Text

Response to Request for Additional Information for License Amendment Request to Make Administrative and Editorial Changes to Technical Specifications and the Operating License
	ML12220A548
Person / Time
Site:	Columbia
Issue date:	07/30/2012
From:	Hettel W; Energy Northwest
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	GO2-12-104, TAC ME7904
	Download: ML12220A548 (71)
	v • d • e

ENER ENERGY W. Grover Hettel Columbia Generating Station P.O. Box 968, PE23 NORTHW EST Richland, WA 99352-0968 Ph. 509.377.8311 I F. 509.377.4150 whettel@energy-northwest.com July 30, 2012 10 CFR 50.90 G02-12-104 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, D.C. 20555-0001

Subject:

COLUMBIA GENERATING STATION, DOCKET NO. 50-397 RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION FOR LICENSE AMENDMENT REQUEST TO MAKE ADMINISTRATIVE AND EDITORIAL CHANGES TO TECHNICAL SPECIFICATIONS AND THE OPERATING LICENSE

References:

1) Letter, GO2-12-003, dated January 9, 2012, BJ Sawatzke (Energy Northwest) to NRC, "License Amendment Request to Make Administrative and Editorial Changes to the Technical Specifications and the Operating License"

2) Letter dated July 2, 2012, NRC to ME Reddemann (Energy Northwest), "Request for Additional Information Regarding License Amendment Request to Make Administrative and Editorial Changes to the Technical Specifications (TAC NO. ME7904)"

Dear Sir or Madam:

By Reference 1, Energy Northwest requested approval of a license amendment request to make administrative and editorial changes to the Columbia Generating Station Technical Specifications and Operating License. Via Reference 2, the Nuclear Regulatory Commission requested additional information related to the Energy Northwest submittal. Transmitted herewith in the enclosure is the Energy Northwest response to the request for additional information.

This letter and its enclosure contain no regulatory commitments. Should you have any questions or require additional information regarding.this matter, please contact Mr. Z.

K. Dunham, Licensing Supervisor, at (509) 377-4735.

I declare under penalty of perjury that the foregoing is true and correct. Executed on the date of this letter.

Soo(

u4D(L

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION FOR LICENSE AMENDMENT REQUEST TO MAKE ADMINISTRATIVE AND EDITORIAL CHANGES TO TECHNICAL SPECIFICATIONS AND THE OPERATING LICENSE Page 2 Respectfully, W. G. Hettel - Vice President, Operations

Enclosure:

As stated cc: NRC Region IV Administrator NRC NRR Project Manager NRC Senior Resident Inspector/988C AJ Rapacz - BPA/1399 WA Horin - Winston & Strawn JO Luce - EFSEC RR Cowley - WDOH

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION FOR LICENSE AMENDMENT REQUEST TO MAKE ADMINISTRATIVE AND EDITORIAL CHANGES TO TECHNICAL SPECIFICATIONS AND THE OPERATING LICENSE Enclosure Page 1 of 4 NRC Request:

1. The licensee indicated that it would be adopting Technical Specifications Task Force (TSTF)-GG-05-01, "Writer's Guide for Plant-Specific Improved Technical Specifications," Revision 1, August 2010 (ADAMS Accession No. ML12046A089).

The licensees' submittal does not appear to be consistent with TSTF-GG-05-01 with respect to the use of the word "continued". Please clarify. Specifically, was this intentional?

Energy Northwest Response:

The change in the use of the "(continued)" notation is not well illustrated in the marked up Technical Specification (TS) pages of the original submittal. The use of the

"(continued)" notation was reviewed in the clean version of the TS that was included as of the original submittal. The use of the "(continued)" notation was verified to be consistent with TSTF-GG-05-01 Rev. 1 with three exceptions. These exceptions were unintentional and occurred in LCO 3.7.4 and Tables 3.3.5.1-1 and 3.3.6.1-1. For these instances, the use of the "(continued)" notation was revised to ensure consistency with TSTF-GG-05-01. A mark-up of the changes (from what was included in Attachment 3 of the original submittal) are included in Attachment 1.

Revised clean pages are included in Attachment 2.

The table below summarizes the use of the "(continued)" notation in the original submittal. The table identifies each instance of the use of the "(continued)" notation and the applicable section in TSTF-GG-05-01.

Affected Specification TSTF-GG-05-01 Section Table of 3.3 2.2.2.d - If a list of Specifications for one Contents Chapter is split across pages, the continued Chapter number and title are repeated one blank line below the single line at the top of the continued page. The term "(continued)"

appears 2 spaces to the right of the Chapter title. The list of Specifications resumes under the repeated title as on the previous page Definitions Physics Testing 2.3.2.f - If a Definition is split across pages, the continued Definition title is repeated immediately below the single line at the top of the continued page. The term

"(continued)" appears two spaces to the right of the Definition title.

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION FOR LICENSE AMENDMENT REQUEST TO MAKE ADMINISTRATIVE AND EDITORIAL CHANGES TO TECHNICAL SPECIFICATIONS AND THE OPERATING LICENSE Enclosure Page 2 of 4 Affected Specification TSTF-GG-05-01 Section ___________________

Logical 1.2, 1.3, 1.4 2.3.3.e - If a subsection is split across Connectors, pages, the continued subsection header is Completion repeated one blank line below the single line Times, at the top of the continued page. The term Frequency "(continued)" appears two spaces to the right of the subsection heading.

Design 4.3 2.4.2.a.5 - If a Section is split across pages, Features the number and heading for the broken Section are repeated one blank line below the single line at the top of the continued page. The term "(continued)" appears two spaces after the heading.

LCO and SR 3.0.4, SR 3.0.4 2.5.1.h - If a Specification is split across Applicability pages, the continued Specification heading is repeated one blank line below the single line at the top of the continued page. The

"(continued)" appears two spaces to the right of the Specification heading.

Required 3.1.1 .D, 3.1.1 .E, 2.5.7.f - If a Required Action is split across Action 3.1.3.A, 3.1.6.B, pages, the Condition letter is repeated on 3.3.2.1.C, 3.3.5.1.B, the following page one blank line below the 3.3.6.2.C, 3.6.1.2.A, single line below the column heading. The 3.6.1.2.B, 3.6.1.3.A, term "(continued)" appears two spaces to 3.6.1.3.C, 3.6.4.2.A, the right of the letter. The Required Action 3.8.1 .A, 3.8.1 .B, text will begin on the same line as the 3.8.2.A, 3.9.4.A, "(continued)."

3.9.8.B, 3.9.9.B, 3.10.2.A, 3.10.4.B, 3.10.6.A Administrative 5.2.2, 5.5.4, 5.5.7, 2.6.2.e - If a Specification is split across Controls 5.5.8, 5.5.9, 5.5.11, pages, the continued Specification number 5.5.12, 5.6.3, 5.7.1, (and heading, if applicable) are repeated 5.7.2 one blank line below the single line at the top of the continued page. The term

"(continued)" appears two spaces to the right of the heading. If no heading exists, the Specification number is repeated as on the previous page, and the term "(continued)"

appears next to it, indented 1.0 inch from the left margin. The continued Specification text follows one blank line below this.

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION FOR LICENSE AMENDMENT REQUEST TO MAKE ADMINISTRATIVE AND EDITORIAL CHANGES TO TECHNICAL SPECIFICATIONS AND THE OPERATING LICENSE Enclosure Page 3 of 4 NRC Request:

2. The description for the proposed editorial change to the TS Limiting Condition for Operation (LCO) 3.3.4.1 refers to TSTF-GG-05-01 section 2.5.5.d.4. However, Section 2.5.6 of TSTF-GG-05-01 is entitled "Technical Specification Sections 3.1 through 3.9 (3.10) Surveillance Requirements Format." Should the reference for the change to LCO 3.3.4.1 be to Section 2.5.6.d?

Enerav Northwest Response:

The reference should be to section 2.5.6.d of TSTSF-GG-05-01 Rev. 1.

NRC Request:

3. The description of the editorial change for TS Table 3.3.5.2-1 refers to adding a header to page 3.3.5.2-3. However, this reference appears to be incorrect. Should it refer to page 3.3.5.2-4 instead?

Energy Northwest Response:

The reference should be to TS page 3.3.5.2-4.

NRC Request:

4. The mark-up page related to TS 5.7.1.e is not consistent with the description on page 5 of the "description and Evaluation of the Proposed TS Changes" in the LAR nor with the provided clean page. Please revise the mark-up page accordingly.

Energy Northwest Response:

The change to TS 5.7.1 .e is incorrect. A revised page of the TS mark-up is provided in .

Additional Items:

1. In reviewing the clean TS, a typographical error was discovered on page 5.5-8. The Specification number for the Diesel Fuel Oil Testing Program, which was continued from the previous page, should be 5.5.9. This error was introduced during the software conversion and is not present in the existing TS. A mark-up of the change (from what was included in Attachment 3 of the original submittal) is included in Attachment 1. A revised clean page of the TS is provided in Attachment 2.

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION FOR LICENSE AMENDMENT REQUEST TO MAKE ADMINISTRATIVE AND EDITORIAL CHANGES TO TECHNICAL SPECIFICATIONS AND THE OPERATING LICENSE Enclosure Page 4 of 4

2. In reviewing the clean Operating License, an editorial error was discovered in section 3.1 of Appendix B (page 3-1). The final paragraph in this section was unintentionally omitted. This error was introduced during the software conversion and is not present in the existing TS. A mark-up of the change (from what was included in Attachment 5 of the original submittal) is included in Attachment 3. A revised clean page is provided in Attachment 4.

3. Additionally, Energy Northwest has received Amendments 223, 224 and the Renewed Facility Operating License (FOL) for Columbia Generating Station (Columbia).

" Amendment 223 deleted obsolete license conditions from the FOL and made other administrative changes. The renewed FOL for Columbia reformatted and added conditions to the license. A mark-up of the changes (from what was included in Attachment 5 of the original submittal) are included in Attachment 3.

The revised clean pages are provided in Attachment 4.

" Amendment 224 revised TS 3.4.7 to add a new Condition and re-number existing Conditions. A mark-up of the change (from what was included in Attachment 3 of the original submittal) is included in Attachment 1. A revised clean page of the TS is provided in Attachment 2.

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION FOR LICENSE AMENDMENT REQUEST TO MAKE ADMINISTRATIVE AND EDITORIAL CHANGES TO TECHNICAL SPECIFICATIONS AND THE OPERATING LICENSE REVISED TS MARK-UP PAGES

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 2 of 5)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

1. LPCI and LRCS Subsystems [ t'j

g. LPCS Pump 1,2,3, E SR 3.3.5.1.2 > 668 gpm and Discharge Flow - 44a), 5(a)

SR 3.3.5.1.4 < 1067 gpm Low (Minimum Flow) 1 SR 3.3.5.1.6

h. LPCI PumpA 1, 2,3, E SR 3.3.5.1.2 > 605 gpm and Discharge Flow - 4 (a), 5(a)

SR 3.3.5.1.4 < 984 gpm Low (Minimum Flow) SR 3.3.5.1.6

i. Manual Initiation 1,2,3,5(a) 2 C SR 3.3.5.1.6 NA 4(a),

2. LPCI B and LPCI C Subsystems

a. Reactor Vessel 2 (b) B SR 3.3.5.1.1 > -142.3 inches Water Level - Low 4Wa), '(a)

SR 3.3.5.1.2 Low Low, Level 1 SR 3.3.5.1.4 SR 3.3.5.1.6

b. Drywell Pressure - 1,2,3 2 (b) B SR 3.3.5.1.2 < 1.88 psig High SR 3.3.5.1.4 SR 3.3.5.1.6

c. LPCI Pump B Start - 4(a), 5(a) C SR 3.3.5.1.5 > 17.24 seconds LOCA Time Delay SR 3.3.5.1.6 and Relay <21.53 seconds

d. LPCI Pump C Start - 1(e) C SR 3.3.5.1:5 > 8.53 seconds 4('a) 5(a)

LOCA Time Delay SR 3.3.5.1i6 and Relay < 10.64 seconds

e. LPCI Pump B Start - 1 C SR 3.3.5.1.2 > 3.04 seconds 4(a), 5(a)

LOCAILOOP Time SR 3.3.5.1.3 and Delay Relay SR 3.3.5.1.6 < 6.00 seconds (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 offsite power circuit pursuant to LCO 3.8.1 and LCO 3.8.2.

Columbia Generating Station 3.3.5.1-7 Amendment No. 4-69 474

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 3 of 5)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

2. LPCl B and .PC; G Subsystems (GOrtinued)

f. Reactor Vessel 1,2,3, 1 per valve C SR 3.3.5.1.2 _ 448 psig Pressure - Low SR 3.3.5.1.4 and (Injection SR 3.3.5.1.6 _<492 psig Permissive) 4 (a), 5(a) 1 per valve B SR 3.3.5.1.2 _ 448 psig SR 3.3.5.1.4 and SR 3.3.5.1.6 _<492 psig

g. LPCI Pumps B & C 1,2,3, 1 per pump E SR 3.3.5.1.2 _>605 gpm Discharge Flow - 4(a) 5(a) SR 3.3.5.1.4 and Low (Minimum flow) 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) 1 ,2,3

3. High Pressure Core Spray (HPCS) System

a. Reactor Vessel 1,2,3, 4 (b) B SR 3.3.5.1.1 - -58 inches Water Level - Low 4 (a), 5(a) SR 3.3.5.1.2 Low, Level 2 SR 3.3.5.1.4 SR 3.3.5.1.6

b. Drywell Pressure - (b) B SR 3.3.5.1.2 1,2,3 4 _<1.88 psig 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 Level - High, 4(a) 5(a) SR 3.3.5.1.2 Level 8 SR 3.3.5.1.4 SR 3.3.5.1.6

d. Condensate Storage 1,2,3, 2 D SR 3.3.5.1.2 >'448 ft 1 inch Tank Level - Low 4(c), 5(c) SR 3.3.5.1.4 elevation SR 3.3.5.1.6 (a) When associated subsystem(s) are required to be OPERABLE.

(b) Also required to initiate the associated DG.

(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.

Columbia Generating Station 3.3.5.1-8 Amendment No. U6 469

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 4 of 5)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

3. HPEq Syste

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 E SR 3.3.5.1.2 _>1200 gpm and 4(a), 5(a)

Rate - Low SR 3.3.5.1.4 < 1512 gpm (Minimum Flow) 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 (d), 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 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 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 (Permissive) SR 3.3.5.1.4 SR 3.3.5.1.6

d. LPCS Pump 1, 2 (d), 3 (d) 2 G SR 3.3.5.1.2 > 119 psig and Discharge Pressure SR 3.3.5.1.4 < 171 psig

- High SR 3.3.5.1.6

e. LPCI Pump A 1, 2 (d), 3 (d) 2 G SR 3.3.5.1.2 > 116 psig and Discharge Pressure SR 3.3.5.1.4 < 134 psig

- High SR 3.3.5.1.6 (a) When associated subsystem(s) are required to be OPERABLE.

(d) With reactor steam dome pressure > 150 psig.

Columbia Generating Station 3.3.5.1-9 Amendment No. 466 469

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 5 of 5)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

4. ADS Trip S stem A

f. Accumulator Backup 1, 2(d), 3 (d) 3 F SR 3.3.5.1.2 >_151.4 psig Compressed Gas SR 3.3.5.1.4 System Pressure - SR 3.3.5.1.6 Low (d)

g. Manual Initiation 1, 2 (d), 3 4 G SR 3.3.5.1.6 NA

5. ADS Trip System B

a. Reactor Vessel 1, 2(d), 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 (d)

b. ADS Initiation Timer 1, 2 (d), 3 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 1, (d) F SR 3.3.5.1.1 2 (d), 3 1 > 9.5 inches Water Level - SR 3.3.5.1.2 Low, Level 3 SR 3.3.5.1.4 (Permissive) SR 3.3.5.1.6

d. LPCI Pumps B & C 1, 2 (d), 3 (d) 2 per pump G SR 3.3.5.1.2 _>116 psig and Discharge Pressure SR 3.3.5.1.4 < 134 psig

- High SR 3.3.5.1.6 (d)

e. Accumulator Backup 1, 2 (d), 3 3 F SR 3.3.5.1.2 _>151.4 psig Compressed Gas SR 3.3.5.1.4 System Pressure - SR 3.3.5.1.6 Low

f. Manual Initiation 1, (d) 4 NA 2 (d), 3 G SR 3.3.5.1.6 (d) With reactor steam dome pressure > 150 psig.

Columbia Generating Station 3.3.5.1-10 Amendment No. 4-66 469

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 2 of 6)

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

2. Primaryvntainmen IsolatioarI eeniA'-dj

b. Reactor Vessel 1,2,3 2 (e) H 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

c. Drywell Pressure - 1,2,3 2(e) H SR 3.3.6.1.2 5 1.88 psig High SR 3.3.6.1.4 SR 3.3.6.1.6

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 Radiation - SR 3.3.6.1.4 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 1 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) Also required to initiate the associated LOCA Time Delay Relay Function pursuant to LCO 3.3.5.1.

Columbia Generating Station 3.3.6.1-6 Amendment No. 469 4-7-2

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 3 of 6)

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

3. RClC System Isolation

e. RCIC Equipment 1,2,3 F SR 3.3.6.1.3 < 180°F Room Area SR 3.3.6.1.4 Temperature - High SR 3.3.6.1.6

f. RCIC Equipment 1,2,3 F SR 3.3.6.1.3 _<

60'F Room Area SR 3.3.6.1.4 Differential SR 3.3.6.1.6 Temperature - High

g. RWCU/RCIC Steam 1,2,3 F SR 3.3.6.1.3 5 180°F Line Routing Area SR 3.3.6.1.4 Temperature - High SR 3.3.6.1.6

h. Manual Initiation 1,2,3 G SR 3.3.6.1.6 NA

4. RWCU System Isolation

a. Differential Flow - 1,2,3 1 F SR 3.3.6.1.1 < 67.4 gpm High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

b. Differential Flow - 1,2,3 1 F SR 3.3.6.1.2 < 46.5 seconds Time Delay SR 3.3.6.1.5 SR 3.3.6A1.6

c. Blowdown Flow - 1,2,3 F SR 3.3.6.1.1 < 271.7 gpm 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

d. Heat Exchanger 1,2,3 F SR 3.3.6.1.3 < 160OF Room Area SR 3.3.6.1.4 Temperature - High SR 3.3.6.1.6 (b) RCIC Manual Initiation only inputs into one of the two trip systems.

Columbia Generating Station 3.3.6.1-7 Amendment No. 4-64 4-7-2

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 4 of 6)

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.RW1IRvstem Isolation

e. Heat Exchanger 1,2,3 1 F SR 3.3.6.1.3 !<70°F Room Area SR 3.3.6.1.4 Ventilation SR 3.3.6.1.6 Differential Temperature - High

f. Pump Room Area 1,2,3 1 per room F SR 3.3.6.1.3 !5 180OF 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 *ý100OF 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 RWCU Line Routing 1,2,3 1 per room F SR 3.3.6.1.3 Area Temperature - SR 3.3.6.1.4 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 1,2,3 2(c) SR 3.3.6.1.6 NA Initiation I. Manual Initiation 1,2,3 2 G SR 3.3.6.1.6 NA (c) SLC System Initiation only inputs into one of the two trip systems.

Columbia Generating Station 3.3.6.1-8 Amendment No. 4-7-2 4-99

RCS Leakage Detection Instrumentation 3.4.7 Insert A ACTIONS ITION REQUIRED ACTION COMPLETION TIME Required Action and [-1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A-r--B AND not met. G ABorCBe in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months A,B,or CEI Fý] Q- All required leakage IE.1 Enter LCO 3.0.3. Immediately detection systems inoperable.

SURVEILLANCE REQUIREMENTS F. Itv*"rrF

I-jL I--I----------------------------------------

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 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 3.4.7-2 Amendment No. 4-W 497-

Insert A C.1 Analyze grab samples of

- NOTE -- ------- C. 1 Analyze grab samples of Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Only applicable when the the drywell atmosphere.

drywell atmospheric gaseous monitoring system AND is the only OPERABLE monitor. C.2 Monitor RCS LEAKAGE by Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months administrative means.

C. Drywell floor drain sump AND flow monitoring system inoperable. C.3 Restore the drywell floor 7 days drain sump flow monitoring system to OPERABLE status.

Control Room AC System 3.7.4 ACTIONSI ]

CONDITION REQUIRED ACTION COMPLETION TIME E. Two control room AC E.1 Initiate action to suspend Immediately subsystems inoperable OPDRVs.

during OPDRVs.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify each control room AC subsystem has the 24 months capability to remove the assumed heat load.

Columbia Generating Station 3.7.4-2 Amendment No. 469 4-99

Programs and Manuals 5.5 5.5 Programs and Manuals 5.1t Diesel Fuel Oil Testing Program (continued)

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/I 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 of these Technical Specifications.

a. Changes to the Bases of the TS shall be made under appropriate administrative controls and reviews.

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 Specification 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.

Columbia Generating Station 5.5-8 Amendment 4-7-7 245

High Radiation Area 5.7 5.7 High Radiation Area 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 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 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.

p

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 briefinqqe -se not require documentation prior to initia4, entry.

(e nti nbied)

.Columbia Generating Station 5.7-2 Amendment No. 1,44,169 442-

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION FOR LICENSE AMENDMENT REQUEST TO MAKE ADMINISTRATIVE AND EDITORIAL CHANGES TO TECHNICAL SPECIFICATIONS AND THE OPERATING LICENSE REVISED TS PAGES (CLEAN)

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 2 of 5)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

1. LPCI and LPCS Subsystems

g. LPCS Pump 1 2,5(3,) E SR 3.3.5.1.2 _>

668 gpm and Discharge Flow - 4(a),

SR 3.3.5.1.4 < 1067 gpm Low (Minimum Flow) 1 SR 3.3.5.1:6

h. LPCI Pump A 1,2,3, E SR 3.3.5.1.2 > 605 gpm and Discharge Flow - 4 (a), 5 (a) SR 3.3.5.1.4 < 984 gpm Low (Minimum Flow) SR 3.3.5.1.6

i. Manual Initiation 1,2,3, 2 C SR 3.3.5.1.6 NA 4(a), 5(a)

2. LPCI B and LPCl C Subsystems

a. Reactor Vessel 1,2,3, 2 (b) B SR 3.3.5.1.1 > -142.3 inches Water Level - Low 4 (a), 5 (a) SR 3.3.5.1.2 Low Low, Level 1 SR 3.3.5.1.4 SR 3.3.5.1.6

b. Drywell Pressure - 1,2,3 2 (b) B SR 3.3.5.1.2 < 1.88 psig High SR 3.3.5.1.4 SR 3.3.5.1.6

c. LPCI Pump B Start - 1,2,3, 1(e) C SR 3.3.5.1.5 > 17.24 seconds (a), 5(a)

LOCA Time Delay 4 SR 3.3.5.1.6 and Relay < 21.53 seconds

d. LPCI Pump C Start - 1,2,3, 1 (e) C SR 3.3.5.1.5 _>

8.53 seconds LOCA Time Delay 4 (a), 5 (a) SR 3.3.5.1.6 and Relay < 10.64 seconds

e. LPCI Pump B Start - 1 C SR 3.3.5.1.2 > 3.04 seconds LOCA/LOOP Time 4(a), %(ý' SR 3.3.5.1.3 and Delay Relay SR 3.3.5.1.6 < 6.00 seconds (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 offsite power circuit pursuant to LCO 3.8.1 and LCO 3.8.2.

Columbia Generating Station 3.3.5.1-7 Amendment No. 469 47 ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 3 of 5)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

2. LPCI B and LPCI C Subsystems

f. Reactor Vessel 1,2,3, 1 per valve C SR 3.3.5.1.2 >_448 psig Pressure - Low SR 3.3.5.1.4 and (Injection SR 3.3.5.1.6 <_492 psig Permissive) 4(a), 5(a) 1 per valve B SR 3.3.5.1.2 _>448 psig SR 3.3.5.1.4 and SR 3.3.5.1.6 <_492 psig

g. LPCI Pumps B & C 1,2,3, 1 per pump E SR 3.3.5.1.2 _>605 gpm Discharge Flow - 4(a), 5(a) SR 3.3.5.1.4 and Low (Minimum flow) 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 1,2,3, 4 (b) B SR 3.3.5.1.1 _ -58 inches Water Level - Low 4 (a) 5 (a) SR 3.3.5.1.2 Low, Level 2 SR 3.3.5.1.4 SR 3.3.5.1.6

b. Drywell Pressure - 1,2,3 (b) B SR 3.3.5.1.2 4 _ 1.88 psig 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 Level - High, 4(a) 5(a) SR 3.3.5.1.2 Level 8 SR 3.3.5.1.4 SR 3.3.5.1.6

d. Condensate Storage 1,2,3, 2 D SR 3.3.5.1.2 > 448 ft 1 inch Tank Level - Low 4(c), 5(c) SR 3.3.5.1.4 elevation SR 3.3.5.1.6 (a) When associated subsystem(s) are required to be OPERABLE.

(b) Also required to initiate the associated DG.

(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.

Columbia Generating Station 3.3.5.1-8 Amendment No. 46re 4-69

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 4 of 5)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

3. HPCS System

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 E SR 3.3.5.1.2 > 1200 gpm and Rate - Low 4(a), 5(a) SR 3.3.5.1.4 < 1512 gpm (Minimum Flow) 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(d), 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 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 1,2 (d), 3 (d) 1 F SR 3.3.5.1.1 > 9.5 inches Water Level - Low, SR 3.3.5.1:2 Level 3 (Permissive) SR 3.3.5.1.4 SR 3.3.5.1.6

d. LPCS Pump 1,2 (d) 3 (d) 2 G SR 3.3.5.1'2 _>

119 psig and Discharge Pressure SR 3.3.5.1.4 < 171 psig

- High SR 3.3.5.1.6

e. LPCI Pump A 1,2 (d) 3 (d) 2 G SR 3.3.5.1.2 _>

116 psig and Discharge Pressure SR 3.3.5.1.4 < 134 psig

- High SR 3.3.5.1.6 (a) When associated subsystem(s) are required to be OPERABLE.

(d) With reactor steam dome pressure > 150 psig.

Columbia Generating Station 3.3.5.1-9 Amendment No. 4-N 469

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 5 of 5)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

4. ADS Trip System A

f. Accumulator Backup 1, 2 (d), 3 (d) 3 F SR 3.3.5.1.2 > 151.4 psig Compressed Gas SR 3.3.5.1.4 System Pressure - SR 3.3.5.1.6 Low

g. Manual Initiation 1, 2 (d), 3 (d) 4 G SR 3.3.5.1.6 NA

5. ADS Trip System B

a. (d)

Reactor Vessel 1, 2 (d), 3 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 Timer 1, (d), (d) 2 3 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 (d) 1, 2 (d), 3 1 F SR 3.3.5.1.1 > 9.5 inches Water Level - SR 3.3.5.1.2 Low, Level 3 SR 3.3.5.1.4 (Permissive) SR 3.3.5.1.6

d. LPCI Pumps B & C 1, 2 (d), 3 (d) 2 per pump G SR 3.3.5.1.2 _>116 psig and Discharge Pressure SR 3.3.5.1.4 _<134 psig

- High SR 3.3.5.1.6

e. Accumulator Backup 1, 2 (d), 3 (d) 3 F SR 3.3.5.1.2 _>151.4 psig Compressed Gas SR 3.3.5.1.4 System Pressure - SR 3.3.5.1.6 Low

f. Manual Initiation 1,22(d), 3 (d) 4 G SR 3.3.5.1.6 NA (d) With reactor steam dome pressure > 150 psig.

Columbia Generating Station 3.3.5.1-10 Amendment No. 466 469

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 2 of 6)

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

2. Primary Containment Isolation

b. Reactor Vessel 1,2,3 2 (e) H 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

c. Drywell Pressure - 1,2,3 2 (e) H SR 3.3.6.1.2 < 1.88 psig High SR 3.3.6.1.4 SR 3.3.6.1.6

d. Reactor Building 1,2,3 2 F SR 3.3.6.1.1 < 16.0 mRlhr Vent Exhaust SR 3.3.6.1.2 Plenum Radiation - SR 3.3.6.1.4 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 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 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) Also required to initiate the associated LOCA Time Delay Relay Function pursuant to LCO 3.3.5.1.

Columbia Generating Station 3.3.6.1-6 Amendment No. 469 4-7-2

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 3 of 6)

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

3. RCIC System Isolation

e. RCIC Equipment 1,2,3 F SR 3.3.6.1.3 < 180OF Room Area SR 3.3.6.1.4 Temperature - High SR 3.3.6.1.6 1

f. RCIC Equipment 1,2,3 .F SR 3.3.6.1.3 < 60OF Room Area SR 3.3.6.1.4 Differential SR 3.3.6.1.6 Temperature - High

g. RWCU/RCIC Steam 1,2,3 F SR 3.3.6.1.3 < 180OF Line Routing Area SR 3.3.6.1.4 Temperature - High SR 3.3.6.1.6 1 (b) NA

h. Manual Initiation 1,2,3 G SR 3.3.6.1.6

4. RWCU System Isolation

a. Differential Flow - 1,2,3 1 F SR 3.3.6.1.1 < 67.4 gpm High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

b. Differential Flow - 1,2,3 1 F SR 3.3.6.1.2 <46.5 seconds Time Delay SR 3.3.6.1.5 SR 3.3.6.1.6

c. Blowdown Flow - 1,2,3 1 F SR 3.3.6.1.1 _ 271.7 gpm 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

d. Heat Exchanger 1,2,3 I F SR 3.3.6.1.3 _<160OF Room Area SR 3.3.6.1.4 Temperature - High SR 3.3.6.1.6 (b) RCIC Manual Initiation only inputs into one of the two trip systems.

Columbia Generating Station 3.3.6.1-7 Amendment No. 4-6.9 47-2

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 4 of 6)

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

e. Heat Exchanger 1,2,3 1 F SR 3.3.6.1.3 _<70°F Room Area SR 3.3.6.1.4 Ventilation SR 3.3.6.1.6 Differential Temperature - High

f. Pump Room Area 1,2,3 1 per room F SR 3.3.6.1.3 *ý180OF 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 *5100OF 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 5 180OF Routing Area SR 3.3.6.1.4 Temperature - High SR 3.3.6.1.6 RWCU Line Routing 1,2,3 1 per room F SR 3.3.6.1.3 Area Temperature - SR 3.3.6.1.4 High SR 3.3.6.1.6 Room 409, 509 < 175°F Areas Room 408, 511 < 180OF 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 1,2,3 2(c) SR 3.3.6.1.6 NA Initiation I. Manual Initiation 1,2,3 2 G SR 3.3.6.1.6 NA (c) SLC System Initiation only inputs into one of the two trip systems.

Columbia Generating Station 3.3.6.1-8 Amendment No. 47-2 4-W

RCS Leakage Detection Instrumentation 3.4.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME

-NOTE ---------- C.1 Analyze grab samples of Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Only applicable when the the drywell atmosphere.

drywell atmospheric gaseous monitoring system AND is the only OPERABLE monitor. C.2 Monitor RCS LEAKAGE by Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months administrative means.

C. Drywell floor drain sump AND flow monitoring system inoperable. C.3 Restore drywell floor drain 7 days sump flow monitoring 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 Condition A, B, AND 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 leakage E.1 Enter LCO 3.0.3. Immediately detection systems inoperable.

Columbia Generating Station 3.4.7-2 Amendment No. 487 224

RCS Leakage Detection Instrumentation 3.4.7 SURVEILLANCE REQUIREMENTS rý -- ---------------------------------------------------------

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 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 3.4.7-3 Amendment No. 449 449

Control Room AC System 3.7.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. Two control room AC E.1 Initiate action to suspend Immediately subsystems inoperable OPDRVs.

during OPDRVs.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify each control room AC subsystem has the 24 months capability to remove the assumed heat load.

Columbia Generating Station 3.7.4-2 Amendment No. 469 449

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.9 Diesel Fuel Oil Testing Program (continued)

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/I 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 of these Technical Specifications.

a. Changes to the Bases of the TS shall be made under appropriate administrative controls and reviews.

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 Specification 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 Pro-gram (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.

Columbia Generating Station 5.5-8 Amendment 47-7 2445

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION FOR LICENSE AMENDMENT REQUEST TO MAKE ADMINISTRATIVE AND EDITORIAL CHANGES TO TECHNICAL SPECIFICATIONS AND THE OPERATING LICENSE REVISED OPERATING LICENSE MARK-UP PAGES

ENERGY NORTHWEST DOCKET NO. 50-397 COLUMBIA GENERATING STATION IRenewed k-*FACILITY OPERATING LICENSE IRenewed P> License No. NPF-21 Irenewed

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

A. The application for 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.D. below); irenewed ,

D. There is reasonable assurance: (i) that the activities authorized by t 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.D. below);

E. Energy Northwest is technically qualified to engage in the activities authorized by this lrenew~ed ý 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 Pmection Requirements and Indemnity Agreements", of the Commission's regulations;

[renewed -- .

G. The issuance o license will not be inimical to the common defense and security or to the health and safety of the public; lRenewed H.A weighing the environmental, economic, technical, and other benefits of the facility agains *ro_Qmental and other costs and considering available alternatives, the issuance of thi 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 IRenewed License No. NPF-21 > AFmordmert .o. 157 169

-y (Pages renumbered)

Irenewed

1. The receipt, pos ssion, and use of source, byproduct and special nuclear material as authorized by this license will be in accordance with the Commission's regulations in 10 Fln-se-r t B- kI CFR Parts 30, 40 and 70.

- : .I Renewed

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

renewed operating rThis"icense 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) Pursuant to 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 Irenewed ] -- in-th.*license; (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 ameridium-241.

IRenewed License No. NPF-21 > Amondment No. 157 169

Insert B 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.

-X (Pages renumbered)

IrenewedThsi C. icense 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). Items in A#tachmont 1 shall be com~plotod as spocified. Attashmon-t I OShereb81Y incorporat~d_ into this license.

(2) Technical Specifications and Environmental Protection Plan renewed The Technical Specifications contained in Appendix , as revised through Amen me. 222-and the Environmental Pr ction Plan contained in Appendix B, are hereby incorporated in theense. 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) initial T-e+t Prearam (SScictn 44. SE.R)* 5Deleted.

The licenseo shall coniduct the initial test programn (6ot forFth inSec~tion 14 of the lisensee's Final Safety Analysi. Report, as a without makiRg any "mndod) moedifications of this program unless cUch moedifications are in accordance with the prov*ision of 10 CFR Section 50.50. in addition, the licensee shall noet make 8ny mfajor moedifieatiens to this programA unless moedifications have been identificd and haVe received prior NRC approval. Major moedifications arc defined s (a)~ Elimination of any test idcntifiod in Section 14 of the lieenseo's Fina Safety Analysis Report, as amenRded, as befing essenitial; Modificatioen* f test objectiY.e, m.ethods or ac.eptance c.itc-ia for any test identified in Se.ti.n 14 of the *ien.see'sFinal Safey Analysis Repert, as am*;d.d, as being essenial;,

(e) PReeformanco of any test at a power level diffrenet fromR that describ~ed i Failure to complete any tests nlddi the described program' (planned or schdued frpower levels up to the aulthorized power level.

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.

lRenewed License No. NPF-21 JAmendment No. 222

-// (Pages renumbered)

(4) . . .a..... . . ..... ...... . . i .. . . #44 Deleted.

Prior to startup following the -4t re-foling outage, the li-enseo shall complete seimic. ,qualifiationsfor all equipment approved by the NRl Gtaff for interim epeFatief:.

(5) E"'" . Q.u..

" ISccto;s 3.10.4= 3..*44---SSER 4*A, FDeleted.I PriFor to oxceoding five (5) percent of rated po-Wr, the wien.see shall proVide the lt.rff fortheir rth Feview

,.F And RAoRFMOML as-arane that all c CgUiPMent is~ted in Appenidix 30 is either cnvironmentallv u aliOficorprov-,"P,"-fi-d-e justification for inter*im 0 E*Vl auelnI f+for all pipe mouwntcd safety related equipm~ent, provide assurance that the gig" values for the as, installed con~figuration do not exceed the "g"values established iR the equ.pment qualificat informaio do4*cm*ntai (QID) files or provide ju.tification forine operation.

(6) .i..... ........... C S,

......... ,. F'Deleted

. -1 Prior t9 startup following the first refucling outage, the lien~see shall podo~rm; epcrational testing of the ultimate heat sink spray ponds to vcrif,' analyzed parameters of drift loss, seepage and operational capacity. T-he licenee shall inAform the NRC staff of scheduled testing at least 30 days in advance o~fsc testing and shall provide the test rslsand-conclusjions for NIRC reviewA and app~eval-(7) T. .- kiW I*:s. (ISet, 3.5 4 ) SSQER ) Deleted.]

The-licen-see-shall sumtfo-r NIRC staff approval, within three years of date of i ssu.ance of this li:cnsc, a turbine system maintenance program based en the m-anu-facturer's cacltin f Fmissile generation probabilities, accaeptable to the NRC staff orVolumIetFically inspect all loWpressure turbine rotors At the second refueling outage, and at eve.; other refueling outage thereafter until a mnaintenance program isapprovd by the NRC staff.

(8) Fuce Cc'cabIluty (Stn. .*.4.*2'., 0 S;F-R. FDeleted. 1 Prior to startup following the first refueling outage, the lien~see shall provide for NRC staff review and appreval revised analyses shoWingq the effets of high burnup fission gas release on loss of cooelant accidenit.

(9)

The lIce.nsee shall implement staff's requirements regard4ig additional IinstrUmletation for detetion of in adequate core cooling Which May result fromi the staffs review of the BVR OwnrB's Group Reports (SLI1 8:211 and SL1 8 218) and the liensee's plant specifi evaluation report addFressing the subjects. Any requiredmdifications shall be completed on a schedule acceptable to the NIRC IRenewed License No. NPF-21 I

_*_ (Pages renumbered)

(10) T-heFral Hydrc'-w Stability (Scctwe, A.4.4. S FDDeleted.1 L II J r-mor to tiujr~up ioiiowni tno rirci roiuoiinc~ ourncio, tno uconcoo cnaii oroviao ror i NRC ct-Ff ro:io and -ew ADn*rA, l rA r iAd tabIL- - A-nA-hic.

(11) Shield Wall Deferral (Section 12.3.2. SSER #4, Licensee 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) Altpr-R;;tp RAFnete ShutEle Pr# AR 74 2 [Deleted.

I i I i wrrior to startup foilowen ig the firit rofuoling outago, tho liconscc chall inttall, toct, andu have.' ewpuruu Trio aiitema~W rumow--A AIWTnuOWn Gyctem.

(13) Deleted.

(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 license 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) D^ SaI B Q'-i" -*.-, .... ;.... (Seetion -- 3'*.1.2.1 (1) [Deleted.J During the startup test prcgramR, the lieensoc shall have on cach shift a lioonccd sndfiv'iual with proe'iouc startup Or epcrating o~ernc on a comparablo BWVR, or an advicor Who mooets these expcReIcne roqUiromon~ets.

,,-e . ; ... Q *.;- , , 40 - *D# T'"A.,

41, l PII.V (16) IDeleted.J The liccnscc shall orArproct tho-docian doficfioncice forF tho control room. -an ecmplcet thc othcr rclatod oeor goncy rocspensc capabiliticc as rOquirced by

.Att-AchFmont -2to-thir,liconco.

IRenewed License No. NPF-21 -oAm..dmt .19. 67 181

-/- (Pages renumbered)

(17) rQpe,. ti.,v,.:

al -,.-

F..,+d^*at.,GF Heat@nEI (Sectien !5.!. SER) Ieee .

The ,I-c"no s..hall not oporat. with pa... al feodw".A-*a tR....hoRting for tho purpo68 o.

oxNtAending the normnal fuol cyclo unleSS acce~ptable justification i6 provided to wreed app**v*d by NRC staff.

(18) M..,*:f....ff.... e, ^,,t^m a,:e r-, ......... at"e; System Legi ;b..

.,., fe.. ID,eleted. ]

InG;.ase [*..*.Y,,.-,-f;eF ,t"Sem, , ... ,yeni

.8.. o,_,empe, OA.3.1.......Se; 6.311: ER S It;-n"tll mo*edlifications to tho Au,,t,',,"*;tomat DoproSSUrfization System acceptable to tho NRC; (19) Relega,, "; ... ,R. (.

IOed *G.

+R,^., ,8.. , 4 D D # ,4 Delj*-te-d.J Prior to Startup folloWing the firsit refueling outage, the controls and monitofrig MnStrumcnetati9en on the HPCS diesel engine 6kid shall be inctallod in a and monRitoring instrumentation shall be located in a Vibration free floor area or (20)be qualified Ghall E~I,,.i,~ for the vibrations C-~.4,,,, that will occur If,.,, duFrig0~CDQ~engine operation+~Dltd (20) Eimerff cn ;, D ecscl E .Rq!-E Sta,-t*Ra System (Oect~o. . 9 R.5 , SE-R , SSE=R-#4.4 e e ed Prior to-startup following the first refueling outage, air dr,'erS shall beA installed i thc dic*cl cngine air starting systom.

(21) eR.Fe4,,-.R^ -h;,,^.. I.;.,,. ,.'len ( -' .4.

A . r-4 , , 4., g-Deleted.

The lI;e-,n*s shall hae, eperable before May 31, 1981, redundant, seis";

atc*ger, I cnVrenmcntally qualed wate*r hillcrS for c*ontrol room HIAC.

lRenewed License No. NPF-21 I >A.mndmnct Nho. 1*9

-/ (Pages renumbered)

(22) 469RIFE)l bystems 7.74242, 7.5.2.3. bE=:R

[Deleted.J Prior to stakup following the firzit rcfucl n %ol outage, the Iiconzee-shall p~evd e te NRC staff for roviow and approVal n rczolvc the following items.

(c-4 capability to attain a cafe chutdoWn candition following the 1966 of any Glass 1E inetrumon~t bus b+ the impact of control systems failurec rcculting from high onRegy line broakc 9n the tranciont and acdn analycoc wa the imnpact of control cystom failuroc due to- th failure of common poWer Sourcec, Sencere, or intrm ntening lines, On thetanitaaye.

(23)

II J I I*

'4.0..144 S QC-. +A\ FDeleted._

Prior to e.e.eding five (5) percent of rated thorm al powe, .. the .Iceneceha,,

provide for NRC Staff review and approval the rocUlte of the roconciliation of the hydrodynamice leads for all the safety related piping eupent and their Emrqcc n,... ,- ... *"+" 4*32 3~ *= CD 44.1 LDeleted.

(24)

Prior to- eceeding five (5) p*ercet of ratRe'd therFma*"l poWer, fUnRctioally "seeofic traOining in mrec reeponco duties mucet be provided to the remaining USf emfergcncy preparednece training Sp( ci~fied inthe minimum staffing roquiremoB of Table B 1 of NUREG 0654 icld na on Shift and- 3 and- 60Q minute aulgmentation capability)#.

(25) ,-,^,t. ,-.... ... ...

D ..., .e ...,e^+;, . 4,.3 D #4

" UAEiDeleted.1 Prier to exceeding five (6) percen~t of rated- thermal power, the liconcee certif,' to the NRC that:

M4 The dictribution of tenc alert ;aees. which arc part of the'alert and nouictlio--;nR system, has been com~pietepd Wo wWe".nt tnimePiu expourew pathway E~mergency Planning Zonie (E=PZ).

(24 Thedisriutin9f Dublic iGnfration brochuere has bencm Rted to the population Within the plumeB oxpocuro pathway EPZ7.

[Renewed License No. NPF-21

-e- (Pages renumbered)

(26)

In the event that the NRC finds that the lack of prFogres in completion of the prcedures in ORthe Foedoal E-m..rgnc.y Management Agoncy's final rule, "1 C.F.R. Part 350, is an indication that a mnajor substantive probleBm xists in achicving or maintaining ani adequate state of preparodnoss, the provisions of 10 C.F.R. Scctwn 60.54(s)(2) will apply.,

(27) Effler~t Radatfcr..Merwtcrs ($et4en 11.5. 44 E- 4 , IDeleted. ]

Prior to July 1, 1981, the licens;ee 6hall proVide the following inom tiot the NR.C st-aff for their re'-iew4, and approFv.al S. e.*.4-,eR

.,t-,ffy vefthe e *

-Ri,,G.i.

2. Evaluation of response times of those instrumentS.

3. Evlatinf the ins;trumenRAts per criteria cet forth in Section.9 -5.4.7oqf ANISI 4121

4. Com pliance) With Secrtion- 5.14. 9 o-f ANSIS_113.10Q.

6. Evaluation of capability to provide a calibrated electrical signal to verif,' circuit a~gwnment and, ifused, a commFitment, that they be gualifieedd~

(28) ERYOF9AFReAtal QwaI0fieat0Rrn._LQnnfinn. *.11,

'14 SSCp4 Q,-D4) [Deleted. J

& 6 II II 20-9F- W Nevcmacr 30, 1995, theO licensee snail enviFronmentally qualmy all elcctrical equipment aGceFEInQ to thle roFV sions etf 1Q CrFR 50.4 Q.

(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) Additional Conccrns [Deleted.J The Additional Concefrns. R--ont-ained Oi Appendix C, a. revised through Neoth eat shall epcratc thc farsiiity in aeeer-uanco with the :Aoeitienal GenccFRn.

IRenewed License No. NPF-21 I Irq JIZ7

X%_ (Pages renumbered)

(31) Mitigation 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.

(33) Control Room Envelope Habitability Pro-gram (CRE)

Upon implementation of Amendment No. 207 adopting TSTF-448, Revision 3, the determination of CRE unfiltered air inleakage as required byýSR 3.7.3.4, in accordance with TS 5.5.14.c.(i), the assessment of CRE habitability as required by Specification 5.5.14.c.(ii), and the measurement of CRE pressure as required by Specification 5.5.14.d, shall be considered met. Following implementation:

(a) The first performance of SR 3.7.3.4, in accordance with Specification 5.5.14.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.

IRenewed License No. NPF-21 A-A.M R.dmo.nt Noe. 207

->O- (Pages renumbered)

(b) The first performance of the periodic assessment of CRE habitability, Specification 5.5.14.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 5.5.14.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.

D. Exemptions from certain requirements of Appendices G, H and 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 tlli Commission.

E. The licensee shall fully implement and maintain in effect all provisions of the Commission-approved physic Il rity-fhiaA, training and qualification-plaR, and safeguards contingency planrf cluding amendments made pursuant to provisions of the Miscellaneous Amendments and Search Requirements revisions to 10 CFR 73.55 (51 SFR 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".

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.

lRenewed License No. NPF-21 NoýAmeidmcnt No. 216 222

Insert C (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 wedges 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.

-,1< (Pages renumbered)

1. This license is effective as of the date of issuance and shall expire at Midnight on December 20, 202-3.

43]

FOR THE NUCLEAR REGULATORY COMMISSION (Original Signed By)

EricJ. Leeds

....... R. ent , Director

[Enclosures Office of Nuclear Reactor Regulation 1"t.....t.dic~ - -- +---Appendix A Technical Specificationsl

1. AttAnhmet4m I

2. 2 _ -- Appendix B Environmental Protection Plan

3. -A-------n- Apnppendiix C Additional Conditions Date of Issuance: Dcombor 20, 1983 < -- May 22, 2012 IRenewed License No. NPF-21 - Amondmcnt Mo. 149

ATTACHMENT 1 TO OPERATING LICENSE NPF-21 Ill = II I I i I I I flC i:censce cnaii eomDiete tno TOIIOWIfl~3 rcauiremontc witnin ~no ccnoauie notoa Delow:

I

1. PreeiqeratiOnal!Aeeetancee Tects Deleted

a. The l"ecnscc shall, pr*io to eading of fuoel in the coeF8 .6

~, emplcto tho Systom 36 preoporational tcsting to as ;uro that thoso moniAteri required for fuel load fully mooet the l *nnl*l *n*ltl*Tl*n r*l I dl

b. The I;sensoo shall su,,.ssfuIlY Gcmpioto tne ;olloWing Pepropoation~awaccoptance tests bcforc cxcccding 5% power:

PT- 33. 2 BR homicsal Waste Perocssring PT- 37.0 D) Miscollancous Radiation Moni4toFrig E~quipm:ent PT 4 0. 0 A. O Gar, m System AT 65.0 A Scaling Steam System AT 66.0 A Condensor Air Removal PT 69.0 A Condensato System PT-70.0 A Condonsato Storago TrFansfcr PT-71.0 A Condensato Filtor Doinor*ealizor S~ystom PT-72.0 A Reactor Fecdwater T-urbinc and Pumps PT-72.0 B RcateFo Fccdwatcr Controls AT 74.0 A Heater Vents and Drains AT 82.0 A Turbine Building Hcating a*d Ventilating PT 02.0 A Off Gas Vault HVAC AT 110.0 A Loosce Pan_ s DotocAtin PTT 201.0 A Pnitrat Containmontr ntegrated Leakage Rate Test AT 3-02.0- A Intoapratod- U Condonoer- nRLoakaco 0 Tost G. The liconsee9 shall com~plote PT- 22.0 B,Nitrc gn... e.tOn. SySteM pr'ior to 9.. Monthl.

after initial criticality.

2. HaneeFs Sweeeks, and. Reesstwa.Rts Ail Q 6S1 *and i ll SI haniger, suDDorts. ana rostraints nooaina instatiatien ana:or medification Will be e.mplet, 0 prier to exceeding 6% peweF.

3. GeRStFuetwen GemplefieR (MasteF Gemeleteefl Ust Sehedul The li~eonoo Shall restrain; fuol loading, prim~ar, syStemR steam pressurization, oxcooding 5 power, and commercial .pe-atien* by prerequi.ite complotion of the asociated categoFio of itom in accrdanco with the schedule ,hoWn on the Project Master Completi* o List dated Dnec.mbe 19, 1983. The licensee shall not eXtn4d the completioR catego*ries for ndividual items oe the liSt without prior noti+*cation aRnd. i*dWid al ccurrence by a rFe.rsentativ- of the NRC Reeginal Office.

lemRciBGal operation i, defined ai the 10*% pGowr warr*nt-y ru OFrJlyh 1, 1084. whiGehvo occurs firsit.

Amendment No. 457- 223 (strikeout amendment number)

ATTACHMENT 2 IDeleted The liensec shall coml.-leto the folloRwing reewuiromnets on the scahoduwlo Rnotod bolW:I

1. weta'jeel G8RtF9l Rey*ew (1)

The lieansoo shall Gubmit a program' plan for DCRDPR fo-r NIRC staff rwgeview wvithin two (2) monRths aftor the i~ssanco of this operating liencse and a summFar,' repot not l-ater than crix to) m8nTnt PriOr te tnh IFr*t rFI11ng OUtag1.

The licensee shall correct a*nd mpleme,Atto the NRC staffs sa tisfaGctin, the following hu'man engineering deficiencie prior to e xco"ding fiVe (*) percent of rate"d th.rmal p JWeVi=

norperative Systemn Status Panels P----GSe .ngatv RtFrwt Multiple meaning abbrcviatiens, lack of abbreviation control Hard tc eperatc pushbuttons on controllers P6.40 Non s~tandard fuiel zoene mon~itor mseter scale, -p 04-9D-644 Idcntical push butteninonpush button status ~ghts, P 829 P9-464 Identical push button/push button indicater lights, Red Werth Minimlzer, Rod Monitor control Sbpael. , P 603 lnadcguate labeling, Isolation Control, P 601 Nen identical RFW meter greupings for Systems A & 8, P 840 F 5 fi Inonsistent scales, CW Ine Plenu Loever Indicator and Coroller, P 810 F= 6.6 Recorder pointe-rsF obcresale numerFals/graduationR marks-F-. 37 R12V doprossurization procedures, call for greater reading accur~acy than i r ...............

surU, nai,*catoer SWitcn anaR~los 9196cUre pGltercAllaelG, -' WUU The Icensee., shall err,"ect and iR ,,plemnt to the N'RC staffs sa*.ia th foin;-g Rg human engineering deflicineies Within four (4) moenths after the isuneof this operating leeensee i~weic warmff signan eeteetion nae D4.~22 valv-e cntrols. P 820 ID6.49 PDepe- chart paper ter ~nerato i I I I I I Monitor +emperature Recorder. P 5320 E 3.7A4 Extension handle for RPS reset switch, P1603 F-6 A4:2 Inc...onsi.ten.t fonts, switch e. heon legends Incons~istent pushbutton color coding ll IP*

WED. ',nina iAentmAPOn -AS .. gven i N ioner to . IN. azrated 9.:02U/!2.

IAmendment No. 162 223 I (strikeout amendment numbers)

,AttaehRmeRt a

- ReEiwlateFy Gu*de 1.97. Reymsffien 2 Gemol*anee The lic*... shall implement (in"tallation or Upgrad. ) reqrirem n*t.of Rogulator; Guide 1..7* RoVi.ion 2 with the ex..eption of itoem (b) and (G)below priorFt startup fllowing the fire*t rofu'-linF *utage.

(b+ Deleted.

() The lireoneep shall imlmn icallad have oporatienal) a wide range

epool lBeol mGon~itrig system Which sa-tisfiecr- the Gatego~' 1 equipment

.upr ccficatfionc in accr9dRance with Rogulater~' Guide 1.9ig7, Rovision 2, prior to Gtadup fellowinG the Aocond refuelingR outRAg A

4. WeEvade EFRefeeney QveFatiRa PFesedUFes (1==OPs)

The licensec shall provide within Me(2) months after the iscuance of thiseoperating licence-,

an addendum to the Procedure. GenRa...t.en Package d"-",icriing the functien and taRk analyi"* arc idcnt"fed in Supplement 1 Ut NUREG 0737.

The i~Vepsee ,ha, ha; e fully f*, GtGal or :A9FQ9AGu , ,v F96MGR69 familkies !T-9GhR*Gal SW=94 GeRte F,\ Q,., 'atienal Support Center, and lergencY Operatiens Facility) pFri*r te exeediRg J:~jI:L ul IJLIIU UU'~U[.

Amendment No. 60, 462

ATTACHMENT 3 LIST OF SHIELD WALLS

1.*-' , OriAD *;,.

F,,,,.Zen, ,t)

,_12 1, '),'j) 7

U A'

.. k tubhneI pamal the,, the eRieqt-Wall outeid. Sp.t o.in tank D..eleted.

Feeff.

12. S al:--',-" ; 4"2. 26. ,-,,- G 4"2 rThe a+c..e. . w. l the mtin toa{ .... .A . ueletea. I

!-3. FSAR

.* OU.*123 27, Zeno*. 11,, SaMe a6 ab, onlY other end Of cvndeGe,* . tDeleted.

!4. FSAR F0*W~e-42.3 34. Zone H 8- The aecoecFG blcotet the epare deFnineraliZerDe Tte-d.-

{bee The access blockout to

- 5* FSAR Figure 12.3-33, Zone G af.a....... the duplicate centrifuge room.

- 6. FSAR Fiqure 12.3-33, Zone F Same as above for the duplicate centrifuge.

- 7* FSAR Figure 12.3-34, Zone J The blockout for one of the two decon concentrators.

- 8. FSAR Figure 12.3-32, Zone D The two block walls at the north end of the truck loading bay.

- 9. FSAR Figure 12.3-32, Zone E The leaded glass viewing window in the radwaste area.

Itcms 1, 2, and 4 will be installed Pri8r tG one year after the issuanco of tho WNP L2 Operating Lieensc.

Shield walls and window identified in items 3-,5, 6, 7, 8, and 9 will be installed if the associated radiation levels at these locations exceed 2.5mR/hr as dictated by the ongoing ALARA reviews.

Amendment No. 7 223 (strikeout amendment number)

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 R eview a nd A ud it............................................................................................................ 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.67-469

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 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 [in .a..rdanc. with 10 G--CFR P51.o (3) a matter, not previously reviewed and evaluated in the documents specified in (1) of thisSubsection, which may have a significant adverse environmental impact.

3-1 [Amendment No. 223 (strikeout amendment number)

Insert D 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 unreviewed 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.

APPENDIX C AD DITIO.'AL CONDITIONS FACILITY OPER.A-TIN".G LICENSE ,NO. NPF 21 r-_ _ _

scnoauls neted ERelew:

I .__*LL LL_ EII_ *__ J L LL _ L J I _ _L--J L I IML ncrgy NR~RtWc~t SRRII -- Mpiy- -ii inc on 66Riiewing eootin Am~eRdmven4 lmpemfeRtatieR NumbeF Bete r;,---

I m F I,e~t;tn ' -m-*,,

44-9 The icensee shall relocate eekaffintchca Impbe 'ont -t-sh.all spcsfification rcguircments to liecnsee conrolle8d docUmoents as desc-rribhed- belo Jun. 30, 197 The location of theso reguiremon~ts shall be rotainod by the licensee a-. T-h~r: ioenee eondition approees the SP9,,,41ati*. r*,-, remonts to liconsee con)trolled- docu-i-mentis (e.g., UFSAR, LCS, etc.), as deGscrbed- in Attac*hmenRt to the liconsee's letter datcd January 14, 190:7. The approval is doeumentcd in the staffLs safty cvaluaticn dated MarC-4h, i 99:7 449 Rcgulato*r Guide 1.160 commitments as Implementation shall described inOAttachment I ttoathe7licensee' letter dated January 14, 1907. days from the date Amendment 449.

4&4- To9 ensure SUfficiently coneRveative SPC OXO Implementation shall hOLACPRs, the calculatin of ACPR wvill b8 com~pleted prier include a censeroativo adde~r bhasedd nonth to eXCeeding 25%

variability .b.e.vcdin the. .6A ;.. pereF for Cycle 13.

-'mparisonwth the A^F'B correlation. TChis, adeilbe at a ROOminmu, the greater. of WFA times the standard deviation in the mean error ef the predictions relative to the calculated matrix( values, or a factor Of 0.976 applied to the .ACPR calculation, and- will be-independent of the Q-9 faster included in the USO6A7- coreato as aconervative bias to the USO96A7 predictions of CPR for the SPG fuel.

Amendment No. )1 223 (strikeout amendment number)

ImpeRmeRtatie4 Nuffbef Date 4-5a This amendment aulthorizc the licensec to 90 days fF IM.he aincorportc in the Final Safety Analysis

+ir~~I ACenIi+I date of Iscuanco.

Roport (ESAR) cortain changoc,tot oh dczcriptian ef the facility. lmplcmcntation oef thus amc~dndent is the incorporation of these changes as dcccribod in the Iiccncoc'c application dated April 14,10908, as supplomontod by loftrem dated April 28, 1998, and May 8,10989, and ovaluHato-d inp tho staff-s Saf*~ E~valua-tion d-atedG- May 24, 1908.

4-.5 TWAc AModIMont ic coditioned on tho) Refueling Outage R-14.

rcgarding inpcinof EGGS cUPProccion pool scrocn m~aterial coupoeR as doecribod i the lIcesne-e' suppl-mRntal Il*lFr dated April 28,1998, and 1 yaluatcd in the staffI S1ety Evaluation dated May 21, 1098.

A .RnndmC.t NAo. 153

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION FOR LICENSE AMENDMENT REQUEST TO MAKE ADMINISTRATIVE AND EDITORIAL CHANGES TO TECHNICAL SPECIFICATIONS AND THE OPERATING LICENSE REVISED OPERATING LICENSE (CLEAN)

ENERGY NORTHWEST DOCKET NO. 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.D. 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.D. 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

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

1. 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) Pursuant to 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

(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

(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

(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

(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) Mitiqation 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

(33) Control Room Envelope Habitability Pro-ram (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 5.5.14.c.(i), the assessment of CRE habitability as required by Specification 5.5.14.c.(ii), and the measurement of CRE pressure as required by Specification 5.5.14.d, shall be considered met. Following implementation:

(a) The first performance of SR 3.7.3.4, in accordance with Specification 5.5.14.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 ifthe 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 5.5.14.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 5.5.14.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

(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 wedges 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

D. Exemptions from certain requirements of Appendices G, H and 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."

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

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

FOR THE NUCLEAR REGULATORY COMMISSION (Original Signed By)

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 4-5 22-3

ATTACHMENT 2 Deleted Amendment No. 462 223

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 D 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 2.5mR/hr as dictated by the ongoing ALARA reviews.

Amendment 7 22-

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 ................... 3-2 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. 4-7 469

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 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 unreviewed 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.

3-1 Amendment No. 22-

APPENDIX C Deleted Amendment No.45-722

v t e Letter Sequence Response to RAI
TAC:ME7904, Control Room Habitability (Approved, Closed)
Initiation Request, Request Acceptance Administration Questions 2 July 2012 Answers 30 July 2012 Results Approval, Approval Other:
MONTHYEAR2012-07-02 [Table View]

GO2-12-104, Response to Request for Additional Information for License Amendment Request to Make Administrative and Editorial Changes to Technical Specifications and the Operating License

Text

Subject:

References:

Dear Sir or Madam:

Enclosure:

Enclosures:

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