERATURE (F)

Figure 3.4.11-2 (Page I of 1)

Hon-Nuclear Heating and Cooldown Curve

<-I Columnbi a G7enerat i ng S tdation 3. 4.1 1 -8 CiAmendnmernt No. .19-,1'9-4G',

193

RCS P/T Limits 3.4.1 1 1400 INITIAL RTndt VALUES ARE 1300 28OF FOR BELTLINE, 34*F FOR UPPER VESSEL, 1200 AND 34'F FOR BOTTOM HEAD 1100 BELTLINE CURVE

-1000 ADJUSTED AS SHOWN:

-J EFPY SHIFT (F)

L 900 33.1 35 w

I-a,, 800 HEATUPICOOLDOWN I- RATE OF COOLANT

< 100FIHR ow 700 600 U

zI-w 0 500 ACCEPTABLE AREA OF cc 0 OPERATION TO THE

,,, 400 RIGHT OF THIS CURVE U 300 3-200

-BELTLINE AND NON-BELTLINE 100 LIMITS 0

0 25 50 75 100 125 150 175 200 225 250 275 300 MINIMUM REACTOR VESSEL METAL TEMPERATURE (F)

Figure 3.4.11-3 (Page 1 of 1)

Nuclear Heating and Cooldown Curve Columnbia Generating Station . 3.4.11- 9 Amendment No. 1+9A r9.164, 193

Reactor Steam Dome Pressure 3.4.12 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12 Reactor Steam Dome Pressure LCO 3.4.12 The reactor steam dome pressure shall be < 1035 psig.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Reactor steam dome A.1 Restore reactor steam 15 minutes pressure not within dome pressure to limit. within limit.

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

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Verify reactor steam dome pressure is 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

< 1035 psig.

I.

Columbia Generating Station 3.4.12-1 Amendment No. 4.49 1691

ECCS - Operating 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 injection/spray subsystem and the Automatic Depressurization System (ADS) function of six safety/relief valves shall be OPERABLE.

APPLICABILITY: MODE 1, MODES 2 and 3. except ADS valves are not required to be OPERABLE with reactor steam dome pressure < 150 psig.

ACTIONS

NOTE-------------------------------------

LCO 3.0.4.b is not applicable to HPCS.

I CONDITION REOUIRED ACTION COMPLETION TIME A. One low pressure ECCS A.1 Restore low pressure 7 days injection/spray ECCS injection/spray subsystem inoperable. subsystem to OPERABLE status.

B. High Pressure Core B.1 Verify by Immediately Spray (HPCS) System administrative means inoperable. - RCIC System is OPERABLE when RCIC System is required to be-OPERABLE.

AND B.2 Restore HPCS System 14 days to OPERABLE status.

(continued)

Columbia Generating Station 3.5. 1-1 Amendment No. 149,169,187

-- -- -t3A ECCS- Operating 3.5.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Two ECCS injection C.1 Restore one ECCS 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months subsystems inoperable. injection/spray subsystem to OPERABLE OR status.

One ECCS injection and one ECCS spray subsystem inoperable.

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, AND B. or C not met.

D.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 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.

(continued)

Columbia Generating Station 3.5.1-2 Amendment No. b4-9 169'

ECCS - Operating 3.5.1 ACTIONS CONDITION REHUIRED ACTION - COMPLETION TIME G. Required Action and G.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 E AND or F not met.

G.2 Reduce reactor steam 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR dome pressure to

< 150 psig.

Two or more required ADS valves inoperable.

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

Systems inoperable.

OR 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. 4-49 1691

ECCS - Operating 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify, for each ECCS injection/spray 31 days subsystem, the piping is filled with water from the pump discharge valve to the injection valve.

SR 3.5.1.2 ------------------- NOTE--------------------

Low pressure coolant injection (LPCI) subsystems may be considered OPERABLE during alignment and operation for decay heat removal with reactor steam dome pressure less than 48 psig in MODE 3, if capable of being manually realigned and not otherwise inoperable.

Verify each ECCS injection/spray subsystem 31 days manual, power operated, and automatic valve in the flow path, that is not locked.

sealed, or otherwise secured in position.

is in the correct position.

SR 3.5.1.3 Verify ADS accumulator backup compressed 31 days gas system average pressure in the required bottles is > 2200 psig.

(continued)

Columbia Generating Station 3.5. 1-4 Amendment No. !49,164 1691

205 I :L-ECCS - Operating 3.5.1 SURVEILLANCE REUUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.7 - ------------ NOTE--------------------

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

Verify each required ADS valve opens when 24 months on a manually actuated. STAGGERED TEST BASIS for each valve solenoid SR 3.5.1.8 ------------------- NOTE--------------------

ECCS actuation instrumentation is excluded.

Verify the ECCS RESPONSE TIME for each ECCS 24 months

- injection/spray subsystem is within limits.

K-I Columbia Generating Station 3.5. 1-6 Amendment No. !49.159 1691

ECCS- Shutdown 3.5.2 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.2 ECCS - Shutdown LCO 3.5.2 Two ECCS injection/spray subsystems shall be OPERABLE.

APPLICABILITY: MODE 4.

MODE 5 except with the spent fuel storage pool gates removed and water level > 22 ft over the top of the reactor pressure vessel flange.

ACTIONS CONDITION REHUIRED ACTION COMPLETION TIME A. One required ECCS A.1 Restore required ECCS 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months injection/spray injection/spray subsystem inoperable. subsystem to OPERABLE status.

B. Required Action and B.1 Initiate action to Immediately associated Completion suspend operations Time of Condition A with a potential for not met. draining the reactor vessel (OPDRVs).

C. Two required ECCS C.1 Initiate action to Immediately injection/spray suspend OPDRVs.

subsystems inoperable.

AND C.2 Restore one ECCS 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months injection/spray subsystem to OPERABLE status.

(continued)

Columbia Generating Station 3.5.2-1 Amendment No. 149,1'9 1691

ECCS - Shutdown 3.5.2 ACTIONS CONDITION REQUIRED ACTION . COMPLETION TIME D. Required Action C.2 D.1 Initiate action to Immediately and associated restore secondary Completion Time not containment to met. OPERABLE status.

AND D.2 Initiate action to Immediately restore one standby gas treatment subsystem to OPERABLE status.

AND D.3 Initiate action to Immediately restore isolation capability in each required secondary containment penetration flow path not isolated.

Columbia Generating Station 3.'5.2- 2 Amendment No. 149,1'0 1691

Eces - Shutdown 3.5.2 SURVErLLANcE REOU[REMENTS SURVEI LLANCE FREQUENCY SR 3.5.2.1 Verify, for each required low pressure ECCS 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months injection/spray subsystem, the suppression pool water level is ~ 18 ft 6 inches.

SR 3.5.2.2 Verify, for the required High Pressure Core 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Spray (HPCS) System. the:

a. Suppression pool water level is

~ 18 ft 6 inches: or

b. Condensate storage tank (CST) water level is ~ 16.5 ft in a single {ST or

~ 10.5 ft in e~ch CST.

SR 3.5.2.3 Verify, for each required ECCS injection/ 31 dilYs spray subsystem, the piping is filled with water from the pump discharge valve to the injection valve.

SR 3.5.2.4 - - - - . - - - - . - - . - . - -NOT E - - ... - - . - - . - . - .

One low pressure coolant injection (LPCI) subsystem may be considered OPERABLE during alignment and operation for decay heat removal. if capilble of being milnually realigned and not otherwise inoperable.

Verify each required ECCS injection/spray 31 dJys subsystem manual. power operated. ilnd automiltic valve in the flow path, that is not locked, seJled, or otherwise secured in position, is in the correct position.

(continued)

ColumbiJ GenerJting Station 1.5.2-3 Amendment No.

1'19.150.165.169,210

205 RCIC System 3.5.3 3.5 EMERGENCY CORE COOLING SYSTEMS--(ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.3 RCIC System LCO 3.5.3 The RCIC System shall be OPERABLE.

APPLICABILITY: MODE 1, MODES 2 and 3 with reactor steam dome pressure > 150 psig.

ACTIONS

NOTE---------------------------

LCO 3.0.4.b is not applicable to RCIC.

I CONDITION REQUIRED ACTION COMPLETION TIME A. RCIC System A.1 Verify by Immediately inoperable. .administrative means High Pressure Core Spray System is OPERABLE.

AND A.2 Restore RCIC System 14 days to OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion ,

Time not met. AND B.2 Reduce reactor steam 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months dome pressure to

- -150 psig.

Columbia Generating Station 3.5..3-1I Amendment No. 149-40-,169,187

RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 Verify the RCIC System piping is filled 31 days with water from the pump discharge valve to the injection valve.

SR 3.5.3.2 Verify each RCIC System manual, power 31 days operated, and automatic valve in the flow path. that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.5.3.3 ------------------- NOTE--------------------

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

Verify, with reactor pressure < 1035 psig 92 days and > 935 psig, the RCIC pump can develop a flow rate > 600 gpm against a system head corresponding to reactor pressure.

SR 3.5.3.4 ------------------- NOTE--------------------

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

Verify, with reactor pressure < 165 psig, 24 months the RCIC pump can develop a flow rate

> 600 gpm against a system head corresponding to reactor pressure.

(continued)

I Columbia Generating Station 3.5.3 -2 Amendment No. 149,1'0 169

RCIC System 3.5.3 SURVEILLANCE REOUIREMENTS _

SURVEILLANCE FREOUENCY SR 3.5.3.5 ------------------- NOTE--------------------

Vessel injection may be excluded.

Verify the RCIC System actuates on an 24 months actual or simulated automatic initiation signal.

Columbia Generating Station 3.5.3 -3 Amendment No. i49,159 1691

Primary Containment 3.6.1.1 3.6 CONTAINMENT SYSTEMS 3;6.1.1 Primary Containment LCO 3.6.1.1 Primary containment shall be OPERABLE.

APPLICABILITY: MODES 1. 2. and 3.-

ACTIONS - -

CONDITION REQUIRED ACTION COMPLETION TIME A. Primary containment A.1 Restore primary 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. containment to OPERABLE status.

B. Required Action and 8.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. 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 3.6.1.1-1 Amendment No. +4-9 1691

Primary Containment 3.6.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.1.1 Perform required visual examinations and In accordance leakage rate testing except for primary with the containment air lock testing, in Primary accordance with the Primary Containment Containment Leakage Rate Testing Program. Leakage Rate Testing Program SR 3.6.1.1.2 Verify drywell to suppression chamber 120 months bypass leakage is < 10% of the acceptable A/Ji- design value of 0.050 ft 2 at an AND initial differential pressure of > 1.5 psid. 48 months following a test with bypass leakage greater than the bypass leakage limit AND 24 months following two consecutive tests with bypass leakage greater than the bypass leakage limit until two consecutive tests are less than or equal to the bypass leakage limit (continued)

Columbia Generating Station 3.6.1.1-2 Amendment No. 149,169 , 201

Primary Containment 3.6.1.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.6.1.1.3 ------------------- NOTE---------------

Performance of SR 3.6.1.1.2 satisfies this surveillance.

Verify individual drywell to suppression 24 months chamber vacuum relief valve bypass pathway leakage is < 1.2% of the acceptable A/J- design value of 0.050 ft 2 at an initial differential pressure of

> 1.5 psid.

I.

SR 3.6.1.1.4 ------------------- NOTE----------------

Performance of SR 3.6.1.1.2 satisfies this surveillance.

Verify total drywell to suppression 24 months chamber vacuum relief valve bypass leakage is < 3.0% of the acceptable A/VK design value of 0.050 ftW at an initial differential pressure of > 1.5 psid.

Columbia Generating Station 3.6.1 .1-3 Amendment No. 201

Primary Containment Air Lock 3.6.1.2 3.6 CONTAINMENT SYSTEMS 3.6.1.2 'Primary Containment Air Lock LCO 3.6.1.2 The primary containment air lock shall be OPERABLE.

APPLICABILITY: MODES 1. 2, and 3.

ACTIONS

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

1. Entry and exit is permissible to perform repairs of the air lock components.

2. Enter applicable Conditions and Required Actions of LCO 3.6.1.1. 'Primary Containment," when air lock leakage results in exceeding overall containment leakage rate acceptance criteria.

CONDITION REQUIRED ACTION COMPLETION TIME A. One primary ------------ NOTES------------

containment air lock 1. Required Actions A.1, door inoperable. A.2; and A.3 are not applicable if both doors in the air lock are inoperable and Condition C is entered.

2. Entry and exit is permissible for 7 days under administrative controls.

A.1 Verify the OPERABLE 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months door is closed.

AND (continued)

Columbia Generating Station 3.6.1.2-1 Amendment No. -149 1691

liLt.

Primary Containment Air Lock 3.6.1.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 Lock the OPERABLE 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months door closed.

AND A.3 -------- NOTE-----

Air lock doors in high radiation areas or areas with limited access due to inerting may be verified locked closed by administrative means.

Verify the OPERABLE Once per 31 days door is locked closed.

B. Primary containment ------ -- NOTES------------

air lock interlock 1. Required Actions 8.1.

mechanism inoperable. B.2. and 8.3 are not applicable if both doors in the air lock are inoperable and Condition C is entered.

2. Entry into and exit from primary containment is permissible under the control of a dedicated individual.

B.1 Verify an OPERABLE 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months door is closed.

AND (continued)

Columbia Generating Station 3.6.1. 2-2 Amendment No. 4-44 1691

Primary Containment Air Lock 3.6.1.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2 Lock an OPERABLE door 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months closed.

AND B.3 -------- NOTE---------

Air lock doors in high radiation areas or areas with limited access due to inerting may be verified locked closed by administrative means.

Verify an OPERABLE Once per 31 days door is locked closed.

C. Primary containment C.1 Initiate action to Immediately air lock inoperable evaluate primary for reasons other than containment overall Condition A or B. leakage rate per LCO 3.6.1.1. using current air lock test results.

AND C.2 Verify a door is 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months closed.

AND C.3 Restore air lock to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE status.

(continued)

Columbia Generating Station 3.6.1.2-3 Amendment No. +44 1691

. IIIs Primary Containment Air Lock 3.6.1.2 ACTIONS CONDITION REHUIRED ACTION COMPLETION TIME K-,

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 not met. AND D.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREOUENCY SR 3.6.1.2.1 ------------------ NOTES------------------

1. An inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test.

2. Results shall be evaluated against acceptance criteria applicable to SR 3.6.1.1.1.

Perform required primary containment air In accordance lock leakage rate testing in accordance with the with the Primary Containment Leakage Rate Primary Testing Program. Containment Leakage Rate Testing Program SR 3.6.1.2.2 Verify only one door in the primary 24 months containment air lock can be opened at a time.

Columbia Generating Station 3.6. 1.2-4 Amendment No. +4-4 1691

PC1Vs J .6. ] . J 3.6 CONTAINMENT SYSTEMS 3.6.1.3 Primary Containment Isolation Valves (PCIVs)

LCD 3.6.1.3 Each PCIV. except reactor building~tosuppression chamber vacuum breukers. shall be OPERABLE.

APPLlCAHILITY: r>10DES 1.2. and 3, When associated instrumentation is required to be OPERABLE per LCO 3.3.6.1. *Primary Containment Isolation Instrumentation.*

Acr IONS

.~ NOTES~- ~~~-~~~~~

]. Penetration flow paths may be unisolaLed intermittently under administrative controls.

2. Separate Condition entry is allowed for each penetration flow path.

3. Enter applicable Conditions and Required Actions for systems made inoperable by PCiVs.

4. Enter applicable Conditions and Required Actions of LCO 3.6.1.1. *Primary Containment." when PCIV leakage results in exceeding overal I containment leakage rate acceptance criteria.

COND] liON REQUIRED ACTION COMPLETION TIME A, - -NOTE- A.l Isolate the affected 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months except Only applicable to penetration flow path for main steam penetration flow paths by use of at least 1 i ne with two PCIVs. one closed ilnd de~activated automatic valve, One or more closed manual valve, 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months for' penetration flow paths tl1ind flange. or main steam line with one PCIV check valve with flow inoper'able for reasons through the valve other than secured.

Condition D.

(continuPd)

Columbia Generating Station 3.6.1.3-1 Amendment No. H9 .169 208 1

pcrvs 3.6. 1 . l ACIIONS CONDITION REQUIRED ACTION CO~1 PLI:.T rON TIM E A. (continued) A.2 - - - - - - - - NOTE S- - - - -

1. Isolation devices in high radiation areas may be verified by use of administrative means.

2. Isolation devices that are locked.

sealed, or otherwise secured may be verified by use of administrative means.

Verify the affected Once per penetration flow path 31 days for is isolated. isolation devices outside primary containment Prior to entering MODE 2 or ] from MODE 4 if primary containment was de-inerted while in MODE 4, if not performed within the previous 92 days. for isoidtion devices inside primary containment (continued)

Columbia Generating Station 3.6.1.]-2 Amendment No. +4-9--;r-&9 ,208

pcrvs 3.6.1 .3 ACTIONS COND IT ION REOIJ I RED AU j ON COMPLETfON TIME B. .. ---- NOTE--- B. 1 Isola t e tile a i f ected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Only applicable to penetration flow path penetration flow paths by use of at least with two PCIVs. one closed and de-activated automatic valve.

One or more closed manual valve, penetration flow paths or b'lind flange.

with two PCIVs inoperable for reasons other than Condition D.

C. ---------NOTE--- .... C. 1 IsolaLe the affected 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months except Only applicable to penetration flow path for excess flow penetration flow paths by use of at least clleck va 1ves with only one PCIV. one closed and (UCVs) de activated automatic valve, One or more closed manual valve, penetration flow paths or blind flange. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for with one PCIV EFCVs inoperable for reasons other than Condition D.

(continued)

Columbia Generating Station 3.6.1.33 L\rnenU!llent No. 149.169,208

PCIVs 3.6.1.3 ACTIONS CONDITION REOliIRFD ACTION COMPLET rON TIMF C. (continued) C.2 -NOTES"--'-'

1. Isolation devices in high radiation areas may be verified by use of administrative means.

2. Isolation devices that are locked.

sealed. or otherwise secured may be verified by use of administrative means.

Verify the affected Once per penetration flow path 31 days for is isolated. isolation devices outside primary containment fJrior to entering MODE 2 or 3 from MODE 4 it pt"imary containment was de inerted while in MODE 4. if not performed within the previous 92 days, for isolation devices inside primary containment (continued)

Columbia Generating Station 3. fj . 1 .3 - 4 Amendment No. 149.]69,208

PC[Vs 3.6.1 .]

ACT IONS CONOITION r~EOU I RED ACT l UN COMPLETION TIME

n. One or more secondary D. 1 Restore leakage rate 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for containment bypass to within limit. hydrostatically leakage rate, MSIV tested 1ine leakage rate. or leakage not on hydrostatically tested a closed system lines leakage rate not within limit.

4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months 's for secondary containment bypcss ieakage 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months for MSIV leakage 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for' hydrostatically tested 1i ne leakage on a closed system 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 A, AND B. C, or 0 not met in MODE 1. 2, or 3. E.2 Be in MODE 4. ]6 hours (continued)

Columbia Generating Station ],6.1.3 5 Amendment No. 149,1',9,208

PCIVs 3.6.1.3 ACTIONS CONDITlON RrOlJ I .';:[0 ,\C TI ON Cor>1PI ETlaN TIME F. Required Action and F.1 Initiate action to Immediately associated Completion suspend operations rime of Condition A, with a potential for S, C, or D not met for draining the reactor PCIV(s) required to be vessel (OPDRVs).

OPERABLE during MODE 4 or 5. OR F.2 Initiate action to Immediately restore valve(s) to OPERABLE status.

I Columbia Generating Station 3.6.1.3-6 Amendment No. 149.169,208

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.0.1.3.: ----NOTE ----------

Not required to be met when the 24 inch and 30 inch primary containment purge valves are open for inerting, de-inerting, pressure control, ALARA or air quality considerations for personnel entry, or Surveillances that require the valves to be open.

Verify each 24 inch and 30 inch primary 31 days containment purge valve is closed.

SR 3.6.1.3.2 ------ --- -----NOTES----*_---*-- -<--

1. Valves and blind flanges in high radiation areas may be verified by use of administrative means.

2. Not required to be met for PCIVs that are open under administrative controls.

Verify each primary containment isolation 31 days manual valve and blind flange that is located outside primary containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed.

(continued)

Columbia Generating Station 3.6.1.3-7 Amendment No. 149,169,208

PCIVs 3.6. 1 .3 SURVEILlANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.3.3 - - -- - - - - - - - - - - - - -NOTES- - - _.. - - - - - - - - . -

1. Valves and blind flanges in high radiation areas may be verified by use of administrative means.

2. Not required to be met for PCIVs that are open under administrative controls.

Verify each primary containment isolation Pr'ior to manual valve and blind flange that is entering MODE 2 located inside primary containment and or 3 from not locked. scaled. or otherwise secured MODE 4 if and is required to be closed during primary accident conditions is closed. containmpnt was de' i nerted while in MODE 4. if not performed within the previous 92 days SR 3.6.1.3.4 Verify continuity of the traversing 31 days incore probe (TIP) shear isolation valve explosive charge.

SR 3.6.1.3.5 Verify the isolation time of each power In accordance operated. automatic PCIV. except MSIVs. wi th Lhe is-within limits. Inservice Testing Program (continued)

Columbia Generating Station 3.6.1.3-8 Amendment No.

149.169.170.175,199 208f

PCIVs 3.6.1 .3 SURVEILlANCl ~EOUIREMENrs SURVEILLANCl FREOUENCY SR 3.0.1.3.6 Verify the isolation time of each MSIV is In accordance 2 3 seconds and ~ 5 seconds. with the Jnservice Testing Program SR 3.6.1.3.7 Verify each automatic PCIV actuates to 24 months the isolation position on an actual or simulated isolation signal.

SR 3.6.1.3.8 Verify a representative sample of reactor 24 months instrument 1 ine [FCVs actuate to the isolation position on an actual or simulated instrument line break signal.

SR 3.6.1.3.9 Remove and test the explosive squib from 24 months on a each shear isolation valve of the TIP STAGGERED TEST System. BASIS SR 3.6.1.3.10 Verify the combined leakage rate for all In accordance secondary containment bypass leakage with the paths is .s. 0.04% primary containment Primary volume/day when pressurized to ~ Pd' Containment Leakage Rate resting Program (continued)

Colu~bia Generating Station 3.6.1.3-9 Amendment No. 149,169199

PCIVs 3.6.1 .3 SURVEILLANCE REQUIREMENTS SliRVEI LlANCE FREQUENCY SR 3.6.1.3.11 Verify leakage rate through each MSIV is In accordance

~ 16.0 scfh when tested at 2 25.0 psig. with the Primary Containment Leakage Rate Test.inC) Program SR 3.6.1.3.12 Verify combined leakage rate through In accordance hydrostatically tested lines that with the penetrate the primary containment. is Primary within limits. Containment.

Leakage Rate Testing Program 208 lumbia Generating St.ation 3.6.1.3 10 Amecdm,'nt NO.20~

Drywell Air Temperature 3.6.1.4 3.6 CONTAINMENT SYSTEMS 3.6.1.4 Drywell Air Temperature LCO 3.6.1.4 Drywell average air temperature shall be < 1351F.

APPLICABILITY: MODES 1. 2. and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Drywell average air A.1 Restore drywell 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months temperature not within average air limit. temperature to within limit.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AND B.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 3.6.1.4.1 Verify drywell average air temperature is 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months within limit.

Columbia Generating Station 3.6. 1.4- 1 Amendment No. 4-49 1691

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 7 days-subsystem inoperable. spray subsystem to OPERABLE status.

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

C. Required Act 4 on and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. 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. 1.5-1I Amendment No. 44@ 1691

- . su RHR Drywell Spray 3.6.1.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.5.1 Verify each RHR drywell-spray subsystem 31 days manual, 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.

SR 3.6.1.5.2 Verify each spray nozzle is unobstructed. 10 years Columbia Generating Station 3.6. 1.5- 2 Amendment No. 4-44 1691

Reactor Buildirnb-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

NOTE----------------------------------

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- breaker.

to-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- breaker.

to-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- -. breaker(s) to to-suppression chamber OPERABLE status.

vacuum breakers inoperable for opening.

(continued)

Columbia Generating Station 3.6.-1. 6-1 Amendment No., 4-4-9 1691

21iL.

Reactor Building-to-Suppression Chamber Vacuum Breakers 3.6.1.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. Two or more lines with D.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 building-to- to OPERABLE status.

suppression chamber vacuum breakers inoperable for opening.

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 not met. AND E.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 (continued)

Columbia Generating Station 3.6. 1.6- 2 Amendment No. +4-4 1691

Reactor Building-to-Suppression Chamber Vacuum Breakers 3.6.1.6 SURVEILLANCE REQUIREMENTS .

SURVEILLANCE . FREQUENCY SR 3.6.1.6.2 Perform a functional test of each vacuum In accordance breaker. with the.

Inservice Testing Program SR 3.6.1.6.3 Verify the full open setpoint of each 24 months vacuum breaker is < 0.5 psid.

Columbia Generating Station 3.6. 1.6-3 Amendment No. 4-49 1691

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.

AND 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- breaker to OPERABLE to-drywell vacuum status.

breaker inoperable for opening.

B. --------- NOTE--------- B.1 Close the open vacuum 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Separate Condition breaker disk.

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

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

(continued)

Columbia Generating Station 3.6.1.7 -1 Amendment No. +4-9 1691

I [IL-Suppression Chamber-to-Drywell Vacuum Breakers 3.6.1.7 ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more C.1 Close one open vacuum 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months suppression chamber- breaker disk.

to-drywell vacuum breakers with two disks not closed.

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 not met. AND D.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Columbia Generating Station 3.6.1.7- 2 Amendment No. 4-4g 1691

Suppression Chamber-to-Drywell Vacuum Breakers 3.6.1.7 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 31 days required vacuum breaker.

AND 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 24 months required vacuum breaker is < 0.5 psid.

I Not required to be met for the rear (drywell-side) disk of vacuum breaker CVB-V-1JK until startup from refueling outage R-18 provided there is no evidence that the front disk has opened or that the rear disk has experienced a differential pressure in the direction that could cause the disk to open. If such evidence exists, then the surveillance requirement will be met within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or the rear disk declared not closed.

Columbia Generating Station 3.6.1.7-3 Amendment No. 149 169 202

MSLC System 3.6.1.8 3.6 CONTAINMENT SYSTEMS 3.6.1.8 Main Steam Isolation Valve Leakage Control (MSLC) System LCO 3.6.1.8 Two MSLC subsystems shall be OPERABLE.

APPLICABILITY: MODES 1. 2, and 3. -

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One MSLC subsystem A.1 Restore MSLC 30 days inoperable. subsystem to OPERABLE status.

B. Two 1ISLC subsystems B.1 Restore one MSLC 7 days inoperable. subsystem to OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AND C.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 3.6.1.8.1 Operate each MSLC blower 2 15 minutes. 31 days (continued)

Columbia Generating Station 3.6.1.8 -1 Amendment No. 4-49 1691

W1I'-

MSLC System 3.6.1.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.8.2 Verify electrical continuity of each 31 days inboard MSLC subsystem heater element circuitry.

SR 3.6.1.8.3 Perform a system functional test of each 18 months MSLC subsystem.

Columbia Generating Station 3.6. 1.8- 2 Amendment No. +4g41691

Suppression Pool Average Temperature 3.6.2.1 3.6 CONTAINMENT SYSTEMS I e.i T .

3.6.2.1 Suppression Pool Average Temperature .

LCO 3.6.2.1 Suppression pool average temperature shall be:

d. < 900 F when THERMAL POWER is > 1% RTP and no testing that adds heat to the suppression pool is being performed:

b. < 105OF when THERMAL POWER is > 1% RTP and testing that adds heat to the suppression pool is being performed:

and C. < 110OF when THERMAL POWER is < 1% RTP.

APPLICABILITY: MODES 1. 2. and 3.

ACTIONS -

CONDITION REQUIRED ACTION COMPLETION TIME A. Suppression pool A.1 .. Verify.suppression Once per hour average temperature pool average

> 90'F but < 1100 F. . temperature < 110-F.

AND AND.

THERMAL POWER > 1X A.2 Restore suppression 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months RTP. pool average temperature to AND .- 900 F.

Not performing testing that adds heat to the suppression pool.

(continued)

Columbia Generating Station 3.6.2. 1-1 Amendment No. +4-9 1691

hiM Suppression Pool Average Temperature 3.6.2.1 ACTIONS

-CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Reduce THERMAL POWER 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion to < 1S RTP.

Time of Condition A not met.

C. Suppression pool C.1 Suspend all testing Immediately average temperature that adds heat to the,

> 105 0F. suppression pool.

AND THERMAL POWER > 1%

RTP.

AND Perfarming testing that adds heat to the suppression pool.

D. Suppression pool D.1 Place the reactor Immediately average temperature mode switch in the

> 110 0F but < 120 0F. shutdown position.

AND D.2 Verify suppression Once per pool average 30 minutes temperature < 120F.

AND D.3 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued)

Columbia Generating Station J.6.2.1-2 Amendment No. 4-4g 1691

Suppression Pool Average Temperature 3.6.2.1 ACTIONS

.CONDITION REQUIRED ACTION a. COMPLETION TIME E. Suppression pool E.1 Depressurize the 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months average temperature reactor vessel to

> 120 0F. < 200 psig.

AND E.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REOUIREMENTS SURVEILLANCE FREOUENCY SR 3.6.2.1.1 Verify suppression pool average 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months temperature is within the applicable limits. AND 5 minutes when performing testing that adds heat to the suppression pool Columbia Generating Station 3.6.2. 1-3 Amendment No. 4-49 1691

Suppression Pool Water Level 3.6.2.2 3.6 CONTAINMENT SYSTEMS 3.6.2.2 Suppression Pool Water Level LCO 3.6.2.2 Suppression pool water level shall be 2 30 ft 9.75 inches and < 31 ft 1.75 inches.

APPLICABILITY: MODES 1. 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Suppression pool water A.1 Restore suppression 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months level not within pool water level to limits. within limits.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REOUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.2.1 Verify suppression pool water level is 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months within limits.

Columbia Generating Station 3.6.2.2-1 Amendment No. -149 1691

RHR Suppression Pool Cooling 3.6.2.3 3.6 CONTAINMENT SYSTEMS 3.6.2.3 Residual Heat Removal (RHR) Suppression Pool Coroling 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 7 days pool cooling-subsystem suppression pool inoperable. cooling subsystem to OPERABLE status.

B. Required Action and B.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 AND not met.

B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR Two RHR suppression pool cooling subsystems inoperable.

Columbia Generating Station 3.-6.2.-3-1 Amendment No. +4-4169l

RHR Suppression Pool Cooling 3.6.2.3 SURVEILLANCE REQUIREMENTS _

SURVEILLANCE - FREQUENCY SR 3.6.2.3.1 Verify each RHR suppression pool cooling 31 days subsystem manual, 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.

SR 3.6.2.3.2 Verify each RHR pump develops a flow rate In accordance

> 7100 gpm through the associated heat with the exchanger while operating in the Inservice suppression pool cooling mode. Testing Program Columbia Generating Station 3.6.2.3- 2 Amendment No. -144 1691

Primary Containment Hydrogen Recombiners 3.6.3.1 K)j 3.6 CONTAINMENT SYSTEMS 3.6.3.1 Deleted Columbia Generating Station 3. 6.3. 1-1 Amendment No. 149-169-1-P, 189

"U'L-Primary Containment Hydrogen Recombiners, 3.6.3.1 This Page Intentionally Left Blank COlUmbia Generating Station 3.6.3.1- 2 Amendment No. +49.169,187-, 189

Primary Containment Atmosphere Mixing System 3.6.3.2 3.6 CONTAINMENT SYSTEMS 3.6.3.2 Primary Containment Atmosphere Mixing System LCO 3.6.3.2 Two head area return fans shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One head area return A.1 Restore head area 30 days fan inoperable. return fan to I OPERABLE status.

B. Two head area return B.1 Verify by 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months fans inoperable. administrative means that the hydrogen and oxygen control function is maintained.

AND B.2 Restore one head area 7 days return fan to OPERABLE status.

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

Columbia Generating Station 3.6.3.2 -1 'Amendment No. 149.169,187

Primary Containment Atmosphere Mixing System 3.6.3.2 SURVEILLANCE REQUIREMENTS _

SURVEILLANCE FREQUENCY SR 3.6.3.2.1 Operate each head area return fan for 92 days

> 15 minutes.

Columbia Generating Station 3.6.3.2 -2 Amendment No. 449 169'

Primary Containment Oxygen Concentration 3.6.3.3 3.6 CONTAINMENT SYSTEMS 3.6.3.3 Primary Containment Oxygen Concentration LCO 3.6.3.3 The primary containment oxygen concentration shall be

< 3.5 volume percent.

APPLICABILITY: MODE 1 during the time period:

a. From 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after THERMAL POWER is > 15% RTP following startup, to

b. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months prior to reducing THERMAL POWER to < 15% RTP prior to the next scheduled reactor shutdown.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Primary containment A.1 Restore oxygen 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months oxygen concentration concentration to not within limit. within limit.

B. Required Action and B.1 Reduce THERMAL POWER 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months associated Completion to < 15% RTP.

Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.3.1 Verify primary containment oxygen 7 days concentration is within limits.

Columbia Generating Station 3.6.3.3 -1 Amendment No. A449 1691

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).

I 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 2, or 3. OPERABLE status.

B. Required Action and B.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 AND not met.

B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months C. Secondary containment C.1 Initiate action to Immediately inoperable during suspend OPDRVs.

OPDRVs.

Columbia Generating Station 3.6.4.1-1 Amendment No. 149,169 199

Secondary Containment 3.6.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1.1 Verify secondary containment vacuum is 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

> 0.25 inch of vacuum water gauge.

SR 3.6.4.1.2 Verify all secondary containment 31 days equipment hatches are closed and sealed.

SR 3.6.4.1.3 Verify each secondary containment access 31 days inner door or each secondary containment access outer door in each access opening is closed.

SR 3.6.4.1.4 Verify each standby gas treatment (SGT) 24 months on a subsystem will draw down the secondary STAGGERED TEST containment to > 0.25 inch of vacuum BASIS water gauge in < 120 seconds.

SR 3.6.4.1.5 Verify each SGT subsystem can maintain 24 months on a

> 0.25 inch of vacuum water gauge in the STAGGERED TEST secondary containment for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months at a BASIS flow rate < 2240 cfm.

Columbia Generating Station 3.6.4.1-2 Amendment No. 149,169 199

SCIVs 3.6.4.2 3.6 CONTAINMENT SYSTEMS 3.6.4.2 Secondary Containment Isolation Valves (SCIVs)

LCO 3.6.4.2 Each SCIV shall be OPERABLE.

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

I ACTIONS

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

1. Penetration flow paths may be unisolated intermittently under administrative controls.

2. Separate Condition entry is allowed for each penetration flow path.

3. Enter applicable Conditions and Required Actions for systems made inoperable by SCIVs.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Isolate the affected 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months penetration flow paths penetration flow path with one SCIV by use of at least inoperable, one closed and de-activated automatic valve, closed manual valve.

or blind flange.

AND (continued)

Columbia Generating Station 3.6.4.2-1 Amendment No. 149,169 199

..,C I Vs

~ . h . ,1 . ?

\('FlnNS CO~W!FION RFJUIRFD ACT[Ii~J COMPurlON 1 1M E A (continued) A7., . - NO TE S

1. [sol d t i 011 devices ill ~l i 9 rl radiation a r'ea S may be verified by use of administrative mr.ans.

2. [solation devices that are locked, sealed, or oUlerwise secured may be verified by use of administrative means.

~-_._---~-~. - -

Verify ttle affected Once per 31 days penetration fl ow path is isolated.

B. - . - NOTE - - - - - - B. 1 Isolat.e the affected 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Only applicable to penetration FJow path penetration flow paths by use of at least wi t h two isolation one closed and valves. de-activated

- -- - - -- - - - -- - . -- - - - - - aut.omatic valve.

closed manual valve.

One or more or blind Flange.

penetration flow pat.hs with two SCIVs inoperable.

(cant i nued)

Columbia Cenpratilllj Station ),6.4.2 2 ArnencJrnent NO. 149,169,199,208

'-,C I Vc,

~ . () . :1 . ?

\" r [ IlNS CONDlrrON krUIlIRED I'lL r I() N COMPU TION riME

c. Re q II i I P l: t, c t i iJ Il llil (j C.l B(, ill MOU[ \. 12 flO 1I rS ds<,ociatf'd Complr:'tion rime of COllclitioll A AND or B not met i rl MOUE l. 2. or 3. C.? Be ill MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months D. Required Action and 0.1 Initiate action Immediately 11ssoci ated Completion to suspend Time of Condition A OPDRVs.

or" B not. met. during OPDRVs.

CQllllnlJia Cf:?IIPrating '-,tatioli 3.6.4.2 3 ,\rnenrJmen t No. 149. 169.J...l,1..9 nf'i

SCIVs 3.6.4.2 SURVEILLANCE REQUIREMENTS SURVE [LLf\NCF SR 3.6.4.2.1 NorES*

1. Val vf? san (j t) 1i nd f 1drl 9e sin ~) i Cd ~l r' ad i a t ion a r P r1 sma y be ve r i fie c1 by use () f r1 d mi il i s t ,'d t i V l' con t (' 0 Is.

2. Not rcquir'.,<J 1.0 be llIet FlH' SCIVs that are open 1I1llj e r 'H1rni II i s t r' a t j ve controls.

Verify each secondary containment 31 clays isolation manual valve and blind flange that is not locked, sealed, or otherwise secured, and is required to be closed during accident conditions is closed.

SR 3.6.4.2.2 Verify the isolation time of each power In accordance operated. automatic SCIV is within with the 1 i mi t s . fnservice Testing Program SR 3.6.4.2.3 Verify each dutomatic SCIV actuates to 24 rnonU1S thr isolation position on an actual Ot' simulated automatic isolation signal.

208 C'J 1 II mb i rJ r, P Ii e r d t. j II 9 S t d til) II

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 vessel (OPDRVs).

for draining the reactor I

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

B. Required Action and B.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 AND not met in MODE 1, 2, or 3. B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months C. Required Action and C.1 Place OPERABLE SGT Immediately associated Completion subsystem in Time of Condition A operation.

not met during OPDRVs. OR C.2 Initiate action to Immediately suspend OPDRVs.

(continued)

Columbia Generating Station 3.6.4.3-1 Amendment No. 149,169 199

SGT System 3.6.4.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. Two SGT subsystems D.1 Enter LCO 3.0.3. Immediately inoperable in MODE 1, 2, or 3.

E. Two SGT subsystems E.1 Initiate action to Immediately inoperable during suspend OPDRVs.

OPDRVs.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.3.1 Operate each SGT subsystem for 31 days

> 10 continuous hours with heaters operating.

SR 3.6.4.3.2 Perform required SGT filter testing in In accordance accordance with the Ventilation Filter with the VFTP Testing Program (VFTP).

SR 3.6.4.3.3 Verify each SGT subsystem actuates on an 24 months actual or simulated initiation signal.

SR 3.6.4.3.4 Verify each SGT filter cooling 24 months recirculation valve can be opened and the fan started.

Columbia Generating Station 3.6.4.3-2 Amendment No. 149,169 199

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 1 and 2 SW subsystems and UHS shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Average sediment depth A.1 Restore average 30 days in one or both spray sediment depth to ponds > 0.5 ft and within limits.

< 1.0 ft.

(continued)

Columbia Generating Station 3.7.1-1 Amendment No. i49 1691

205 SW System and UHS 3.7.1 ACTIONS - _-

CONDITION REQUIRED ACTION - COMPLETION TIME C. Required Action and C.11 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 AND or B not met.

C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR Both SW subsystems inoperable.

OR UHS inoperable for reasons other than Condition A.

SURVEILLANCE REQUIREMENTS SURVEILLANCE---- FREOUENCY SR 3.7.1.1 Verify the water level of each UHS spray 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months pond is > 432 ft 9 inches mean sea level.

(continued)

Columbia Generating Station 3.7.1-3 Amendment No. +4-9 1691

IrnL-SW System and UHS 3.7.1 SURVEILLANCE REQUIREMENTS _

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

SR 3.7.1.3 -NOTE ------------

Isolation of flow to individual components does not render SW subsystem inoperable.

Verify each SW subsystem manual, power 31 days operated, and automatic valve in the flow path servicing safety related systems or components, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.7.1.4 Verify average sediment depth in each UHS 92 days spray pond is < 0.5 ft.

SR 3.7.1.5 Verify each SW subsystem actuates on an 24 months actual or simulated initiation signal.

K>

Columbia Generating Station 3.7 .1-4 Amendment No. i41g- 1691

HPCS SW System 3.7.2 3.7 PLANT SYSTEMS 3.7.2 High Pressure Core Spray (HPCS) Service Water (SW- System LCO 3.7.2 The HPCS SW System shall be OPERABLE.

APPLICABILITY: MODES 1, 2. and 3.

ACTIONS CONDITION REOUIRED ACTION COMPLETION TIME A. HPCS SW System A.1 Declare HPCS System Immediately inoperable. inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1 ------------------- NOTE--------------------

Isolation of flow to individual components does not render HPCS SW System inoperable.

Verify each HPCS SW System manual, power 31 days operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.7.2.2 Verify the HPCS SW System actuates on an 24 months actual or simulated initiation signal.

Columbia Generating Station 3.7. 2-1 Amendment No. 4-49 1691

CREF System 3.7.3 3.7 PLANT SYSTEMS 3.7.3 Control Room Emergency F iltra,:ion (CREF) System LCO 3.7.3 Two CREF subsystems shall be OPERABLE.

................- NOTE ------------------------------

The control room envelope (CRE) boundary may be opened intermittently under administrative control. I 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 CREF subsystem A.1 Restore CREF 7 days inoperable for reasons subsystem to OPERABLE other than Condition status.

B.

B. One or more CREF B.1 Initiate action to Immediately subsystems inoperable implement mitigating due to inoperable CRE actions.

boundary in MODE 1, 2, or 3. AND.

B.2 Verify mitigating 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months actions ensure CRE occupant exposures to radiological chemical, and smoke hazards will not exceed limits.

AND (continued)

Columbia Generating Station 3.7.3-I Amendment No; 149.16 .199 o188 207

CREF System 3.7.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.3 Restore CRE boundary 90 days to OPERABLE status, C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Associated Compietion Time of Condition.A or AND B not met in MODE 1.

2, or 3. C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months D. Required Action and D.1 Place OPERABLE CREF Immediately associated Completion subsystem in Time ofCondition A pressurization mode.

not met during OPDRVs. OR D.2 Initiate action to Immediately suspend OPDRVs.

E. Two CREF subsystems E.1 Enter LCO 3.0.3. Immediately inoperable in MODE 1, 2, or 3 for reasons other than Condition B.

(continued)

Columbia Generating Station 3.7.3-2 Amendment No.

14'J,1CO,13o8,o 207

CREF System 3.7.3 ACTIONS CONDITION REQU I RED ACT ION COMPLETION TIME F. Two CREF subsystems F.1 Initiate action to Immediately inoperable during suspend OPDRVs.

OPDRVs.

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

SURVEILLANCE REQUIREMENTS SURVEILLA~CE FREQUENCY SR 3.7.3.1 Operate each CREF subsystem for ~ 10 31 days continuous hours with the heaters operating.

SR 3.7.3.2 Perform required CREF filter testing in In accordance accordance with the Ventilation Filter with the VFTP Testing Program (VFTP).

(continued)

Columbia Generating Station 3.7.3-3 Amendment No.

149,169,188,199,207 216

CREF System 3.7.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREOUENCY SR 3.1'.3.3 Verify each CREF subsystem actuates on an 24 months actual or simulatec initiation signal.

SR 3.7.3.4 Perform required CRE unfiltered air In accordance inleakage testing in accordance with the with the Control Room Envelope Habitability Program. Control Room Envelope Habitabi lity Program r i Iý) t. on Co I umh i ý) Gt_*npr a tin ,, .) 3. 7.3-4 Amendment No. 149,169,199 207

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, During operations with a potential vessel (OPDRVs).

for draining the reactor I

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

B. Required Action and B.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 AND not met in MODE 1, 2, or 3. B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months C. Required Action and C.1 Place OPERABLE Immediately associated Completion control room AC Time of Condition A subsystem in not met during operation.

OPDRVs.

OR C.2 Initiate action to Immediately suspend OPDRVs.

(continued)

Columbia Generating Station 3.7.4-1 Amendment No. 149,169 199

Control Room AC System 3.7.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. Two control room AC D.1 Enter LCO 3.0.3. Immediately subsystems inoperable in MODE 1, 2. or 3.

E. Two control room AC E.1 Initiate action to Immediately subsystems inoperable suspend OPDRVs.

during OPDRVs.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify each control room AC subsystem has 24 months the capability to remove the assumed heat load.

Columbia Generating Station 3.7.4-2 Amendment No. 149,169 199

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 activity rate of the gases not within noble gases to within limit., limit.

B. Required Action and B.1 Isolate all main 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion steam lines.

Time not met.

OR 8.2 Isolate SJAE. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months OR B.3.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND B.3.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Columbia Generating Station 3.7 . 5- 1 Amendment No. +449 1691

Ml.t Main Condenser Offgas 3.7.5 SURVEILLANCE RECUJREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 ------------------- NOTE--------------------

Not required to be performed until 31 days after any main steam line not isolated and SJAE in operation.

Verify the gross gamma activity rate of the 31 days noble gases is < 332 mCi/second after decay of 30 minutes. AND Once within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after a

> 50% increase in the nominal steady state fission gas release after factoring out increases due to changes in THERMAL POWER level Columbia Generating Station 3.7. 5-2 Amendment No. 4-4g 1691

Main Turbine Bypass System 3.7.6 3.7 PLANT SYSTEMS 3.7.6 Main Turbine Bypass System LCO 3.7.6 The Main Turbine.Bypass System shall be OPERABLE.

OR LCO 3.2.2. "MINIMUM CRITICAL POWER RATIO .(MCPR)." limits for an inoperable Main Turbine Bypass System. as specified in the COLR, are made applicable.

APPLICABILITY: THERMAL POWER > 25% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the A.1 Satisfy the 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months LCO not met. requirements of the LCO.

B. Required Action and B.1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion to < 25% RTP.

Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify one complete cycle of each main 31 days turbine bypass valve.

(continued)

Columbia Generating Station 3.7.6-1 'Amendment No. A4-4 1691

Main Turbine Bypass System 3;7.6 SURVEILLANCE REOUIREMENTS SURVEILLANCE n FREOUENCY SR 3.7.6.2 Perform a system functional test. 24 months SR 3.7.6.3 Verify the TURBINE BYPASS SYSTEM RESPONSE 24 months TIME is within limits.

Columbia Generating Station 3.7. 2 Amendment No. 4 1691

Spent Fuel Storage Pool Water Level 3.7.7 3.7 PLANT SYSTEMS 3.7.7 Spent Fuel Storage Pool Water Level LCO 3.7.7 The spent fuel storage pool water level shall be > 22 ft over the top of irradiated fuel assemblies seated in the spent fuel storage pool racks.

APPLICABILITY: During movement of irradiated fuel assemblies in the spent fuel storage pool.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Spent fuel storage A.1 -------- NOTE---------

pool water level not LCO 3.0.3 is not within limit. applicable.

Suspend movement of Immediately irradiated fuel assemblies in the spent fuel storage pool.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1 Verify the spent fuel storage pool water 7 days level is > 22 ft over the top of irradiated fuel assemblies seated in the spent fuel

.storage pool racks.

Columbia Generating Station 3.7.7 -1 Amendment No. +4-9 1691

AC Sources - Operating I 3.8.1 3;8- ELECTRICAL POWER SYSTEMS 3.8.1 AC Sources -Operating LCO 3.8.1 The following AC electrical power sources shall be OPERABLE:

a. Two qualified circuits between the offsite transmission network and the'onsite Class 1E AC Electric Power Distribution System: and

b. Three diesel generators (OGs).

APPLICABILITY: MODES 1, 2, and 3.

- NOTE----------------------------

Division 3 AC electrical power sources are not required to be OPERABLE when High Pressure Core Spray System is inoperable.

ACTIONS

NOTE-------------------------------------

LCO 3.0.4.b is not applicable to DGs.

- - - -- - -- - - - - - - - - - - - - - - --- - - - -- - I- - - - - - - - - - - - - - - -- - - - - - - - - --- - - -

I CONDITION REQUIRED ACTION COMPLETION TIME A. One offsite circuit A.1 Perform SR 3.8.1.1 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. for OPERABLE offsite circuit. AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND (continued)

Columbia Generating Station -3.8.1-1 Amendment No.' 149.169,187

AC Sources - Operating

.3.8.1 ACT ION S CONDITION I REQUIRED ACTION I COMPLETION TIME A. (continued) A.2 Declare required 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months from feature(s) with no discovery of no offsite power offsite powe, available inoperable to one division when the redundant concurrent with required feature(s) inoperability are inoperable. of redundant required feature(s)

-AND-A.3 Restore offsite 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months circuit to OPERABLE status. AND 6 days from discovery of failure to meet LCO when not associated with Required Action 8.4.2.2 AND 17 days from discovery of failure to meet LCO B. One required DG B.1 Perform SR 3.8.1.1 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. for OPERABLE offsite circuit(s). AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND (continued)

Columbia Generating Station 3.8. 1-2 Amendment No. 444-.4-&4 197

205 AC Sources -Operating

.8.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.4.2.1 Establish risk 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months management actions for the alternate AC sources.

AND B.4.2.2 Restore required DG 14 days to OPERABLE status.

AND .

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

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

L ________________________________ L (continued)

Columbia Generating Station 3.8.1 -4 Amendment No. +4g49--4G 197

AC Sources -Operating 3.3.1 ACTIONS CONDITION REQUIRED ACTION ICOMPLETION TIME D. One offsite circuit ------------ NOTE-------------

inoperable. Enter applicable Conditions and Required Actions of ANC LCO 3.8.7, "Distribution Systems- Operating," when One required DG Condition D is entered with inoperable. no AC power source to any division.

D.1 Restore offsite 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months circuit to OPERABLE status.

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

E. Twc required DGs E.1 Restore one required 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months inoperable. DG to OPERABLE status. OR 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months if Division 3 DG is inoperable F. Recuired 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, AND B, C, D, 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 G. Three or more required G.1 Enter LCO 3.0.3. Immediately AC sources inoperable.

Columbia Generating Station 3.8.1- 5 Amendment No. 149,1 4 197

f 'ill AC Sources -Operating 3.8.1 .

.. l SURVEILLANCE REOUIREMENTS-..

SURVEILLANCE 'FREQUENCY K)

SR 3.8.1.1 Verify correct breaker alignment and 7 days indicated 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.per.iod. prior to 'loading.

- I . ' . . . - .

.: . ;. : I..,.:

. . . .. . . t

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.

- .- - - . -- - -- i - . -! .; . . :, :

Verify each required DG starts from standby 31 days -' -

- conditions'and,:achieves' steady stat'e: . > N-

.^, C ...........

a..a: . Voltage. > 3910V:and- < 4400 4V and . .. : - -: i, ...... :. : :; K.)U frequency' Ž58'.8 Hz and'< 61'.2'Hz'for . ;- . .:

N I' '- . -

.. -. a, ... ..

DG;1'and DG-2; and' ......

b. Voltage > 3910 V and < 4400 V and frequency > 58.8 Hz and < 61.2 Hz for I DG-3.

(continued)

... .4 . :,.:. -

.; . w .

.... . . ..... , , x . x - . .

-- -*S^' Colu'mbia Generating'Station 3.8.1-6 Amendment, No'. 449'., 16 8k6)

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURV EI LLANCE FREOUENCY SR 3.8.1.3 - - - - - - - - - - - - - - - - - - - NOTES - - - - - - - - - - - - - - - - - -

1. DG loadings may include gradual loading as recommended by the manufacturer.

2. Momentary transients outside the load range do not invalidate this test.

3. This Surveillance shall be conducted on only one DG at a time.

4. This SR shall be preceded by. and immediately follow. without shutdown.

a successful performance of SR 3.8.1.2 or SR 3.8.1.7.

5. The endurance test of SR 3.8.1.14 may be performed in lieu of the load-run test in SR 3.8.1.3 provided the requirements. except the upper load limits. of SR 3.8.1.3 are met.

Verify each required OG is synchronized and 31 days loaded and operates for 2 60 minutes at a load 2 4000 kW and ~ 4400 kW for OG-1 and DG-2. and 2 2340 kW and ~ 2600 kW for OG-3.

SR 3.8.1.4 Verify each required day tank contains fuel 31 days oi 1 to support greater than or equal to one hour of operation at full load plus 10%.

SR 3.8.1.5 Check for and remove accumulated water from 31 days each required day tank.

(continued)

Columbia Generating Station 3.8.1-7 Amendment No. 149,169.173 215

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.6 Verify each required fuel oil transfer 92 days subsystem operates to automatically transfer fuel oil from the storage tank to the day tank.

SR 3.8.1.7 ------------------- NOTE --------------------

All DG starts may be preceded by an engine prelube period.

Verify each required DG starts from standby 184 days condition and achieves:

a. For DG-1 and DG-2 in < 15 seconds, voltage > 3910 V and frequency

> 58.8 Hz, and after steady state conditions are reached, maintains voltage > 3910 V and < 4400 V and frequency ) 58.8 Hz and < 61.2 Hz; and

b. For DG-3, in < 15 seconds, voltage

> 3910 V and frequency Ž 58.8 Hz, and after steady state conditions are reached, maintains voltage > 3910 V and < 4400 V and frequency > 58.8 Hz and < 61.2 Hz.

(continued)

Columbia Generating Station 3.8.1-8 Amendment No. 149,169,173,181 204

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY 4

SR 3.8.1.8 ------------------- NOTE-----------------

The automatic transfer function of this Surveillance shall not normally be performed in MODE 1 or 2. However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Verify automatic and manual transfer of the 24 months power supply, to safety related buses from the startup offsite circuit to the backup offsite circuit.

4.

SR 3.8.1.9 ----------------- NOTES------------------

1. Credit may be taken for unplanned events that satisfy this SR.

2. If performed with the DG synchronized with offsite power, it shall be performed at a power factor as close to the power factor of the single largest post-accident load as practicable. However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition, the power factor shall be maintained as close to the limit as practicable.

Verify each required DG rejects a load 24 months greater than or equal to its associated single largest post-accident load, and following load rejection, the frequency is

< 66.75 Hz.

(continued)

Columbia Generating Station 3.8.1-9 Amendment No. 204 149,169,17-3

AC Sources- Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.10 ---------------- NOTES ----------------------

1. Credit may be taken for unplanned events that satisfy this SR.

2. If performed with the DG synchronized with offsite power, it shall be performed at a power factor of < 0.9 for DG-1 and DG-2, and < 0.91 for DG-

3. However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition, the power factor shall be maintained as close to the limit as practicable.

Verify each required DG does not trip and 24 months voltage is maintained < 4784 V during and following a load rejection of a load

> 4400 kW for DG-1 and DG-2 and > 2600 kW for DG-3.

SR 3.8.1.11 -NOTES -------------------

1. All DG starts may be preceded by an engine prelube period.

2. This Surveillance shall not normally be performed in MODE 1, 2, or 3 (not applicable to DG-3). However, portions of the surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated loss of 24 months offsite power signal:

a. De-energization of emergency buses; (continued)

Columbia Generating Station 3.8.1-10 Amendment No. 204 149,169.181 ,203

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.11 (continued)

b. Load shedding from emergency buses for Divisions 1 and 2; and

c. DG auto-starts from standby condition and:

1. energizes permanently connected loads in < 15 seconds for DG-1 and DG-2, and in < 18 seconds for DG-3,

2. energizes auto-connected shutdown loads,

3. maintains steady state voltage

> 3910 V and < 4400 V.

4. maintains steady state frequency

> 58.8 Hz and < 61.2 Hz, and

5. supplies permanently connected and auto-connected shutdown loads for

> 5 minutes.

(continued)

Columbia Generating Station 3.8.1-11 Amendment No. 204 149,169,131,.203

AC Sources- Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.12 NOTES-------------------

1. All DG starts may be preceded by an engine prelube period.

2. This Surveillance shall not normally be performed in MODE 1 or 2 (not applicable to DG-3). However, portions of the surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated Emergency 24 months Core Cooling System (ECCS) initiation signal each required DG auto-starts from standby condition and:

a. For DG-1 and DG-2, in < 15 seconds achieves voltage > 3910 V, and after steady state conditions are reached, maintains voltage > 3910 V and

< 4400 V and, for DG-3, in

< 15 seconds achieves voltage 5 3910 V, and after steady state conditions are reached, maintains voltage , 3910 V and < 4400 V;

b. In < 15 seconds, achieves frequency

> 58.8 Hz and after steady state conditions are achieved, maintains frequency Ž 58.8 Hz and < 61.2 Hz;

c. Operates for > 5 minutes; (continued)

I ____________________________

Columbia Generating Station 3.8.1-12 Amendment No. 204 149,169,14-3

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.12 (continued)

d. Permanently connected loads remain energized from the offsite power system: and

e. Emergency loads are auto-connected to the offsite power system.

SR 3.8.1.13 ------------------NOTE --------------------

Credit may be taken for unplanned events that satisfy this SR.

Verify each required DG's automatic trips 24 months are bypassed on an actual or simulated ECCS initiation signal except:

a. Engine overspeed;

b. Generator differential current; and C. Incomplete starting sequence.

(continued)

Columbia Generating Station 3.8.1-13 Amendment No. -49,--69*--4 204

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY S

SR 3.8.1.14 -------------------- NOTES----------------

1. Momentary transients outside the load, excitation current, and power factor ranges do not invalidate this test.

2. Credit may be taken for unplanned events that satisfy this SR.

3. If performed with the DG synchronized with offsite power, it shall be performed at a power factor of < 0.9 for DG-1 and DG-2, and < 0.91 for DG-

3. However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition, the power factor shall be maintained as close to the limit as practicable.

Verify each required DG operates for 24 months

> 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s:

a. For > 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded > 4650 kW for DG-1 and DG-2, and > 2850 kW for DG-3; and

b. For the remaining hours of the test loaded > 4400 kW for DG-1 and DG-2, and > 2600 kW for DG-3.

(continued)

Columbia Generating Station 3.8.1-14 Amendment No. 204 14%+9,169,8+

AC Sources- Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.15 --------------------NOTES -------------------

1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated > 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months loaded > 4000 kW for DG-1 and DG-2, and > 2340 kW for DG-3.

Momentary transients outside of load range do not invalidate this test.

2. All DG starts may be preceded by an engine prelube period.

Verify each required DG starts and 24 months achieves:

a. For DG-1 and DG-2, in < 15 seconds.

voltage > 3910 V and frequency

> 58.8 Hz, and after steady state conditions are reached, maintains voltage > 3910 V and < 4400 V and frequency > 58.8 Hz and < 61.2 Hz; and

b. For DG-3, in < 15 seconds, voltage

> 3910 V and frequency > 58.8 Hz, and after steady state conditions are reached, maintains voltage > 3910 V and < 4400 V and frequency > 58.8 Hz and < 61.2 Hz.

(continued)

Columbia Generating Station 3.8.1-15 Amendment No. 204 149.16*P,3,203

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.16 ------------------- NOTE --------------------

This Surveillance shall not normally be performed in MODE 1, 2. or 3 (not applicable to DG-3). However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Verify each required DG: 24 months

a. Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power;

b. Transfers loads to offsite power source; and

c. Returns to ready-to-load operation.

SR 3.8.1.17 -------------------NOTE --------------------

Credit may be taken for unplanned events that satisfy this SR.

Verify, with a DG operating in test mode 24 months and connected to its bus, an actual or simulated ECCS initiation signal overrides the test mode by:

a. Returning DG to ready-to-load operation; and

b. Automatically energizing the emergency load from offsite power.

(continued)

Columbia Generating Station 3.8.1-16 Amendment No. 204 149, 1ýW 101, 123

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY t

SR 3.8.1.18 ----------------- NOTE ---------------------

This Surveillance shall not normally be performed in MODE 1. 2, or 3. However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Verify interval between each sequenced load 24 months block is within +/- 10% of design interval for each time delay relay.

SR 3.8.1.19 ------------------ NOTES----------------

1. All DG starts may be preceded by an engine prelube period.

2. This Surveillance shall not normally be performed in MODE 1, 2, or 3 (not applicable to DG-3). However, portions of the surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Verify, on an actual or simulated loss of 24 months offsite power signal in conjunction with an actual or simulated ECCS initiation signal:

a. De-energization of emergency buses;

b. Load shedding from emergency buses for DG-1 and DG-2; and (continued)

Columbia Generating Station 3.8.1-17 Amendment No. 204 149,169,1801,203

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.19 (continued)

c. DG auto-starts from standby condition and:

1. energizes permanently connected loads in < 15 seconds,

2. energizes auto-connected emergency loads,

3. maintains steady state voltage

> 3910 V and < 4400 V,

4. maintains steady state frequency

> 58.8 Hz and < 61.2 Hz, and

5. supplies permanently connected and auto-connected emergency loads for

> 5 minutes..

SR 3.8.1.20 -------------------NOTE-----------------

All DG starts may be preceded by an engine prelube period.

Verify, when started simultaneously from 10 years standby condition, DG-1 and DG-2 achieves, in < 15 seconds, voltage > 3910 V and frequency Ž 58.8 Hz, and DG-3 achieves, in

< 15 seconds, voltage > 3910 V and frequency > 58.8 Hz.

Columbia Generating Station 3.8.1-18 Amendment No. 204

AC Sources - Shutdown 3.8.2 3.8 ELECTRICAL POWER SYSTEMS 3.8.2 AC Sources - Shutdown LCO 3.8.2 The following AC electrical power sources shall be OPERABLE:

a. One qualified circuit between the offsite transmission network and the onsite Class I E AC electrical power distribution subsystem9sO required by LCO 3.8.8, "Distribution Systems - Shutdown;"

b. One diesel generator (DG) capable of supplying one division of the Division I or 2 onsite Class 1E AC electrical power distribution subsystem(s) required by LCO 3.8.8; and

c. The Division 3 DG capable of supplying the Division 3 onsite Class IE AC electrical power distribution subsystem, when the-Division 3 onsite Class IE electrical power distribution subsystem is required by LCO 3.8.8.

APPLICABILITY: MODES 4 and 5.

Columbia Generating Station 3.8.2-1 Amendment No. 149,169 199

AC Sources - Shutdown 3.8.2 ACTIONS I

CONDITION REQUIRED ACTION COMPLETION TIME A. Required offsite -------------- NOTE----------

circuit inoperable. Enter applicable Condition and Required Actions of LCO 3.8.8, when any required division is de-energized as a result of Condition A.

A.1 Declare affected Immediately required feature(s) with no offsite power available inoperable.

OR A.2.1 Initiate action to suspend operations Immediately I

with a potential for draining the reactor vessel (OPDRVs).

AND A.2.2 Initiate action to restore required Immediately I

offsite power circuit to OPERABLE status.

B. Division 1 or 2 required DG B.1 Initiate action to suspend OPDRVs.

Immediately I

inoperable.

AND B.2 Initiate action to restore required DG Immediately I

to OPERABLE status.

(continued)

Columbia Generating Station 3.8.2-2 Amendment No. 149,169 199

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

"APPLICABI LITY: When associated DG is required to'be OPERABLE.

ACTIONS

- - - - - '- - - 0" - - - - - 0 - - - - - - -

~

- - - - - - - - - - - - NOT E- - - -'- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -

Separate Condition entry is allowed for each DG.

~

CONDITWN REQUIRED ACTION COMPLETION TIME A. One or more DGs with A.1 Restore stored fuel '48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months fuel oil 1 eve 1 1 es s oil 1 eve 1 to withi n than a 7 day supply 1 i mi t.

and greater thana 6 day supply.

B. One or more DGs with B.l Restore lube oil 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months lube oil inventory inventory to withi n less than a 7 day 1 i mit.

supply and greater than a 6 day supply.

(continued)

Columbia Generating Station 3.8.3-1 Amendment No. 149.169 215

Diesel Fuel Oil. Lube Oil, and Starting Air 3.8.3 ACTIONS .

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more DGs with C.1 Restore stored fuel 7 days stored fuel oil total oil total particulates not particulates to within limit. within limit.

D. One or more DGs with D.1 Restore stored fuel 30 days new fuel oil oil properties to properties not within within limits.

limits.

E. One or more DGs with E.1 Restore required 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months required starting air starting air receiver receiver pressure: pressure to within limit.

1. For DG-1 and DG-2.

< 230 psig and

> 150 psig: and

2. For DG-3,

< 223 psig and

> 150 psig.

F. Required Action and F.1 Declare associated DG Immediately associated Completion inoperable.

Time of Condition A.

B, C. D. or E not met.

OR One or more DGs with stored diesel fuel oil, lube oil, or starting air subsystem not within l:mits for reasons other than Condition A. B. C, D, or E.

K>

Columbia Generating Station 3.8.3-32 Amendment No. A4341691

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREOUENCY SR 3.8.3.1 Verify each fuel oil storage subsystem 31 days contains L a 7 day supply of fuel.

SR 3.8.3.2 Verify lube oil inventory is ) a 7 day 31 days' supply.

SR 3.8.3.3 Veri fy fuel oi 1 properties of new and In accordance stored fuel oil are tested in accordance . wi th the Oi esel with, and maintained within the limits of, Fuel Oil the Di esel Fuel Oi 1 Testing Program. Testing Program SR 3.8.3.4 Verify each required OG air s ta rt receiver 31 days pressure is:

a. L 230 psig for DG-1 and DG-2; and

b. L 223 psig fo r OG-3.

SR 3.8.3.5 Check for and remove accumulated water from 92 days each fuel oil storage tank.

Columbia Generating Station 3.8.3-3 Amendment No. 149.169 215

DC Sources - Operating 3.8.4 3.8 ELECTRICAL POWER SYSTEMS 3.8.4 DC Sources.- Operating LCO 3.8.4 The Division 1, Division 2, and Division 3 DC electrical power subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required Division A.1 Restore battery 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months 1 or 2 125 V DC terminal voltage to battery charger greater than or equal inoperable, to the minimum established float voltage.

AND A.2 Verify battery float Once per 12 current < 2 amps. hours AND A.3 Restore required 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months battery charger to OPERABLE status.

(continued)

Columbia Generating Station 3.8.4-1 Amendment No. 149,169 204

DC Sources - Operating 3.8.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. One required Division B.1 Restore battery 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months 3 125 V DC battery terminal voltage to charger inoperable, greater than or equal to the minimum established float voltage.

AND B.2 Verify battery float Once per 12 current < 2 amps. hours AND B.3 Restore required 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months

-battery charger to OPERABLE status.

C. One required Division C.1 Restore battery 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months 1 250 V DC battery terminal voltage to charger inoperable, greater than or equal to the minimum established float voltage.

AND C.2 Verify battery float Once per 12 current < 2 amps. hours AND C.3 Restore required 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months battery charger to OPERABLE status.

(continued)

Columbia Generating Station 3.8.4-2 Amendment No. 149 .169 204

DC Sources - Operating 3..8.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. One required Division D.1 Restore battery to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months 1 or 2 125 V DC OPERABLE status.

battery inoperable.

E. One required Division E.1 Restore battery to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months 3 125 V DC battery OPERABLE status.

inoperable.

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

inoperable.

G. Division 1 or 2 125 V DC electrical power G.1 Restore Division 1 and 2 125 V DC 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months I

subsystem inoperable electrical power for reasons other than subsystems to Condition A or D. OPERABLE status.

H. Required Action and H.1 Declare High Pressure Immediately associated Completion Core Spray System Time of Condition B or inoperable.

E not met.

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

(continued)

Columbia Generating Station 3.8.4-3 Amendment No. 204 149,16,1*9

DC Sources - Operating 3.8.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME I. Required Action and 1.1 Declare associated Immediately associated Completion supported features Time of Condition C or inoperable.

F not met.

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

J. Required Action and associated Completion J.1, Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months II Time of Condition A or AND D not met.

J.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR Required Action and associated Completion Time of Condition G not met.

Columbia Generating Station 3.8.4-4 Amendment No. 204 149,169,164

DC Sources - Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREOUENCY SR 3.8.4.1 Verify battery terminal voltage is greater 7 days than or equal to the minimum established float voltage.

SR 3.8.4.2 Verify each required battery charger supplies the required load for > 1.5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months 24 months I

at:

a. > 126 V for the 125 V battery chargers; and

b. > 252 V for the 250 V battery charger.

SR 3.8.4.3 ------------------- NOTES----------------

1. The modified performance discharge II test in SR 3.8.6.6 may be performed in lieu of SR 3.8.4.3.

2. This Surveillance shall not be performed in MODE 1. 2, or 3 for the Division 1 and 2 125 V DC batteries.

However, credit may be taken for unplanned events that satisfy this SR.

Verify battery capacity is adequate to 24 months supply, and maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test.

I Columbia Generating Station 3.8.4-5 Amendment No. 149,I60.169 204

DC Sources - Shutdown 3.8.5 3.8 ELECTRICAL POWER SYSTEMS 3.8.5 DC Sources -. Shutdown LCO 3.8.5 DC electrical power subsystem(s) shall be OPERABLE to support the electrical power distribution subsystem(s) required by LCO 3.8.8, "Distribution Systems-Shutdown."

APPLICABILITY: MODES 4 and 5.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required battery A.1 Restore battery 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months charger inoperable, terminal voltage to greater than or equal AND to the minimum established float The redundant division voltage.

battery and battery charger OPERABLE. AND A.2 Verify battery float Once per 12 current < 2 amps. hours AND A.3 Restore required 7 days battery charger to OPERABLE status.

(continued)

Columbia Generating Station 3.8.5-1 Amendment No. i49*6 *,494 204

DC Sources - Shutdown 3.8.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. One or more required DC electrical power B.1 Declare affected required feature(s)

Immediately I

subsystems inoperable, inoperable.

for reasons other than Condition A. OR OR B.2.1 Initiate action to Immediately suspend operations Required Action and with a potential for Completion Time of draining the reactor Condition A not met. vessel.

AND B.2.2 Initiate action to restore required DC Immediately I

electrical power subsystems to OPERABLE status.

Columbia Generating Station 3.8.5-2 Amendment No. 1-49,d69,99 204

DC Sources - Shutdown 3.8.5 SUIRVEIL ANCE REOUIREMENTS SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY i

SR 3.8.5.1------------------- NOTE ---------------.-.-.

The following SRs are not required to be performed: SR 3.8.4.2, and SR 3.8.4.3.

I For DC electrical power subsystems required In accordance to be OPERABLE the following SRs are with applicable applicable: SRs SR 3.8.4.1, SR 3.8.4.2, and SR 3.8.4.3.

I Columbia Generating Station 3.8.5-3 Amendment No. 204

Battery Parameters 3.8.6 3.8 ELECTRICAL POWER SYSTEMS 3.8.6 Battery Parameters I

LCO 3.8.6 Battery parameters for the Division 1, 2, and 3 batteries shall be within limits.

APPLICABILITY: When associated DC electrical power subsystems are required to be OPERABLE.

ACTIONS

NOTE ---------------------------------

Separate Condition entry is allowed for each battery.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more batteries A.1 Perform SR 3.8.4.1. 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months with one or more battery cells float AND voltage < 2.07 V.

A.2 Perform SR 3.8.6.1. 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months AND A.3 Restore affected cell 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months voltage > 2.07 V.

B. One or more batteries B.1 Perform SR 3.8.4.1. .2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months with float current > 2 amps. AND B.2 Restore battery float 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months current to,< 2 amps.

(continued)

Columbia Generating Station 3.8.6-1 Amendment No. 149,169 204

Battery Parameters 3.8.6 I

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME

NOTE ----------- ------------ NOTE----------

Required Action C.2 shall Required Actions C.1 and C.2 be completed if are only applicable if electrolyte level was electrolyte level was below below the top of plates. the top of plates.

C. One or more batteries C.1 Restore electrolyte. 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months with one or more cells level to above top of electrolyte level less plates.

than minimum established design AND limits.

C.2 Verify no evidence of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months leakage.

AND C.3 Restore electrolyte 31 days level to greater than or equal to minimum established design limits.

D. One or more batteries D.1 Restore battery pilot 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months with pilot cell cell temperature to electrolyte greater than or equal temperature less than to minimum minimum established, established design limits.

E. Two or more redundant E.1 Restore battery 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months division batteries parameters for with battery affected battery in parameters not within one division to limits. within limits.

(continued)

Columbia Generating Station 3.8.6-2 Amendment No. 149,169 204

Battery Parameters 3.8.6 I

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME F. One or more batteries F.1 Declare associated Immediately with a required battery inoperable.

Battery Parameter not met for reasons other than Condition A. B, C, D, or E.

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

OR One or more batteries with one or more battery cell(s) float voltage < 2.07 V and float current > 2 amps.

Columbia Generating Station 3.B.6-3 Amendment No. 149,169 204

Battery Parameters 11, 3.8.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1- ------------------ NOTE-----------------

Not required to be met when battery terminal voltage is less than the minimum established float voltage of SR 3.8.4.1.

Verify each battery float current is < 2 7 days amps.

SR 3.8.6.2 Verify each battery pilot cell voltage is 31 days

> 2.07 V.

SR 3.8.6.3 Verify each battery connected cell 31 days electrolyte level is greater than or equal to minimum established design limits.

SR 3.8.6.4 Verify each battery pilot cell temperature 31 days is greater than or equal to minimum established design limits.

SR 3.8.6.5 Verify each battery connected cell voltage 92 days is > 2.07 V.

(continued)

Columbia Generating Station 3.8.6-4 Amendment No. 149,169 204

Battery Parameters 3.8.6 I

SURVEILLANCE REQUIREMENTS I.

SURVEILLANCE FREQUENCY 4.

SR 3.8.6.6 NOTE--------------------

This Surveillance shall not be performed in MODE 1, 2, or 3 for the Division 1 and 2 125 V DC batteries. However, credit may be taken for unplanned events that satisfy this SR.

Verify battery capacity is > 80% of the 60 months manufacturer's rating for the 125 V batteries and > 83.4% of the manufacturer's AND rating for the 250 V battery, when subjected to a performance discharge test 12 months when or a modified performance discharge test. battery shows degradation or has reached 85%

of expected life with capacity < 100%

of manufacturer's rating AND 24 months when battery has reached 85% of the expected life with capacity > 100%

of manufacturer's rating I ____________________________

Columbia Generating Station 3.8.6-5 Amendment No. 204

Distribution Systems - Operating 3.8.7 3.8 ELECTRICAL POWER SYSTEMS 3.8.7 Distribution Systems- Operating LCO 3.8.7 The following AC and DC electrical power distribution subsystems shall be OPERABLE:

a. Division -landDivision 2 AC electrical power distribution subsystems:

b. Division 1 and Division 2 125 V DC electrical power distribution subsystems;

c. Division 1 250 V DC electrical power distribution subsystem; and

d. Division 3 AC and DC electrical power distribution subsystems.

APPLICABILITY: MODES 1. 2. and 3.

ACTIONS CONDITION REHUIRED ACTION COMPLETION TIME A. Division 1 or 2 AC A.1 Restore Division 1 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months electrical power and 2 AC electrical distribution subsystem power distribution AND inoperable. subsystems to 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 (continued)

Columbia Generating Station 3.8.7 -1 Amendment No. A449 1691

lL.

Distribution Systems -Operating 3.8.7 ACTIONS CONDITION REOUIRED ACTION - COMPLETION TIME B. Division 1 or 2 125 V B.1 Restore Division 1 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months DC electrical power and 2 125 V DC distribution subsystem electrical power AND inoperable. distribution subsystems to 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months from OPERABLE status. discovery of failure to meet LCO 3.8.7.a or b C. Required Action and C.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 AND or B not met.

C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months D. Division 1 250 V DC D.1 Declare associated Immediately electrical power supported feature(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.1 Enter LCO 3.0.3. Immediately with inoperable electrical power distribution subsystems that result in a loss of function.

Columbia Generating Station 3.8.7- 2 Amendment No. +474169l

Distribution Systems- Operating 3.8.7 SURVEILLANCE REOUIREMENTS SURVEILLANCE FREOUENCY SR 3.8.7.1 Verify correct breaker alignments and 7 days indicated power availability to required AC and DC electrical power distribution subsystems.

Columbia Generating Station 3mo 3.8.7 -3 Amendment No. 4-44 1691

Distribution Systems -Shutdown 3.8.8 3.8 ELECTRICAL POWER SYSTEMS 3.8.8 Distribution Systems-Shutdown LCO 3.8.8 The necessary portions of the Division 1. Division 2. and Division 3 AC and DC electrical power distribution subsystems shall be OPERABLE to support equipment required to be OPERABLE.

APPLICABILITY: MODES 4 and 5.

I I

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Declare associated Immediately AC or DC electrical supported required power distribution feature(s) subsystems inoperable, inoperable.

OR A.2.1 Initiate action to suspend operations Immediately I

with a potential for draining the reactor vessel.

AND A.2.2 Initiate actions to restore required AC Immediately I

and DC electrical power distribution subsystems to OPERABLE status.

AND (continued)

Columbia Generating Station 3.8.8-1 Amendment No. 149.169 199

Distribution Systems- Shutdown 3.8.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.3 Declare associated required shutdown Immediately I

cooling subsystem(s) inoperable and not in operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct breaker alignments and 7 days indicated power availability to required AC and DC electrical power distribution subsystems.

Columbia Generating Station 3.8.8-2 Amendment No. 149,169 199

Refueling Equipment Interlocks 3.9.1 3.9 REFUELING OPERATIONS 3.9.1 Refueling Equipment Interlocks LCO 3.9.1 The refueling equipment interlocks associated with the refuel position shall be OPERABLE.

APPLICABILITY: During in-vessel fuel movement with equipment associated with the interlocks when the reactor mode switch is in the refuel position.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Suspend in-vessel Immediately refueling equipment fuel movement with interlocks inoperable. equipment associated with the inoperable interlock(s).

Columbia Generating Station 3.9.1 -1 Amendment No. 4-4-9 1691

Refueling Equipment Interlocks 3.9.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE - FREQUENCY SR 3.9.1.1 Perform CHANNEL FUNCTIONAL TEST on each of 7 days the following required refueling equipment interlock inputs:

a. All-rods-in,

b. Refueling platform position,

c. Refueling platform fuel grapple fuel-loaded.

d. Refueling platform frame-mounted hoist fuel-loaded, and

e. Refueling platform trolley-mounted hoist fuel-loaded.

Columbia Generating Station 3.9. 1-2 Amendment No. +4-9 1691

Refueling Position One-Rod-Out Interlock 3.9.2 3.9 REFUELING OPERATIONS 3.9.2 Refuel Position One-Rod-Out Interlock -

LCO 3.9.2 The refuel position one-rod-out interlock shall be OPERABLE.

APPLICABILITY: MODE 5 with the reactor mode switch in the refuel position and any control rod withdrawn.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refuel position one- A.1 Suspend control rod Immediately rod-out interlock withdrawal.

inoperable.

AND A.2. Initiate action to Immediately fully insert all insertable control rods in core cells containing one or more fuel assemblies.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Verify reactor mode switch locked in refuel 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months position.

(continued)

Columbia Generating Station 3.9.2-1 Amendment No.. 4-49 169l

Refueling Position One-Rod-Out Interlock 3.9.2 SURVEILLANCE REQUIREMENTS .-

SURVEILLANCE -FREQUENCY SR 3.9.2.2 ------------------- NOTE--------------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after any control rod is withdrawn.

Perform CHANNEL FUNCTIONAL TEST. 7 days Columbia Generating Station 3.9. 2-2 Amendment No. +4-9 1691

Control Rod Position 3.9.3 3.9 REFUELING OPERATIONS 3.9.3 Control Rod Position LCO 3.9.3 All control rods shall be fully inserted.

APPLICABILITY: When loading fuel assemblies into the core.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more control A.1 Suspend loading fuel Immediately rods not fully assemblies into the inserted. core.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Verify all control rods are fully inserted. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Columbia Generating Station 3.9.3-1 Amendment No. +4-9 1691

Control Rod Position Indication 3.9.4 3.9 REFUELING OPERATIONS 3.9.4 Control Rod Position Indication LCO 3.9.4 Each control-rod 'full-in' position indication channel shall be OPERABLE.

APPLICABILITY: MODE 5.

ACTIONS

-NOTE-------------------------------------

Separate Condition entry is allowed for each required channel.

CONDITION REHUIRED ACTION COMPLETION TIME A. One o-r more required A.1.1 Suspend in-vessel Immediately control rod position fuel movement.

indication channels inoperable. -AND A.1.2 --Suspend control rod Immediately withdrawal.

AND -

A.1.3 Initiate action to Immediately fully insert all insertable control rods in core cells containing one or more fuel assemblies.

OR (continued)

Columbia Generating Station 3.9.4 -1 Amendment No. 4-49 1691

Control Rod Position Indication 3.9.4 ACTIONS CONDITION REQUIRED ACTION v COMPLETION TIME A. (continued) A.2.1 Initiate action to Immediately fully insert the control rod associated with the inoperable position indicator.

AND A.2.2 Initiate action to Immediately disarm the control rod drive associated with the fully inserted control rod.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.4.1 Verify each channel has no "full-in" Each time the indication on each control rod that is not control rod is "full-in." withdrawn from the "full-in" position Columbia Generating Station 3.9.4- 2 Amendment No. 444 169l

Control Rod OPERABILITY- Refueling 3.9.5 3.9 REFUELING OPERATIONS 3.9.5 Control Rod OPERABILITY -Refueling LCO 3.9.5 Each withdrawn control rod shall be OPERABLE.

APPLICABILITY: MODE 5.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more withdrawn A.1 Initiate action to Immediately control rods ful-ly insert inoperable. inoperable withdrawn control rods.

SURVEILLANCE REOUIREMENTS SURVEILLANCE FREOUENCY SR 3.9.5.1 ----------- NOTE--------------------

Not required to be performed until 7 days after the control rod is withdrawn.

Insert each withdrawn control rod at least 7 days one notch.

SR 3.9.5.2 Verify each withdrawn control rod scram 7 days accumulator pressure is > 940 psig.

Columbia Generating Station 3.9.5-1 Amendment No. i4-9 1691

RPV Water Level- Irradiated Fuel 3.9.6 3.9 REFUELING OPERATIONS X 3.9.6 Reactor Pressure Vessel (RPV) Water Level- Irradiated Fuel LCO 3.9.6 RPV water level shall be > 22 ft above the top of the RPV flange.

APPLICABILITY: - During movement of irradiated fuel assemblies within the RPV.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RPV water level not A.1 Suspend movement of Immediately within limit. irradiated fuel assemblies within the RPV.

SURVEILLANCE REOUIREMENTS _

SURVEILLANCE FREOUENCY SR 3.9.6.1 Verify RPV water level is > 22 ft above the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months top of the RPV flange.

Columbia Generating Station 3.9.6-1 Amendment No. gag 1691l

RPV Water Level-New Fuel or Control Rods 3.9.7 3.9 REFUELING OPERATIONS 3.9.7 Reactor Pressure Vessel (RPV) Water Level-New Fuel or Control Rods LCO 3.9.7 RPV water level shall be > 23 ft above the top of irradiated fuel assemblies seated within the RPV.

I APPLICABILITY: During movement of new fuel assemblies or handling of control rods within the RPV when irradiated fuel assemblies are seated within the RPV.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RPV water level not A.1 Suspend movement of Immediately within limit, new fuel assemblies and handling of control rods within the RPV.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify RPV water level is > 23 ft above the top of irradiated fuel assemblies seated 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months I

within the RPV.

Columbia Generating Station 3.9.7-1 Amendment No. 149,169 199

RHR- High Water Level 3.9.8 3.9 REFUELING OPERATIONS 3.9.8 Re'sidual Heat Removal (RHR)- High Water Level LCO 3.9.8 One RHR shutdown cooling subsystem shall be OPERABLE and in operation.

NOTE----------------------------

The required RHR shutdown cooling subsystem may be removed from operation for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period.

APPLICABILITY: MODE 5 with irradiated-fuel in the reactor pressure vessel (RPV) and with the water level > 22 ft above the top of the'RPV flange. -

ACTIONS CONDITION 'REQUIRED ACTION COMPLETION TIME A. Required RHR shutdown A.1 Verify an alternate 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months cooling subsystem method'of decay heat inoperable. removal is available. AND Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter B. Required Action and B.1 Suspend loading Immediately associated Completion irradiated fuel Time of Condition A assemblies into the not met. RPV.

AND B.2 Initiate action to Immediately restore secondary containment to OPERABLE status.

AND (continued)

Columbia Generating Station 3.9.8-1 Amendment No. 4-4-9 1691

RHR-High Water Level 3.9.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.3 Initiate action to Immediately restore one standby gas treatment subsystem to OPERABLE status.

AND 8.4 Initiate action to Immediately restore isolation capability in each required secondary containment penetration flow path not isolated.

C. No RHR shutdown C.1 Verify reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from cooling subsystem in coolant circulation discovery of no operation. by an alternate reactor coolant method. circulation AND Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter AND C.2 Monitor reactor Once per hour coolant temperature.

Columbia Generating Station 3.9.8-2 Amendment No. 4-49 1691

RHR- High Water Level 3.9.8 SURVEILLANCE REQUIREMENTS.

SURVEILLANCE FREQUENCY SR 3.9.8.1 Verify one RHR shutdown cooling subsystem 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is operating.

Columbia Generating Station 3.9.8-3 Amendment No. 4-49 1691

RHR- Low Water Level 3.9.9 3.9 REFUELING OPERATIONS 3.9.9 Residual Heat Removal (RHR) -Low Water Level LCO 3.9.9 Two RHR shutdown cooling subsystems shall be OPERABLE, and one RHR shutdown cooling subsystem shall be in operation.

- ------------------------NOTE----------------------------

The required operating shutdown cooling subsystem may be removed from operation for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period.

APPLICABILITY: MODE 5 with irradiated fuel in the reactor pressure vessel (RPV) and with the water level < 22 ft above the top of the RPV flange.

ACTIONS CONDITION REOUIRED ACTION COMPLETION TIME A. One or two RHR A.1 Verify an alternate 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months shutdown cooling method of decay heat subsystems inoperable. removal is available AND for each inoperable RHR shutdown cooling Once per subsystem. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter B. Required Action and B.1 Initiate action to Immediately associated Completion restore secondary Time of Condition A containment to not met. OPERABLE status.

AND

,(continued)

Columbia Generating Station 3.9.9 -1 Amendment No. 4-49 1691

RHRI-Low Water Level 3.9.9 ACTIONS CONDITION REQUIRED ACTION v COMPLETION TIME B. (continued) B.2 Initiate action to Immediately restore one standby gas treatment subsystem to OPERABLE status.

AND B.3 Initiate action to Immediately restore isolation capability in each required secondary containment penetration flow path not isolated.

C. No RHR shutdown C.1 Verify reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from cooling subsystem in coolant circulation discovery of no operation. by an alternate reactor coolant method. circulation AND Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter AND C.2 Monitor reactor Once per hour coolant temperature.

K-,

Columbia Generating Station 3.9.9- 2 Amendment No. i44 1691

RHR- Low Water Level 3.9.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE - FREOUENCY SR 3.9.9.1 Verify one RHR shutdown cooling subsystem 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is operating.

Columbia Generating Station 3.9.9-3 Amendment No. 4-4-9 1691

Decay Time 3.9.10 3.9 REFUELING OPERATIONS 3.9.10 Decay Time LCO 3.9.10 The reactor shall be subcritical for at least 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

APPLICABILITY: During in-vessel fuel movement.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. With the reactor A.1 Suspend in-vessel Immediately subcritical for less fuel movement.

than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.10.1 Verify the rector has been subcritical for Once prior to at least 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . the movement of irradiated fuel in the reactor vessel.

Columbia Generating Station 3.9.10-1 Amendment No. 199 1

Inservice Leak and Hydrostatic Testing Operation 3.10.1 3.10 SPECIAL OPERATIONS 3.10.1 Inservice Leak and Hydrostatic Testi~g Operation LCD 3.10.1 The average reactor coolant temperature specified in Table 1.1-1 for MODE 4 may be changed to "NA." and operation considered not to be in MODE 3; and the requirements of LCO 3.4.10, "Residual Heat Removal (RHR) Shutdown Cooling System-Cold Shutdown," may be suspended to allow reactor coolant temperature> 200°F:

For performance of an inservice leak or hydrostatic test, As a consequence of maintaining adequate pressure for an inservice leak or hydrostatic test, or As a consequence of maintaining adequate pressure for control rod scram time testing initiated in conjunction with an inservice leak or hydrostatic test, provided the following MODE 3 LCOs are met:

a. LCD 3.3.6.2. "Secondary Containment Isolation Instrumentation." Functions 1. 3, and 4 of Table 3.3.6.2-1;

b. LCO 3.6.4.1. "Secondary Containment";

c. LCD 3.6.4.2. "Secondary Containment Isolation Valves (SCIVs)"; and

d. LCD 3.6.4.3, "Standby Gas Treatment (SGT) System."

APPLICABI LITY: MODE 4 with average reactor coolant temperature> 200°F.

Columbia Generating Station 3.10.1-1 Amendment No. 149.169 209

Inservice Leak and Hydrostatic Testing Operation 3.10.1 ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each requirement of the LCO.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 -------- NOTE---------

above requirements not Required Actions to met. be in MODE 4 include reducing average reactor coolant temperature to

< 200 0F.

Enter the applicable Immediately Condition of the affected LCO.

OR A.2.1 Suspend activities Immediately that could increase the average reactor coolant temperature or pressure.

AND A.2.2 Reduce average 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months reactor coolant temperature to

< 200 0F.

Columbia Generating Station 3.10.1 - 2 Amendment No. A4g41691

Inservice Leak and Hydrostatic Testing Operation 3.10.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE -FREUENCY SR 3.10.1.1 Perform the applicable SRs for the required According to MODE 3 LCOs. the applicable SRs Columbia Generating Station 3'.10. 1-3 Amendment No. b4-9 1691

Reactor Mode Switch Interlock Testing 3.10.2 3.10 SPECIAL OPERATIONS 3.10.2 Reactor Mode Switch Interlock Testing '

LCO 3.10.2 The reactor mode switch position specified in Table 1.1-1 for MODES 3. 4. and 5 may be changed to include the run, startup/hot standby, and refuel position. and operation considered not to be in MODE 1 or 2, to allow testing of instrumentation associated with the reactor mode switch interlock functions, provided:

a. All control rods remain fully inserted in core cells containing one or more fuel assemblies; and

b. No CORE ALTERATIONS are in progress.

APPLICABILITY: MODES 3 and 4 with the reactor mode switch in the run.

startup/hot. standby, or refuel position, MODE 5 with the reactor mode switch in the run or startup/hot standby position.

ACTIONS -

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 Suspend CORE Immediately above requirements not ALTERATIONS except met. for control rod insertion.

AND A.2 Fully insert all 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months insertable control rods in core cells containing one or more fuel assemblies.

AND (continued)

Columbia Generating Station 3.10.2-1 -Amendment No. 4-49 1691

Reactor Mode Switch Interlock Testing 3.10.2

',\

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME

'\>

A. (continued) A.3.1 Place the reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months mode switch in the shutdown position.

OR A.3.2 -------- NOTE---------

Only applicable in MODE 5.

Place the reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months mode switch in the refuel position.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.2.1 Verify all control rods are fully inserted 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months in core cells containing one or more fuel assemblies.

SR 3.10.2.2 Verify no CORE ALTERATIONS are in progress. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months K>

Columbia Generating Station 3.10.2- 2 Amendment No. 4-49 1691

Single Control Rod Withdrawal- Hot Shutdown 3.10.3 3.10 SPECIAL OPERATIONS 3.10.3 Single Control Rod Withdrawal -Hot Shutdown -

LCO 3.10.3 The reactor mode switch position specified in Table 1.1-1 for MODE 3 may be-changed to include the refuel position.;

and operation considered not to be in MODE 2. to allow withdrawal of a single control rod, provided the following requirements are met:

a. LCO 3.9.2. 'Refuel Position One-Rod-Out Interlock";

b. LCO 3.9.4. 'Control Rod Position Indication":

. All other control rods are fully inserted; and

d. 1. LCO 3.3.1.1. "Reactor Protection System (RPS)

Instrumentation." MODE 5 requirements for Functions l.a. 1.b. 7.a, 7.b, 10. and 11 of Table 3.3.1.1-1, and LCO 3.9.5. "Control Rod OPERABILITY- Refueling."

OR

2. All other control rods in a five by five array centered on the control rod being withdrawn are disarmed, at which time LCO 3.1.1. "SHUTDOWN MARGIN (SDM)," MODE 3 requirements may be changed to allow the single control rod withdrawn to be assumed to be the highest worth control rod.

APPLICABILITY: MODE 3 with the reactor mode switch in the refuel position.

Columbia Generating Station 3.10.3-1 Amendment No. 4-49 1691

Single Control Rod Withdrawal -Hot Shutdown 3.10.3 ACTIONS

NOTE--------------- --------------------

Separate Condition entry is allowed for each requirement of the LCO.

CONDITION I REQUIRED ACTION I COMPLETION TIME A. One or more of the A.1 -------- NOTES--------

above requirements not 1. Required Actions met. to fully insert all insertable control rods include placing the reactor mode switch in the shutdown position.

2. Only applicable if the requirement not met is a required LCO.

Enter the applicable Immediately Condition of the affected LCO.

OR A.2.1 Initiate action to Immediately fully insert all insertable control rods.

AND A.2.2 Place the reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months mode switch in the shutdown position.

Columbia Generating Station 3.10.3- 2 Amendment No. +4-9 1691

Single Control Rod Withdrawal- Hot Shutdown 3.10.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.3.1 Perform the applicable SRs for the required According to LCOs. the applicable SRs SR 3.10.3.2 ------------------- NOTE--------------------

Not required to be met if SR 3.10.3.1 is satisfied for LCO 3.10.3.d.1 requirements.

Verify all control rods, other than the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months control rod being withdrawn, in a five by five array centered on the control rod being withdrawn, are disarmed.

SR 3.10.3.3 Verify all control rods, other than the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months control rod being withdrawn, are fully inserted.

Columbia Generating Station 3.10.3 -3 Amendment No. +4-9 1691

Single Control Rod Withdrawal -Cold Shutdown 3.10.4 3.10 SPECIAL OPERATIONS 3.10.4 Single Control Rod Withdrawal- Cold Shutdown -

LCO 3.10.4 The reactor mode switch position specified in Table 1.1-1 for. MODE 4 may be changed-to include the refuel position,-

and operation considered not to be in MODE 2. to allow withdrawal of a single control rod, and subsequent removal of the associated'co'nt'ol rod drive (CRD) if desired, provided the following requirements are met:

a. All other control rods are fully inserted:'

b. 1. LCO 3.9.2."Refuel Position One-Rod-Out Interlock,"

and LCO 3.9.4'.' "Control Rod Position Indication."

OR

2. A control rod withdrawal block is inserted; and

c. 1. LCO 3.3.1:.1, "Reactor Protection System (RPS)

Instrumentation," MODE 5 requirements for Functions l.a. 1.b. 7.a. 7.b, 10, and 11 of Table 3.3.1.1-1, LCO 3.3.8.2, "Reactor Protection System (RPS)

Electric Power Monitoring." MODE 5 requirements, and LCO 3.9.5. "Control Rod OPERABILITY- Refueling,"

OR

2. All other control rods in a five by five array centered on the control rod being withdrawn are disarmed, at which time LCO 3.1.1. "SHUTDOWN MARGIN (SDM)." MODE 5 requirements may be changed to allow the single control rod withdrawn to be assumed to be the highest worth control rod.

APPLICABILITY: MODE 4 with the reactor-mode switch in the refuel position.

Columbia Generating Station 3.10.4 -1 Amendment No. 449 1691

Single Control Rod Withdrawal-Cold Shutdown 3.10.4 ACTIONS

'<2

NOTE-------------------------------------

Separate Condition entry is allowed for each requirement of the LCO.

CONDITION I REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 -------- NOTES--------

above requirements not 1. Required Actions met with the affected to fully insert control rod all insertable insertable. control rods include placing the reactor mode switch in the shutdown position.

2. Only applicable if the requirement not met is a required LCO.

Enter the applicable Immediately Condition of the affected LCO.

OR A.2.1 Initiate action to Immediately fully insert all insertable control rods.

AND A.2.2 Place the reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months mode switch in the shutdown position.

(continued)

K>

Columbia Generating Station 3.

. 10.4- 2 Amendment No. +4-9 1691

Single Control Rod Withdrawal - Cold Shutdown 3.10.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. One or more of the B.1 Suspend withdrawal of Immediately above requirements not the control rod and met with the affected removal of associated control rod not CRD.

insertable.

AND B.2.1 Initiate action to Immediately fully insert all control rods.

OR B.2.2 Initiate action to Immediately satisfy the requirements of this LCO.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.4.1 Perform the applicable SRs for the required According to LCOs. applicable SRs SR 3.10.4.2 ------------------- NOTE--------------------

Not required to be met if SR 3.10.4.1 is satisfied for LCO 3.10.4.c.1 requirements.

Verify all control rods, other than the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months control rod being withdrawn, in a five by five array centered on the control rod being withdrawn, are disarmed.

(continued)

Columbia Generating Station 3.10.4 -3 Amendment No. A4-41691!

Single Control Rod Withdrawal- Cold Shutdown 3.10.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY K>

SR 3.10.4.3 Verify all control rods, other than the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months control rod being withdrawn. are fully inserted.

SR 3.10.4.4 ------------------- NOTE--------------------

Not required to be met if SR 3.10.4.1 is satisfied for LCO 3.10.4.b.1 requirements.

Verify a control rod withdrawal block is 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months inserted.

Columbia Generating Station 3.10.4 -4 Amendment No. +49 1691

Single CRD Removal- Refueling 3.10.5 3.10 SPECIAL OPERATIONS 3.10.5 Single Control Rod Drive (CRD) Removal -Refueling--

LCO 3.10.5 The requirements of LCO 3.3.1.1. 'Reactor Protection System (RPS) Instrumentation"i LCO 3.3.8.2. "Reactor Protection System (RPS) Electric' Power Monitoring"; LCO 3.9.1.

"Refueling Equipment Interlocks": LCO 3.9.2, "Refuel Position One-Rod-Out Interlock': LCO 3.9.4. "Control Rod Position Indication"; and LCO 3.9.5. "Control Rod OPERABILITY-Refueling." may be suspended in MODE 5 to allow the removal of a single'CRD associated with a control rod withdrawn from a core'cell containing one or more fuel assemblies, provided the following requirements are met:

a. All other control rods are fully inserted;

b. All other control rods in a five by five array centered on the withdrawn control rod are disarmed;

c. A control rod withdrawal block is inserted, and LCO 3.1.1. "SHUTDOWN MARGIN (SDM)." MODE 5 requirements may be changed to allow the single control rod withdrawn to be assumed to be the highest worth control rod; and

d. No other CORE ALTERATIONS are in progress.

APPLICABILITY: MODE 5 with LCO 3.9.5 not met.

ACTIONS ' -

CONDITION REOUIRED ACTION COMPLETION TIME A. One or more of the A.1 Suspend removal of 'Immediately above requirements not the CRD mechanism.

met.' ' '

AND (continued)

Columbia Generating Station 3.10.5-1 Amendment No. 4-49 1691

Single CRD Removal - Refueling 3.10.5 ACTIONS CONDITION REQUIRED ACTION - COMPLETION TIME .>

A. (continued) A.2.1 Initiate action to Immediately fully insert all control rods.

OR A.2.2 Initiate action to Immediately satisfy the requirements of this LCO.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY.

SR 3.10.5.1 Verify all controls rods, other than the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months control rod withdrawn for the removal of the associated CR0. are fully inserted.

SR 3.10.5.2 Verify all control rods, other than the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months control rod withdrawn for the removal of the associated CRD, in a five by five array centered on the control rod withdrawn for the removal of the associated CR0. are disarmed.

SR 3.10.5.3 Verify a control rod withdrawal block is 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months inserted.

(continued)

Columbia Generating Station 3.10.5- 2 Amendment No. +4g 1691

Single CRD Removal- Refueling 3.10.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.5.4 Perform SR 3.1.1.1. According to SR 3.1.1.1 SR 3.10.5.5 Verify no other CORE ALTERATIONS are in 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months progress.

Columbia Generating Station 3.10.5 -3 Amendment No. 444 1691

Multiple Control Rod Withdrawal -Refueling 3.10.6 3.10 SPECIAL OPERATIONS 3.10.6 Multiple Control Rod Withdrawal - Refueling LCO 3.10.6 The requirements of LCO 3.9.3. "Control Rod Position':

LCO 3.9.4, "Control Rod Position Indication"; and LCO 3.9.5.

"Control Rod OPERABILITY -Refueling," may be suspended, and the "full-in" position indicators may be bypassed for any number of control rods in MODE 5. to allow withdrawal of these control rods, removal of associated control rod drives (CRDs). or both, provided the following requirements are met:

a. The four fuel assemblies are removed from the core cells associated with each control rod or CRD to be removed;

b. All other control rods in core cells containing one or more fuel assemblies are fully inserted; and

c. Fuel assemblies shall only be loaded in compliance with an approved spiral reload sequence.

APPLICABILITY: MODE 5 with LCO 3.9.3. LCO 3.9.4. or LCO 3.9.5 not met.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 Suspend withdrawal -of Immediately above requirements not control rods and met. removal of associated CRDs.

AND A.2 Suspend loading fuel Immediately assemblies.

AND (continued)

Columbia Generating Station 3.10.6-1 Amendment No. +449 1691

Multiple Control Rod Withdrawal -Refueling 3.10.6 ACTIONS CONDITION REQUIRED ACTION -- COMPLETION TIME A. (continued) A.3.1 Initiate action to Immediately fully insert all control rods in core cells containing one or more fuel assemblies.

OR A.3.2 Initiate action to Immedi~ately satisfy the requirements of this LCO.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY.

SR 3.10.6.1 Verify the four fuel assemblies are removed 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months from core cells associated with each control rod or CR0 removed.

SR 3.10.6.2 Verify all other control rods in core cells 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months containing one or more fuel assemblies are fully inserted.

SR 3.10.6.3 ------------------- NOTE--------------------

Only required to be met during fuel loading.

Verify fuel assemblies being loaded are in 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months compliance with an approved spiral reload sequence.

Columbia Generating Station 3.10.6-2 Amendment No. +4g 1691

Control Rod Testing-Operating 3.10.7 3.10 SPECIAL OPERATIONS 3.10.7 Control Rod Testing -Operating LCO 3.10.7 The requirements of LCO 3.1.6, 'Rod Pattern Control." may be suspended to allow performance of SDM demonstrations.

control rod scram time-testing. and control rod friction testing provided:

a. The banked position withdrawal sequence requirements of SR 3.3.2.1.8 are changed to require the control rod sequence to conform to the specified test sequence.

OR

b. The RWM is bypassed; the requirements of LCO 3.3.2.1, "Control Rod Block-Instrumentation," Function 2 are suspended; and conformance to the approved control rod sequence for the specified test is-verified by a second licensed operator or other qualified member of the technical staff.

APPLICABILITY: MODES 1 and 2 with LCO -3.1.6 not met.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the A.1 Suspend performance Immediately LCO not met. of the test and exception to LCO 3.1.6.

Columbia Generating Station 3.10.7- 1 Amendment No. 449 1691

Control Rod Testing- Operating 3.10.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.7.1 ------------------- NOTE--------------------

Not required to be met if SR 3.10.7.2 satisfied.

Verify movement of control rods is in During control compliance with the approved control rod rod movement sequence for the specified test by a second licensed operator or other qualified member of the technical staff.

SR 3.10.7.2 ------------------- NOTE--------------------

Not required to be met if SR 3.10.7.1 satisfied.

Verify control rod sequence input to the Prior to RWM is in conformance with the approved control rod control rod sequence for the specified movement test.

K>

Columbia Generating Station 3.10.7- 2 Amendment No. +44 1691

SDM Test - Refueling 3.10.8 3.10 SPECIAL OPERATIONS 3.10.8 SHHUTDOWN MARGIN (SDM) Test- Refueling LCO 3.10.8 The reactor mode switch position specified in Table 1.1-1 for MODE 5 may be changed to include the startup/hot standby position, and operation-considered not to b*e'in MODE 2. to allow SDM testing, provided the following requirements are met:

a. LCO 3.3.1.1, "Reactor Protection System Instrumentation." MODE-2 requirements for Function 2.a and 2.d of Table 3.3.1.1-1:

b. 1. LCO 3.3.2.1. "Control Rod Block Instrumentation."

MODE 2 requirements for, Function 2 of Table 3.3.2.1-1. with banked position withdrawal sequence requirements of SR 3.3.2.1.8 changed to require the control rod sequence to conform to the SDM test sequence, OR

2. Conformance to the approved control rod sequence for the SDM test-is verified by a second licensed operator or other qualified member of the technical staff;

c. Each withdrawn-control rod shall be coupled to the' associated control rod drive (CRD);

d. All control rod withdrawals during out of sequence control rod moves shall be made in notch out mode;

e. No other CORE ALTERATIONS are in progress: and

f. CRD charging water header pressure 2 940 psig.

APPLICABILITY: MODE 5 with the reactor mode switch in startup/hot standby position.

Columbia Generating Station 3.10.8-1 Amendment No. +49 1691

SDM Test- Refueling 3.10.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME NOTE------------

------------ NOTE-------------

Separate Condition entry Rod worth minimizer may be is allowed for each bypassed as allowed by LCO control rod. 3.3.2.1. 'Control Rod Block

.... Instrumentation," if required, to allow insertion A. One or more control of inoperable control rod and rods not coupled to continued operation.

its associated CRD. .......------.....

A.1 Fully insert 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months inoperable control rod.

AND A.2 Disarm the associated 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months CRD.

B. One or more of the B.1 Place the reactor Immediately above requirements not mode switch in the met for reasons other shutdown or refuel than Condition A. position.

Columbia Generating Station 3.10. 8-2 Amendment No. +4g41691

SDM Test- Refueling 3.10.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREOUENCY SR 3.10.8.1 Perform the MODE 2 applicable SRs for According to LCO 3.3.1.1. Functions 2.a and 2.d of the applicable Table 3.3.1.1-1. SRs SR 3.10.8.2 ------ NOTE--------------------

Not required to be met if SR 3.10.8.3 satisfied.

Perform the MODE 2 applicable SRs for According to LCO 3.3.2.1, Function 2 of Table 3.3.2.1-1. the applicable SRs SR 3.10.-8.3 -------------------NOTE-------------------

Not required to be met if SR 3.10.8.2 satisfied.

Verify movement of control rods is in During control compliance with the approved control-rod rod movement sequence for the SDM test by a second licensed operator or other qualified member of the technical staff.

SR 3.10.8.4 Verify no other CORE ALTERATIONS are in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months progress.

(continued)

Columbia Generating Station 3.10.8-3 Amendment-No. 4-49 1691

SDM Test- Refueling 3.10.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.8.5 Verify each withdrawn control rod does not Each time the go to the withdrawn overtravel position. control rod is withdrawn to "full out" position AND Prior to satisfying LCO 3.10.8.c requirement after work on control rod or CRD System that could affect coupling SR 3.10.8.6 Verify CRD charging water header pressure 7 days

> 940 psig.

Columbia Generating Station 3.10.8,-4 Amendment No. 4-49 1691

Design Features 4.0 4.0 DESIGN FEATURES 4.1 Site Location 4.1.1 Site and Exclusion Area Boundaries The site area shall include the area enclosed by the exclusion area plus the plant property lines that fall-outside the exclusion area, as shown in Figure 4.1-1. The exclusion area boundary is a circle with its center at the reactor and a radius of 1950 meters.

4.1.2 Low Population Zone The low population zone is all the land within a circle with its center at the reactor and a radius of 4827 meters.

4.2 Reactor Core 4.2-.1 Fuel Assemblies The reactor shall contain 764 fuel assemblies. Each assembly shall consist of a matrix of Zircaloy clad fuel rods with an initial composition of depleted, natural, or slightly enriched uranium dioxide`(UD,) as fuel material and water rods or channels.

Limited substitutions of zirconium alloy or stainless steel filler rods for fuel rods, in accordance with approved applications of fuel rod configurations. may be used. Fuel assemblies shall be limited to those fuel designs that have been analyzed with applicable NRC staff approved codes and methods and shown by tests or analyses to comply with all safety-design bases. A limited number of lead fuel assemblies that have not completed representative testing'may be placed in nonlimiting core regions.

4.2.2 Control Rod Assemblies The reactor core shall contain 185 cruciform shaped control rod assemblies. The control material shall be boron carbide and hafnium metal as approved by the NRC.

(continued)

Columbia Generating Station 4 .0-1 Amendment No. '49.169,185

Ili Design Features 4.0 4.0 DESIGN FEATURES (continued) \J) 4.3 Fuel Storage 4.3.1 Criticality 4.3.1.1 The spent fuel storage racks are designed and shall be maintained with:

a. kenf<*0.95 if fully flooded with unborated water, which includes an allowance for uncertainties as described in Section 9.1.2 of the FSAR: and

b. A nominal 6.5 inch center to center distance between fuel assemblies placed in the storage racks.

4.3.1.2 The new fuel storage racks are designed and, with fuel assemblies inserted, shall be maintained with:

a. keff < 0.95 if fully flooded with unborated water, which includes an allowance for uncertainties as described in Section 9.1.1 of the FSAR; and

b. A maximum of 60 new fuel assemblies stored in the new fuel storage racks, arranged in 6 spatially separated zones. Within a storage zone, the nominal center-to-center distance between cells for storing fuel assemblies is 14 inches. The nominal center-to-center distance between cells for storing fuel assemblies in adjacent zones is 37 inches. Design features relied upon to spatially limit the placement of fuel bundles within the new fuel vault are required to be installed prior to placement of new fuel bundles in the vault.

4.3.2 Drainage The spent fuel-storage pool is designed and shall be maintained to prevent inadvertent draining of the pool below elevation 583 ft 1.25 inches.

4.3.3 Capacitv The spent fuel storage pool is designed and shall be maintained with a storage capacity limited to no more.than 2658 fuel

-assemblies.

. K)

Columbia Generating Station 4.0-2 Amendment No. j49.j63 1691

Design Features 4.0 Figure 4.1-1 Site Area Boundary Columbia Generatiung Station 4 4.0-3 Amendment No. +4-9 1691

Responsibility 5.1 5.0 ADMINISTRATIVE CONTROLS 5.1 Responsibility 5.1.1 The Plant General Manager shall be responsible for overall unit operation and shall delegate in writing the succession to this responsibility during his absence.

The Plant General Manager or his designee shall approve, prior to implementation, each proposed test, experiment, and modification to systems or equipment that affect nuclear safety.

5.1.2 The Shift Manager (SM) shall be responsible for the control room command function. During any absence of the SM from the control room while the unit is in MODE 1, 2. or 3, an individual with an active Senior Reactor Operator (SRO) license shall be designated to assume the control room command function. During any absence of the SM from the control room while the unit is in MODE 4 or 5.

an individual with an active SRO license or Reactor Operator license shall be designated to assume the control room command function.

Columbia Generating Station 5.1-1 Amendment No. 449 1691

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

a. Lines of authority, responsibility, and communication shall be defined and established throughout highest management levels. intermediate levels 'and all operating organization positions. -These relationships shall be documented and updated,- as appropriate. in organization charts, functional

'descriptions of departmental responsibilities and relationships, and job descriptions for key personnel positions. or in equivalent forms of do'cumentation. These requirements shall be documented in the FSAR.

b. The Plant General Manager shall be responsible for overall safe operation of the plant and shall have control over those onsite activities necessary.for safe operation and maintenance of the plant.-

c. The Chief Executive Officer shall have corporate -

responsibility for overall plant nuclear safety and shall take any measures needed-to ensure acceptable performance of the staff in operating, maintaining, and providing technical

- support to the plant'to ensure nuclear safety.

d. The individuals who train the operating staff, carry out health physics, or perform quality'assurance functions may report to the appropriate onsite manager; however, these individuals shall have sufficient organizational freedom to ensure their independence'from operating pressures.

5.2.2 Un'it Staff The unit staff organization shall include the following:

a. At least two Equipment Operators shall be assigned when the unit is in MODE 1. 2.or 3; and at least one Equipment Operator shall be assigned when the unit is in MODE 4 or 5.

(continued)

Columbia Generating Station .. 5.2-1 -Amendment,.No. 44.9 1691

Organization 5.2 5.2 Organization 5.2.2 Unit Staff (continued)

b. Shift crew composition may be less than the mlnlmum requirement of 10 CFR 50.54(m)(2)(i) and 5.2.2.a and 5.2.2.f for a period6f time not to exceed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months in order to accommodate unexpected absence of on-duty shift crew members provided immediate action is taken to restore the shift crew composition to within the minimum requirements.

c. An individual qualified to implement radiation protection procedures shall be on site when fuel is in the reactor.

The position may be vacant for not more than 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months . in order to provide for unexpected absence. provided immediate action is taken to fill the required position.

d. Deleted.

e. The Operations Manager or Assistant Operations Manager shall hold an SRO license.

f. An individual shall provide advisory technical support to the unit operations shift crew in the areas of thermal hydra~lics. reactor engineering, and plant analysis with regard to the safe operation of the unit. This individual shall meet the qualifications specified by the Commission Policy Statement on Engineering Expertise on Shift.

Columbia Generating Station 5.2-2 Amendment No. 149,169.182 213

Unit Staff Oualifications 5.3 5.0 ADMINISTRATIVE CONTROLS V 5.3 Unit Staff Oualifications 11

. . I . . I -1 5.3.1 Each member of the unit staff shall meet or exceed the minimum qualifications of ANSI/ANS N18.1-1971, for comparable positions described in the FSAR, except for:

a. The Operations Manager, who shall meet the requirements of ANSI/ANS N18.1-1971 with the exception that in lieu of meeting the stated ANSI/ANS requirement to hold a Senior Reactor Operator (SRO) license at the time of appointment to the position, the Operations Manager shall:

1. Hold an SRO license at the time of appointment;

2. Have held an SRO license; or

3. Have been certified for equivalent SRO knowledge; and

b. The Radiation Protection Manager, who shall meet or exceed the qualifications of Regulatory Guide 1.8, Revision 1-R.

May 1977.

5.3.2 For the purpose of 10 CFR 55.4. a licensed Senior Reactor Operator (SRO) and a licensed Reactor Operator (RO) are those individuals who, in addition to meeting the requirements of TS 5.3.1. perform the functions described in 10 CFR 50.54(m).

Columbia Generating Station 5.3-1 Amendment No. 1491E.9,182

(?swap b Xe, &6a-q-a2

Procedures 5.4 5.0 ADMINISTRATIVE CONTROLS 5.4 Procedures 5.4.1 Written procedures shall be established, implemented, and maintained covering the following activities:

a. The applicable procedures recommended in Regulatory Guide 1.33, Revision 2. Appendix A, February 1978;

b. The emergency operating procedures required to implement the requirements of NUREG-0737 and NUREG-0737. Supplement 1. as stated in Generic Letter 82-33;

c. Quality assurance program for radioactive effluent and radiological environmental monitoring:

d. Fire Protection Program implementation; and

e. All programs specified in Specification 5.5.

Columbia Generating Station 5.4-1 Amendment No. 449 1691

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

5.5.1 Offsite Dose Calculation Manual (ODCM)

a. The ODCM shall contain the methodology and parameters used in the calculation-of-offsite doses resulting from radioactive gaseous and liquid effluents, in the calculation of gaseous and liquid effluent monitoring alarm and trip setpoints, and in the conduct of the radiological environmental monitoring program; and

b. The ODCM shall also contain the radioactive effluent controls and radiological environmental monitoring activities, and descriptions of the information that should be included in the Annual Radiological Environmental Operating and Radioactive Effluent Release reports required by Specification 5.6.1 and Specification 5.6.2.

c. Licensee initiated changes to the ODCM:

1. Shall be documented and records of reviews performed shall be retained. This documentation shall contain:

(a) Sufficient information to support the change(s) together with the appropriate analyses or evaluations justifying the change(s), and (b) A determination that the change(s) maintain the levels of radioactive effluent control required pursuant to 10 CFR 20.1302, 40 CFR 190, 10 CFR 50.36a, and 10 CFR 50, Appendix I, and do not adversely impact the accuracy or reliability of effluent, dose, or setpoint calculations;

2. Shall become effective after review and acceptance by the Plant Operations Committee and the approval of the Plant General Manager; and (continued)

Columbia Generating Station 5.5-1 Amendment No. 149,169, 190

Manuals Programs and Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1 Offsite Dose Calculation Manual (ODCM) (continued)

3. Shall be submitted to the NRC in the form of a complete, legible copy of the entire ODCM as a part of, or concurrent with, the Radioactive Effluent Release Report for the period of the report in which any change in the ODCM was made. Each change shall be identified by markings in the margin of the affected pages, clearly indicating the area of the page that was changed, and shall indicate the date (i.e., month and year) the change was implemented.

5.5.2 Primary Coolant Sources Outside Containment This program provides controls to minimize leakage from those portions of systems outside containment that could contain highly radioactive fluids during a serious transient or accident to levels as low as practicable. The systems include the Low Pressure Core Spray, High Pressure Core Spray, Residual Heat Removal, Reactor Core Isolation Cooling, process sampling, (the program requirements shall apply to the Post Accident Sampling System until such time as administrative controls provide for continuous isolation of the associated penetration(s) or a modification eliminates the potential leakage path(s)),

containment monitoring, and Standby Gas Treatment. The program shall include the following:

a. Preventive maintenance and periodic visual inspection requirements; and

b. Integrated leak test requirements for each system at 24 month intervals or less.

The provisions of SR 3.0.2 are applicable to the 24 month Frequency for performing integrated system leak test activities.

5.5.3 Deleted (continued)

Columbia Generating Station 5.5-2 Amendment No. 149,1-9,18-8 189

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.4 Radioactive Effluent Controls Program This program, conforming to 10 CFR 50.36a. provides for the control of radioactive effluents and for maintaining the doses to members of the public from radioactive effluents as low as reasonably achievable. The program shall be contained in the ODCM, shall be implemented by procedures, and shall include remedial actions to be taken whenever the program limits are exceeded. The program shall include the following elements:

a. Limitations on the functional capability of radioactive liquid and gaseous monitoring instrumentation including surveillance tests and setpoint determination in accordance with the methodology in the 0DCM;

b. Limitations on the concentrations of radioactive material released in liquid effluents to unrestricted areas.

conforming to 10 times the concentration values in Appendix B, Table 2, Column 2 to 10 CFR 20.1001 - 20.2402;

c. Monitoring, sampling, and analysis of radioactive liquid and gaseous effluents pursuant to 10 CFR 20.1302 and with the methodology and parameters in the ODCM;

d. Limitations on the annual and quarterly doses or dose commitment to a member of the public from radioactive materials in liquid effluents released from each unit to unrestricted areas, conforming to 10 CFR 50, Appendix I;

e. Determination of cumulative and projected dose contributions from radioactive effluents for the current calendar quarter and current calendar year in accordance with the methodology and parameters in the ODCM at least every 31 days; (continued)

Columbia Generating Station 5.5-3 Amendment No. 149.19,182 184

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

f. Limitations on the functional capability and use of the liquid and gaseous effluent treatment systems to ensure that appropriate portions of these systems are used to reduce releases of radioactivity when the projected doses in a period of 31 days would exceed 2% of the guidelines for the annual dose or dose commitment, conforming to 10 CFR 50, Appendix I;

g. Limitations on the dose rate resulting from radioactive material released in gaseous effluents from the site to areas at or beyond the site boundary shall be limited to the following:

1. For noble gases: less than or equal to a dose rate of 500 mrems/yr to the whole body and less than or equal to a dose rate of 3000 mrems/yr to the skin, and

2. For iodine-131. iodine-133, tritium, and for all radionuclides in particulate form with half lives

> 8 days: less than or equal to a dose rate of 1500 mrems/yr to any organ:

h. Limitations on the annual and quarterly air doses resulting from noble gases released in gaseous effluents from each unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I;

i. Limitations on the annual and quarterly doses to a member of the public from iodine-131..iodine-133, tritium, and all radionuclides in particulate form with half lives > 8 days in gaseous effluents released from each unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I; J. Limitations on the annual dose or dose commitment to any member of the public, beyond the site boundary, due to releases of radioactivity and to radiation from uranium fuel cycle sources, conforming to 40 CFR 190; and

k. Limitations on venting and purging of the primary containment through the Standby Gas Treatment System to maintain releases as low as reasonably achievable.

(continued)

Columbia Generating Station 5.5-4 Amendment No. 149,169 182

205 205 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 Ventilation Filter Testing Program (VFTP) (continued)

ESF Ventilation System Flowrate (cfm)

SGT System 4320 to 5280 CREF System 900 to 1100

b. Demonstrate for each of the ESF systems that an inplace test of the charcoal adsorber shows a penetration and system bypass < 0.05% when tested in accordance with Regulatory Guide 1.52, Revision 2, and ASME N510-1989 at the system flowrate specified below:

ESF Ventilation System Flowrate (cfm)

SGT System CREF System 4320 to 5280 900 to 1100 I

c. Demonstrate for each of the ESF systems that a laboratory test of a sample of the charcoal adsorber, when obtained as described in Regulatory Guide 1.52, Revision 2, shows the methyl iodide penetration less than the value specified below when tested in accordance with ASTM D3803-1989 at a temperature of 30 0 C (86 0 F) and the relative humidity specified below. Testing of the SGT System will also be conducted at a face velocity of 75 feet per minute.

ESF Ventilation System Penetration (M) RH (M)

SGT System 0.5 70 CREF System 2.5 70 Allowed tolerances in the above testing parameters of temperature, relative humidity, and face velocity are as specified in ASTM D3803-1989.

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

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

SGT System CREF System

<8

<6 4320 to 5280 900 to 1100 I

(continued)

Columbia Generating Station 5.5-7 Amendment No. 149,169,18t2 199

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

e. Demonstrate that the heaters for each of the ESF systems dissipate the nominal value specified below when tested in accordance with ASME N510-1989:

ESF Ventilation System Wattage (kW)

SGT System 18.6 to 22.8 CREF System 4.5 to 5.5 5.5.8 ExDlosive Gas and Storage Tank Radioactivity Monitoring Program This program provides controls for potentially explosive gas mixtures contained in the Main Condenser Offgas Treatment System and the quantity of radioactivity contained in unprotected outdoor liquid storage tanks.

The program shall include:

a. The limits for concentrations of hydrogen in the Main Condenser Offgas Treatment System and a surveillance program to ensure the limits are maintained. Such limits shall be appropriate to the system's design criteria (i.e.. whether or not the system is designed to withstand a hydrogen explosion): and

b. A surveillance program to ensure that the quantity of radioactivity contained in all outside temporary liquid radwaste tanks that are not surrounded by liners, dikes, or walls, capable of holding the tanks' contents and that do not have tank overflows and surrounding area drains connected to the Liquid Radwaste Treatment System is less than the amount that would result in'concentrations greater than the limits of Appendix B. Table 2. Column 2 to 10 CFR 20.1001- 20.2402. at the nearest potable water supply and the nearest surface water supply in an unrestricted area, in the'event of an uncontrolled release of the tanks' contents.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Explosive Gas and Storage Tank Radioactivity Monitoring Program Surveillance Frequencies.

(continued) kuzulullJIg GnanrAtinq Colu~mbia ucss, Sztation SlU8y SsSgu} 5.5A-A J.;7-1 Amendm-nt KN-r'II~IuII~III. I1 iz 7Zr7 Re% im-1.LU1

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.9 Diesel Fuel Oil Testing Program A di esel fuel oil testing program shall establ ish the requi red testing of both new fuel oil and stored fuel oil. The program shall include sampling and testing requirements. and acceptance criteria. all in accordance with applicable ASTM Standards. The purp~se of the program is to establish the following:

a. Acceptability of new fuel.oil for use prior to addition to storage tanks by determi ni ng that the fuel oi 1 has:

1. An API gravity, a specific gravity, or an absolute specific gravity within limits.

2. A kinematic viscosity, if gravity was not determined by comparison with the supplier's certificate, and a flash point within limits for ASTM 2-D fuel oil.

3.* A water and sediment content within limits or a clear and bright appearance with proper color;

b. Other properties for ASTM 2-D fuel oil are within limits within 31 days following sampling and addition to storage tanks; and

c. Total particulate concentration of the fuel oil in the storage tanks is ~ 10 mg/l when tested every 31 days.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Diesel Fuel Oil Testing Program test Frequencies.

5.5.10 Technical Specifications (TS) Bases Control Program This program provides a means for processing changes to the Bases to these Technical Specifications.

a. Changes to the Bases of the TS shall be made under appropriate administrative controls and reviews.

(continued)

Columbia Generating Station 5.5-9 Amendment No. 149,169 215

Programs and Manuals Programs and Manuals- .

5.5 5.5 Programs and Manuals 5.5.10 Technical SDecifications (TS) Bases Control Program (continued)

b. Licensees may make changes to Bases without prior NRC approval provided the changes do not require either of the following:

1. A change in the TS incorporated in the license; or

2. A change to the updated FSAR or Bases that requires NRC approval pursuant to 10 CFR 50.59.

c. The Bases Control Program shall contain provisions to ensure that the Bases are maintained consistent with the FSAR.

d. Proposed changes that meet the criteria of 5.5.10.b above shall be reviewed and approved by the NRC prior to implementation. Changes to the Bases implemented without prior NRC approval shall be provided to the NRC on a frequency consistent with 10 CFR 50.71(e).

5.5.11 Safety Function Determination Program (SFDP)

This program ensures loss of safety function is detected and appropriate actions taken; Upon entry into LCO 3.0.6. an evaluation shall be made to determine if loss of safety function exists. Additionally, other appropriate limitations and remedial or compensatory actions may be identified to be taken as a result of the support system inoperability and corresponding exception to entering supported system Condition and Required Actions. This program implements the requirements of LCO 3.0.6.

a. The SFDP shall contain the following:

1. Provisions for cross division checks to ensure a loss of the capability to perform the safety function assumed in the accident analysis does not go undetected;

2. Provisions for ensuring the plant is maintained in a safe condition if a loss of function condition exists; (continued)

Columbia Generating Station 5.5-10 Amendment No. 149-6-9,177 AUG 15 2M2

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.11 Safety Function Determination Program (SFOP) (continued)

3. Provisions to ensure that an inoperable supported system's Completion Time is not inappropriately extended as a-result of multiple support system inoperabilities; and

4. Other appropriate limitations and remedial or compensatory actions.

b. A loss of safety function exists when, assuming no concurrent single failure, a safety function assumed in the accident analysis cannot be performed. For the purpose of this program, a loss of safety function may exist when a support system is inoperable, and:

1. A required system redundant to system(s) supported by the inoperable support system is also inoperable; or

2. A required system redundant to system(s) in turn supported by the inoperable supported system is also inoperable; or

3. A required system redundant to support system(s) for the supported systems described in b.1 and b.2 above is also inoperable.

c. The SFDP identifies where a loss of safety function exists.

If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered.

5.5.12 Primary Containment Leakage Rate Testing Program The Primary Containment Leakage Rate Testing Program shall establish the leakage rate testing of the containment as required by 10 CFR 50.54(o) and 10 CFR 50. Appendix J. Option B. as modified by approved exemptions. This program shall be in accordance with the guidelines contained in Regulatory Guide 1.163, wPerformance-Based Containment Leak-Test Program," dated -

September 1995, as modified by the following exceptions: The next Type A test performed after the July 20, 1994, Type A test (continued)

Columbia Generating Station 5.5-11 Amendment No. !49.169, 191

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.12 Primary Containment Leakage Rate Testing Program (continued) shall be performed no later than July 20, 2009, and compensation for flow meter inaccuracies in excess of those specified in ANSI/ANS 56.8-1994 will be accomplished by increasing the actual instrument reading by the amount of the. full scale inaccuracy when assessing the effect of local leak rates against the criteria established in Specification 5.5.12.a.

The peak calculated primary containment internal pressure for the design basis loss of coolant accident, Pa, is 38 psig.

The maximum allowable primary containment leakage rate, La, at Pa, shall be 0.5% of primary containment air weight per day.

Leakage rate acceptance criteria are:

a. Primary containment leakage rate acceptance criterion is

< 1.0 La. During the first unit startup following testing in accordance with this program, the leakage rate acceptance criteria are < 0.60 La for the Type B and Type C tests (except for main steam isolation valves) and < 0.75 La for Type A tests;

b. Primary containment air lock testing acceptance criteria are:

1) Overall primary containment air lock leakage rate is

< 0.05 La when tested at > Pa; and

2) For each door, leakage rate is < 0.025 La when pressurized to > 10 psig.

The provisions of SR 3.0.3 are applicable to the Primary Containment Leakage Rate Testing Program.

5.5.13 Battery Monitoring and Maintenance Program This Program, provides for restoration and maintenance, which includes the following:

a. Actions to restore battery cells with float voltage < 2.13 V; and (continued)

Col-umbia Generating Station 5.5-12 Amendment No. 149,169A,,*91-9 204

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.13 Battery Monitoring and Maintenance Program (continued)

b. Actions to equalize and test battery cells that had been discovered with electrolyt~ level below the top of the plates; and

c. Actions to verify that the remalnlng cells are> 2.07 V when a cell or cells have been found to be < 2.13 V.

5.5.14 Control Room Envelope Habitability Program A Control Room Envelope (CRE) Habitability Program shall be established and implemented to ensure that CRE habitability is maintained such that, with an OPERABLE Control Room Emergency Filtration (CREF) System, CRE occupants can control the reactor safely under normal conditions and maintain it in a safe condition following a radiological event, hazardous chemical release, or a smoke challenge. The program shall ensure that adequate radiation protection is provided to permit access and occupancy of the CRE under design basis accident (DBA) conditions without personnel receiving radiation exposures in excess of 5 rem total effective dose equivalent (TEDE) for the duration of the accident. The program shall include the following elements:

a. ,The definition of the CRE and the CRE boundary.

b. Requirements for maintaining the CRE boundary in its design conditi,on including configuration control and preventive maintenance.

c. Requirements for (i) determining the unfiltered air inleakage past the CRE boundary into the CRE in accordance with the testing methods and at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197.

"Demonstrating Control Room Envelope Integrity at Nuclear Power Reactors," Revision 0, May 2003, and (ii) assessing CRE habitability at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, Revision O.

(continued)

Columbia Generating Station 5.5-13 Amendment No. 204,287 216

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.14 Control Room Envelope H bitability Program (continued)

d. Measurement, at designated locations, of the CRE pressure relative to all external areas adjacent to the CRE boundary during the pressurization mode of operation by one subsystem of the CREF System, operating at the flow rate required by.

the VFTP, at a Frequency of 24 months on a STAGGERED TEST BASIS. The result:3 shall be trended and used as part of the 24 month assessment of the CRE boundary.

e. The quantitative limits on unfiltered air inleakage into the CRE. These limits shall be stated in a manner to allow direct comparison To the unfiltered air inleakage measured by the testing described in paragraph c. The unfiltered air inleakage limit for radiological challenges is the' inleakage flow rate assumed -in the licensing basis analyses for DBA consequences. Unfltered air inleakage limits for hazardous chemicals must ensure that exposure of CRE occupants to these hazards will be within the assumptions in the licensing basis.

f. The provisions of SR 3.0.2 are applicable to the Frequencies for assessing CRE htabitability, determining CRE unfiltered inleakage, and meaEuring CRE pressure and assessing the CRE boundary as required by paragraphs c and d, respectively.

Columbid Generdting Station E.5-14 Amendment No. 207

Reporting Requirements 5.6 5.0 ADMINISTRATIVE CONTROLS 5.6 Reporting Requirements The following reports shall be submitted-in accordance with 10 CFR 50.4.

5.6.1 Annual Radiological Environmental Operating Report The Annual Radiological Environmental Operating Report covering the operation of the unit during the previous calendar year shall be submitted by May 15 of each year. The report shall include summaries, interpretations, and analyses of trends of the results of the Radiological Environmental Monitoring Program for the reporting period. The material provided shall be consistent with the objectives outlined in the Offsite Dose Calculation Manual (ODCM), and in 10 CFR 50. Appendix I. Sections IV.B.2, IV.B.3, and IV.C.

The Annual Radiological Environmental Operating Report shall include the results of analyses of all radiological environmental samples and of all environmental radiation measurements taken during the period pursuant to the locations specified in the table and figures in the ODCM, as well as summarized and tabulated results of these analyses and measurements in the format of the table in the Radiological Assessment Branch Technical Position, Revision 1, November 1979. In the event that some individual results are not available for inclusion with the report, the report shall be submitted-noting and explaining the reasons for the missing results. The missing data shall be submitted in a supplementary report as soon as possible.

5.6.2 Radioactive Effluent Release Report The Radioactive Effluent Release Report covering the operation of the unit shall be submitted in accordance with 10 CFR 50.36a. The report shall include a summary of the quantities of radioactive liquid and gaseous effluents and solid waste released from the unit. The material provided shall be consistent with the objectives outlined in the ODCM and the Process Control Program and in conformance with 10 CFR 50.36a and 10 CFR 50, Appendix I, Section IV.B.1.

(continued)

Columbia Generating Station 5.6- 1 Amendment No. 149.169 , 190

Reporting Requirements 5.6 5.6 Reporting Requirements (continued) 5.6.3 CORE OPERATING LIMITS REPORT (COLR)

a. Core operating limits shall be established prior to each reload cycle, or prior to any remaining portion of a reload cycle, and shall be documented in the COLR for the following:

1. The APLHGR for Specification 3.2.1;

2. The MCPR for Specification 3.2.2;

3. The LHGR for Specification 3.2.3; and

4. LCO 3.3.1.3, "Oscillation Power Range Monitor (OPRM)

Instrumentation."

b. The analytical methods used to determine the core operating limits shall be those previously reviewed and approved by the NRC, specifically those described in the following documents:

1. XN-NF-81-58(P)(A). "RODEX2 Fuel Rod Thermal-Mechanical Response Evaluation Model," Exxon Nuclear Company

2. XN-NF-85-67(P)(A). "Generic Mechanical Design for Exxon Nuclear Jet Pump BWR Reload Fuel." Exxon Nuclear Company

3. EMF-85-74(P) Supplement 1(P)(A) and Supplement 2(P)(A).

"RODEX2A (BWR) Fuel Rod Thermal-Mechanical Evaluation Model," Siemens Power Corporation

4. ANF-89-98(P)(A). "Generic Mechanical Design Criteria for BWR Fuel Designs," Advanced Nuclear Fuels Corporation

5. XN-NF-80-19(P)(A) Volume 1. "Exxon Nuclear Methodology for Boiling Water Reactors - Neutronic Methods for Design and Analysis," Exxon Nuclear Company (continued)

Columbia Generating Station 5.6-2 Amendment No. 149,1G9,171,132, 190

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.3 CORE OPERATING LIMITS REPORT (COLR) (continued)

-6. XN-NF-80-19(P)(A) Volume 4. "Exxon Nuclear Methodology for Boiling Water Reactors: Application of tHe ENC Methodology to BWR Reloads," Exxon Nuclear Company

7. EMF-2158(P)(A), "Siemens Power Corporation Methodology for Boiling Water Reactors: Evaluation and Validation of CASMO-4/MICROBURN-B2," Siemens Power Corporation

8. XN-NF-80-19(P)(A) Volume 3, "Exxon Nuclear Methodology for Boiling Water Reactors, THERMEX: Thermal Limits Methodology Summary Description," Exxon Nuclear Company

9. XN-NF-84-105(P)(A) Volume 1, "XCOBRA-T: A Computer Code for BWR Transient Thermal-Hydraulic Core Analysis,"

Exxon Nuclear Company

10. ANF-524(P)(A). "ANF Critical Power Methodology for Boiling Water Reactors," Advanced Nuclear Fuels Corporation

11. ANF-913(P)(A) Volume 1. "COTRANSA2: A Computer Program for Boiling Water Reactor Transient Analysis," Advanced Nuclear Fuels Corporation

12. ANF-1358(P)(A) "The Loss of Feedwater Heating Transient in Boiling Water Reactors." Advanced Nuclear Fuels Corporation 13: EMF-2209(P)(A). "SPCB Critical Power. Correlation,"

Siemens Power Corporation

14. EMF-2245(P)(A), "Application of Siemens Power Corporation's Critical Power Correlations to Co-Resident Fuel," Siemens Power Corporation

15. EMF-2361(P)(A), "EXEM BWR-2000 ECCS Evaluation Model,"

Framatome ANP Richland (continued)

Columbia Generating Station 5.6-3 Amendment No. 171,1&S, 190 O49n 4,58,r9n

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.3 CORE OPERATING LIMITS REPORT (COLR) (continued)

16. EMF-2292(P)(A), ATRIUM' -10: Appendix K Spray Heat Transfer Coefficients." Siemens Power Corporation

17. EMF-CC-074(P)(A) Volume 4, "BWR Stability Analysis Assessment of STAIF with Input from MICROBURN-B2."

Siemens Power Corporation

18. CENPD-300-P-A, "Reference Safety Report for Boiling Water Reactor Reload Fuel," ABB Combustion Engineering Nuclear Operations

19. NEDO-32465-A, "BWR Owners' Group Reactor Stability Detect and Suppress Solutions Licensing Basis Methodology and Reload Applications"

20. NEDC-33419P, "GEXL97 Correlation Applicable to ATRIUM 10 Fuel," Global Nuclear Fuel

21. NEDE-240ll-P-A and NEDE-24011-P-A-US, "General Electric Standard Application for Reactor Fuel (GESTAR II) and Supplement for United States," Global Nuclear Fuel

c. The core operating limits shall be determined such that all applicable limits (e.g., fuel thermal mechanical limits, core thermal hydraulic limits, Emergency Core Cooling Systems (ECCS) limits. nuclear limits such as SDM. transient analysis limits. and accident analysis limits) of the safety analysis are met.

d. The COLR, including any midcycle reV1Slons or supplements, shall be provided upon issuance for each reload cycle to the NRC.

5.6.4 Post Accident Monitoring (PAM) Instrumentation Report When a report is required by Condition B or F of LCO 3.3.3.1.

"Post Accident Monitoring (PAM) Instrumentation," a report shall be submitted within the following 14 days. The report shall outline the preplanned alternate method of monitoring. the cause of the inoperability, and the plans and schedule for restoring the instrumentation channels of the Function to OPERABLE status.

Columbia Generating Station 5.6-4 Amendment No. 211 149.154,169.185.190

-* ,High Radiation Area 5.7 5.0 ADMINISTRATIVE CONTROLS 5.7 High Radiation Area - --

As provided in paragraph 20.1601(c) of 10 CFR Part 20.'the following controls shall be applied to high radiation areas lin place of'the controls required by paragraph 20.1601(a) and (b) of 10 CFR Part 20.

5.7.1 High Radiation Areas with Dose Rates not Exceeding 1.0 rem/hour (at 30 centimeters from the radiation -sources or from any surface Denetrated bv the radiation)

a. Each entryway to such an area shall be barricaded and conspicuously posted as a high radiation area. Such barricades may be'opened as necessary to permit entry or exit of personnel or equipment.

b. Access to, and activities in. each such area shall be controlled by mea'ns of a Radiation Work Permit (RWP) or equivalent that Includes specification of radiation dose rates in the immediate work area(s) and other appropriate radiation protection equipment and measures.

c. Individuals qualified in radiation protection procedures and personnel continuously escorted by such individuals may be exempted from the requirement for an RWP or equivalent while performing their issigned duties provided that they are otherwise-following plant radiation protection procedures for entry'to.'exit from, and work in such areas.

d. Each individual or group entering such an area shall possess:

1. A-radiation monitoring device that continuously displays rdidation 'dose rates in the area; or

- 2.. A radiation monitoring device that continuously integrates the'radiation dose rates in the area and alarms when the device's dose alarm setpoint is reached, with an appropriate alarm setpoint: or

- (continued)

Columbia Generating Station 5.7-1 Amendment No. 149.149,182 h f 62-3

High Radiation Area 5.7 5.7 High Radiation Area 5.7.1 Hiah Radiation Areas with Dose Rates not Exceeding l.0 rem/hour (at 30 centimeters from the radiation sources or from any surface penetrated by the radiation) (continued)

3. A radiation monitoring device that continuously transmits dose rate and cumulative dose to a remote

-receiver monitored by radiation protection personnel responsible for controlling personnel radiation exposure within'the area; or

4. A self-reading dosimeter (e.g... pocket ionization chamber. or electronic dosimeter) and.

(i) Be under the surveillance, as specified in the RWP or equivalent, while in the area. of an individual qualified in radiation protection procedures.

equipped with a radiation monitoring device that continuously displays radiation dose rates in the area; who is responsible for controlling personnel radiation exposure within the area, or (ii) Be under the surveillance, as specified in the RWP or equivalent, while in the-area. by means of closed circuit television, of personnel qualified in radiation protection procedures, responsible Sta for controlling personnel radiation exposure in the area, and with the means to communicate with

'individuals in the area who are covered by such surveillance.

e. Except for individuals qualified in radiation protection procedures, or personnel continuously escorted by such individuals, entry into such areas shall be made only after dose rates in the area have been determined and entry personnel are knowledgeable of them. These continuously escorted personnel will receive a pre-job briefing prior to entry into such areas. This dose rate determination, knowledge,'and pre-job briefing dose not require documentation prior to initial entry.

(continued)

Columbia Generating Station 5.7-2 Amendment No. 14.96-9,l82 '

! Ad sS a-OJAr

High Radiation Area 5.7 5.7 High Radiation Area 5.7.2 High Radiation Areas with Dose Rates Greater than 1.0 rem/hour (at

-30 centimeters from the radiation source or from any surface penetrated by the radiation). but less than 500 rads/hour (at l meter from the radiation-source or from any surface penetrated bWthe radiation)

a. Each entryway to such an area shall be conspicuously posted as a high radiationa'area and shall be provided with a locked or continuously guarded door or gate that prevents unauthorized entry, and-in addition:

1. All such door and gate keys shall be maintained under the administrative control of the Shift Supervisor, Radiation Protection Manager, or his or her designee.

2. Doors and gates shall remain locked except during periods of personnel or equipment entry or exit.

b.' Access to. and activities in. each such area shall be controlled by means of an RWP or equivalent that includes specification of radiation dose rates in the immediate work area(s) and other.app'ropriate radiation protection equipment and measures.

c. Individuals qualified in radiation protection procedures may be exempted from the requirement for an RWP or equivalent while performing radiation surveys in such areas provided that they are otherwise following plant radiation protection procedures for entry to. exit from.-and work in such areas.

d. Each individual or group entering such an area shall possess:

1. A radiation monitoring device that continuously integrates the'radiation rates in the area and alarms when the device's dose alarm setpoint is reached, with

- an appropriate alarm setpoint, or

2. AVradiation monitoring device that continuously transmits dose'rate and cumulative dose to a remote receiver monitored by radiation protection personnel responsible for controlling personnel radiation

- exposure within the area with the means to communicate with and control every individual in the area, or (continued)

Columbia Generating Station 5.7-3 Amendment No. 449-419,182 f- *,&6-V_96bs

High Radiation Area

' High Radiation Area 5.7 5.7 High Radiation Area 5.7.2 High Radiation Areas with Dose Rates Greater than 1.0 rem/hour (at 30 centimeters from the-radiation source or from any surface penetrated by-the radiation), but less than 500 rads/hour (at I meter from the radiation source or from any surface penetrated by the radiation) (continued)

3. A self-reading dosimeter (e.g., pocket ionization chamber or electronic dosimeter) and.

(i) Be under the surveillance, as specified in the RWP or equivalent, while in the area, of an individual qualified in radiation protection procedures.

equipped with a radiation monitoring device that continuously displays radiation dose rates in the area; who is responsible for controlling personnel exposure within the area, or (ii) Be under the surveillance, as specified in the RWP or equivalent, while in the area, by means of closed circuit television, of personnel qualified in radiation protection procedures, responsible for controlling personnel radiation exposure in the area, and with the means to communicate with and control every individual in the area.

4. In those cases where options 2. and 3.. above are impractical or determined to be inconsistent with the "As Low As is Reasonably Achievable" principle, a radiation monitoring device that continuously displays radiation dose rates in the area.

e. Except for individuals qualified in radiation protection procedures, or personnel continuously escorted by such individuals, entry into such areas shall be made only after dose rates in the area have been determined and entry personnel are knowledgeable of them. These continuously escorted personnel will receive a pre-job briefing prior to entry into such areas. This dose rate determination, knowledge, and pre-job briefing dose not require documentation prior to initial entry.

(continued)

Columbia Generating Station 5.7-4 Amendment No. 149-169,182

High Radiation Area 5.7 5.7 High Radiation Area 5.7.2 High Radiation Areas with Dose Rates Greater than 1.0 rem/hour (at 30 centimeters from the radiation source or from any surface penetrated by the radiation). but less than 500 rads/hour (at 1 meter from the radiation source or from any surface penetrated by the radiation) (continued)

f. Such individual areas that are within a larger area where no I enclosure exists for purpose of locking and where no I enclosure can reasonably be constructed around the I individual area need not be controlled by a locked door or I gate, nor continuously guarded, but shall be barricaded, I conspicuously posted, and a clearly visible flashing light I shall be activated at the area as a warning device.

Columbia Generating Station 5.7-5 Amendment No. 149,169,182 QtORW begp~ do & a- '1(O Qb-b

LICZNS,7AUl-HORI+/-Y -FlB.cc'l Do Vol V~

APPENDIX B TO FACILITY OPERATING LICENSE NO. NPF-21 ENERGY NORTHWEST COLUMBIA GENERATING STATION DOCKET NO. 50-397 ENVIRONMENTAL PROTECTION PLAN (NONRADIOLOGICAL)

Amendment No. 4R,169 hJAN 6 U 231

ENERGY NORTHWEST COLUMBIA GENERATING STATION ENVIRONMENTAL PROTECTION PLAN (NON-RADIOLOGICAL)

TABLE OF CONTENTS Section Page 1.0 Objectives of the Environmental Protection Plan. 1-1 2.0 Environmental Protection Issues .2-1 2.1 Aquatic Resources Issues.2-1 2.2 Terrestrial Resources Issues.2-1 3.0 Consistency Requirements .3-1 3.1 Plant Design and Operation .3-1 3.2 Reporting Related to the NPDES Permit and State Certification ........................ 3-2 3.3 Changes Required for Compliance with Other Environmental Regulations........................................................................................................ 3-3 4.0 Environmental Conditions .4-1 4.1 Unusual or Important Environmental Events .4-1 4.2 Environmental Monitoring .4-1 5.0 Administrative Procedures .5-1 5.1 Review and Audit .5-1 5.2 Records Retention .5-1 5.3 Changes in Environmental Protection Plan .5-1 5.4 Plant Reporting Requirements.5-2

'Amendment No. 5,169 JAN (t o I20

1.0 Objectives of the Environmental Protection Plan The Environmental Protection Plan (EPP) is to provide for protection of nonradiological environmental values during operation of the Columbia Generating Station facility. The principal objectives of the EPP are as follows:

(1) Verify that the plant is operated in an environmentally acceptable manner, as established by the FES-OL and other NRC environmental impact assessments.

(2) Coordinate NRC requirements and maintain consistency with other Federal, State and local requirements for environmental protection.

(3) Keep NRC informed of the environmental effects of facility construction and operation and of actions taken to control those effects.

Environmental concerns identified in the FES-OL which relate to water quality matters are regulated by way of the licensee's NPDES permit.

1-1 Amendrpent No. 169 JAN o0.. Ad

2.0 Environmental Protection Issues In the FES-OL dated December 1981, the staff considered the environmental impacts associated with the operation of Columbia Generating Station. Certain environmental issues were identified which required study or license conditions to resolve environmental concerns and to assure adequate protection of the environment.

2.1 Aquatic Resources Issues The one aquatic issue raised by the staff in the FES-OL was that the disposal of chlorinated effluents in the river could have significant impacts on Hanford Reach biota if chlorine content were not carefully controlled (Section 5.5.2.2). This matter is addressed by the NPDES permit issued by the State of Washington Energy Facility Site Evaluation Council (EFSEC). Also, in the FES-OL (Section 5.5.3.2), the staff acknowledged that entrainment and impingement studies might be performed in accordance with special conditions of the water withdrawal permit, issued by the U.S. Army Corps of Engineers.

The NRC will rely on these agencies for regulation of matters involving water quality and aquatic biota.

2.2 Terrestrial Resources Issues There is uncertainty in predicting the potential impact of cooling tower drift on vegetation surrounding the site (FES Section 5.5.1.1). To resolve the 2-1 Amendment No. 169 JAN 0 V 2"01

uncertainty, the staff recommended a monitoring program to detect any effe6ts of cooling tower drift on vegetation (FES Section 5.5.3.1).

NRC requirements with regard to the terrestrial issues are specified in Subsection 4.2 of this EPP.

2-2

3.0 Consistency Requirements 3.1 Plant Design and Operation The licensee may make changes in station design or operation or perform tests or experiments affecting the environment provided such activities do not involve an unreviewed environmental question and do not involve a change in the EPP. Changes in plant design or operation or performance of tests or experiments which do not affect the environment are not subject to the requirements of this EPP. Activities governed by Section 3.3 are not subject to the requirements of this Section.

Before engaging in unauthorized construction or-operation activities which may significantly affect the environment, the licensee shall prepare and record

/ an environmental evaluation of such activity. Activities are excluded from this requirement if all measurable nonradiological effects are confined to the on-site areas previously disturbed during site preparation and plant construction. When the evaluation indicates that such activity involves an unreviewed environmental question, the licensee shall provide a written evaluation of such activity and obtain prior NRC approval. When such activity involves a change in the EPP, such activity and change to the EPP may be implemented only in accordance with an appropriate license amendment as set forth in Section 5.3 of this EPP.

A proposed change, test or experiment shall be deemed to involve an unreviewed environmental question if it concerns: (1) a matter which may result in a 3-1

significant increase in any adverse environmental impact previously evaluated in the FES-OL, environmental impact appraisals, or in any decisions of the Atomic Safety and Licensing Board; or (2) a significant change in effluents or power level or (3) a matter, not previously reviewed and evaluated in the documents specified in (1) of this Subsection, which may have a significant adverse environmental impact.

The licensee shall maintain records of changes in facility design or operation and of tests and experiments carried out pursuant to this Subsection. These records shall include written evaluations which provide bases for the determination that the change, test, or experiment does not involve an un reviewed environmental question or constitute a decrease in the effectiveness of this EPP to meet the objectives specified in Section 1.0. The licensee shall include as part of its Annual Environmental Operating Report (per Subsection 5.4.1) brief descriptions, analyses, interpretations, and evaluations of such changes, tests and experiments.

3.2 Reporting Related to the NPDES Permit and State Certification Changes to, or renewals of, the NPDES Permit or the State certification shall be reported to the NRC within 30 days following the date the change or renewal is approved. If a permit or certification, in part or in its entirety, is appealed and stayed, the NRC shall be notified within 30 days following the date the stay is granted.

3-2 Amendment No. 223

The NRC shall be notified of changes to the effective NPDES Permit proposed by the licensee by providing NRC with a copy of the proposed change at.the same time it is submitted to the permitting agency. 'The licensee shall provide the NRC a copy of the application for renewal of the NPDES Permit at the same time the application is submitted to the permitting agency.

3.3 Changes Required for Compliance with Other Environmental Regulations Changesin plant design or operation and performance of tests or experiments which are required to achieve compliance with other Federal, State, and local environmental regulations are not subject to the requirements of Section 3.1.

3-3

4.0 Environmental Conditions 4.1 Unusual or Important Environmental Events Any occurrence of an unusual or important event that indicates or could result in significant environmental impact causally related to plant operation shall be recorded and reported to the NRC within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months followed by a written report per Subsection 5.4.2. The following are examples: excessive bird impaction events, onsite plant or animal disease outbreaks, mortality or unusual occurrence of any species protected by the Endangered Species Act of 1973, fish kills, increase in nuisance organisms or conditions, and a significant, unanticipated or emergency discharge of waste water or chemical substances.

No routine monitoring programs are required to implement this condition.

4.2 Environmental Monitoring 4.2.1 Cooling Tower Drift Study A terrestrial monitoring program shall-be conducted to verify the level of effect from cooling tower drift. Soil and vegetation samples will be collected at locations subject to drift deposition and at control stations and analyzed for relevant chemical and physical parameters. Samples will be collected once per year during the seasonal peak of plant growth commencing no later than 18 months after issuance of a full power (100%) license. This program shall be terminated when data from three growing seasons after commencement of full power operation have been collected, provided the data support hypotheses of no adverse effects. Results and interpretation shall be included as part of the Annual Environmental Operating Report (Subsection 5.4.1).

4-1

5.0 Administrative Procedures 5.1 Review and Audit The licensee shall provide for review and audit of compliance with the Environmental Protection Plan. The audits shall be conducted independently of the individual or groups responsible for performing the specific activity. A description of the organization structure utilized to achieve the independent review and audit function and results of the audit activities shall be maintained and made available for inspection.

5.2 Records Retention Records and logs relative to the environmental aspects of station operation shall be made and retained in a manner convenient for review and inspection.

These records and logs shall be made available to NRC on request.

Records of modifications to plant structures, systems and components determined to potentially affect the continued protection of the environment shall be retained for the life of the plant. All other records, data and logs relating to this EPP shall be retained for five years or, where applicable, in

- accordance with the requirements of other agencies.

5.3 Changes in Environmental Protection Plan Request for change in the Environmental Protection Plan shall include an assessment of the environmental impact of the proposed change and a supporting 5-1

justification. Implementation of such changes in the EPP shall not commence-

.. prior to NRC approval of the proposed changes in the form of a license amendment incorporating the appropriate revision to the Environmental Protection Plan.

5.4 Plant Reporting Requirements 5.4.1 Routine Reports An Annual Environmental Operating Report describing implementation of this EPP

-for the previous year shall be submitted to the NRC prior to May 1 of each year. The initial recst; shall be submitted prior to May 1 of the year following issuance of the operating license. The period of the first report shall begin with the date of issuance of the operating license.

The report shall include summaries and analyses of the results of the environmental protection activities required by Subsection 4.2 of this Environmental Protection Plan for the report period, including a comparison with and related preoperational studies, operational controls (as appropriate),

and previous non-radiological environmental monitoring reports, and an assess-ment of the observed impacts of the plant operation on the environment. If harmful effects or evidence of trends toward irreversible damage to the environment are observed, the licensee shall provide a detailed analysis of the data and a proposed course of-mitigating action.

5-2

. The Annual Environmental Operating Report shall ~also include:

- (a) A list of EPP noncompliances and the corrective actions taken to remedy them.

(b) A list of all changes in station design or operation, tests, and exteriments made in accordance with Subsection 3.1 which involved a potentially significant unreviewed environmental question.

(c) A list of nonroutine reports submitted in accordance with Subsection 5.4.2.

(d) A summary of NPDES permit related water quality reports sent to EFSEC during the report period.

. .I-In-the event that some results are not available by the report due date, the report shall be submitted noting and explaining the missing results. The missing results shall be submitted as soon as possible in a supplementary report.

5.4.2 Nonroutine Reports A written report shall be submitted to the NRC within 30 days of occurrence of a nonroutine event. The report shall (a) describe, analyze, and evaluate the event, including extent and magnitude of the impact and plant operating

/,

5-3

characteristics, (b) describe the probable cause of the event,' (c)'fd .

i: the action taken to correct the reported event, (d) indicate the corrective-action taken to preclude repetition of the event and to prevent similar occurrences involving similar components or systems, and (e) indicate the agencies notified and their preliminary responses.

Events reportable under this subsection which also require reports to other Federal, State or local agencies shall be reported in accordance with those reporting requirements in lieu of the requirements of this subsection. The NRC shall be provided a copy of such report at the same time it is submitted to the other agency. This subsection does not apply to nonradiological water quality matters within the scope of the NPDES permit.

. I ,z I I I

I

'Ku~ 5-4

," I , - I - I. __- . . -

APPENDIX C Deleted Amendment No. 149, 151, 153, 157223

Enclosure 2 Federal Register Notice of Renewed Facility Operating License ML12089A045

[7590-01-P]

NUCLEAR REGULATORY COMMISSION

[DOCKET NO. 50-397; NRC-2010-0029]

Energy Northwest, Columbia Generating Station RECORD OF DECISION AND ISSUANCE OF RENEWED FACILITY OPERATING LICENSE FOR AN ADDITIONAL 20-YEAR PERIOD AGENCY: Nuclear Regulatory Commission.

ACTION: License renewal application; issuance.

SUMMARY

The U.S. Nuclear Regulatory Commission (NRC or the Commission) has issued renewed facility operating license No. NPF-21 to Energy Northwest (the licensee), the operator of the Columbia Generating Station (Columbia). Renewed facility operating license No. NPF-21 authorizes operation of Columbia by the licensee at reactor core power levels not in excess of 3,486 megawatts thermal in accordance with the provisions of the Columbia renewed operating license and its technical specifications. This also serves as the record of decision for the renewal of facility operating license No. NPF-21, consistent with the NRC's regulations.

ADDRESSES: Please refer to Docket 10 NRC-2010-0029 when contacting the NRC about the availability of information regarding this document. You may access information related to this document, which the NRC possesses and are publicly available, using any of the following methods:

Federal Rulemaking Web site: Go to http://www.regulations.gov and search for Docket 10 NRC-2010-0029 Address questions about NRC dockets to Carol Gallagher; telephone: 301-492-3668; e-mail: CaroI.Gallagher@nrc.gov.

-2

NRC's Agencywide Documents Access and Management System (ADAMS):

You may access publicly available documents online in the NRC Library at http://www.nrc.gov/reading-rm/adams.htmL To begin the search, select "ADAMS Public Documents" and then select "Begin Web-based ADAMS Search." For problems with ADAMS, please contact the NRC's Public Document Room (PDR) reference staff at 1-800-397-4209, 301-415-4737, or bye-mail to pdr.resource@nrc.gov. The ADAMS accession number for each document referenced in this notice (if that document is available in ADAMS) is provided the first time that a document is referenced.

NRC's PDR: You may examine and purchase copies of public documents at the NRC's PDR, Room 01-F21, One White Flint North, 11555 Rockville Pike, Rockville, Maryland 20852.

SUPPLEMENTARY INFORMATION:

Discussion Notice is hereby given that the NRC has issued renewed facility operating license No.

NPF-21 to Energy Northwest, the operator of Columbia. Renewed facility operating license No.

NPF-21 authorizes operation of Columbia by the licensee at reactor core power levels not in excess of 3,486 megawatts thermal in accordance with the provisions of the Columbia renewed operating license and its technical specifications.

The notice also serves as the record of decision for the renewal of facility operating license No. NPF-21, consistent with Title 10 of the Code of Federal Regulations (10 CFR),Section 51.103. As discussed in the final supplemental environmental impact statement for Columbia, Supplement 47 to NUREG-1437, "Generic Environmental Impact Statement for License Renewal of Nuclear Plants (GElS) Regarding Columbia Generating Station," dated April

- 3 2012 (ADAMS Accession Nos. ML12096A334 and ML12096A336), the Commission has considered a range of reasonable alternatives that included: (1) natural gas-fired combined cycle (NGCC); (2) new nuclear; (3) combination alternative (NGCC), hydroelectric, wind, and conservation and efficiency); (4) offsite new nuclear and NGCC; (5) coal-fired power; (6) energy conservation and energy efficiency; (7) purchased power; (8) solar power; (9) wind power; (10) biomass waste; (11) hydroelectric power; (12) ocean wave and current energy; (13) geothermal power; (14) municipal solid waste; (15) biofuels; (16) oil-fired power; (17) fuel cells; (18) delayed retirement; and (19) the no-action alternative. The factors considered in the record of decision can be found in the final supplemental environmental impact statement for Columbia.

Columbia is a boiling-water reactor located in Benton County, Richland, Washington.

The application for the renewed license, "Columbia Generating Station License Renewal Application," dated January 2012 (Accession No. ML100250656), complied with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's regulations. As required by the Act and the Commission's regulations in 10 CFR Chapter I, the Commission has made appropriate findings, which are set forth in the license.

Prior public notice of the action involving the proposed issuance of the renewed license and of an opportunity for a hearing regarding the proposed issuance of the renewed license was published in the Federal Register on March 11, 2010 (75 FR 11576).

- 4 For further details with respect to this action, see: (1) Energy Northwest's license renewal application for Columbia Generating Station dated January 19, 2010, as supplemented by letters dated through April 23, 2012; (2) the Commission's safety evaluation report NUREG 2123, "Safety Evaluation Report Related to the License Renewal of Columbia Generating Station," dated May 2012 (ADAMS Accession Nos. ML12139A300 and ML12139A302); (3) the licensee's Final Safety Analysis Report; and (4) the Commission's final environmental impact statement (NUREG-1437, Supplement 47), for the Columbia Generating Station, published April 2012.

Dated at Rockville, Maryland, this 22nd day of May, 2012.

Regulatory Commission

/

M. Reddemann - 2 If you have any questions regarding this issue, please feel free to contact me at 301-415-3897 or bye-mail at Arthur.Cunanan@nrc.gov.

Sincerely, IRAJ Arthur Cunanan, Project Manager Projects Branch 1 Division of License Renewal Office of Nuclear Reactor Regulation Docket No. 50-397

Enclosures:

1. Columbia Generating Station Renewed Facility Operating License

2. Federal Register Notice of Renewed Facility Operating License cc: See next page DISTRIBUTION:

See next page ML12089A042 (PKG) ML12089A043 (LTR) ML12089A045 (FRN) ML12089A090 (LlC)

Concurred via e-mail OFFICE

PM:RPB1:DLR LA:RPB1 :DLR Tech Editor* I PM:LPL4:DORL I BC:LPL4:DORL i

I i NAME I ACunanan i IKing KAzariah- LWilkins MMarkley Kribbs DATE 4/4/12 4/4/12 4/10/12 5/10/12 *4/12 OFFICE BC:RPB1 :DLR D:DLR:NRR OGC (NLO) D:NRR :RPB1:DLR NAME DMorey

MGalioway LSubin ELeeds ACunanan i

i DATE 5/14/12 5/17/12 5/17112 05122/12 . 05/22/12 OFFICIAL RECORD COPY

ML12089A043

Contents

Text

SUBJECT:

Dear Mr. Reddemann:

Enclosures:

SUBJECT:

Enclosures:

SUMMARY

Enclosures:

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