ML103140657: Difference between revisions
StriderTol (talk | contribs) (Created page by program invented by StriderTol) |
StriderTol (talk | contribs) (Created page by program invented by StriderTol) |
||
| Line 18: | Line 18: | ||
=Text= | =Text= | ||
{{#Wiki_filter:UNITED NUCLEAR REGULATORY WASHINGTON, D.C. 20555*0001 January 31, 2011 Mr. David A. Heacock President and Chief Nuclear Officer Virginia Electric and Power Company Innsbrook Technical Center 5000 Dominion Boulevard Glen Allen, VA 23060-6711 NORTH ANNA POWER STATION, UNIT NOS. 1 AND 2,ISSUANCE OF AMENDMENTS TO ADOPT TECHNICAL SPECIFICATION TASK FORCE (TSTF)-425, REVISION 3, FOR THE RELOCATION OF SPECIFIC SURVEILLANCE FREQUENCY REQUIREMENTS TO A LICENSEE CONTROLLED PROGRAM (TAC NOS. ME3689 AND ME3690) | {{#Wiki_filter:UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555*0001 January 31, 2011 Mr. David A. Heacock President and Chief Nuclear Officer Virginia Electric and Power Company Innsbrook Technical Center 5000 Dominion Boulevard Glen Allen, VA 23060-6711 | ||
==SUBJECT:== | |||
NORTH ANNA POWER STATION, UNIT NOS. 1 AND 2,ISSUANCE OF AMENDMENTS TO ADOPT TECHNICAL SPECIFICATION TASK FORCE (TSTF)-425, REVISION 3, FOR THE RELOCATION OF SPECIFIC SURVEILLANCE FREQUENCY REQUIREMENTS TO A LICENSEE CONTROLLED PROGRAM (TAC NOS. ME3689 AND ME3690) | |||
==Dear Mr. Heacock:== | ==Dear Mr. Heacock:== | ||
The U.S. Nuclear Regulatory Commission (NRC, the Commission) has issued the enclosed Amendment Nos. 262 and 243 to Renewed Facility Operating License Nos. NPF-4 and NPF-7 for the North Anna Power Station, Unit Nos. 1 and 2. The amendment consists of changes to the Technical Specifications (TSs) in response to your application dated March 30, 2010, as supplemented by letters dated August 30, 2010 and January 18, 2011. The amendments revise the TSs by relocating specific surveillance frequencies to a licensee-controlled program with the implementation of Nuclear Energy Institute 04-10, "Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies." The changes are consistent with NRC-approved Industry Technical Specification Task Force (TSTF) Standard Technical Specifications change TSTF-425, Revision 3. | |||
D. Heacock -A copy of our related safety evaluation is also enclosed. | The U.S. Nuclear Regulatory Commission (NRC, the Commission) has issued the enclosed Amendment Nos. 262 and 243 to Renewed Facility Operating License Nos. NPF-4 and NPF-7 for the North Anna Power Station, Unit Nos. 1 and 2. The amendment consists of changes to the Technical Specifications (TSs) in response to your application dated March 30, 2010, as supplemented by letters dated August 30, 2010 and January 18, 2011. | ||
The Notice of Issuance will be included in the Commission's biweekly Federal Register notice. Sincerely, r. V. Sreenivas, Project Plant Licensing Branch Division of Operating Reactor Office of Nuclear Reactor Docket Nos. 50-338 and | The amendments revise the TSs by relocating specific surveillance frequencies to a licensee-controlled program with the implementation of Nuclear Energy Institute 04-10, "Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies." The changes are consistent with NRC-approved Industry Technical Specification Task Force (TSTF) Standard Technical Specifications change TSTF-425, Revision 3. | ||
D. Heacock - 2 A copy of our related safety evaluation is also enclosed. The Notice of Issuance will be included in the Commission's biweekly Federal Register notice. | |||
Sincerely, | |||
: r. V. Sreenivas, Project Manager Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket Nos. 50-338 and 50-339 | |||
==Enclosures:== | ==Enclosures:== | ||
: 1. Amendment No. 262 to 2. Amendment No. 243 to 3. Safety Evaluation cc w/encls: Distribution via Listserv UNITED NUCLEAR REGULATORY WASHINGTON, D.C. 20555-0001 VIRGINIA ELECTRIC AND POWER DOCKET NO. NORTH ANNA POWER STATION. UNIT AMENDMENT TO RENEWED FACILITY OPERATING Amendment No. 262 Renewed License No. NPF-4 The Nuclear Regulatory Commission (the Commission) has found that: The application for amendment by Virginia Electric and Power Company et al.. (the licensee) dated March 30,2010, as supplemented by letters dated August 30,2010 and January 18, 2011, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations set forth in 10 CFR Chapter I; The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; There is reasonable assurance (i) that the activities authorized by this amendment 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; The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied. | : 1. Amendment No. 262 to NPF-4 | ||
-2 Accordingly, the license is amended by changes to paragraph 2.C.(2) of Renewed Facility Operating License No. NPF-4, as indicated in the attachment to this license amendment, and is hereby amended to read as follows: Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 262, are hereby incorporated in the renewed license. The licensee shall operate the facility in accordance with the Technical Specifications. This license amendment is effective as of its date of issuance and shall be implemented within 180 days of issuance. | : 2. Amendment No. 243 to NPF-7 | ||
FOR THE NUCLEAR REGULATORY COMMISSION Gloria Kulesa, Chief Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation | : 3. Safety Evaluation cc w/encls: Distribution via Listserv | ||
UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 VIRGINIA ELECTRIC AND POWER COMPANY DOCKET NO. 50-338 NORTH ANNA POWER STATION. UNIT NO.1 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 262 Renewed License No. NPF-4 | |||
: 1. The Nuclear Regulatory Commission (the Commission) has found that: | |||
A. The application for amendment by Virginia Electric and Power Company et al.. (the licensee) dated March 30,2010, as supplemented by letters dated August 30,2010 and January 18, 2011, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations set forth in 10 CFR Chapter I; B. The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C. There is reasonable assurance (i) that the activities authorized by this amendment 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; D. The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E. The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied. | |||
-2 | |||
: 2. Accordingly, the license is amended by changes to paragraph 2.C.(2) of Renewed Facility Operating License No. NPF-4, as indicated in the attachment to this license amendment, and is hereby amended to read as follows: | |||
(2) Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 262, are hereby incorporated in the renewed license. The licensee shall operate the facility in accordance with the Technical Specifications. | |||
: 3. This license amendment is effective as of its date of issuance and shall be implemented within 180 days of issuance. | |||
FOR THE NUCLEAR REGULATORY COMMISSION Gloria Kulesa, Chief Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation | |||
==Attachment:== | ==Attachment:== | ||
Changes to License No. NPF-4 and the Technical Specifications Date of Issuance: | Changes to License No. NPF-4 and the Technical Specifications Date of Issuance: January 31, 2011 | ||
January 31, 2011 UNITED NUCLEAR REGULATORY WASHINGTON, D.C. 20555-0001 VIRGINIA ELECTRIC AND POWER DOCKET NO. NORTH ANNA POWER STATION, UNIT AMENDMENT TO RENEWED FACILITY OPERATING Amendment No. 243 Renewed License No. 7 The Nuclear Regulatory Commission (the Commission) has found that: The application for amendment by Virginia Electric and Power Company et al.. (the licensee) dated March 30,2010, as supplemented by letters dated August 30 and January 18. 2010. complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act). and the Commission's rules and regulations set forth in 10 CFR Chapter I; The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; There is reasonable assurance (i) that the activities authorized by this amendment 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; The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied. | |||
-2 Accordingly, the license is amended by changes to paragraph 2.C.(2) of Renewed Facility Operating License No. NPF-7, as indicated in the attachment to this license amendment, and is hereby amended to read as follows: Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 243, are hereby incorporated in the renewed license. The licensee shall operate the facility in accordance with the Technical Specifications. This license amendment is effective as of its date of issuance and shall be implemented within 180 days of issuance. | UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 VIRGINIA ELECTRIC AND POWER COMPANY DOCKET NO. 50-339 NORTH ANNA POWER STATION, UNIT NO.2 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 243 Renewed License No. NPF~ 7 | ||
FOR THE NUCLEAR REGULATORY COMMISSION Gloria Kulesa, Chief Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation | : 1. The Nuclear Regulatory Commission (the Commission) has found that: | ||
A. The application for amendment by Virginia Electric and Power Company et al.. (the licensee) dated March 30,2010, as supplemented by letters dated August 30 and January 18. 2010. complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act). and the Commission's rules and regulations set forth in 10 CFR Chapter I; B. The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C. There is reasonable assurance (i) that the activities authorized by this amendment 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; D. The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E. The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied. | |||
-2 | |||
: 2. Accordingly, the license is amended by changes to paragraph 2.C.(2) of Renewed Facility Operating License No. NPF-7, as indicated in the attachment to this license amendment, and is hereby amended to read as follows: | |||
(2) Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 243, are hereby incorporated in the renewed license. The licensee shall operate the facility in accordance with the Technical Specifications. | |||
: 3. This license amendment is effective as of its date of issuance and shall be implemented within 180 days of issuance. | |||
FOR THE NUCLEAR REGULATORY COMMISSION Gloria Kulesa, Chief Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation | |||
==Attachment:== | ==Attachment:== | ||
Changes to License No. NPF-7 and the Technical Specifications Date of Issuance: | Changes to License No. NPF-7 and the Technical Specifications Date of Issuance: January 31,2011 | ||
January 31,2011 ATTACHMENT TO LICENSE AMENDMENT NO. 262 RENEWED FACILITY OPERATING LICENSE NO. NPF-4 DOCKET NO. 50-338 AND TO LICENSE AMENDMENT NO. 243 RENEWED FACILITY OPERATING LICENSE NO. NPF-7 DOCKET NO. 50-339 Replace the following pages of the Licenses and the Appendix "A" Technical Specifications (TSs) with the enclosed pages as indicated. | |||
The revised pages are identified by amendment number and contain vertical lines indicating the areas of change. Remove Pages Insert Pages Licenses Licenses License No. NPF-4, page 3 License No. NPF-4, page 3 License No. NPF-7, page 3 License No. NPF-7, page 3 3.1.1-1 3.1.1-1 3,1.2-2 3.1.2-2 3.1.4-3 3.1.4-3 3.1.5-2 3.1.5-2 3.1.6-3 3.1.6-3 3.1,7-3 3.1.7-3 3.1.9-2 3.1.9-2 3.2.1-3 3.2.1-3 3.2.2-2 3.2.2-2 3.2.3-1 3.2.3-1 3.2.4-3 3.2.4-3 3.2.4-4 3.2.4-4 3.3.1-8 3.3.1-8 3.3.1-9 3.3.1-9 3.3.1-10 3.3.1-10 3.3.1-11 3.3.1-11 3.3.1-12 3.3.1-12 3.3.2-5 3.3.2-5 3.3.2-6 3.3.2-6 3.3.2-7 3.3.2-7 3.3.3-2 3.3.4-1 3.3.4- | ATTACHMENT TO LICENSE AMENDMENT NO. 262 RENEWED FACILITY OPERATING LICENSE NO. NPF-4 DOCKET NO. 50-338 AND TO LICENSE AMENDMENT NO. 243 RENEWED FACILITY OPERATING LICENSE NO. NPF-7 DOCKET NO. 50-339 Replace the following pages of the Licenses and the Appendix "A" Technical Specifications (TSs) with the enclosed pages as indicated. The revised pages are identified by amendment number and contain vertical lines indicating the areas of change. | ||
-3 3.7.5-4 3.7.6-1 3.7.6-1 3.7.7-1 3.7.7-1 3.7.8-3 3.7.8-3 3.7.8-4 3.7.9-1 3.7.9-1 3.7.10-3 3.7.10-3 3.7.11-2 3.7.11-2 3.7.12-4 3.7.12-4 3.7.12-5 3.7.12-5 3.7.15-1 3.7.15-1 3.7.16-1 3.7.16-1 3.7.17-1 3.7.17-1 3.7.19-2 3.7.19-2 3.8.1-8 3.8.1-8 3.8.1-9 3.8.1-9 3.8.1-10 3.8.1-10 3.8.1-11 3.8.1-11 3.8.1-12 3.8.1-12 3.8.1-13 3.8.1-13 3.8.1-14 3.8.1-14 3.8.1-15 3.8.1-15 3.8.1-16 3.8.1-16 3.8.1-17 3.8.1-17 3.8.1-18 3.8.1-18 3.8.1-19 3.8.3-3 3.8.3-3 3.8.4-2 3.8.4-2 3.8.4-3 3.8.4-3 3.8.4-4 3.8.4-4 3.8.4-5 3.8.6-2 3.8.6-2 3.8.6-3 3.8.6-3 3.8.7-2 3.8.7-2 3.8.8-2 3.8.8-2 3.8.9-3 3.8.9-3 3.8.10-2 3.8.10-2 3.9.1-1 3.9.1-1 3.9.3-2 3.9.3-2 3.9.4-2 3.9.4-2 3.9.5-2 3.9.5-2 3.9.6-3 3.9.6-3 3.9.7-1 3.9.7-1 5.5-17 5.5-17 | Remove Pages Insert Pages Licenses Licenses License No. NPF-4, page 3 License No. NPF-4, page 3 License No. NPF-7, page 3 License No. NPF-7, page 3 3.1.1-1 3.1.1-1 3,1.2-2 3.1.2-2 3.1.4-3 3.1.4-3 3.1.5-2 3.1.5-2 3.1.6-3 3.1.6-3 3.1,7-3 3.1.7-3 3.1.9-2 3.1.9-2 3.2.1-3 3.2.1-3 3.2.2-2 3.2.2-2 3.2.3-1 3.2.3-1 3.2.4-3 3.2.4-3 3.2.4-4 3.2.4-4 3.3.1-8 3.3.1-8 3.3.1-9 3.3.1-9 3.3.1-10 3.3.1-10 3.3.1-11 3.3.1-11 3.3.1-12 3.3.1-12 3.3.2-5 3.3.2-5 3.3.2-6 3.3.2-6 3.3.2-7 3.3.2-7 | ||
*3* Pursuant to the Act and 10 CFR Part 70, VEPCa 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 Updated Final Safety Analysis Report; Pursuant to the Act and 10 CFR Parts 30, 40, and 70, VEPCO 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; Pursuant to the Act and 10 CFR Parts 30.40, and 70, VEPCO to receive, possess, and use in amounts as required any byproduct, source, or special nuclear material, without restriction to chemical or physical form, for sample analysis or instrument calibration or associated with radioactive apparatus or component; and Pursuant to the Act and 10 CFR Parts 30 and 70, VEPCO to possess, but not separate, such byproduct and special nuclear materials as may be produced by the operation of the faCility. This renewed operating license shall be deemed to contain and is subject to the conditions specified in the following Commission regulations in 10 CFR Chapter I: Part 20, Section 30.34 of Part 30, Section 40.41 of Part 40, Sections SO.54 and 50.59 of Part 50, and Section 70.32 of Part 70; 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: Maximum Power Level VEPCO is authorized to operate the North Anna Power Station, Unit NO.1, at reactor core power levels not in excess of 2940 megawatts (thermal). Technical Specifications The Technical Sl'1l"lr.ificatlons contained in Appendix A, as revised through Amendment No.262 hereby incorporated in the renewed license. The licensee shall operate the facility in accordance with the Technical SpeCifications. | -2 3.3.3-2 3.3.3-2 3.3.4-1 3.3.4-1 3.3.4-2 3.3.4-2 3.3.5-2 3.3.5-2 3.3.5-3 3.3.6-2 3.3.6-2 3.4.1-2 3.4.1-2 3.4.2-1 3.4.2-1 3.4.3-2 3.4.3-2 3.4.4-1 3.4.4-1 3.4.5-2 3.4.5-2 3.4.5-3 3.4.6-2 3.4.6-2 3.4.7-3 3.4.7-3 3.4.8-2 3.4.8-2 3.4.9-2 3.4.9-2 3.4.11-3 3.4.11-3 3.4.11-4 3.4.11-4 3.4.12-3 3.4.12-3 3.4.12-4 3.4.12-4 3.4.13-2 3.4.13-2 3.4.14-2 3.4.14-2 3.4.15-3 3.4.15-3 3.4.16-2 3.4.16-2 3.4.17-2 3.4.17-2 3.4.19-1 3.4.19-1 3.5.1-2 3.5.1-2 3.5.2-2 3.5.2-2 3.5.2-3 3.5.2-3 3.5.4-2 3.5.4-2 3.5.5-2 3.5.5-2 3.5.6-2 3.5.6-2 3.6.2-5 3.6.2-5 3.6.3-5 3.6.3-5 3.6.3-6 3.6.3-6 3.6.4-1 3.6.4-1 3.6.5-1 3.6.5-1 3.6.6-1 3.6.6-1 3.6.6-2 3.6.6-2 3.6.7-2 3.6.7-2 3.6.7-3 3.6.7-3 3.6.8-1 3.6.8-1 3.6.8-2 3.6.8-2 3.7.2-2 3.7.2-2 3.7.3-2 3.7.3-2 3.7.4-1 3.7.4-1 3.7.4-2 3.7.5-2 3.7.5-2 3.7.5-3 3.7.5-3 | ||
Renewed License /\In. NPF*4 | |||
-3 3.7.5-4 3.7.6-1 3.7.6-1 3.7.7-1 3.7.7-1 3.7.8-3 3.7.8-3 3.7.8-4 3.7.9-1 3.7.9-1 3.7.10-3 3.7.10-3 3.7.11-2 3.7.11-2 3.7.12-4 3.7.12-4 3.7.12-5 3.7.12-5 3.7.15-1 3.7.15-1 3.7.16-1 3.7.16-1 3.7.17-1 3.7.17-1 3.7.19-2 3.7.19-2 3.8.1-8 3.8.1-8 3.8.1-9 3.8.1-9 3.8.1-10 3.8.1-10 3.8.1-11 3.8.1-11 3.8.1-12 3.8.1-12 3.8.1-13 3.8.1-13 3.8.1-14 3.8.1-14 3.8.1-15 3.8.1-15 3.8.1-16 3.8.1-16 3.8.1-17 3.8.1-17 3.8.1-18 3.8.1-18 3.8.1-19 3.8.3-3 3.8.3-3 3.8.4-2 3.8.4-2 3.8.4-3 3.8.4-3 3.8.4-4 3.8.4-4 3.8.4-5 3.8.6-2 3.8.6-2 3.8.6-3 3.8.6-3 3.8.7-2 3.8.7-2 3.8.8-2 3.8.8-2 3.8.9-3 3.8.9-3 3.8.10-2 3.8.10-2 3.9.1-1 3.9.1-1 3.9.3-2 3.9.3-2 3.9.4-2 3.9.4-2 3.9.5-2 3.9.5-2 3.9.6-3 3.9.6-3 3.9.7-1 3.9.7-1 5.5-17 5.5-17 | |||
The removal of these conditions shall be made by an amendment to the renewed license supported by a favorable evaluation by the Commission: If VEPCO plans to remove or to make significant changes in the normal operation of equipment that controls the amount of radioactivity in eftluents from the North Anna Power Station. the Renewed License No. NPF*7 | |||
MODE 2 with keff < 1.0, MODES 3, 4, and 5. ACTIONS CONDITION REQU | *3* | ||
The predicted reactivity values may be adjusted (normalized) to correspond to the measured core reactivity prior to exceeding a fuel burnup of 60 effective full power days (EFPD) after each fuel loading. Verify measured core reactivity is within +/- 1% Ak/k of predicted values. | (2) Pursuant to the Act and 10 CFR Part 70, VEPCa 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 Updated Final Safety Analysis Report; (3) Pursuant to the Act and 10 CFR Parts 30, 40, and 70, VEPCO 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, VEPCO to receive, possess, and use in amounts as required any byproduct, source, or special nuclear material, without restriction to chemical or physical form, for sample analysis or instrument calibration or associated with radioactive apparatus or component; and (5) Pursuant to the Act and 10 CFR Parts 30 and 70, VEPCO to possess, but not separate, such byproduct and special nuclear materials as may be produced by the operation of the faCility. | ||
C. This renewed operating license shall be deemed to contain and is subject to the conditions specified in the following Commission regulations in 10 CFR Chapter I: | |||
Part 20, Section 30.34 of Part 30, Section 40.41 of Part 40, Sections SO.54 and 50.59 of Part 50, and Section 70.32 of Part 70; 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 VEPCO is authorized to operate the North Anna Power Station, Unit NO.1, at reactor core power levels not in excess of 2940 megawatts (thermal). | |||
AND Each control and shutdown rod within limits of LCO 3.1.4. AND Each control bank within the insertion limits of LCO 3.1.6. | (2) Technical Specifications The Technical Sl'1l"lr.ificatlons contained in Appendix A, as revised through Amendment No.262 ~e hereby incorporated in the renewed license. The licensee shall operate the facility in accordance with the Technical SpeCifications. | ||
NORTH ANNA | |||
Verify the most withdrawn rod and the least withdrawn rod of the affected banks are s 12 steps apart. Reduce THERMAL POWER to S 50% RTP. | * UNIT 1 Renewed License /\In. NPF*4 Amendment NOQ 262 | ||
Verify is within limit. | |||
Once after each refueling prior to THERMAL POWER exceeding 75% RTP AND Once within 12 hours after achieving equilibrium conditions after exceeding, by 10% RTP. the THERMAL POWER at whi ch (Z) was last verified AND In accordance with the Surveillance Frequency Control Program North Anna Units 1 and 2 Amendments 262 and 243 N FAH 3.2.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) | -3 (3) Pursuant to the Act and 10 CFR Parts 30, 40, and 70. VEPCa 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, VEPCa to receive, possess, and use in amounts as required any byproduct, source, or 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, VEPCa to possess, but not separate, such byproduct and special nuclear materials as may be produced by the operation of the facility, C. This renewed license shall be deemed to contain and is subject to the conditions specified in the Commission's regulations as set forth in 10 CFR Chapter! and Is subject to all applicable provisions 01 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: | ||
A.4 THERMAL POWER does not have to be reduced to comply with this Required Action. | (1) Maximum Power Level VEPca is authorized to operate the facility at steady state reactor core power levels not in excess of 2940 megawatts (thermal). | ||
(2) Technical Specifications The Technical Sper,ifications contained in Appendix A, as revised through Amendment No.243 are hereby incorporated In the renewed license. The licensee shall operate the facility in accordance with the Technical Specifications. | |||
(3) Additional Conditions The matters speciiied in the following conditions shall be completed to the satisfaction of the Commission within the stated time periods following the issuance of the condition or within the operational restrictions indicated. The removal of these conditions shall be made by an amendment to the renewed license supported by a favorable evaluation by the Commission: | |||
NOTE ---------The AFD shall be considered outside limits when two or more OPERABLE excore channels indicate AFD to be outside limits. | : a. If VEPCO plans to remove or to make significant changes in the normal operation of equipment that controls the amount of radioactivity in eftluents from the North Anna Power Station. the NORTH ANNA* UNIT 2 Renewed License No. NPF*7 Hla1dre1t ~. 243 | ||
MODE I with THERMAL POWER 50% RTP. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. AFD not within limits. A.I Reduce THERMAL POWER to < 50% RTP. | |||
SDM 3.1.1 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM) | |||
A.6 | LCO 3.1.1 SDM shall be within the limits provided in the COLR. | ||
APPLICABILITY: MODE 2 with keff < 1.0, MODES 3, 4, and 5. | |||
ACTIONS CONDITION REQU IRED ACTI ON COMPLETION TIME A. SDM not within limit. A.l Initiate boration to 15 minutes restore SDM to within 1imit. | |||
Verify QPTR is within limit by | SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.1.1 Verify SDM to be within limits. In accordance with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.1.1-1 Amendments262 and 243 | ||
In accordance with the Survei 11 ance Frequency Control Program North Anna Units 1 and 2 3.2.4-3 Amendments 262 and 243 QPTR 3.2.4 SURVEILLANCE REQUIREMENTS SR Not required to be performed until 12 hours after input from one or more Power Range Neutron Flux channels are inoperable with THERMAL POWER > 75% RTP. Verify QPTR is within limit using the | |||
Core Reactivity 3.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1. 2.1 -------------------NOTE------------------- | |||
channels R.1 | The predicted reactivity values may be adjusted (normalized) to correspond to the measured core reactivity prior to exceeding a fuel burnup of 60 effective full power days (EFPD) after each fuel loading. | ||
;s in required state for existing unit conditions. | Verify measured core reactivity is within Once prior to | ||
Be in MODE 2. | +/- 1% Ak/k of predicted values. entering MODE 1 after each refueling AND | ||
NOTE -------Refer to Table 3.3.1-1 to determine which SRs apply for each RTS SURVEILLANCE FREQUENCY SR 3.3.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.1.2 Not required to be performed until 12 hours after THERMAL POWER is 15% RTP. Compare results of calorimetric heat balance calculation to power range channel Adjust power range output if calorimetric heat balance calculation result exceeds power range channel output by more than +2% RTP. | -----NOTE----- | ||
Perform TADOT. In accordance with the Survei11ance Frequency Control Program North Anna Units 1 and 2 3.3.1-9 Amendments 262 and 243 RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.7 | Only required after 60 EFPD In accordance with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.1.2-2 Amendments 262 and 243 | ||
Rod Group Alignment Limits 3.1.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. More than one rod not 0.1.1 Verify SDM to be 1 hour within alignment within the limit 1imit. provided in the COLR. | |||
OR 0.1.2 Initiate boration to 1 hour restore required SDM to withi n 1imit. | |||
In accordance with the Surveillance Frequency Control Program | AND D.2 Be in MODE 3. 6 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.4.1 Verify individual rod positions within In accordance alignment limit. with the Surveillance Frequency Control Program SR 3.1. 4.2 Verify rod freedom of movement In accordance (trippability) by moving each rod not fully with the inserted in the core ~ 10 steps in either Survei 11 ance . | ||
direction. Frequency Control Program SR 3.1.4.3 Verify rod drop time of each rod, from the Pri or to reactor fully withdrawn position, is s 2.7 seconds criti ca 1ity from the beginning of decay of stationary after each gripper coil voltage to dashpot entry, removal of the with: reactor head | |||
: a. Tavg 2 500°F; and | |||
: b. All reactor coolant pumps operating. | |||
North Anna Units 1 and 2 3.1.4-3 Amendments 262 and 243 | |||
Shutdown Bank Insertion Limits 3.1.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. One shutdown bank B.1 Verify SDM to be Once per inserted ~ 18 steps within the limits 12 hours below the insertion provided in the COLR. | |||
limit and immovable. | |||
AND AND B.2 Restore the shutdown 72 hours Each control and bank to within shutdown rod within insertion limit. | |||
limits of LCO 3.1.4. | |||
AND Each control bank within the insertion limits of LCO 3.1.6. | |||
C. Required Action and C.1 Be in MODE 3. 6 hours associated Completion Time not met. | |||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify each shutdown bank is within the In accordance insertion limits specified in the COLR. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.1. 5-2 Amendments 262 and 243 | |||
Control Bank Insertion Limits 3.1.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.2 Verify each control bank is within the In accordance insertion limits specified in the COLR. with the Surveillance Frequency Control Program SR 3.1.6.3 Verify each control bank not fully In accordance withdrawn from the core is within the with the sequence and overlap limits specified in Surveillance the COLR. Frequency Control Program North Anna Units 1 and 2 3.1.6-3 Amendments262 and 243 | |||
Rod Position Indication 3.1. 7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. One demand position 0.1.1 Verify by Once per 8 hours indicator per bank administrative means inoperable for one or all RPI s for the more banks. affected banks are OPERABLE. | |||
AND D.1.2 Verify the most Once per 8 hours withdrawn rod and the least withdrawn rod of the affected banks are s 12 steps apart. | |||
-OR D.2 Reduce THERMAL POWER 8 hours to S 50% RTP. | |||
E. Required Action and E,1 Be in MODE 3. 6 hours associated Completion Time not met. | |||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.1 Perform CHANNEL CALIBRATION of each RPI. In accordance with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.1.7-3 Amendments 262 and 243 | |||
PHYSICS TESTS Exceptions-MODE 2 3.1.9 ACTIONS CONDITION REQUIRED ACTION COMPLETI ON TIME D. Required Action and 0.1 Be in MODE 3. 15 minutes associated Completion Time of Condition C not met; SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.9.1 Perform a CHANNEL OPERATIONAL TEST on power Prior to range and intermediate range channels per initiation of SR 3.3.1.7. SR 3.3.1.8, and Table 3.3.1-1. PHYSICS TESTS SR 3.1.9.2 Verify the RCS lowest loop average In accordance temperature is ~ 531°F. with the Surveillance Frequency Control Program SR 3.1. 9.3 Verify THERMAL POWER is ~ 5% RTP. In accordance with the Surveillance Frequency Control Program SR 3.1. 9.4 Verify SDM to be within the limits provided In accordance in the COLR. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.1.9-2 Amendments 262 and 243 | |||
FQ(Z) 3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.1 ------------------NOTE--------------- | |||
If Fg(Z) measurements indicate F~(Z)] | |||
maximum over z [ K(Z) has increased since the previous evaluation of FS(Z): | |||
: a. Increase F~(Z) by the appropriate factor and verify Fg(Z) is still within limits; or | |||
: b. Repeat SR 3.2.1.1 once per 7 EFPO until two successive flux maps indicate F~(Z)l maximum over z [ K(Z) has not increased. | |||
Verify F~(Z) is within limit. Once after each refueling prior to THERMAL POWER exceeding 75% RTP AND Once within 12 hours after achieving equilibrium conditions after exceeding, by | |||
~ 10% RTP. the THERMAL POWER at whi ch F~ (Z) was last verified AND In accordance with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.2.1-3 Amendments 262 and 243 | |||
N FAH 3.2.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.4 ---------NOTE-------- | |||
THERMAL POWER does not have to be reduced to comply with this Required Action. | |||
--------------------- | |||
Perform SR 3.2.2.1. Prior to THERMAL POWER exceeding 50% RTP | |||
-AND Pri or to THERMAL POWER exceeding 75% RTP AND 24 hours after THERMAL POWER reaching 2 95% RTP B. Required Action and B.1 Be in MODE 2. 6 hours associated Completion Time not met. | |||
SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.2.2.1 Verify F1H ;s within limits specified Once after each in the COLR. refueling prior to THERMAL POWER exceeding 75% RTP AND In accordance with the Survei 11 ance Frequency Control Program North Anna Units 1 and 2 3.2.2-2 Amendments262 and 243 | |||
AFD 3.2.3 3.2 POWER DISTRIBUTION LIMITS 3.2.3 AXIAL FLUX DIFFERENCE (AFD) lCO 3.2.3 The AFD in % flux difference units shall be maintained within the limits specified in the COLR. | |||
- - - - - - - - - - - - NOTE - - - - - - - - - | |||
The AFD shall be considered outside limits when two or more OPERABLE excore channels indicate AFD to be outside limits. | |||
APPLICABILITY: MODE I with THERMAL POWER ~ 50% RTP. | |||
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. AFD not within limits. A.I Reduce THERMAL POWER 30 minutes to < 50% RTP. | |||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 Verify AFD within limits for each OPERABLE In accordance excore channel. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.2.3-1 Amendments 262 and 243 | |||
QPTR 3.2.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.6 --------NOTE-------- | |||
Perform Required Action A.6 only after Required Action A.5 is completed. | |||
-------------------- | |||
Perform SR 3.2.1.1 and With"j n 24 hours SR 3.2.2.1. after achieving equil i bri urn Conditions at RTP not to exceed 48 hours after increasing THERMAL POWER above the limit of Required Action A.1 B. Required Action and B.1 Reduce THERMAL POWER 4 hours associated Completion to ~ 50% RTP. | |||
Time not met. | |||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.1 ------------------NOTES--------------- | |||
: 1. With input from one Power Range Neutron Flux channel inoperable and THERMAL POWER ~ 75% RTP, the remaining three power range channels can be used for calculating QPTR. | |||
: 2. SR 3.2.4.2 may be performed in lieu of this Surveillance. | |||
Verify QPTR is within limit by In accordance with calculation. the Survei 11 ance Frequency Control Program North Anna Units 1 and 2 3.2.4-3 Amendments 262 and 243 | |||
QPTR 3.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.2 -------------------NOTE--------------- | |||
Not required to be performed until 12 hours after input from one or more Power Range Neutron Flux channels are inoperable with THERMAL POWER | |||
> 75% RTP. | |||
Verify QPTR is within limit using the In accordance with movable incore detectors. the Surveillance Frequency Control Program North Anna Units 1 and 2 3.2.4-4 Amendments 262 and 243 | |||
RTS Instrumentation 3.3.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME R. One or more channels R.1 Verify interlock ;s in 1 hour inoperable. required state for existing unit conditions. | |||
OR R.2 Be in MODE 2. 7 hours S. One trip mechanism S.l Restore inoperable 48 hours inoperable for one trip mechanism to RTB. OPERABLE status. | |||
OR S.2 Be in MODE 3. 54 hours SURVEILLANCE REQUIREMENTS | |||
- - - - - - - - - - - - - - - - NOTE - - - - - - - | |||
Refer to Table 3.3.1-1 to determine which SRs apply for each RTS Function. | |||
SURVEILLANCE FREQUENCY SR 3.3.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.1.2 -------------------NOT£----------- | |||
Not required to be performed until 12 hours after THERMAL POWER is | |||
~ 15% RTP. | |||
Compare results of calorimetric heat In accordance with balance calculation to power range the Surveillance channel output~ Adjust power range Frequency Control output if calorimetric heat balance Program calculation result exceeds power range channel output by more than +2% RTP. | |||
North Anna Units 1 and 2 3.3.1-8 Amendments 262 and 243 | |||
RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.3 -------------------NOTE-------------- | |||
Not required to be performed until 72 hours after THERMAL POWER is 2 15% RTP. | |||
Compare results of the incore detector In accordance with measurements to Nuclear the Surveillance Instrumentation System (NIS) AFD. Frequency Control Adjust NIS channel if absolute Program difference is 2 3%. | |||
SR 3.3.1.4 -------------------NOTE-------------- | |||
This Surveillance must be performed on the reactor trip bypass breaker immediately after placing the bypass breaker in service. | |||
Perform TADOT. In accordance with the Survei1lance Frequency Control Program SR 3.3.1.5 Perform ACTUATION LOGIC TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.6 -------------------NOTE-------------- | |||
Verification of setpoint is not required. | |||
Perform TADOT. In accordance with the Survei11ance Frequency Control Program North Anna Units 1 and 2 3.3.1-9 Amendments 262 and 243 | |||
RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.7 -------------------NOTE-------------- | |||
Not required to be performed for source range instrumentation prior to entering MODE 3 from MODE 2 until 4 hours after entry into MODE 3. | |||
Perform COT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.8 ~------------------NOTE--------------- -----NOTE---- | |||
This Surveillance shall include Only required when verification that interlocks P-6 not performed within and P-10 are in their required state the frequency for existing unit conditions. specified in the Surveillance Control Program Perform COT. | |||
Prior to reactor startup Four hours after reducing power below P-6 for source range instrumentation Twelve hours after reducing power below P-IO for power and intermediate range instrumentation AND In accordance with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.3.1-10 Amendments 262 and 243 | |||
RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.9 -------------------NOTES------------- | |||
: 1. Adjust NIS channel if absolute difference ~ 3%. | |||
: 2. Not required to be performed until 72 hours after THERMAL POWER is | |||
~ 50% RTP. | |||
Compare results of the excore channels In accordance with to incore detector measurements. the Surveillance Frequency Control Program SR 3.3.1.10 -------------------NOTE-------------- | |||
This Surveillance shall include verification that the time constants are adjusted to the prescribed values. | |||
Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.1.11 -------------------NOTE-------------- | |||
Neutron detectors are excluded from CHANNEL CALIBRATION. | |||
Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.1.12 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.3.1-11 Amendments 262 and 243 | |||
RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.13 Perform COT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.14 -------------------NOTE-------------- | |||
Verification of setpoint ;s not required. | |||
Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.15 -------------------NOTE-------------- | |||
Verification of setpoint ;s not required. | |||
Perform TADOT. Prior to exceeding the P-8 interlock whenever the unit has been in MODE 3, i f not performed within the previous 31 days SR 3.3.1.16 -------------------NOTE-------------- | |||
Neutron detectors are excluded from response time testing. | |||
Verify RTS RESPONSE TIME is within In accordance with 1im; ts. the Surveillance Frequency Control Program North Anna Units 1 and 2 3.3.1-12 Amendments262 and 243 | |||
ESFAS Instrumentation 3.3.2 ACTIONS CONDITION REQUIRED ACTION COMPLETI ON TIME J. One or more channels J.l Verify interlock is in 1 hour inoperable. required state for existing unit condition. | |||
OR J.2.1 Be in MODE 3. 7 hours AND J.2.2 Be in MODE 4. 13 hours SURVEILLANCE REQUIREMENTS | |||
- - - - - - - - - - - - - - - -NOTE - - - - - - - - - - - - - | |||
Refer to Table 3.3.2-1 to determine which SRs apply for each ESFAS Function. | Refer to Table 3.3.2-1 to determine which SRs apply for each ESFAS Function. | ||
SURVEILLANCE FREQUENCY SR 3.3.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.2.2 Perform ACTUATION LOG[C TEST. In accordance with the Survei 11 ance Frequency Control Program SR 3.3.2.3 Perform MASTER RELAY TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.4 Perform COT In accordance with the Survei 11 ance Frequency Control Program North Anna Units 1 and 2 3.3.2-5 Amendments 262 and 243 | |||
ESFAS Instrumentation 3.3.2 SURVEI LLANCE FREQUENCY SR 3.3.2.5 -------------------NOTE------------- | |||
Not required to be performed for SLAVE RELAYS if testing would: | |||
: 1. Result in an inadvertent Reactor Trip System or ESFAS Actuation if accompanied by a single failure in the Safeguard Test Cabinet; | |||
: 2. Adversely affect two or more components in one or more ESFAS system(s}; or | |||
: 3. Create a reactivity, thermal | |||
Two outside RS subsystems inoperable. | Two outside RS subsystems inoperable. | ||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.7.1 Verify casing cooling tank temperature is In accordance | |||
and automatic valve in the flow path that is not locked, sealed. or otherwise secured in position is in the correct position. | ~ 35°F and ~ 50°F. with the Surveillance Frequency Control Program SR 3.6.7.2 Verify casing cooling tank contained In accordance borated water volume is ~ 116,500 gal. with the Surveillance Frequency Control Program SR 3.6.7.3 Verify casing cooling tank boron In accordance concentration is ~ 2600 ppm and ~ 2800 ppm. with the Surveillance Frequency Control Program North Anna Units 1 and 2 Amendments 262 and 243 | ||
: b. Each RS pump starts automatically; and c. Each casing cooling pump starts automat; ca 11 y. | RS System 3.6.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.7.4 Verify each RS and casing cooling manual. In accordance power operated. and automatic valve in the with the flow path that is not locked, sealed. or Surveillance otherwise secured in position is in the Frequency correct position. Control Program SR 3.6.7.5 Verify each RS and casing cooling pump's In accordance developed head at the flow test point is with the greater than or equal to the required Inservice developed head. Testing Program SR 3.6.7.6 Verify on an actual or simulated actuation In accordance signal (s): with the Surveillance | ||
: a. Each RS automatic valve in the flow path Frequency that is not locked. sealed, or otherwise Control Program secured in position, actuates to the correct position; | |||
Foll owing | : b. Each RS pump starts automatically; and | ||
* maintenance which could cause nozzle I blockage North Anna Units 1 and 2 3.6.7-3 Amendments 262 and 243 Chemical Addition System 3.6.8 3.6 CONTAINMENT SYSTEMS 3.6.8 Chemical Addition LCO 3.6.8 The Chemical Addition System shall be APPLICABILITY: | : c. Each casing cooling pump starts automat; ca 11 y. | ||
MODES 1, 2, 3, and 4. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Chemical Addition | SR 3.6.7.7 Verify. by visual inspection, each RS train In accordance containment sump component is not with the restricted by debris and shows no evidence Surveillance of structural distress or abnormal Frequency corrosion. Control Program SR 3.6.7.8 Verify each spray nozzle is unobstructed. Foll owing | ||
A.l Restore Chemical Addition System to OPERABLE status. | * maintenance which could cause nozzle I blockage North Anna Units 1 and 2 3.6.7-3 Amendments 262 and 243 | ||
Chemical Addition System 3.6.8 3.6 CONTAINMENT SYSTEMS 3.6.8 Chemical Addition System LCO 3.6.8 The Chemical Addition System shall be OPERABLE. | |||
Isolate affected flow path. Be in MODE 3. Be in MODE 4. | APPLICABILITY: MODES 1, 2, 3, and 4. | ||
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Chemical Addition A.l Restore Chemical 72 hours System inoperable. Addition System to OPERABLE status. | |||
MODES 1, 2, and 3, MODE 4 when steam generator is relied upon for heat removal. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required SG PORV | B. Required Action and B.l Be in MODE 3. 6 hours associated Completion Time not met. AND B.2 Be in MODE 5. 84 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.8.1 Verify each Chemical Addition System In accordance manual. power operated, and automatiC valve with the in the flow path that is not locked, Surveillance sealed, or otherwise secured in position is Frequency in the correct position. Control Program SR 3.6.8.2 Verify chemical addition tank solution In accordance volume is ~ 4800 gal and ~ 5500 gal. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.6.8-1 Amendments 262 and 243 | ||
A.1 Restore required SG PORV line to OPERABLE status. | |||
B.1 Restore all but one SG PORV line to OPERABLE status. 24 hours C. Required Action and associated Completion Time not met. | Chemical Addition System 3.6.8 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.6.8.3 Verify chemical addition tank NaOH solution In accordance concentration is ~ 12% and ~ 13% by with th'e wei ght. Surveillance Frequency Contro 1 Program SR 3.6.8.4 Verify each Chemical Addition System In accordance automatic valve in the flow path that is with the not locked, sealed, or otherwise secured in Surveillance position, actuates to the correct position . Frequency on an actual or simulated actuation signal. Control Program SR 3.6.8.5 Verify Chemical Addition System flow from In accordance each solutionis flow path. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.6.8-2 Amendments 262 and 243 | ||
MSTVs 3.7.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1 -------------------NOTE------------------- | |||
North Anna Units 1 and 2 3.7.5-2 Amendments 262 and 243 AFW System 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.2 | Only required to be performed in MODES 1 and 2. | ||
Verify the developed head of each AFW pump at the flow test point is greater than or equal to the required developed head. | Verify isolation time of each MSTV is In accordance | ||
::;; 5 seconds. with the Inservice Testing Program SR 3.7.2.2 -------------------NOTE------------------- | |||
Only required to be performed in MODES 1 and 2. | |||
Verify each MSTV actuates to the isolation In accordance position on an actual or simulated with the actuation signal. Surveillance Frequency Control Program North Anna Units 1 and 2 3.7.2-2 Amendments262 and 243 | |||
MFIVs, MFPDVs, MFRVs, and MFRBVs 3.7.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. One or more MFPDV 0.1 Close or isolate 72 hours inoperable. MFPDV. | |||
AND 0.2 Verify MFPDV is closed ! Once per 7 days or isolated. | |||
E. Two valves in the same E.1 Isolate affected flow 8 hours flow path inoperable . path. | |||
F. . Required Action and F.1 Be in MODE 3. 6 hours associated Completion Time not met. AND F.2 Be in MODE 4. 12 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 Verify the isolation time of each MFIV, In accordance MFRV, and MFRBV is ~ 6.98 seconds and the with the isolation time of each MFPDV is Inservice | |||
~ 60 seconds. i Test; n9 Program SR 3.7.3.2 Verify each MFIV, MFPOV, MFRV, and MFRBV In accordance actuates to the isolation position on an with the actual or Simulated actuation signal. Surveillance Frequency Control Program North Anna Units 1 and 2 3.7.3-2 Amendments 262 and 243 | |||
SG PORVs 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Steam Generator Power Operated Relief Valves (SG PORVs) | |||
LCO 3.7.4 Three SG PORV lines shall be OPERABLE. | |||
APPLICABILITY: MODES 1, 2, and 3, MODE 4 when steam generator is relied upon for heat removal. | |||
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required SG PORV A.1 Restore required SG 7 days 1ine inoperable. PORV line to OPERABLE status. | |||
B. Two or more required B.1 Restore all but one SG SG PORV lines PORV line to OPERABLE inoperable. status. 24 hours C. Required Action and C.1 Be in MODE 3. 6 hours associated Completion Time not met. AND C.2 Be in MODE 4 without 24 hours reliance upon steam generator for heat removal. | |||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify one complete cycle of each SG In accordance with PORV. , the Surveil 1ance I Frequency Control Program North Anna Units 1 and 2 3.7.4-1 Amendments 262 and 243 | |||
SG PORVs 3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.2 Verify one complete cycle of each 5G In accordance with PORV manua1 isolation valve. the Surveillance Frequency Control Program North Anna Units 1 and 2 Amendments 262 and 243 | |||
AFW System 3.7 .5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 6 hours associated Completion Time for Condition A AND or B not met. | |||
C.2 Be in MODE 4. 18 hours OR Two AFW trains inoperable in MODE 1, 2, or 3. | |||
D. Three AFW trains 0.1 ---------NOTE------- | |||
inoperable in MODE 1, LCO 3.0.3 and all 2, or 3. other LCO Required Actions requiring MODE changes are suspended until one AFW train is restored to OPERABLE status. | |||
-------------------- | |||
Initiate action to Immediately restore one AFW train to OPERABLE status. | |||
E. Required AFW train E.1 Initiate action to Immediately inoperable in MODE 4. restore AFW train to OPERABLE status. | |||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 Verify each AFW manual, power operated, and, In accordance automatic valve in each water flow path, with the and in both steam supply flow paths to the Surveillance steam turbine driven pump, that is not Frequency locked. sealed, or otherwise secured in Control Program position, is in the correct position. | |||
North Anna Units 1 and 2 3.7.5-2 Amendments 262 and 243 | |||
In accordance with the Surveillance Frequency Control Program North Anna Units 1 and 2 | AFW System 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.2 -------------------NOTE----------------- | ||
Not required to be performed for the turbine driven AFW pump until 24 hours after ~ 1005 psig in the steam generator. | |||
Verify the developed head of each AFW pump In accordance at the flow test point is greater than or with the equal to the required developed head. Inservice Testing Program SR 3.7.5.3 -------------------NOTE------------------- | |||
Not applicable in MODE 4 when steam generator is relied upon for heat removal. | |||
Verify each AFW automatic valve that is not In accordance locked, sealed. or otherwise secured in with the position. actuates to the correct position . Survei 11 ance on an actual or simulated actuation signal. Frequency Control Program SR 3.7.5.4 --------------------NOTES----------------- | |||
: 1. Not required to be performed for the turbine driven AFW pump until 24 hours after ~ 1005 psig in the steam generator. | |||
: 2. Not applicable in MODE 4 when steam generator is relied upon for heat removal. | |||
Verify each AFW pump starts automatically In accordance on an actual or simulated actuation signal. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.7.5-3 Amendments 262 and 243 | |||
AFW System 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.5 Verify proper a1ignment of the required AFW Prior to flow paths by verifying flow from the enter; ng MODE 3, emergency condensate storage tank to each whenever unit steam generator. has been in MODE 5, 6, or defueled for a cumulative period> 30 days North Anna Units 1 and 2 3.7.5-4 Amendments 262 and 243 | |||
ECST 3.7.6 3.7 PLANT SYSTEMS 3.7.6 Emergency Condensate Storage Tank (ECST) | |||
LCO 3.7.6 The ECST shall be OPERABLE. | |||
APPLICABILITY: MODES 1, 2, and 3, MODE 4 when steam generator is relied upon for heat removal. | |||
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ECST inoperable. A.l Verify by 4 hours administrative means OPERABILITY of AND Condensate Storage Tank. Once per 12 hours thereafter AND A.2 Restore ECST to 7 days OPERABLE status. | |||
B. Required Action and B.1 Be in MODE 3. 6 hours associated Completion Time not met. AND B.2 Be in MODE 4, without 24 hours reliance on steam generator for heat removal. | |||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify the ECST contains In accordance with the | |||
;;:.; 110,000 gal. Surveillance Frequency Control Program North Anna Units 1 and 2 3.7.6-1 Amendments 262 and 243 | |||
Secondary Specific Activity 3.7.7 3.7 PLANT SYSTEMS 3.7.7 Secondary Specific Activity LCO 3.7.7 The specific activity of the secondary coolant shall be | |||
~ 0.10 ~Ci/gm DOSE EQUIVALENT 1-131. | |||
APPLICABILITY: MODES 1. 2, 3. and 4. | |||
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. 'Specific activity not A.1 Be in MODE 3. 6 hours withi n 1imit. | |||
Be in MODE 5. 36 hours SURVEILLANCE REMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1 Verify the specific activity of the In accordance secondary coolant is ~ 0.10 ~Ci/gm DOSE with the EQUIVALENT 1-131. Surveillance' Frequency Cont ro1 Program North Anna Units 1 and 2 3.7.7-1 Amendments 262 and 243 | |||
SW System 3.7.8 SURVEILLANCE REMENTS SURVEILLANCE FREQUENCY SR 3.7.8.1 ------------ft------NOTE------------------ft-Isolation of SW flow to individual components does not render the SW System inoperable. | |||
Verify each SW System manual, power In accordance operated, and automatic valve in the flow with the path servicing safety related equipment, Surveillance that is not locked, sealed, or otherwise Frequency secured in position, is in the correct Control Program position. | |||
SR 3.7.8.2 Verify each SW System automatic valve in In accordance the flow path that is not locked, sealed, with the or otherwise secured in position, actuates Surveillance to the correct position on an actual or Frequency simulated actuation signal. Control Program North Anna Units 1 and 2 3.7.8-3 Amendments 262 and 243 | |||
S\~ System 3.7.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.8.3 Verify each SW pump starts automatically on In accordance an actual or simulated actuation signal. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.7.8-4 Amendments 262 and 243 | |||
UHS 3.7.9 3.7 PLANT SYSTEMS 3.7.9 Ultimate Heat Sink (UHS) | |||
LCO 3.7.9 The UHS shall be OPERABLE. | |||
APPLICABILITY: MODES 1, 2, 3, and 4. | |||
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. UHS inoperable. A.I Be in MODE 3. 6 hours AND A.2 Be in MODE 5. 36 hours SURVEILLANCE REQUIREMENTS SURVEI LLANC E FREQUENCY SR 3.7.9.1 Verify water level of the Service Water In accordance Reservoir is ~ 313 ft mean sea level. with the Surveillance Frequency Control Program SR 3.7.9.2 Verify average water temperature of the In accordance Service Water Reservoir is ~ 95°F. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.7.9-1 Amendments 262 and 243 | |||
MCR/ESGR EVS I 3.7.10 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. (continued) | |||
OR Two required MCR/ESGR EVS trains inoperable during movement of recently irradiated fuel assemblies for reasons other than Condition B. | |||
F. Two required MCR/ESGR F.l Enter LCO 3.0.3. Immediately EVS trains inoperable in MODE 1, 2, 3, or 4 for reasons other than Condition B. | |||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.10.1 Operate each required MCR/ESGR EVS train In accordance for ~ 10 continuous hours with the heaters with the operating. Surveillance Frequency Control Program SR 3.7.10.2 Perform required MCR/ESGR EVS filter In accordance testing in accordance with the Ventilation with VFTP Filter Testing Program (VFTP). | |||
SR 3.7.10.3 Not Used North Anna Units 1 and 2 3.7.10-3 Amendments 262 and 243 | |||
MCR/ESGR ACS 3.7.11 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. Less than 100% of the E.1 Enter LCO 3.0.3. Immediately MCR/ESGR ACS cooling equivalent to a single OPERABLE MCR/ESGR ACS subsystem available in MODE 1, 2, 3, or 4. | |||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.11.1 Verify each required MCR/ESGR ACS chiller In accordance has the capability to remove the assumed with the heat load. Surveillance Frequency Control Program North Anna Units 1 and 2 3.7.11-2 Amendments 262 and 243 | |||
Eees PREACS 3.7.12 ACTIONS CONDITION REQUIRED ACTION TION TIME D. Two ECCS PREACS trains 0.1.1 Verify ECCS leakage 1 hour inoperable due to log is less than the inoperable ECeS pump room maximum allowable boundary affecting unfiltered leakage. | |||
filtration capability. | |||
AND 0.1.2 Verify by field Once per walkdown that ECCS 12 hours leakage is less than thereafter the maximum allowable unfiltered leakage. | |||
AND D.1.3 Restore ECCS pump room 14 days boundary to OPERABLE status. | |||
OR 0.2 Restore ECCS pump room 24 hours boundary to OPERABLE status. | |||
E. Required Action and E.1 Be in MODE 3. 6 hours associated Completion Time not met. AND E.2 Be in MODE 5. 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.12.1 Operate each ECCS PREACS train for In accordance with the | |||
~ 10 continuous hours with the Surveillance Frequency heaters operating. Control Program North Anna Units 1 and 2 3.7.12-4 Amendments 262 and 243 | |||
ECCS PREACS 3.7 .12 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.12.2 Actuate each ECCS PREACS train by In accordance with the aligning Safeguards Area exhaust Surveillance Frequency flow and Auxiliary Building Central Control Program exhaust flow through the Auxiliary Building HEPA filter and charcoal adsorber assembly. | |||
SR 3.7.12.3 Perform required ECCS PREACS filter In accordance with the testing in accordance with the VFTP Ventilation Filter Testing Program (VFTP) . | |||
SR 3.7.12.4 Verify Safeguards Area exhaust flow In accordance with the is diverted and each Auxiliary Surveillance Frequency Building filter bank is actuated on Control Program an actual or simulated actuation signal. | |||
SR 3.7.12.5 Verify one ECCS PREACS train can In accordance with the maintain a negative pressure Surveillance Frequency relative to adjacent areas during Control Program post accident mode of operation. | |||
North Anna Units 1 and 2 3.7.12-5 Amendments 262 and 243 | |||
FBVS 3.7.15 3.7 PLANT SYSTEMS 3.7.15 Fuel Building Ventilation System (FBVS) | |||
LCO 3.7.15 The FBVS shall be OPERABLE and in operation. | |||
- - - - - - - - - - NOTE The fuel building boundary may be opened intermittently under administrative control. | |||
APPLICABILITY: During movement of recently irradiated fuel assemblies in the fuel building. | |||
ACTIONS | |||
- - - - - - - - - - - - - - - - NOTE - - - - - - | |||
LCO 3.0.3 is not applicable. | LCO 3.0.3 is not applicable. | ||
A.l Suspend movement of fuel assemblies in the | CONDITION REQUIRED ACTION COMPLETION TIME A. FBVS inoperable. A.l Suspend movement of Immediately recently irradiated OR fuel assemblies in the fuel building. | ||
In accordance with the | FBVS not in operation. | ||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.15.1 Verify the FBVS can maintain a pressure In accordance | |||
~ -0.125 inches water gauge with respect with the to atmospheric pressure. Survei 11 ance Frequency Control Program North Anna Units 1 and 2 3.7.15-1 Amendments 262 and 243 | |||
Fuel Storage Pool Water Level 3.7.16 3.7 PLANT SYSTEMS 3.7.16 Fuel Storage Pool Water Level LCO 3.7.16 The fuel storage pool water level shall be ~ 23 ft over the top of irradiated fuel assemb1ies seated in the storage racks. | |||
APPLICABILITY: During movement of irradiated fuel assemblies in the fuel storage poo1. | |||
Verify each required EDG | ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel storage pool A.l --------NOTE-------- | ||
In accordance with the | water level not within LCO 3.0.3 is not limit. applicable. | ||
Suspend movement of Immediately i rradi ated fuel assemblies in the fuel storage pool. | |||
In accordance with the Surveillance Frequency Control Program | SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.16.1 Verify the fuel storage pool water level is In accordance | ||
Verify | ~ 23 ft above the top of the irradiated with the fuel assemblies seated in the storage Surveillance racks. Frequency Control Program North Anna Units 1 and 2 3.7.16-1 Amendments262 and 243 | ||
Verify each required EDG | Fuel Storage Pool Boron Concentration 3.7.17 3.7 PLANT SYSTEMS 3.7.17 Fuel Storage Pool Boron Concentration LCO 3.7.17 The fuel storage pool boron concentration shall be | ||
; : : 2600 ppm. | |||
APPLICABILITY: When fuel assemblies are stored in the fuel storage pool. | |||
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel storage pool :------------NOTE------------ | |||
boron concentration LCO 3.0.3 is not applicable. | |||
not within limit. | |||
Verify each | A.l Suspend movement of Immediately fuel assemblies in the fuel storage pool. | ||
AND A.2 Initiate action to Immediately restore fuel storage pool boron concentration to within limit. | |||
SURVEILLANCE REMENTS | |||
, | |||
Verify on | SURVEILLANCE FREQUENCY SR 3.7.17.1 Verify the fuel storage pool boron In accordance concentration is within limit. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.7.17-1 Amendments 262 and 243 | ||
CC System 3.7.19 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.19.1 Verify each CC manual. power operated, and In accordance automatic valve in the flow path servicing with the the residual heat removal system, that is Surveillance not locked, sealed, or otherwise secured in Frequency position, is in the correct position. Control Program North Anna Units 1 and 2 3.7.19-2 Amendments 262 and 243 | |||
AC Sources-Operating 3.B.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and In accordance indicated power availability for each with the required offsite circuit. Survei 11 ance Frequency Control Program SR 3.8.1.2 -------------------NOTES-------------- | |||
: 1. All EOG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading. | |||
: 2. A modified EOG start involving idling and gradual accelerat i on to synchronous speed may be used for this SR as recommended by the manufacturer. When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.7 must be met. | |||
Verify each required EOG starts from In accordance standby conditions and achieves steady with the state voltage ~ 3740 V and ~ 4580 V, and Surveillance frequency ~ 59.5 Hz and ~ 60.5 Hz. Frequency Cont ro 1 Program North Anna Units 1 and 2 3.8.1-8 Amendments 262 and 243 | |||
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.8.1.3 -------------------NOTES-------------- | |||
: 1. EDG loadings may include gradual loading as recommended by the manufacturer. | |||
: 2. Momentary transients outside the load range do not invalidate this test. | |||
: 3. This Surveillance shall be conducted on only one EDG at a time. | |||
: 4. This SR shall be preceded by and immediately follow without shutdown a successful performance of SR 3.8.1.2 or SR 3.8.1.7. | |||
Verify each required EDG is synchronized In accordance and loaded and operates for ~ 60 minutes with the at a load ~ 2500 kW and ~ 2600 kW. Surveillance Frequency Control Program SR 3.8.1.4 Verify each required day tank contains In accordance | |||
~ 450 gal of fuel oil. with the Surveillance Frequency Control Program SR 3.8.1.5 Check for and remove accumulated water I In accordance from each required day tank. with the Surveillance Frequency Control Program SR 3.8.1.6 Verify each required fuel oil transfer In accordance pump operates to transfer fuel oil from with the the storage tank to the day tank. Surveillance Frequency Control Program North Anna Units 1 and 2 3.8.1-9 Amendments 262 and 243 | |||
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1. 7 -------------------NOTE--------------- | |||
All EDG starts may be preceded by an engine prelube period. | |||
Verify each required EDG starts from In accordance standby* condition and achieves with the Surveillance | |||
: a. In ~ 10 seconds. voltage ~ 3960 V and Frequency Control frequency ~ 59.5 Hz; and Program | |||
: b. Steady state voltage ~ 3740 V and | |||
~ 4580 V, and frequency ~ 59.5 Hz and | |||
~ 60.5 Hz. | |||
SR 3.8.1.8 -------------------NOTES------------- | |||
: 1. This Surveillance is only applicable to Unit 1. | |||
: 2. This Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the unit is maintained or enhanced. | |||
Verify manual transfer of AC power sources In accordance from the normal offsite circuit to the with the alternate required offsite circuit. Surveillance Frequency Contra 1 Program North Anna Units 1 and 2 3.8.1-10 Amendments 262 and 243 | |||
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.9 -------------------NOTE--------------- | |||
If performed with EDG synchronized with offsite power, it shall be performed at a power factor ~ 0.9. However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition, the power factor shall be maintained as close to the limit as practicable. | |||
Verify each required EDG rejects a load In accordance greater than or equal to its associated with the single largest post-accident load, and: Surve'j 11 ance Frequency Control | |||
: a. Following load rejection, the frequency Program is ~ 66 Hz; | |||
: b. Within 3 seconds following load rejection, the voltage is ~ 3740 V and | |||
~ 4580 V; and | |||
: c. Within 3 seconds following load rejection, the frequency is ~ 59.5 Hz and ~ 60.5 Hz. | |||
North Anna Units 1 and 2 3.8.1-11 Amendments 262 and 243 | |||
AC Sources-operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.10 -------------------NOTES-------------- | |||
: 1. All EDG starts may be preceded by an engine prelube period. | |||
: 2. This Surveillance shall not normally be performed in MODE I, 2, 3, or 4. | |||
However. portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the unit is maintained or enhanced. | |||
Verify on an actual or simulated loss of In accordance offsite power signal: with the Surveillance | |||
: a. De-energization of emergency buses; Frequency Control Program | |||
: b. Load shedding from emergency buses; | |||
: c. Each required EDG auto-starts from standby condition and: | |||
: 1. energizes permanently connected loads in s 10 seconds, | |||
: 2. energizes auto-connected shutdown loads through sequencing timing relays, | |||
: 3. maintains steady state voltage | |||
~ 3740 V and s 4580 V, | |||
: 4. maintains steady state frequency | |||
~ 59.5 Hz and ~ 60.5 Hz, and | |||
: 5. supplies permanently connected and auto-connected shutdown loads for | |||
~ 5 minutes. | |||
North Anna Units 1 and 2' 3.8.1-12 Amendments 262 and 243 | |||
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.11 -------------------NOTES-------------- | |||
: 1. All EDG starts may be preceded by prelube period. | |||
: 2. This Surveillance shall not normally be performed in MODE 1 or 2. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the unit is maintained or enhanced. | |||
Verify on an actual or simulated In accordance Engineered Safety Feature (ESF) actuation with the signal each LCO 3.8.1.b EDG auto-starts Surveillance from standby condition and: Frequency Contra 1 Program | |||
: a. In ~ 10 seconds after auto-start and during tests, achieves voltage | |||
~ 3960 V and frequency ~ 59.5 Hz; | |||
: b. Achieves steady state voltage ~ 3740 V and ~ 4580 V and frequency ~ 59.5 Hz and ~ 60.5 Hz; | |||
: c. Operates for ~ 5 minutes; | |||
: d. Permanently connected loads remain energized from the offsite power system; and | |||
: e. Emergency loads are energized or auto-connected through the sequencing timing relays from the offsite power system. | |||
North Anna Units 1 and 2 3.8.1-13 Amendments 262 and 243 | |||
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.12 ---------~---------NOTE---------------- | |||
This Surveillance shall not normally be performed in MODE 1 or 2. However. this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the unit is maintained or enhanced. | |||
Verify each required EDG's automatic trips In accordance are bypassed on actual or simulated with the automatic start signals except: Surveillance Frequency Contra1 | |||
: a. Engine overspeed; and Program | |||
: b. Generator differential current. | |||
North Anna Units 1 and 2 3.8.1-14 Amendments 262 and 243 | |||
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.B.l.13 -------------------NOTES-------------- | |||
: 1. Momentary transients outside the load and power factor ranges do not invalidate this test. | |||
: 2. This Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the unit is maintained or enhanced. | |||
: 3. If performed with EDG synchronized with offsite power. it shall be performed at a power factor ~ 0.9. However. if grid conditions do not permit. the power factor limit is not required to be met. | |||
Under this condition the power factor shall be maintained as close to the limit as practicable. | |||
Verify each required EDG operates for In accordance | |||
~ 24 hours! with the Surveillance | |||
: a. For ~ 2 hours loaded ~ 2900 kW and Frequency Control S; 3000 kW; and Program | |||
: b. For the remaining hours of the test loaded ~ 2500 kW and s; 2600 kW. | |||
North Anna Units 1 and 2 3.B.I-15 Amendments 262 and 243 | |||
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.14 -------------------NOTES----------------- | |||
: 1. This Surveillance shall be performed within 5 minutes of shutting down the EDG after the EDG has operated | |||
~ 2 hours loaded ~ 2500 kW and | |||
~ 2600 kW or after operating temperatures have stabilized. | |||
Momentary transients outside of load range do'not invalidate this test. | |||
: 2. All EDG starts may be preceded by an engine prelube period. | |||
Verify each required EDG starts and In accordance achieves with the Surveillance | |||
: a. In ~ 10 seconds, voltage ~ 3960 V and Frequency Contro 1 frequency ~ 59.5 Hz; and Program | |||
: b. Steady state voltage ~ 3740 V, and | |||
~ 4580 V and frequency ~ 59.5 Hz and | |||
~ 60.5 Hz. | |||
SR 3.8.1.15 -------------------NOTE------------------ | |||
This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the unit is maintained or enhanced. | |||
Verify each required EOG: In accordance with the | |||
: a. Synchronizes with offsite power source Surveil 1ance while loaded with emergency loads upon Frequency Control a simulated restoration of offsite Program power; | |||
: b. Transfers loads to offsite power source; and | |||
: c. Returns to ready-to-load .operation. | |||
North Anna Units 1 and 2 3.8.1-16 Amendments 262 and 243 | |||
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.16 -------------------NOTE------------------ | |||
This Surveillance shall not normally be performed in MODE 1. 2. 3, or 4. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the unit is maintained or enhanced. | |||
Verify each required sequencing timing In accordance relay is within the design tolerance. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.8.1-17 Amendments 262 and 243 | |||
AC Sources-Operating 3.B.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.B.1.17 ------------------NOTES------------------ | |||
: 1. All EDG starts may be preceded by an engine prelube period. | |||
: 2. This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. | |||
However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the unit is maintained or enhanced. | |||
Verify on an actual or simulated loss of In accordance offsite power signal in conjunction with with the an actual or simulated ESF actuation Surveillance signal: Frequency Control Program | |||
: a. De-energization of emergency buses; | |||
: b. Load shedding from emergency buses; and | |||
: c. Each LeO 3.8.1.b EDG auto-starts from standby condition and: | |||
: 1. energizes permanently connected loads in ~ 10 seconds, | |||
: 2. energizes auto-connected emergency loads through load sequencing timing relays, | |||
: 3. achieves steady state voltage | |||
~ 3740 V and ~ 4580 V, | |||
: 4. achieves steady state frequency | |||
~ 59.5 Hz and ~ 60.5 Hz. and | |||
: 5. supplies permanently connected and auto-connected emergency loads for | |||
~ 5 minutes. | |||
North Anna Units 1 and 2 3.8.1-18 Amendments 262 and 243 | |||
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.8.1.18 -------------------NOTE------------------ | |||
All EDG starts may be preceded by an engine prelube period. | |||
---------------~-------------------------- | |||
Verify when started simultaneously from In accordance standby condition. each LCO 3.B.1.b EDG with the achieves: Surveillance Frequency Control | |||
: a. in $ 10 seconds, voltage ~ 3960 V and Program frequency ~ 59.5 Hz; and | |||
: b. steady state voltage~ 3740 V and | |||
$ 4580 V, and frequency ~ 59.5 Hz and | |||
$ 60.5 Hz. | |||
North Anna Units 1 and 2 3.8.1-19 Amendments 262 and 243 | |||
Diesel Fuel Oil and Starting Air 3.8.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME F. Required Action and F.l Declare associated Immediately associated Completion EDG(s) inoperable. | |||
Time not met. | |||
One or more EDGs diesel fuel oil or starting air subsystem not within limits for reasons other than Condition A, B, C, 0, or E. | |||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify fuel oil inventory ~ 90,000 gal. In accordance | |||
* wi th the Surveillance Frequency Control Program SR 3.8.3.2 Verify fuel oil properties of new and In accordance stored fuel oil are tested in accordance wi th the Oi ese 1 with, and maintained within the limits of, Fuel Oil the Diesel Fuel Oil Testing Program. Testing Program SR 3.8.3.3 Verify each EOG air start receiver pressure In accordance is ~ 175 psig. with the Surveillance Frequency Control Program SR 3.8.3.4 Check for and remove accumulated water from In accordance each stored fuel oil storage tank. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.8.3-3 Amendments 262 and 243 | |||
DC Sources-Operating 3.8.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. --------NOTE--------- 0.1 Declare associated Immediately Separate Condition shared component{s) entry is allowed for inoperable. | |||
each DC subsystem. | |||
One or more required LCO 3.8.4.c DC electrical power subsystem(s) inoperable. | One or more required LCO 3.8.4.c DC electrical power subsystem(s) inoperable. | ||
SURVEILLANCE REQUIREMENTS SURVEILLANCE I FREQUENCY SR 3.8.4.1 Verify for each required Station and EOG In accordance battery, terminal voltage is ~ 129 V on with the float charge. Surveillance Frequency Control Program SR 3.8.4.2 Verify for each required Station and EDG In accordance battery, there is no visible corrosion at with the battery terminals and connectors. Surveillance Frequency OR Control Program Verify battery connection resistance is | |||
~ 1.5E-4 ohm for inter-cell connections. | |||
OR Verify battery connection resistance is 1.5E-4 ohm for inter-cell connections. 1.5E-4 ohm for inter-rack connections. 1.5E-4 ohm for inter-tier connections. | ~ 1.5E-4 ohm for inter-rack connections. | ||
and 1.5E-4 ohm for terminal | ~ 1.5E-4 ohm for inter-tier connections. | ||
and ~ 1.5E-4 ohm for terminal conn~ctions. | |||
SR 3.8.4.3 Verify for each required Station and EDG In accordance battery, cells, cell plates, and racks with the show no visual indication of physical Surveillance damage or abnormal deterioration that Frequency could degrade battery performance. Control Program North Anna Units 1 and 2 3.8.4-2 Amendments 262 and 243 | |||
DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.8.4.4 For. each required Station and EDG battery, In accordance remove visible terminal corrosion, verify with the battery cell to cell and terminal Surveillance connections are clean and coated with Frequency anti-corrosion material. Control Program SR 3.8.4.5 Verify for each required Station and EDG In accordance battery, connection resistance is with the | |||
~ 1.5E-4 ohm for inter-cell connections, Surveil 1ance | |||
~ 1.5E-4 ohm for inter-rack connections, Frequency | |||
~ 1.5E-4 ohm for inter-tier connections, Control Program and ~ 1.5E-4 ohm for terminal connections. | |||
SR 3.8.4.6 Verify each required Station battery In accordance charger supplies ~ 270 amps at ~ 125 V with the for ~ 4 hours. Surveillance Frequency Control Program SR 3.8.4.7 Verify each required EDG battery charger In accordance supplies ~ 10 amps at ~ 125 V for with the | |||
~ 4 hours. Survei 11 ance Frequency Control Program North Anna Units 1 and 2 3.8.4-3 Amendments 262 and 243 | |||
DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.8 -------------------NOTES------------- | |||
: 1. The modified performance discharge test in SR 3.8.4.9 may be performed in lieu of the service test in SR 3.8.4.8. | |||
: 2. The performance discharge test in SR 3.8.4.9 may be performed in lieu of the service test in SR 3.8.4.8. | |||
: 3. This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. | |||
However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the unit is maintained or enhanced. | However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the unit is maintained or enhanced. | ||
Verify for each required Station | Verify for each required Station battery. In accordance capacity is adequate to supply, and with the maintain in OPERABLE status, the required Surveillance emergency loads for the design duty cycle Frequency when subjected to a battery service test. Control Program North Anna Units 1 and 2 3.8.4-4 Amendments 262 and 243 | ||
DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.9 -------------------NOTE-------------- | |||
This Surveillance shall not normally be performed in MODE 1, 2, 3~ or 4 for Station batteries. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the unit is maintained or enhanced. | |||
Verify for each required Station and EOG In accordance battery~ capacity is ~ 80% of the with the manufacturer's rating when subjected to a Surveillance performance discharge test or a modified Frequency performance discharge test. Control Program 18 months when battery shows degradation or has reached 85% | |||
of expected life North Anna Units 1 and 2 3.8.4-5 Amendments 262 and 243 | |||
Battery Cell Parameters 3.8.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3 Restore battery cell 31 days parameters to Table 3.8.6-1 Category A and B limits. | |||
COMPLETION TIME | i B. Required Action and B.1 Declare associated Immediately associated Completion battery inoperable. | ||
Time of Condition A not met. | |||
OR One or more Station batteries with average electrolyte temperature of the representative cells | |||
< 60°F. | |||
OR One or more Station or EDG batteries with one or more battery cell parameters not within Table 3.8.6-1 Category C values. | |||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 Verify for each required Station and EDG In accordance battery cell parameters meet Table 3.8.6-1 with the Category A limits. Surveillance Frequency Control Program North Anna Units 1 and 2 3.8.6-2 Amendments 262 and 243 | |||
COMPLETION TIME | |||
Battery Cell Parameters 3.8.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.2 Verify for each required Station and EDG In accordance battery cell parameters meet Table 3.8.6-1 with the Category B limits. Surveil 1ance Frequency Control Program AND Once within 24 hours after a battery discharge | |||
< 110 V Once within 24 hours after a battery overcharge | |||
> 150 V SR 3.8.6.3 Verify average electrolyte temperature of I n accordance representative cells for each required with the Station battery ;s ~ 60°F. Surveillance Frequency Control Program North Anna Units 1 and 2 3.8.6-3 Amendments 262 and 243 | |||
Inverters-Operating 3.8.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. One or more inverters B.1 ---------NOTE------- | |||
required by Enter applicable LCO 3.B.7.b Conditions and inoperable. Required Actions of LCO 3.8.9, 1I0istribution Systems-Operating" with any vital bus de-energized. | |||
--------------------- | |||
Declare associated 7 days shared components inoperable. | |||
C. Required Action and C.l Be in MODE 3. 6 hours associated Completion Time of Condition A AND not met. | |||
C.2 Be in MODE 5. 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct inverter voltage and In accordance alignment to required AC vital buses. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.8.7-2 Amendments 262 and 243 | |||
In accordance with the Surveillance Frequency Control Program | Inverters-Shutdown 3.B.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct inverter voltage and In accordance alignments to required AC vital buses. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.8.8-2 Amendments 262 and 243 | ||
4 | |||
In accordance with the | Distribution Systems-Operating 3.8.9 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME F. --------NOTE--------- 'F.! Declare associated Immediately Separate Condition shared components entry is allowed for inoperable. | ||
each AC vital subsystem. | |||
Verify | --------------------- | ||
In accordance with the | One or more required LCO 3.B.9.b AC vital electrical power distribution subsystem{s) inoperable. | ||
G. Required Action and G.! Be in MODE 3. 6 hours associated Completion Time for Condition At AND B, or C not met. | |||
G.2 Be in MODE 5. 36 hours H. Two or more H.! Enter LCO 3.0.3. Immediately LCO 3.B.g.a electrical power distribution subsystems inoperable that result in a loss of safety function. | |||
SURVEILLANCE REMENTS SURVEI lLANCE FREQUENCY SR 3.B.9.1 Verify correct breaker alignments and In accordance voltage to required AC, DC, and AC vital with the bus electrical power distribution Surveillance subsystems. Frequency Control Program North Anna Units 1 and 2 3.8.9-3 Amendments 262 and 243 | |||
Distribution Systems-Shutdown 3.8.10 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (conti nued) A.2.4 Initiate actions to Immediately restore required AC, DC, and AC vital bus electrical power distribution subsystems to OPERABLE status. | |||
A.2.5 Declare associated Immediately required residual heat removal subsystem(s) inoperable and not in operation. | |||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.10.1 Verify correct breaker alignments and In accordance voltage to required AC, DC, and AC vital with the bus electrical power distribution Surveillance subsystems. Frequency Control Program North Anna Units 1 and 2 3.8.10-2 Amendments 262 and 243 | |||
Boron Concentration 3.9.1 3.9 REFUELING OPERATIONS 3.9.1 Boron Concentration LCO 3.9.1 Boron concentrations of the Reactor Coolant System (RCS) , the refueling canal, and the refueling cavity shall be maintained within the limit specified in the COLR. | |||
APPLICABILITY: MODE 6. | |||
- - NOTE - - - - - - - - | |||
Only applicable to the refueling canal and refueling cavity when connected to the RCS. | |||
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Boron concentration A.l Suspend CORE Immediately not within limit. ALTERATIONS. | |||
AND A.2 Suspend positive Immediately reactivity additions. | |||
AND A.3 Initiate action to Immediately restore boron concentration to within limit. | |||
SURVEILLANCE IREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Verify boron concentration is within the In accordan ce wi th limit specified in the COLR. the Surveillance Frequency Control Program North Anna Units 1 and 2 3.9.1-1 Amendments 262 and 243 | |||
Nuclear Instrumentation 3.9.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.9.3.2 -------------------NOTE------------------- | |||
Neutron detectors are excluded from CHANNEL CALIBRATION. | |||
Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.9.3-2 Amendments 262 and 243 | |||
Containment Penetrations 3.9.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.4.1 Verify each required containment In accordance penetration ;s in the required status. with the Surveillance Frequency Control Program SR 3.9.4.2 -------------------NOTE------------------- | |||
Not required to be met for containment purge and exhaust valve(s) in penetrations closed to comp1y with LCO 3.9.4.c.1. | |||
Verify each required containment purge and In accordance exhaust valve actuates to the isolation with the position on manual initiation. Surveillance Frequency Control Program North Anna Units 1 and 2 Amendments 262 and 243 | |||
RHR and Coolant Circulation-High Water Level 3.9.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (conti nued) A.4 Close equipment hatch 4 hours and secure with four bolts. | |||
AND A.S Close one door in each 4 hours installed air lock. | |||
A.6.1 Close each penetration 4 hours providing direct access from the containment atmosphere to the outside atmosphere with a manual or automatic isolation valve, blind flange, or equivalent. | |||
A.6.2 Verify each 4 hours penetration is capable of being closed by an OPERABLE Contaoi nment Purge and Exhaust Isolation System. | |||
SURVEI LLANCE IREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify one RHR loop is in operation and In accordance circulating reactor coolant at a flow rate with the of ;:?! 3000 gpm. Survei 11 ance Frequency Control Program North Anna Units 1 and 2 3.9.5-2 Amendments 262 and 243 | |||
RHR and Coolant Circulation-Low Water Level 3.9.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.5.2 Verify each 4 hours penetration is capable of being closed by an OPERABLE Containment Purge and Exhaust Isolation System. | |||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify one RHR loop is in operation and In accordance circulating reactor coolant at a flow rate with the of: Surveil 1ance Frequency | |||
: a. ~ 3000 gpm. or Control Program | |||
: b. ~ 2000 gpm if RCS temperature S 140°F and time since entry into MODE 3 | |||
~ 100 hours. | |||
SR 3.9.6.2 -------------------NOTE------------------- | |||
Not required to be performed until 24 hours after a required RHR pump is not in operation. | |||
Verify correct breaker alignment and In accordance indicated power available to the required with the RHR pump that is not in operation. Surveillance Frequency Control Program North Anna Units 1 and 2 3.9.6-3 Amendments 262 and 243 | |||
Refueling Cavity Water Level 3.9.7 3.9 REFUELING OPERATIONS 3.9.7 Refueling Cavity Water Level LCO 3.9.7 Refueling cavity water level shall be maintained ~ 23 ft above the top of reactor vessel flange. | |||
APPLICABILITY: During movement of irradiated fuel assemblies within containment. | |||
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refueling cavity water A.l Suspend movement of Immediately 1evel not within i rradi ated fuel 1imit. assemblies within containment. | |||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify refueling cavity water 1evel is In accordance | |||
~ 23 ft above the top of reactor vessel with the flange. Surveillance | |||
* Frequency Control Program North Anna Units 1 and 2 3.9.7-1 Amendments 262 and 243 | |||
Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.16 | |||
: e. The quantitative limits on unfiltered air inleakage into the MCR/ESGR envelope. These limits shall be stated 1n a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph c. The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of design basis accident consequences. Unfiltered air inleakage limits for hazardous chemicals must ensure that exposure of MCR/ESGR envelope occupants to these hazards will be within the assumptions in the licensing basis. | |||
: f. The provisions of SR 3.0.2 are applicable to the Frequencies for assessing MCR/ESGR envelope habitability, determining MCR/ESGR envelope unfiltered inleakage, and measuring MCR/ESGR envelope pressure and assessing the MCR/ESGR envelope boundary as required by paragraphs c and d, respectively. | |||
5.5.17 Surveillance Frequency Control Program This program provides controls for Surveillance Frequencies. The program shall ensure that Surveillance Requirements specified in the Technical Specification are performed at interval sufficient to assure the associated Limiting Conditions for Operation are met. | |||
: a. The Surveillance Frequency Control Program shall contain a list of Frequenci es of those Survei 11 ance Requi rements for whi c,h the Frequency is controlled by the program. | |||
: b. Changes to the Frequencies listed in the Surveillance Frequency Control Program shall be made in accordance with NEI 04-10, IIRisk-Informed Method for Control of Surveillance Frequenc1es,1I Rev; s1 on 1. | |||
: c. The provisions of Surveillance ReqUirements 3.0.2 and 3.0.3 are applicable to the Frequencies established in the Surveillance Frequency Control Program. | |||
North Anna Units 1 and 2 5.5-17 Amendments 262 and 243 | |||
UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555*0001 SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION RELATED TO AMENDMENT NO. 262 TO RENEWED FACILITY OPERATING LICENSE NO. NPF-4 AND AMENDMENT NO. 243 TO RENEWED FACILITY OPERATING LICENSE NO. NPF-7 VIRGINIA ELECTRIC AND POWER COMPANY NORTH ANNA POWER STATION. UNITS 1 AND 2 DOCKET NOS. 50-338 AND 50-339 | |||
==1.0 INTRODUCTION== | ==1.0 INTRODUCTION== | ||
By application dated March 30, 2010 (Agencywide Documents Access and Management System (ADAMS), Accession Nos. ML100900162, ML100900163, ML100900167), as supplemented by letters dated August 30, 2010 (ADAMS Accession No. ML102430462) and January 18, 2011 (ADAMS Accession No. ML110200451), Virginia Electric and Power Company (the licensee) submitted a request for changes to the North Anna Power Station, Unit Nos. 1 and 2 (NAPS 1 and 2), Technical Specifications (TSs). The requested change is to relocate specific surveillance frequencies to a licensee-controlled program with the implementation of Nuclear Energy Institute (NEI) 04-10, "Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies." The changes are consistent with NRC-approved Industry Technical Specification Task Force (TSTF) Standard Technical Specifications (STS) change TSTF-425, Revision 3. The supplemental letter provided additional information that clarified the application, did not expand the scope of the application as originally noticed, and did not change the U.S. Nuclear Regulatory Commission (NRC, the Commission) staff's original proposed no significant hazard consideration determination. | By application dated March 30, 2010 (Agencywide Documents Access and Management System (ADAMS), Accession Nos. ML100900162, ML100900163, ML100900167), as supplemented by letters dated August 30, 2010 (ADAMS Accession No. ML102430462) and January 18, 2011 (ADAMS Accession No. ML110200451), Virginia Electric and Power Company (the licensee) submitted a request for changes to the North Anna Power Station, Unit Nos. 1 and 2 (NAPS 1 and 2), Technical Specifications (TSs). The requested change is to relocate specific surveillance frequencies to a licensee-controlled program with the implementation of Nuclear Energy Institute (NEI) 04-10, "Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies." The changes are consistent with NRC-approved Industry Technical Specification Task Force (TSTF) Standard Technical Specifications (STS) change TSTF-425, Revision 3. The supplemental letter provided additional information that clarified the application, did not expand the scope of the application as originally noticed, and did not change the U.S. Nuclear Regulatory Commission (NRC, the Commission) staff's original proposed no significant hazard consideration determination. | ||
This safety evaluation (SE) documents the NRC staff's review of the impact of the proposed TS changes specifically address when implemented, TSTF-425 relocates most periodic frequencies of TS surveillances to a licensee controlled program, the Surveillance Frequency Control Program (SFCP), and provides requirements for the new program in the Administrative Controls section of the TS. All surveillance frequencies can be relocated except: Frequencies that reference other approved programs for the specific interval (such as the In-Service Testing Program or the Primary Containment Leakage Rate Testing Program); | This safety evaluation (SE) documents the NRC staff's review of the impact of the proposed TS changes specifically address when implemented, TSTF-425 relocates most periodic frequencies of TS surveillances to a licensee controlled program, the Surveillance Frequency Control Program (SFCP), and provides requirements for the new program in the Administrative Controls section of the TS. All surveillance frequencies can be relocated except: | ||
Frequencies that are purely event-driven | Frequencies that reference other approved programs for the specific interval (such as the In-Service Testing Program or the Primary Containment Leakage Rate Testing Program); | ||
{e.g., "each time the control rod is withdrawn to | Frequencies that are purely event-driven {e.g., "each time the control rod is withdrawn to | ||
-the 'full out' position"); | |||
Frequencies that are event-driven, but have a time component for performing the surveillance on a one-time basis once the event occurs (e.g., "within 24 hours after thermal power reaching;;:: | - 2 the 'full out' position"); | ||
95% RTP [rated thermal power]"); | Frequencies that are event-driven, but have a time component for performing the surveillance on a one-time basis once the event occurs (e.g., "within 24 hours after thermal power reaching;;:: 95% RTP [rated thermal power]"); and Frequencies that are related to specific conditions (e.g., battery degradation, age and capacity) or conditions for the performance of a surveillance requirement (e.g., "drywell to suppression chamber differential pressure decrease"). | ||
and Frequencies that are related to specific conditions (e.g., battery degradation, age and capacity) or conditions for the performance of a surveillance requirement (e.g., "drywell to suppression chamber differential pressure decrease"). | A new program is added to the Administrative Controls of TS Section 5 as Specification 5.5.17. | ||
A new program is added to the Administrative Controls of TS Section 5 as Specification 5.5.17. The new program is called the SFCP and describes the requirements for the program to control changes to the relocated surveillance frequencies. | The new program is called the SFCP and describes the requirements for the program to control changes to the relocated surveillance frequencies. The TS Bases for each of the affected surveillance requirements are revised to state that the frequency is set in accordance with the SFCP. Some surveillance requirements Bases do not contain a discussion of the frequency. In these cases, the Bases describing the current frequency were added to maintain consistency with the Bases for similar surveillances. These instances are noted in the markup along with the source of the text. The proposed licensee changes to the Administrative Controls of the TS to incorporate the SFCP include a specific reference to Nuclear Energy Institute (NEI) 04-10, "Risk-Informed Technical Specifications Initiative 5B, Risk-Informed Method for Control of Surveillance Frequencies," Revision 1, as the basis for making any changes to the surveillance frequencies once they are relocated out of the TS. | ||
The TS Bases for each of the affected surveillance requirements are revised to state that the frequency is set in accordance with the SFCP. Some surveillance requirements Bases do not contain a discussion of the frequency. | In a letter dated September 19, 2007, the NRC staff approved NEI 04-10, Revision 1 (ADAMS Accession No. ML072570267), as acceptable for referencing in licensing actions to the extent specified and under the limitations delineated in NEI 04-10, and the SE providing the basis for NRC acceptance of NEI 04-10. | ||
In these cases, the Bases describing the current frequency were added to maintain consistency with the Bases for similar surveillances. | |||
These instances are noted in the markup along with the source of the text. The proposed licensee changes to the Administrative Controls of the TS to incorporate the SFCP include a specific reference to Nuclear Energy Institute (NEI) 04-10, "Risk-Informed Technical Specifications Initiative 5B, Risk-Informed Method for Control of Surveillance Frequencies," Revision 1, as the basis for making any changes to the surveillance frequencies once they are relocated out of the TS. In a letter dated September 19, 2007, the NRC staff approved NEI 04-10, Revision 1 (ADAMS Accession No. ML072570267), as acceptable for referencing in licensing actions to the extent specified and under the limitations delineated in NEI 04-10, and the SE providing the basis for NRC acceptance of NEI 04-10. | ==2.0 REGULATORY EVALUATION== | ||
In the "Final Policy Statement: Technical Specifications for Nuclear Power Plants" published in the Federal Register (FR) (58 FR 39132, published July 22, 1993), the NRC addressed the use of Probabilistic Safety Analysis (PSA), currently referred to as Probabilistic Risk Assessment (PRA) in STS. In this 1993 FR publication, the NRC states, in part: | |||
'The Commission believes that it would be inappropriate at this time to allow requirements which meet one or more of the first three criteria [of 10 CFR 50.36] to be deleted from technical specifications based solely on PSA (Criterion 4). | |||
However, if the results ofPSA indicate that technical specifications can be relaxed or removed, a deterministic review will be performed. " | |||
"The Commission Policy in this regard is consistent with its Policy Statement on | |||
'Safety Goals for the operation of Nuclear Power Plants,' 51 FR 30028, published on August 21, 1986. The Policy Statement on Safety Goals states in part, probabilistic results should also be reasonably balanced and supported through use of deterministic arguments. In this way, judgments can be made about the degree of confidence to be given these [probabilistic] estimates and assumptions. | |||
This is a key part of the process for determining the degree of regulatory conservatism that may be warranted for particular decisions. This | |||
'defense-in-depth' approach is expected to continue to ensure the protection of public health and safety. " | |||
- 3 | |||
'The Commission will continue to use PSA, consistent with its policy on Safety Goals, as a tool in evaluating specific line item improvements to Technical Specifications, new requirements, and industry proposals for risk-based Technical Specification changes. " | |||
Approximately 2 years later the NRC provided additional detail concerning the use of PRA in the "Final Policy Statement: Use of Probabilistic Risk Assessment in Nuclear Regulatory Activities" published in the Federal Register (60 FR 42622, August 16,1995). In this FR publication, the NRC states, in part: | |||
"The Commission believes that an overall policy on the use of PRA methods in nuclear regulatory activities should be established so that the many potential applications of PRA can be implemented in a consistent and predictable manner that would promote regulatory stability and efficiency. In addition, the Commission believes that the use of PRA technology in NRC regulatory activities should be increased to the extent supported by the state-of-the-art in PRA methods and data and in a manner that complements the NRC's deterministic approach. " | |||
"PRA addresses a broad spectrum of initiating events by assessing the event frequency. Mitigating system reliability is then assessed, including the potential for multiple and common-cause failures. The treatment, therefore, goes beyond the single failure requirements in the deterministic approach. The probabilistic approach to regulation is, therefore, considered an extension and enhancement of traditional regulation by conSidering risk in a more coherent and complete manner. " | |||
'Therefore, the Commission believes that an overall policy on the use of PRA in nuclear regulatory activities should be established so that the many potential applications of PRA can be implemented in a consistent and predictable manner that promotes regulatory stability and efficiency. This policy statement sets forth the Commission's intention to encourage the use of PRA and to expand the scope of PRA applications in aI/ nuclear regulatory matters to the extent supported by the state-of-the-art in terms of methods and data. " | |||
'Therefore, the Commission adopts the fol/owing policy statement regarding the expanded NRC use of PRA: | |||
(1) The use of PRA technology should be increased in aI/ regulatory matters to the extent supported by the state-of-the-art in PRA methods and data and in a manner that complements the NRC's deterministic approach and supports the NRC's traditional defense-in-depth philosophy. | |||
(2) PRA and associated analyses (e.g., sensitivity studies, uncertainty analyses, and importance measures) should be used in regulatory matters, where practical within the bounds of the state-of-the-art, to reduce unnecessary conseNatism associated with current regulatory requirements, regulatory guides, license commitments, and staff practices. Where appropriate, PRA should be used to support the proposal for additional regulatory requirements in accordance with Title 10 of the Code of Federal Regulations (10 CFR) 50.109 (Backfit Rule). Appropriate procedures for including PRA in the process should be developed and followed. It is, of course, understood that the intent of this policy is that existing rules and regulations shall be complied with unless these rules and regulations are | |||
-4 revised. | |||
(3) PRA evaluations in support of regulatory decisions should be as realistic as practicable and appropriate supporting data should be publicly available for review. | |||
(4) The Commission's safety goals for nuclear power plants and subsidiary numerical objectives are to be used with appropriate consideration of uncertainties in making regulatory judgments on the need for proposing and backfitting new generic requirements on nuclear power plant licensees. " | |||
In 10 CFR 50.36, the NRC established its regulatory requirements related to the content of TSs. | |||
Pursuant to 10 CFR 50.36, TSs are required to include items in the following five specific categories related to station operation: (1) safety limits, limiting safety system settings, and limiting control settings; (2) limiting conditions for operation; (3) surveillance requirements; (4) design features; and (5) administrative controls. | |||
As stated in 10 CFR 50.36(c)(3), "Surveillance requirements are requirements relating to test, calibration, or inspection to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met." These categories will remain in the TSs. The new TS SFCP provides the necessary administrative controls to require that surveillance frequencies relocated to the SFCP are conducted at a frequency to assure that the necessary quality of systems and components are maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met. Changes to surveillance frequencies in the SFCP are made using the methodology contained in NEI 04-10, including qualitative considerations, results of risk analyses, sensitivity studies and any bounding analyses, and recommended monitoring of structures, systems, and components (SSCs), and required to be documented. Furthermore, changes to frequencies are subject to regulatory review and oversight of the SFCP implementation through the rigorous NRC review of safety-related SSC performance provided by the reactor oversight program. | |||
Licensees are required by TS to perform surveillance test, calibration, or inspection on specific safety-related system equipment (e.g., reactivity control, power distribution, electrical, and instrumentation) to verify system operability. Surveillance frequencies, currently identified in TSs, are based primarily upon deterministic methods such as engineering jUdgment, operating experience, and manufacturer's recommendations. The licensee's use of NRC-approved methodologies identified in NEI 04-10 provides a way to establish risk-informed surveillance frequencies that complement the deterministic approach and support the NRC's traditional defense-in-depth philosophy. | |||
The licensee's SFCP ensures that surveillance requirements specified in the TSs are performed at intervals sufficient to assure the above regulatory requirements are met. Existing regulatory requirements, such as 10 CFR 50.65, "Requirements for Monitoring the Effectiveness of Maintenance at Nuclear Power Plants," and 10 CFR 50, Appendix B (corrective action program), | |||
require licensee monitoring of surveillance test failures and implementing corrective actions to address such failures. One of these actions may be to consider increasing the frequency at which a surveillance test is performed. In addition, the SFCP implementation guidance in NEI 04-10 requires monitoring the performance of SSCs for which surveillance frequencies are decreased to assure reduced testing does not adversely impact the SSCs. These requirements, and the monitoring required by NEI 04-10, ensure that surveillance frequencies are sufficient to assure that the requirements of 10 CFR 50.36 are satisfied and that any performance deficiencies will be identified and appropriate corrective actions taken. | |||
- 5 Regulatory Guide (RG) 1.174, "An Approach for Using Probabilistic Risk Assessment in Risk-Informed Decisions on Plant-Specific Changes to the Licensing Basis," describes a risk-informed approach, acceptable to the NRC, for assessing the nature and impact of proposed permanent licensing-basis changes by considering engineering issues and applying risk insights. This RG also provides risk acceptance guidelines for evaluating the results of such evaluations. | |||
In RG 1.177, "An Approach for Plant-Specific, Risk-Informed Decisionmaking: Technical Specifications," it describes an acceptable risk-informed approach specifically for assessing proposed permanent TS changes. | |||
In RG 1.200, "An Approach for Determining the Technical Adequacy of Probabilistic Risk Assessment Results for Risk-Informed Activities," it describes an acceptable approach for determining whether the quality of the PRA, in total or the parts that are used to support an application, is sufficient to provide confidence in the results, such that the PRA can be used in regulatory decision making for light water-reactors. | |||
==3.0 TECHNICAL EVALUATION== | |||
The licensee's adoption of TSTF-425 for NAPS provides for administrative relocation of applicable surveillance frequencies, and provides for the addition of the SFCP to the administrative controls of TS. TSTF-425 also requires the application of NEI 04-10 for any changes to surveillance frequencies within the SFCP. The licensee's application for the changes proposed in TSTF--425 included documentation regarding the PRA technical adequacy consistent with the requirements of RG 1.200, "An Approach for Determining the Technical Adequacy of Probabilistic Risk Assessment Results for Risk-Informed Activities," Revision 1. In accordance with NEI 04-10 PRA methods are used, in combination with plant performance data and other considerations, to identify and justify modifications to the surveillance frequencies of equipment at nuclear power plants. This is in accordance with guidance provided in RG 1.174, "An Approach for Using Probabilistic Risk Assessment in Risk-Informed Decisions on Plant-Specific Changes to the Licensing Basis," and RG 1.177 in support of changes to surveillance test intervals. | |||
3.1 RG 1.177 Five Key Safety Principles In RG 1.177 it identifies five key safety principles required for risk-informed changes to TSs. Each of these principles is addressed by the industry methodology document, NEI 04-10. | |||
3.1.1 The Proposed Change Meets Current Regulations In 10 CFR 50.36(c)(3) it provides that TSs will include surveillances which are "requirements relating to test, calibration, or inspection to assure that necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met." In NEI 04-10 it provides guidance for relocating the surveillance frequencies from the TSs to a licensee-controlled program by providing an NRC-approved methodology for control of the surveillance frequencies. The surveillance category remains in the TSs, as required by 10 CFR 50.36(c)(3). | |||
-6 This change is consistent with other NRC-approved TS changes in which the surveillance frequencies are relocated to licensee-controlled documents, such as surveillances performed in accordance with the In-service Testing Program or the Primary Containment Leakage Rate Testing Program. Thus, this proposed change meets the first key safety principle of RG 1.177 by complying with current regulations. | |||
3.1.2 The Proposed Change Is Consistent With the Defense-in-Depth Philosophy Consistency with the defense-in-depth philosophy, the second key safety principle of RG 1.177, is maintained if: | |||
* A reasonable balance is preserved among prevention of core damage, prevention of containment failure, and consequence mitigation. | |||
* Over-reliance on programmatic activities to compensate for weaknesses in plant design is avoided. | |||
* System redundancy, independence, and diversity are preserved commensurate with the expected frequency, consequences of challenges to the system, and uncertainties (e.g., | |||
no risk outliers). Because the scope of the proposed methodology is limited to revision of surveillance frequencies, the redundancy, independence, and diversity of plant systems are not impacted. | |||
* Defenses against potential common cause failures are preserved, and the potential for the introduction of new common cause failure mechanisms is assessed. | |||
* Independence of barriers is not degraded. | |||
* Defenses against human errors are preserved. | |||
* The intent of the General Design Criteria in 10 CFR Part 50, Appendix A, is maintained. | |||
In TSTF-425, it requires the application of NEI 04-10 for any changes to surveillance frequencies within the SFCP. In NEI 04-10 it uses both the core damage frequency (CDF) and the large early release frequency (LERF) metrics to evaluate the impact of proposed changes to surveillance frequencies. The guidance of RG 1.174 and RG 1.177 for changes to CDF and LERF is achieved by evaluation using a comprehensive risk analysis, which assesses the impact of proposed changes including contributions from human errors and common cause failures. | |||
Defense-in-depth is also included in the methodology explicitly as a qualitative consideration outside of the risk analysis, as is the potential impact on detection of component degradation that could lead to an increased likelihood of common cause failures. Both the quantitative risk analysis and the qualitative considerations assure a reasonable balance of defense-in-depth is maintained to ensure protection of public health and safety, satisfying the second key safety principle of RG 1.177. | |||
3.1.3 The Proposed Change Maintains Sufficient Safety Margins The engineering evaluation that will be conducted by the licensee under the SFCP when frequencies are revised will assess the impact of the proposed frequency change with the principle that sufficient safety margins are maintained. The guidelines used for making that assessment will include ensuring the proposed surveillance test frequency change is not in conflict with approved industry codes and standards or adversely affects any assumptions or inputs to the safety analysis, or, if such inputs are affected, justification is provided to ensure | |||
-7 sufficient safety margin will continue to exist. | |||
The design, operation, testing methods, and acceptance criteria for SSCs, specified in applicable codes and standards (or alternatives approved for use by the NRC) will continue to be met as described in the plant licensing basis (including the Updated Final Safety Analysis Report and bases to TS), since these are not affected by changes to the surveillance frequencies. Similarly, there is no impact to safety analysis acceptance criteria as described in the plant licensing basis. | |||
Thus, safety margins are maintained by the proposed methodology, and the third key safety principle of RG 1.177 is satisfied. | |||
3.1.4 When Proposed Changes Result in an Increase in Core Damage Frequency or Risk, the Increases Should Be Small and Consistent With the Intent of the Commission's Safety Goal Policy Statement In RG 1.177 it provides a framework for evaluating the risk impact of proposed changes to surveillance frequencies. This requires the identification of the risk contribution from impacted surveillances, determination of the risk impact from the change to the proposed surveillance frequency, and performance of sensitivity and uncertainty evaluations. TSTF-425 requires application of NEI 04-10 in the SFCP. In NEI 04-10 it satisfies the intent of RG 1.177 requirements for evaluating the change in risk, and for assuring that such changes are small. | |||
3.1.4.1 Quality of the PRA The quality of the NAPS PRA is compatible with the safety implications of the proposed TS change and the role the PRA plays in justifying the change. That is, the more the potential change in risk or the greater the uncertainty in that risk from the requested TS change, or both, the more rigor that must go into ensuring the quality of the PRA. | |||
The licensee used RG 1.200 to address the technical adequacy of the NAPS PRA. RG 1.200 is NRC's developed regulatory guidance, which endorses with comments and qualifications the use of the American Society of Mechanical Engineers (ASME) RA-Sb-2005, "Addenda to ASME RA-S-002 Standard for Probabilistic Risk Assessment for Nuclear Power Plant Applications," NEI 00-02, "PRA Peer Review Process Guidelines," and NEI 05-04, "Process for Performing Follow-On PRA Peer Reviews Using the ASME PRA Standard." The licensee has performed an assessment of the PRA models used to support the SFCP against the requirements of RG 1.200 to assure that the PRA models are capable of determining the change in risk due to changes to surveillance frequencies of SSCs, using plant-specific data and models. Capability category II of ASME RA-Sb-2005 is applied as the standard, and any identified deficiencies to those requirements are assessed further to determine any impacts to proposed decreases to surveillance frequencies, including by the use of sensitivity studies where appropriate. | |||
The NRC staff reviewed the licensee's assessment of the NAPS PRA and the remaining open deficiencies that do not conform to capability category II of the ASME PRA standard (Table 1 of of the license amendment request, as modified by a response to the NRC staffs request for additional information). The NRC staffs assessment of the remaining open "gaps," to assure that they may be addressed and dispositioned for each surveillance frequency evaluation per the NEI 04-10 methodology, is provided below. | |||
Gap #1: The model for anticipated transient without scram (ATWS) uses a conservative unfavorable exposure time. The licensee identified that this conservative simplification assumes that pressure relief capacity is always insufficient, and that ATWS will be assessed in sensitivity studies when required. The NRC staff | |||
- 8 concurs that assuming a conservative exposure time can be addressed per the methodology of NEI 04-10. | |||
Gap#2: Support system initiating events fault tree include a multiplier which should be replaced with the newer methodology of Electric Power and Research Institute (EPRI) EPRI-TR-1013490, "Support System Initiating Events: Identification and Quantification Guideline." The licensee identified that this gap is important for changes involving the support systems and will be addressed using the EPRI methodology. The NRC staff concurs that this deficiency can be addressed per the methodology of NEI 04-10. | |||
Gap #3: Operator action to restore Emergency Core Cooling System functions for station blackout is not addressed and the documentation does not reflect this required action. The licensee identified the impact as being a small nonconservatism and that a sensitivity analysis would include consideration of this human action. The NRC staff concurs that this deficiency can be addressed per the methodology of NEI04-10. | |||
Gap #4: Consequential loss of reactor coolant pump seal cooling is not included in the model. Since this failure mode would require concurrent failure of two separate systems, the licensee stated that the impact should be comparable or lower than consequential pressurizer power-operated relief valve failures, which are modeled. | |||
Sensitivity analyses will include consideration of this failure mode. The NRC staff concurs that this deficiency can be addressed per the methodology of NEI 04-10 by additional logic models when required. | |||
Gap #5: Electrical bus cross-tie unavailability is not modeled. Additional modeling of this capability will be made to address the gap with sensitivity studies, and therefore the NRC staff concurs that this deficiency can be addressed per the methodology of NEI04-10. | |||
Gap #6: Success criteria involving operator response is not discussed. The licensee identified this as a documentation issue, and therefore the NRC staff concurs that this deficiency can be addressed per the methodology of NEI 04-10. | |||
Gap #7: Inadvertent safety injection actuation is not addressed in the PRA model. The licensee has identified that this deficiency has been addressed subsequent to the submittal to add this initiator and therefore this gap no longer exists. Therefore, the NRC staff finds this action acceptable. | |||
Gap #8: No formal documentation of plant walkdowns and interviews with plant personnel. | |||
The NRC staff concurs that this deficiency can be addressed per the methodology of NEI 04-10. Operator action to restore Emergency Core Cooling System functions for station blackout is not addressed and the documentation does not reflect this required action. The licensee identified the impact as being a small nonconservatism and that a sensitivity analysis would include consideration of this human action. The NRC staff concurs that this deficiency can be addressed per the methodology of NEI04-10. | |||
Consequential loss of reactor coolant pump seal cooling is not included in the model. Since this failure mode would require concurrent failure of two separate systems, the licensee stated that the impact should be comparable or lower than consequential pressurizer power-operated relief valve failures, which are modeled. Sensitivity analyses will include consideration of this failure mode. The NRC staff concurs that this deficiency can be addressed per the methodology of NEI 04-10 by additional logic models when required. | |||
Electrical bus cross-tie unavailability is not modeled. Additional modeling of this capability will be made to address the gap with sensitivity studies, and therefore the NRC staff concurs that this deficiency can be addressed per the methodology of NEI04-10. | |||
Success criteria involving operator response is not discussed. | |||
The licensee identified this as a documentation issue, and therefore the NRC staff concurs that this deficiency can be addressed per the methodology of NEI 04-10. Inadvertent safety injection actuation is not addressed in the PRA model. The licensee has identified that this deficiency has been addressed subsequent to the submittal to add this initiator and therefore this gap no longer exists. Therefore, the NRC staff finds this action acceptable. | |||
No formal documentation of plant walkdowns and interviews with plant personnel. | |||
The licensee has identified this as a documentation issue and therefore the NRC staff concurs that this deficiency can be addressed per the methodology of NEI04-10. | The licensee has identified this as a documentation issue and therefore the NRC staff concurs that this deficiency can be addressed per the methodology of NEI04-10. | ||
The PRA model does not distinguish between water relief and steam relief for pressurizer power-operated relief valves failure to reclose failure mode. The guidance of EPRI-1 011 047 will be used to develop sensitivity models. Therefore, the NRC staff concurs that this deficiency can be addressed per the methodology of NEI 04-10. Time windows for successful completion of operator actions need to be updated. The licensee identified similarities with other PRA models based on plant-specific analyses, and identified that a sensitivity study using a factor of two for the | Gap #9: The PRA model does not distinguish between water relief and steam relief for pressurizer power-operated relief valves failure to reclose failure mode. The guidance of EPRI-1 011 047 will be used to develop sensitivity models. Therefore, the NRC staff concurs that this deficiency can be addressed per the methodology of NEI 04-10. | ||
-9 probability offailure of the action would be used. Therefore, the NRC staff concurs that this deficiency can be addressed per the methodology of NEI 04-10. Required action times are based on similar actions for other PRA models rather than on time measurements from walkthroughs or simulator scenarios. | Gap #10: Time windows for successful completion of operator actions need to be updated. | ||
The licensee does not expect any significant changes based on comparisons with other PRA models, and considers this to be a documentation issue. The NRC staff concurs that this deficiency can be addressed per the methodology of NEI 04-10. Gaps #12, #13, #14, #15, #16: | The licensee identified similarities with other PRA models based on plant-specific analyses, and identified that a sensitivity study using a factor of two for the | ||
Deficiencies in documentation of human errors, key assumptions and key sources of uncertainty were identified. | |||
The NRC staff concurs that these deficiencies in documentation can be addressed per the methodology of NEI04-10. | -9 probability offailure of the action would be used. Therefore, the NRC staff concurs that this deficiency can be addressed per the methodology of NEI 04-10. | ||
Gap A realistic evaluation of secondary side isolation capability for steam generator tube releases is required. | Gap#11: Required action times are based on similar actions for other PRA models rather than on time measurements from walkthroughs or simulator scenarios. The licensee does not expect any significant changes based on comparisons with other PRA models, and considers this to be a documentation issue. The NRC staff concurs that this deficiency can be addressed per the methodology of NEI 04-10. | ||
The licensee identified that additional steam generator relief valve demands are not considered, and that a more realistic model will be developed to support sensitivity studies. The NRC staff concurs that this deficiency can be addressed per the methodology of NEI 04-10. Based on the licensee's assessment using the applicable PRA standard and RG 1.200, the level of PRA quality, combined with the proposed evaluation and disposition of gaps, is sufficient to support the evaluation of changes proposed to surveillance frequencies within the SFCP, and is consistent with Regulatory Position 2.3.1 of RG 1.177. 3.1.4.2 Scope of the PRA The licensee is required to evaluate each proposed change to a relocated surveillance frequency using the guidance contained in NEI 04-10 to determine its potential impact on risk, due to impacts from internal events, fires, seismic, other external events, and from shutdown conditions. | Gaps #12, #13, #14, #15, #16: Deficiencies in documentation of human errors, key assumptions and key sources of uncertainty were identified. The NRC staff concurs that these deficiencies in documentation can be addressed per the methodology of NEI04-10. | ||
Consideration is made of both CDF and LERF metrics. In cases where a PRA of sufficient scope or where quantitative risk models were unavailable, the licensee uses bounding analyses, or other conservative quantitative evaluations. | Gap #17: A realistic evaluation of secondary side isolation capability for steam generator tube releases is required. The licensee identified that additional steam generator relief valve demands are not considered, and that a more realistic model will be developed to support sensitivity studies. The NRC staff concurs that this deficiency can be addressed per the methodology of NEI 04-10. | ||
A qualitative screening analysis may be used when the surveillance frequency impact on plant risk is shown to be negligible or zero. The individual plant examination of external events (IPEEE) fire-induced vulnerability evaluation analysis, and the IPEEE seismic margins analysis, will be used to provide insights for fires and seismic events. Other external hazards were screened during the IPEEE assessment, and will therefore be qualitatively assessed for this application. | Based on the licensee's assessment using the applicable PRA standard and RG 1.200, the level of PRA quality, combined with the proposed evaluation and disposition of gaps, is sufficient to support the evaluation of changes proposed to surveillance frequencies within the SFCP, and is consistent with Regulatory Position 2.3.1 of RG 1.177. | ||
The licensee's evaluation methodology is sufficient to ensure the scope of the risk contribution of each surveillance frequency change is properly identified for evaluation, and is consistent with Regulatory Position 2.3.2 of RG 1.177. 3.1.4.3 PRA Modeling The licensee will determine whether the SSCs affected by a proposed change to a surveillance frequency are modeled in the PRA. Where the SSC is directly or implicitly modeled, a quantitative evaluation of the risk impact may be carried out. The methodology adjusts the failure probability of the impacted SSCs, including any impacted common cause failure modes, based on the proposed change to the surveillance frequency. | 3.1.4.2 Scope of the PRA The licensee is required to evaluate each proposed change to a relocated surveillance frequency using the guidance contained in NEI 04-10 to determine its potential impact on risk, due to impacts from internal events, fires, seismic, other external events, and from shutdown conditions. | ||
Where the SSC is not modeled in the PRA, bounding analyses are performed to characterize the impact of the proposed change to the | Consideration is made of both CDF and LERF metrics. In cases where a PRA of sufficient scope or where quantitative risk models were unavailable, the licensee uses bounding analyses, or other conservative quantitative evaluations. A qualitative screening analysis may be used when the surveillance frequency impact on plant risk is shown to be negligible or zero. | ||
-surveillance frequency. | The individual plant examination of external events (IPEEE) fire-induced vulnerability evaluation analysis, and the IPEEE seismic margins analysis, will be used to provide insights for fires and seismic events. Other external hazards were screened during the IPEEE assessment, and will therefore be qualitatively assessed for this application. | ||
Potential impacts on the risk analyses due to screening criteria and truncation levels are addressed by the requirements for PRA technical adequacy consistent with guidance contained in RG 1.200, and by sensitivity studies identified in NEI 04-10. The licensee will perform quantitative evaluations of the impact of selected testing strategy (Le., staggered testing or sequential testing) consistently with the guidance of NUREG/CR-6141 and NUREG/CR-5497, as discussed in NEI 04-10. Thus, through the application of NEI 04-10 the NAPS PRA modeling is sufficient to ensure an acceptable evaluation of risk for the proposed changes in surveillance frequency, and is consistent with Regulatory Position 2.3.3 of RG 1.177. 3.1.4.4 Assumptions for Time-Related Failure Contributions The failure probabilities of SSCs modeled in the NAPS PRA include a standby time-related contribution and a cyclic demand-related contribution. | The licensee's evaluation methodology is sufficient to ensure the scope of the risk contribution of each surveillance frequency change is properly identified for evaluation, and is consistent with Regulatory Position 2.3.2 of RG 1.177. | ||
The NEI 04-10 criterion adjusts the time-related failure contribution of SSCs affected by the proposed change to surveillance frequency. | 3.1.4.3 PRA Modeling The licensee will determine whether the SSCs affected by a proposed change to a surveillance frequency are modeled in the PRA. Where the SSC is directly or implicitly modeled, a quantitative evaluation of the risk impact may be carried out. The methodology adjusts the failure probability of the impacted SSCs, including any impacted common cause failure modes, based on the proposed change to the surveillance frequency. Where the SSC is not modeled in the PRA, bounding analyses are performed to characterize the impact of the proposed change to the | ||
This is consistent with RG 1.177, Section 2.3.3, which permits separation of the failure rate contributions into demand and standby for evaluation of surveillance requirements. | |||
If the available data does not support distinguishing between the time-related failures and demand failures, then the change to surveillance frequency is conservatively assumed to impact the total failure probability of the SSC, including both standby and demand contributions. | - 10 surveillance frequency. Potential impacts on the risk analyses due to screening criteria and truncation levels are addressed by the requirements for PRA technical adequacy consistent with guidance contained in RG 1.200, and by sensitivity studies identified in NEI 04-10. | ||
The SSC failure rate (per unit time) is assumed to be unaffected by the change in test frequency, and will be confirmed by the required monitoring and feedback implemented after the change in surveillance frequency is implemented. | The licensee will perform quantitative evaluations of the impact of selected testing strategy (Le., | ||
The process requires consideration of qualitative sources of information with regards to potential impacts of test frequency on SSC performance, including industry and plant-specific operating experience, vendor recommendations, industry standards, and code-specified test intervals. | staggered testing or sequential testing) consistently with the guidance of NUREG/CR-6141 and NUREG/CR-5497, as discussed in NEI 04-10. | ||
Thus, the process is not reliant upon risk analyses as the sole basis for the proposed changes. The potential beneficial risk impacts of reduced surveillance frequency, including reduced downtime, lesser potential for restoration errors, reduction of potential for test caused transients, and reduced test-caused wear of equipment, are identified qualitatively, but are conservatively not required to be quantitatively assessed. | Thus, through the application of NEI 04-10 the NAPS PRA modeling is sufficient to ensure an acceptable evaluation of risk for the proposed changes in surveillance frequency, and is consistent with Regulatory Position 2.3.3 of RG 1.177. | ||
Thus, through the application of NEt 04-10, the licensee has employed reasonable assumptions with regard to extensions of surveillance test intervals, and is consistent with Regulatory Position 2.3.4 of RG 1.177. 3.1.4.5 Sensitivity and Uncertainty Analyses In NEI 04-10 it requires sensitivity studies to assess the impact of uncertainties from key assumptions of the PRA, uncertainty in the failure probabilities of the affected SSCs, impact to the frequency of initiating events, and of any identified deviations from capability category II of ASME PRA Standard (ASME RA-Sb-2005). | 3.1.4.4 Assumptions for Time-Related Failure Contributions The failure probabilities of SSCs modeled in the NAPS PRA include a standby time-related contribution and a cyclic demand-related contribution. The NEI 04-10 criterion adjusts the time-related failure contribution of SSCs affected by the proposed change to surveillance frequency. This is consistent with RG 1.177, Section 2.3.3, which permits separation of the failure rate contributions into demand and standby for evaluation of surveillance requirements. If the available data does not support distinguishing between the time-related failures and demand failures, then the change to surveillance frequency is conservatively assumed to impact the total failure probability of the SSC, including both standby and demand contributions. The SSC failure rate (per unit time) is assumed to be unaffected by the change in test frequency, and will be confirmed by the required monitoring and feedback implemented after the change in surveillance frequency is implemented. The process requires consideration of qualitative sources of information with regards to potential impacts of test frequency on SSC performance, including industry and plant-specific operating experience, vendor recommendations, industry standards, and code-specified test intervals. Thus, the process is not reliant upon risk analyses as the sole basis for the proposed changes. | ||
Where the sensitivity analyses identify a potential impact on the proposed change, revised surveillance frequencies are considered, along with any qualitative considerations that may bear on the results of such sensitivity studies. Required monitoring and feedback of SSC performance once the revised surveillance frequencies are implemented will also be performed. | The potential beneficial risk impacts of reduced surveillance frequency, including reduced downtime, lesser potential for restoration errors, reduction of potential for test caused transients, and reduced test-caused wear of equipment, are identified qualitatively, but are conservatively not required to be quantitatively assessed. Thus, through the application of NEt 04-10, the licensee has employed reasonable assumptions with regard to extensions of surveillance test intervals, and is consistent with Regulatory Position 2.3.4 of RG 1.177. | ||
Thus, through the application of NEI 04-10, the licensee has appropriately considered the possible impact of PRA model uncertainty and sensitivity to key assumptions and model limitations, and is consistent with regulatory position 2.3.5 of RG 1.177. 3.1.4.6 Acceptance Guidelines The licensee will quantitatively evaluate the change in total risk (including internal and external 11 events contributions) in terms of CDF and LERF for both the individual risk impact of a proposed change in surveillance frequency and the cumulative impact from all individual changes to surveillance frequencies using the guidance contained in NRC-approved NEI 04-10 in accordance with the TS SFCP. Each individual change to surveillance frequency must show a risk impact below 1 per year for change to CDF, and below 1 per year for change to LERF. These are consistent with the limits of RG 1.174 for very small changes in risk. Where the RG 1.174 limits are not met, the process either considers revised surveillance frequencies which are consistent with RG 1.174 or the process terminates without permitting the proposed changes. Where quantitative results are unavailable to permit comparison to acceptance guidelines, appropriate qualitative analyses are required to demonstrate that the associated risk impact of a proposed change to surveillance frequency is negligible or zero. Otherwise, bounding quantitative analyses are required which demonstrate the risk impact is at least one order of magnitude lower than the RG 1.174 acceptance guidelines for very small changes in risk. In addition to assessing each individual SSC surveillance frequency change, the cumulative impact of all changes must result in a risk impact below | 3.1.4.5 Sensitivity and Uncertainty Analyses In NEI 04-10 it requires sensitivity studies to assess the impact of uncertainties from key assumptions of the PRA, uncertainty in the failure probabilities of the affected SSCs, impact to the frequency of initiating events, and of any identified deviations from capability category II of ASME PRA Standard (ASME RA-Sb-2005). Where the sensitivity analyses identify a potential impact on the proposed change, revised surveillance frequencies are considered, along with any qualitative considerations that may bear on the results of such sensitivity studies. Required monitoring and feedback of SSC performance once the revised surveillance frequencies are implemented will also be performed. Thus, through the application of NEI 04-10, the licensee has appropriately considered the possible impact of PRA model uncertainty and sensitivity to key assumptions and model limitations, and is consistent with regulatory position 2.3.5 of RG 1.177. | ||
These are consistent with the limits of RG 1.174 for acceptable changes in risk, as referenced by RG 1.177 for changes to surveillance frequencies. | 3.1.4.6 Acceptance Guidelines The licensee will quantitatively evaluate the change in total risk (including internal and external | ||
The NRC staff interprets this assessment of cumulative risk as a requirement to calculate the change in risk from a baseline model utilizing failure probabilities based on the surveillance frequencies prior to implementation of the SFCP, compared to a revised model with failure probabilities based on changed surveillance frequencies. | |||
The NRC staff further notes that the licensee includes a provision to exclude the contribution to cumulative risk from individual changes to surveillance frequencies associated with insignificant risk increases (less than SE-8 CDF and SE-9 LERF) once the baseline PRA models are updated to include the effects of the revised surveillance frequencies. | ~ 11 events contributions) in terms of CDF and LERF for both the individual risk impact of a proposed change in surveillance frequency and the cumulative impact from all individual changes to surveillance frequencies using the guidance contained in NRC-approved NEI 04-10 in accordance with the TS SFCP. Each individual change to surveillance frequency must show a risk impact below 1 E~6 per year for change to CDF, and below 1 E~7 per year for change to LERF. | ||
The quantitative acceptance guidance of RG 1.174 is supplemented by qualitative information to evaluate the proposed changes to surveillance frequencies, including industry and plant-specific operating experience, vendor recommendations, industry standards, the results of sensitivity studies, and SSC performance data and test history. The final acceptability of the proposed change is based on all of these considerations and not solely on the PRA results compared to numerical acceptance guidelines. | These are consistent with the limits of RG 1.174 for very small changes in risk. Where the RG 1.174 limits are not met, the process either considers revised surveillance frequencies which are consistent with RG 1.174 or the process terminates without permitting the proposed changes. | ||
Post implementation performance monitoring and feedback are also required to assure continued reliability of the components. | Where quantitative results are unavailable to permit comparison to acceptance guidelines, appropriate qualitative analyses are required to demonstrate that the associated risk impact of a proposed change to surveillance frequency is negligible or zero. Otherwise, bounding quantitative analyses are required which demonstrate the risk impact is at least one order of magnitude lower than the RG 1.174 acceptance guidelines for very small changes in risk. In addition to assessing each individual SSC surveillance frequency change, the cumulative impact of all changes must result in a risk impact below 1E-S per year for change to CDF, and below 1E-6 per year for change to LERF. The total CDF and total LERF must be reasonably shown to be less than 1E-4 per year and 1 E~S per year, respectively. These are consistent with the limits of RG 1.174 for acceptable changes in risk, as referenced by RG 1.177 for changes to surveillance frequencies. The NRC staff interprets this assessment of cumulative risk as a requirement to calculate the change in risk from a baseline model utilizing failure probabilities based on the surveillance frequencies prior to implementation of the SFCP, compared to a revised model with failure probabilities based on changed surveillance frequencies. The NRC staff further notes that the licensee includes a provision to exclude the contribution to cumulative risk from individual changes to surveillance frequencies associated with insignificant risk increases (less than SE-8 CDF and SE-9 LERF) once the baseline PRA models are updated to include the effects of the revised surveillance frequencies. | ||
The licensee's application of NEI 04-10 provides reasonable acceptance guidelines and methods for evaluating the risk increase of proposed changes to surveillance frequencies, consistent with Regulatory Position 2.4 of RG 1.177. Therefore, the proposed methodology satisfies the fourth key safety principle of RG 1.177 by assuring any increase in risk is small consistent with the intent of the Commission's Safety Goal Policy Statement. The Impact of the Proposed Change Should Be Monitored Using Performance Measurement Strategies The licensee's adoption of TSTF-42S requires application of NEI 04-10 in the SFCP. In NEI 04-10 it requires performance monitoring of SSCs whose surveillance frequency has been revised as part of a feedback process to assure that the change in test frequency has not resulted in degradation of equipment performance and operational safety. The monitoring and feedback includes consideration of maintenance rule monitoring of equipment performance. | The quantitative acceptance guidance of RG 1.174 is supplemented by qualitative information to evaluate the proposed changes to surveillance frequencies, including industry and plant-specific operating experience, vendor recommendations, industry standards, the results of sensitivity studies, and SSC performance data and test history. | ||
In the event of degradation of SSC performance, the surveillance frequency will be reassessed in accordance with the methodology, in addition to any corrective actions which may apply as part of the | The final acceptability of the proposed change is based on all of these considerations and not solely on the PRA results compared to numerical acceptance guidelines. Post implementation performance monitoring and feedback are also required to assure continued reliability of the components. The licensee's application of NEI 04-10 provides reasonable acceptance guidelines and methods for evaluating the risk increase of proposed changes to surveillance frequencies, consistent with Regulatory Position 2.4 of RG 1.177. Therefore, the proposed methodology satisfies the fourth key safety principle of RG 1.177 by assuring any increase in risk is small consistent with the intent of the Commission's Safety Goal Policy Statement. | ||
-maintenance rule requirements. | 3.1.S The Impact of the Proposed Change Should Be Monitored Using Performance Measurement Strategies The licensee's adoption of TSTF-42S requires application of NEI 04-10 in the SFCP. In NEI 04-10 it requires performance monitoring of SSCs whose surveillance frequency has been revised as part of a feedback process to assure that the change in test frequency has not resulted in degradation of equipment performance and operational safety. The monitoring and feedback includes consideration of maintenance rule monitoring of equipment performance. In the event of degradation of SSC performance, the surveillance frequency will be reassessed in accordance with the methodology, in addition to any corrective actions which may apply as part of the | ||
The performance monitoring and feedback specified in NE 04-10 is sufficient to reasonably assure acceptable SSC performance and is consistent with regulatory position 3.2 of RG 1.177. Thus, the fifth key safety principle of RG 1.177 is satisfied. | |||
3.2 Addition of Surveillance Frequency Control Program to Administrative Controls The licensee has included the SFCP and specific requirements into the Administrative Controls, TS Section 5.5.17, Surveillance Frequency Control Program, as follows: This program provides controls for SUNeillance Frequencies. | - 12 maintenance rule requirements. The performance monitoring and feedback specified in NE 04-10 is sufficient to reasonably assure acceptable SSC performance and is consistent with regulatory position 3.2 of RG 1.177. Thus, the fifth key safety principle of RG 1.177 is satisfied. | ||
The program shall ensure that SUNeiJIance Requirements specified in the Technical Specifications are performed at inteNals sufficient to assure that the associated Limiting Conditions for Operation are met. The SUNeillance Frequency Control Program shall contain a list of Frequencies of the SUNeillance Requirements for which the Frequency is controlled by the program. Changes to the Frequencies listed in the SUNeillance Frequency Control Program shall be made in accordance with NEI04-10, "Risk-Informed Method for Control of SUNeiJIance Frequencies, " Revision 1. The provisions of SUNeillance Requirements 3.0.2 and 3.0.3 are applicable to the Frequencies established in the SUNeil/ance Frequency Control Program. The proposed program is consistent with the model application of TSTF-425, and is therefore acceptable. | 3.2 Addition of Surveillance Frequency Control Program to Administrative Controls The licensee has included the SFCP and specific requirements into the Administrative Controls, TS Section 5.5.17, Surveillance Frequency Control Program, as follows: | ||
3.3 Summary The NRC staff has reviewed the licensee's proposed relocation of some surveillance frequencies to a licensee controlled document, and controlling changes to surveillance frequencies in accordance with a new program, the SFCP, identified in the administrative controls of TS. The SFCP and TS Section 5.5.17 references NEI 04-10, which provides a risk-informed methodology using plant-specific risk insights and performance data to revise surveillance frequencies within the SFCP. This methodology supports relocating surveillance frequencies from TS to a licensee-controlled document, provided those frequencies are changed in accordance with NEI 04-10 which is specified in the Administrative Controls of the TS. The proposed licensee adoption of TSTF-425 and risk-informed methodology of NEI 04-10 as referenced in the Administrative Controls of TS, satisfies the key principles of risk-informed decision making applied to changes to TS as delineated in RG 1.177 and RG 1.174, in that: The proposed change meets current regulations; The proposed change is consistent with defense-in-depth philosophy; | This program provides controls for SUNeillance Frequencies. The program shall ensure that SUNeiJIance Requirements specified in the Technical Specifications are performed at inteNals sufficient to assure that the associated Limiting Conditions for Operation are met. | ||
: a. The SUNeillance Frequency Control Program shall contain a list of Frequencies of the SUNeillance Requirements for which the Frequency is controlled by the program. | |||
: b. Changes to the Frequencies listed in the SUNeillance Frequency Control Program shall be made in accordance with NEI04-10, "Risk-Informed Method for Control of SUNeiJIance Frequencies, " Revision 1. | |||
: c. The provisions of SUNeillance Requirements 3.0.2 and 3.0.3 are applicable to the Frequencies established in the SUNeil/ance Frequency Control Program. | |||
The proposed program is consistent with the model application of TSTF-425, and is therefore acceptable. | |||
3.3 Summary The NRC staff has reviewed the licensee's proposed relocation of some surveillance frequencies to a licensee controlled document, and controlling changes to surveillance frequencies in accordance with a new program, the SFCP, identified in the administrative controls of TS. The SFCP and TS Section 5.5.17 references NEI 04-10, which provides a risk-informed methodology using plant-specific risk insights and performance data to revise surveillance frequencies within the SFCP. This methodology supports relocating surveillance frequencies from TS to a licensee-controlled document, provided those frequencies are changed in accordance with NEI 04-10 which is specified in the Administrative Controls of the TS. | |||
The proposed licensee adoption of TSTF-425 and risk-informed methodology of NEI 04-10 as referenced in the Administrative Controls of TS, satisfies the key principles of risk-informed decision making applied to changes to TS as delineated in RG 1.177 and RG 1.174, in that: | |||
The proposed change meets current regulations; The proposed change is consistent with defense-in-depth philosophy; | |||
* The proposed change maintains sufficient safety margins; Increases in risk resulting from the proposed change are small and consistent with the Commission's Safety Goal Policy Statement; and | * The proposed change maintains sufficient safety margins; Increases in risk resulting from the proposed change are small and consistent with the Commission's Safety Goal Policy Statement; and | ||
* The impact of the proposed change is monitored with performance measurement strategies. | * The impact of the proposed change is monitored with performance measurement strategies. | ||
In 10 CFR 50.36(c)(3) it states "[Technical specifications will include items in the following categories:] | In 10 CFR 50.36(c)(3) it states "[Technical specifications will include items in the following categories:] Surveillance Requirements. Surveillance Requirements are requirements relating to test, calibration, or inspection to assure that the necessary quality of systems and components is | ||
Surveillance Requirements. | |||
Surveillance Requirements are requirements relating to test, calibration, or inspection to assure that the necessary quality of systems and components is | |||
- 13 maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met." The NRC staff finds that with the proposed relocation of surveillance frequencies to an owner-controlled document and administratively controlled in accordance with the TS SFCP, the licensee continues to meet the regulatory requirement of 10 CFR 50.36, and, specifically, 10 CFR 50.36(c)(3), surveillance requirements. | |||
The NRC has concluded, on the basis of the considerations discussed above, that (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner, (2) such activities will be conducted in compliance with the NRC's regulations, and (3) the issuance of the amendments will not be inimical to the common defense and security or to the health and safety of the public. | |||
==4.0 STATE CONSULTATION== | |||
In accordance with the Commission's regulations, the Virginia State official was notified of the proposed issuance of the amendment. The State official had no comments. | |||
==5.0 ENVIRONMENTAL CONSIDERATION== | |||
== | The amendments change a requirement with respect to the installation or use of facility components within the restricted area as defined in 10 CFR Part 20. The NRC staff has determined that the amendments involve no significant increase in the amounts and no significant change in the types of any effluents that may be released offsite, and that there is no significant increase in individual or cumulative occupational radiation exposure. The Commission has previously issued a proposed finding that the amendments involve no significant hazards considerations, and there has been no public comment on such finding (75 FR 27833). | ||
Accordingly, the amendments meet the eligibility criteria for categorical exclusion set forth in 10 CFR 51.22{c)(9). Pursuant to 10 CFR 51.22{b), no environmental impact statement or environmental assessment need be prepared in connection with the issuance of the amendments. | |||
==6.0 CONCLUSION== | |||
*S E input by memo dated 9-24-2010 OFFICE LPL2-1/PM LPL2-1/LA DRAlAPLAlBC DIRS/ITSB/BC NAME IVSreenivas MO'Brien DHarrison* | |||
RElliott SRohrer for) 11/15/10 09/24/2010 11/17/10 | The license amendment request proposes TS changes that will revise the TSs by relocating specific surveillance frequencies to a licensee-controlled program with the implementation of NEI 04-10, "Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies." The changes are consistent with NRC-approved Industry TSTF Standard Technical Specifications change TSTF-425, Revision 3. | ||
The NRC staff finds that with the proposed relocation of surveillance frequencies to an owner-controlled document and administratively controlled in accordance with the TS SFCP, the licensee continues to meet the regulatory requirement of 10 CFR 50.36, and specifically, 10 CFR 50.36(c)(3), surveillance requirements. | |||
Therefore, the NRC staff has concluded, based on the considerations discussed above, that: (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner; (2) such activities will be conducted in compliance with the Commission's regulations; and, (3) the issuance of the amendment will not be inimical to the common defense and security or to the health and safety of the public. | |||
Principal Contributors: Andrew Howe, NRRIDRA Date of Issuance: January 31, 2011 | |||
ML103140657 *S E input by memo dated 9-24-2010 OFFICE LPL2-1/PM LPL2-1/LA DRAlAPLAlBC DIRS/ITSB/BC OGC LPL2-1/BC LPL2-1/PM NAME IVSreenivas MO'Brien DHarrison* RElliott DRoth NLO GKulesa !VSreenivas SRohrer for) | |||
~11/10/10 11/15/10 09/24/2010 11/17/10 11/29/10 1128111 1/31/11}} | |||
Revision as of 07:19, 13 November 2019
| ML103140657 | |
| Person / Time | |
|---|---|
| Site: | North Anna  |
| Issue date: | 01/31/2011 |
| From: | V Sreenivas Plant Licensing Branch II |
| To: | Heacock D Virginia Electric & Power Co (VEPCO) |
| Sreenivas V.NRR/DORL/LPL2-1 415-2597 | |
| References | |
| TAC ME3689, TAC ME3690 | |
| Download: ML103140657 (138) | |
Text
UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555*0001 January 31, 2011 Mr. David A. Heacock President and Chief Nuclear Officer Virginia Electric and Power Company Innsbrook Technical Center 5000 Dominion Boulevard Glen Allen, VA 23060-6711
SUBJECT:
NORTH ANNA POWER STATION, UNIT NOS. 1 AND 2,ISSUANCE OF AMENDMENTS TO ADOPT TECHNICAL SPECIFICATION TASK FORCE (TSTF)-425, REVISION 3, FOR THE RELOCATION OF SPECIFIC SURVEILLANCE FREQUENCY REQUIREMENTS TO A LICENSEE CONTROLLED PROGRAM (TAC NOS. ME3689 AND ME3690)
Dear Mr. Heacock:
The U.S. Nuclear Regulatory Commission (NRC, the Commission) has issued the enclosed Amendment Nos. 262 and 243 to Renewed Facility Operating License Nos. NPF-4 and NPF-7 for the North Anna Power Station, Unit Nos. 1 and 2. The amendment consists of changes to the Technical Specifications (TSs) in response to your application dated March 30, 2010, as supplemented by letters dated August 30, 2010 and January 18, 2011.
The amendments revise the TSs by relocating specific surveillance frequencies to a licensee-controlled program with the implementation of Nuclear Energy Institute 04-10, "Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies." The changes are consistent with NRC-approved Industry Technical Specification Task Force (TSTF) Standard Technical Specifications change TSTF-425, Revision 3.
D. Heacock - 2 A copy of our related safety evaluation is also enclosed. The Notice of Issuance will be included in the Commission's biweekly Federal Register notice.
Sincerely,
- r. V. Sreenivas, Project Manager Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket Nos. 50-338 and 50-339
Enclosures:
- 1. Amendment No. 262 to NPF-4
- 2. Amendment No. 243 to NPF-7
- 3. Safety Evaluation cc w/encls: Distribution via Listserv
UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 VIRGINIA ELECTRIC AND POWER COMPANY DOCKET NO. 50-338 NORTH ANNA POWER STATION. UNIT NO.1 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 262 Renewed License No. NPF-4
- 1. The Nuclear Regulatory Commission (the Commission) has found that:
A. The application for amendment by Virginia Electric and Power Company et al.. (the licensee) dated March 30,2010, as supplemented by letters dated August 30,2010 and January 18, 2011, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations set forth in 10 CFR Chapter I; B. The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C. There is reasonable assurance (i) that the activities authorized by this amendment 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; D. The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E. The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.
-2
- 2. Accordingly, the license is amended by changes to paragraph 2.C.(2) of Renewed Facility Operating License No. NPF-4, as indicated in the attachment to this license amendment, and is hereby amended to read as follows:
(2) Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 262, are hereby incorporated in the renewed license. The licensee shall operate the facility in accordance with the Technical Specifications.
- 3. This license amendment is effective as of its date of issuance and shall be implemented within 180 days of issuance.
FOR THE NUCLEAR REGULATORY COMMISSION Gloria Kulesa, Chief Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation
Attachment:
Changes to License No. NPF-4 and the Technical Specifications Date of Issuance: January 31, 2011
UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 VIRGINIA ELECTRIC AND POWER COMPANY DOCKET NO. 50-339 NORTH ANNA POWER STATION, UNIT NO.2 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 243 Renewed License No. NPF~ 7
- 1. The Nuclear Regulatory Commission (the Commission) has found that:
A. The application for amendment by Virginia Electric and Power Company et al.. (the licensee) dated March 30,2010, as supplemented by letters dated August 30 and January 18. 2010. complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act). and the Commission's rules and regulations set forth in 10 CFR Chapter I; B. The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C. There is reasonable assurance (i) that the activities authorized by this amendment 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; D. The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E. The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.
-2
- 2. Accordingly, the license is amended by changes to paragraph 2.C.(2) of Renewed Facility Operating License No. NPF-7, as indicated in the attachment to this license amendment, and is hereby amended to read as follows:
(2) Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 243, are hereby incorporated in the renewed license. The licensee shall operate the facility in accordance with the Technical Specifications.
- 3. This license amendment is effective as of its date of issuance and shall be implemented within 180 days of issuance.
FOR THE NUCLEAR REGULATORY COMMISSION Gloria Kulesa, Chief Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation
Attachment:
Changes to License No. NPF-7 and the Technical Specifications Date of Issuance: January 31,2011
ATTACHMENT TO LICENSE AMENDMENT NO. 262 RENEWED FACILITY OPERATING LICENSE NO. NPF-4 DOCKET NO. 50-338 AND TO LICENSE AMENDMENT NO. 243 RENEWED FACILITY OPERATING LICENSE NO. NPF-7 DOCKET NO. 50-339 Replace the following pages of the Licenses and the Appendix "A" Technical Specifications (TSs) with the enclosed pages as indicated. The revised pages are identified by amendment number and contain vertical lines indicating the areas of change.
Remove Pages Insert Pages Licenses Licenses License No. NPF-4, page 3 License No. NPF-4, page 3 License No. NPF-7, page 3 License No. NPF-7, page 3 3.1.1-1 3.1.1-1 3,1.2-2 3.1.2-2 3.1.4-3 3.1.4-3 3.1.5-2 3.1.5-2 3.1.6-3 3.1.6-3 3.1,7-3 3.1.7-3 3.1.9-2 3.1.9-2 3.2.1-3 3.2.1-3 3.2.2-2 3.2.2-2 3.2.3-1 3.2.3-1 3.2.4-3 3.2.4-3 3.2.4-4 3.2.4-4 3.3.1-8 3.3.1-8 3.3.1-9 3.3.1-9 3.3.1-10 3.3.1-10 3.3.1-11 3.3.1-11 3.3.1-12 3.3.1-12 3.3.2-5 3.3.2-5 3.3.2-6 3.3.2-6 3.3.2-7 3.3.2-7
-2 3.3.3-2 3.3.3-2 3.3.4-1 3.3.4-1 3.3.4-2 3.3.4-2 3.3.5-2 3.3.5-2 3.3.5-3 3.3.6-2 3.3.6-2 3.4.1-2 3.4.1-2 3.4.2-1 3.4.2-1 3.4.3-2 3.4.3-2 3.4.4-1 3.4.4-1 3.4.5-2 3.4.5-2 3.4.5-3 3.4.6-2 3.4.6-2 3.4.7-3 3.4.7-3 3.4.8-2 3.4.8-2 3.4.9-2 3.4.9-2 3.4.11-3 3.4.11-3 3.4.11-4 3.4.11-4 3.4.12-3 3.4.12-3 3.4.12-4 3.4.12-4 3.4.13-2 3.4.13-2 3.4.14-2 3.4.14-2 3.4.15-3 3.4.15-3 3.4.16-2 3.4.16-2 3.4.17-2 3.4.17-2 3.4.19-1 3.4.19-1 3.5.1-2 3.5.1-2 3.5.2-2 3.5.2-2 3.5.2-3 3.5.2-3 3.5.4-2 3.5.4-2 3.5.5-2 3.5.5-2 3.5.6-2 3.5.6-2 3.6.2-5 3.6.2-5 3.6.3-5 3.6.3-5 3.6.3-6 3.6.3-6 3.6.4-1 3.6.4-1 3.6.5-1 3.6.5-1 3.6.6-1 3.6.6-1 3.6.6-2 3.6.6-2 3.6.7-2 3.6.7-2 3.6.7-3 3.6.7-3 3.6.8-1 3.6.8-1 3.6.8-2 3.6.8-2 3.7.2-2 3.7.2-2 3.7.3-2 3.7.3-2 3.7.4-1 3.7.4-1 3.7.4-2 3.7.5-2 3.7.5-2 3.7.5-3 3.7.5-3
-3 3.7.5-4 3.7.6-1 3.7.6-1 3.7.7-1 3.7.7-1 3.7.8-3 3.7.8-3 3.7.8-4 3.7.9-1 3.7.9-1 3.7.10-3 3.7.10-3 3.7.11-2 3.7.11-2 3.7.12-4 3.7.12-4 3.7.12-5 3.7.12-5 3.7.15-1 3.7.15-1 3.7.16-1 3.7.16-1 3.7.17-1 3.7.17-1 3.7.19-2 3.7.19-2 3.8.1-8 3.8.1-8 3.8.1-9 3.8.1-9 3.8.1-10 3.8.1-10 3.8.1-11 3.8.1-11 3.8.1-12 3.8.1-12 3.8.1-13 3.8.1-13 3.8.1-14 3.8.1-14 3.8.1-15 3.8.1-15 3.8.1-16 3.8.1-16 3.8.1-17 3.8.1-17 3.8.1-18 3.8.1-18 3.8.1-19 3.8.3-3 3.8.3-3 3.8.4-2 3.8.4-2 3.8.4-3 3.8.4-3 3.8.4-4 3.8.4-4 3.8.4-5 3.8.6-2 3.8.6-2 3.8.6-3 3.8.6-3 3.8.7-2 3.8.7-2 3.8.8-2 3.8.8-2 3.8.9-3 3.8.9-3 3.8.10-2 3.8.10-2 3.9.1-1 3.9.1-1 3.9.3-2 3.9.3-2 3.9.4-2 3.9.4-2 3.9.5-2 3.9.5-2 3.9.6-3 3.9.6-3 3.9.7-1 3.9.7-1 5.5-17 5.5-17
- 3*
(2) Pursuant to the Act and 10 CFR Part 70, VEPCa 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 Updated Final Safety Analysis Report; (3) Pursuant to the Act and 10 CFR Parts 30, 40, and 70, VEPCO 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, VEPCO to receive, possess, and use in amounts as required any byproduct, source, or special nuclear material, without restriction to chemical or physical form, for sample analysis or instrument calibration or associated with radioactive apparatus or component; and (5) Pursuant to the Act and 10 CFR Parts 30 and 70, VEPCO to possess, but not separate, such byproduct and special nuclear materials as may be produced by the operation of the faCility.
C. This renewed operating license shall be deemed to contain and is subject to the conditions specified in the following Commission regulations in 10 CFR Chapter I:
Part 20, Section 30.34 of Part 30, Section 40.41 of Part 40, Sections SO.54 and 50.59 of Part 50, and Section 70.32 of Part 70; 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 VEPCO is authorized to operate the North Anna Power Station, Unit NO.1, at reactor core power levels not in excess of 2940 megawatts (thermal).
(2) Technical Specifications The Technical Sl'1l"lr.ificatlons contained in Appendix A, as revised through Amendment No.262 ~e hereby incorporated in the renewed license. The licensee shall operate the facility in accordance with the Technical SpeCifications.
NORTH ANNA
- UNIT 1 Renewed License /\In. NPF*4 Amendment NOQ 262
-3 (3) Pursuant to the Act and 10 CFR Parts 30, 40, and 70. VEPCa 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, VEPCa to receive, possess, and use in amounts as required any byproduct, source, or 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, VEPCa to possess, but not separate, such byproduct and special nuclear materials as may be produced by the operation of the facility, C. This renewed license shall be deemed to contain and is subject to the conditions specified in the Commission's regulations as set forth in 10 CFR Chapter! and Is subject to all applicable provisions 01 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 VEPca is authorized to operate the facility at steady state reactor core power levels not in excess of 2940 megawatts (thermal).
(2) Technical Specifications The Technical Sper,ifications contained in Appendix A, as revised through Amendment No.243 are hereby incorporated In the renewed license. The licensee shall operate the facility in accordance with the Technical Specifications.
(3) Additional Conditions The matters speciiied in the following conditions shall be completed to the satisfaction of the Commission within the stated time periods following the issuance of the condition or within the operational restrictions indicated. The removal of these conditions shall be made by an amendment to the renewed license supported by a favorable evaluation by the Commission:
- a. If VEPCO plans to remove or to make significant changes in the normal operation of equipment that controls the amount of radioactivity in eftluents from the North Anna Power Station. the NORTH ANNA* UNIT 2 Renewed License No. NPF*7 Hla1dre1t ~. 243
SDM 3.1.1 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM)
LCO 3.1.1 SDM shall be within the limits provided in the COLR.
APPLICABILITY: MODE 2 with keff < 1.0, MODES 3, 4, and 5.
ACTIONS CONDITION REQU IRED ACTI ON COMPLETION TIME A. SDM not within limit. A.l Initiate boration to 15 minutes restore SDM to within 1imit.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.1.1 Verify SDM to be within limits. In accordance with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.1.1-1 Amendments262 and 243
Core Reactivity 3.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1. 2.1 -------------------NOTE-------------------
The predicted reactivity values may be adjusted (normalized) to correspond to the measured core reactivity prior to exceeding a fuel burnup of 60 effective full power days (EFPD) after each fuel loading.
Verify measured core reactivity is within Once prior to
+/- 1% Ak/k of predicted values. entering MODE 1 after each refueling AND
NOTE-----
Only required after 60 EFPD In accordance with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.1.2-2 Amendments 262 and 243
Rod Group Alignment Limits 3.1.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. More than one rod not 0.1.1 Verify SDM to be 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> within alignment within the limit 1imit. provided in the COLR.
OR 0.1.2 Initiate boration to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> restore required SDM to withi n 1imit.
AND D.2 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.4.1 Verify individual rod positions within In accordance alignment limit. with the Surveillance Frequency Control Program SR 3.1. 4.2 Verify rod freedom of movement In accordance (trippability) by moving each rod not fully with the inserted in the core ~ 10 steps in either Survei 11 ance .
direction. Frequency Control Program SR 3.1.4.3 Verify rod drop time of each rod, from the Pri or to reactor fully withdrawn position, is s 2.7 seconds criti ca 1ity from the beginning of decay of stationary after each gripper coil voltage to dashpot entry, removal of the with: reactor head
- a. Tavg 2 500°F; and
- b. All reactor coolant pumps operating.
North Anna Units 1 and 2 3.1.4-3 Amendments 262 and 243
Shutdown Bank Insertion Limits 3.1.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. One shutdown bank B.1 Verify SDM to be Once per inserted ~ 18 steps within the limits 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> below the insertion provided in the COLR.
limit and immovable.
AND AND B.2 Restore the shutdown 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Each control and bank to within shutdown rod within insertion limit.
limits of LCO 3.1.4.
AND Each control bank within the insertion limits of LCO 3.1.6.
C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify each shutdown bank is within the In accordance insertion limits specified in the COLR. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.1. 5-2 Amendments 262 and 243
Control Bank Insertion Limits 3.1.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.2 Verify each control bank is within the In accordance insertion limits specified in the COLR. with the Surveillance Frequency Control Program SR 3.1.6.3 Verify each control bank not fully In accordance withdrawn from the core is within the with the sequence and overlap limits specified in Surveillance the COLR. Frequency Control Program North Anna Units 1 and 2 3.1.6-3 Amendments262 and 243
Rod Position Indication 3.1. 7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. One demand position 0.1.1 Verify by Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> indicator per bank administrative means inoperable for one or all RPI s for the more banks. affected banks are OPERABLE.
AND D.1.2 Verify the most Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> withdrawn rod and the least withdrawn rod of the affected banks are s 12 steps apart.
-OR D.2 Reduce THERMAL POWER 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> to S 50% RTP.
E. Required Action and E,1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.1 Perform CHANNEL CALIBRATION of each RPI. In accordance with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.1.7-3 Amendments 262 and 243
PHYSICS TESTS Exceptions-MODE 2 3.1.9 ACTIONS CONDITION REQUIRED ACTION COMPLETI ON TIME D. Required Action and 0.1 Be in MODE 3. 15 minutes associated Completion Time of Condition C not met; SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.9.1 Perform a CHANNEL OPERATIONAL TEST on power Prior to range and intermediate range channels per initiation of SR 3.3.1.7. SR 3.3.1.8, and Table 3.3.1-1. PHYSICS TESTS SR 3.1.9.2 Verify the RCS lowest loop average In accordance temperature is ~ 531°F. with the Surveillance Frequency Control Program SR 3.1. 9.3 Verify THERMAL POWER is ~ 5% RTP. In accordance with the Surveillance Frequency Control Program SR 3.1. 9.4 Verify SDM to be within the limits provided In accordance in the COLR. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.1.9-2 Amendments 262 and 243
FQ(Z) 3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.1 ------------------NOTE---------------
If Fg(Z) measurements indicate F~(Z)]
maximum over z [ K(Z) has increased since the previous evaluation of FS(Z):
- a. Increase F~(Z) by the appropriate factor and verify Fg(Z) is still within limits; or
- b. Repeat SR 3.2.1.1 once per 7 EFPO until two successive flux maps indicate F~(Z)l maximum over z [ K(Z) has not increased.
Verify F~(Z) is within limit. Once after each refueling prior to THERMAL POWER exceeding 75% RTP AND Once within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after achieving equilibrium conditions after exceeding, by
~ 10% RTP. the THERMAL POWER at whi ch F~ (Z) was last verified AND In accordance with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.2.1-3 Amendments 262 and 243
N FAH 3.2.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.4 ---------NOTE--------
THERMAL POWER does not have to be reduced to comply with this Required Action.
Perform SR 3.2.2.1. Prior to THERMAL POWER exceeding 50% RTP
-AND Pri or to THERMAL POWER exceeding 75% RTP AND 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after THERMAL POWER reaching 2 95% RTP B. Required Action and B.1 Be in MODE 2. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met.
SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.2.2.1 Verify F1H ;s within limits specified Once after each in the COLR. refueling prior to THERMAL POWER exceeding 75% RTP AND In accordance with the Survei 11 ance Frequency Control Program North Anna Units 1 and 2 3.2.2-2 Amendments262 and 243
AFD 3.2.3 3.2 POWER DISTRIBUTION LIMITS 3.2.3 AXIAL FLUX DIFFERENCE (AFD) lCO 3.2.3 The AFD in % flux difference units shall be maintained within the limits specified in the COLR.
- - - - - - - - - - - - NOTE - - - - - - - - -
The AFD shall be considered outside limits when two or more OPERABLE excore channels indicate AFD to be outside limits.
APPLICABILITY: MODE I with THERMAL POWER ~ 50% RTP.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. AFD not within limits. A.I Reduce THERMAL POWER 30 minutes to < 50% RTP.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 Verify AFD within limits for each OPERABLE In accordance excore channel. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.2.3-1 Amendments 262 and 243
QPTR 3.2.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.6 --------NOTE--------
Perform Required Action A.6 only after Required Action A.5 is completed.
Perform SR 3.2.1.1 and With"j n 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> SR 3.2.2.1. after achieving equil i bri urn Conditions at RTP not to exceed 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> after increasing THERMAL POWER above the limit of Required Action A.1 B. Required Action and B.1 Reduce THERMAL POWER 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> associated Completion to ~ 50% RTP.
Time not met.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.1 ------------------NOTES---------------
- 1. With input from one Power Range Neutron Flux channel inoperable and THERMAL POWER ~ 75% RTP, the remaining three power range channels can be used for calculating QPTR.
- 2. SR 3.2.4.2 may be performed in lieu of this Surveillance.
Verify QPTR is within limit by In accordance with calculation. the Survei 11 ance Frequency Control Program North Anna Units 1 and 2 3.2.4-3 Amendments 262 and 243
QPTR 3.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.2 -------------------NOTE---------------
Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after input from one or more Power Range Neutron Flux channels are inoperable with THERMAL POWER
> 75% RTP.
Verify QPTR is within limit using the In accordance with movable incore detectors. the Surveillance Frequency Control Program North Anna Units 1 and 2 3.2.4-4 Amendments 262 and 243
RTS Instrumentation 3.3.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME R. One or more channels R.1 Verify interlock ;s in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> inoperable. required state for existing unit conditions.
OR R.2 Be in MODE 2. 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br /> S. One trip mechanism S.l Restore inoperable 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> inoperable for one trip mechanism to RTB. OPERABLE status.
OR S.2 Be in MODE 3. 54 hours6.25e-4 days <br />0.015 hours <br />8.928571e-5 weeks <br />2.0547e-5 months <br /> SURVEILLANCE REQUIREMENTS
- - - - - - - - - - - - - - - - NOTE - - - - - - -
Refer to Table 3.3.1-1 to determine which SRs apply for each RTS Function.
SURVEILLANCE FREQUENCY SR 3.3.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.1.2 -------------------NOT£-----------
Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after THERMAL POWER is
~ 15% RTP.
Compare results of calorimetric heat In accordance with balance calculation to power range the Surveillance channel output~ Adjust power range Frequency Control output if calorimetric heat balance Program calculation result exceeds power range channel output by more than +2% RTP.
North Anna Units 1 and 2 3.3.1-8 Amendments 262 and 243
RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.3 -------------------NOTE--------------
Not required to be performed until 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after THERMAL POWER is 2 15% RTP.
Compare results of the incore detector In accordance with measurements to Nuclear the Surveillance Instrumentation System (NIS) AFD. Frequency Control Adjust NIS channel if absolute Program difference is 2 3%.
SR 3.3.1.4 -------------------NOTE--------------
This Surveillance must be performed on the reactor trip bypass breaker immediately after placing the bypass breaker in service.
Perform TADOT. In accordance with the Survei1lance Frequency Control Program SR 3.3.1.5 Perform ACTUATION LOGIC TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.6 -------------------NOTE--------------
Verification of setpoint is not required.
Perform TADOT. In accordance with the Survei11ance Frequency Control Program North Anna Units 1 and 2 3.3.1-9 Amendments 262 and 243
RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.7 -------------------NOTE--------------
Not required to be performed for source range instrumentation prior to entering MODE 3 from MODE 2 until 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> after entry into MODE 3.
Perform COT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.8 ~------------------NOTE--------------- -----NOTE----
This Surveillance shall include Only required when verification that interlocks P-6 not performed within and P-10 are in their required state the frequency for existing unit conditions. specified in the Surveillance Control Program Perform COT.
Prior to reactor startup Four hours after reducing power below P-6 for source range instrumentation Twelve hours after reducing power below P-IO for power and intermediate range instrumentation AND In accordance with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.3.1-10 Amendments 262 and 243
RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.9 -------------------NOTES-------------
- 1. Adjust NIS channel if absolute difference ~ 3%.
- 2. Not required to be performed until 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after THERMAL POWER is
~ 50% RTP.
Compare results of the excore channels In accordance with to incore detector measurements. the Surveillance Frequency Control Program SR 3.3.1.10 -------------------NOTE--------------
This Surveillance shall include verification that the time constants are adjusted to the prescribed values.
Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.1.11 -------------------NOTE--------------
Neutron detectors are excluded from CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.1.12 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.3.1-11 Amendments 262 and 243
RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.13 Perform COT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.14 -------------------NOTE--------------
Verification of setpoint ;s not required.
Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.15 -------------------NOTE--------------
Verification of setpoint ;s not required.
Perform TADOT. Prior to exceeding the P-8 interlock whenever the unit has been in MODE 3, i f not performed within the previous 31 days SR 3.3.1.16 -------------------NOTE--------------
Neutron detectors are excluded from response time testing.
Verify RTS RESPONSE TIME is within In accordance with 1im; ts. the Surveillance Frequency Control Program North Anna Units 1 and 2 3.3.1-12 Amendments262 and 243
ESFAS Instrumentation 3.3.2 ACTIONS CONDITION REQUIRED ACTION COMPLETI ON TIME J. One or more channels J.l Verify interlock is in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> inoperable. required state for existing unit condition.
OR J.2.1 Be in MODE 3. 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br /> AND J.2.2 Be in MODE 4. 13 hours SURVEILLANCE REQUIREMENTS
- - - - - - - - - - - - - - - -NOTE - - - - - - - - - - - - -
Refer to Table 3.3.2-1 to determine which SRs apply for each ESFAS Function.
SURVEILLANCE FREQUENCY SR 3.3.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.2.2 Perform ACTUATION LOG[C TEST. In accordance with the Survei 11 ance Frequency Control Program SR 3.3.2.3 Perform MASTER RELAY TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.4 Perform COT In accordance with the Survei 11 ance Frequency Control Program North Anna Units 1 and 2 3.3.2-5 Amendments 262 and 243
ESFAS Instrumentation 3.3.2 SURVEI LLANCE FREQUENCY SR 3.3.2.5 -------------------NOTE-------------
Not required to be performed for SLAVE RELAYS if testing would:
- 1. Result in an inadvertent Reactor Trip System or ESFAS Actuation if accompanied by a single failure in the Safeguard Test Cabinet;
- 2. Adversely affect two or more components in one or more ESFAS system(s}; or
- 3. Create a reactivity, thermal, or hydraulic transient condition in the Reactor Coolant System.
Perform SLAVE RELAY TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.6 -------------------NOTE-------------
Verification of relay setpoints not required.
Perform TADOT. In accordance with the Survei 11 ance Frequency Control Program North Anna Units 1 and 2 3.3.2-6 Amendments 262 and 243
ESFAS Instrumentation 3.3.2 SURVEILLANCE FREQUENCY SR 3.3.2.7 -------------------NOTE-------------
Verification of setpoint not required for manual initiation or interlock functions.
Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.2.8 -------------------NOTE-------------
This Surveillance shall include verification that the time constants are adjusted to the prescribed values.
Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.2.9 -------------------NOTE-------------
Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after SG pressure is
~ 1005 psig.
Verify ESFAS RESPONSE TIMES are In accordance with within limit. the Surveillance Frequency Control Program North Anna Units 1 and 2 3.3.2-7 Amendments 262 and 243
PAM Instrumentation 3.3.3 SURVEILLANCE REQUIREMENTS
- - - - - - NOTE - - - - - - -
SR 3.3.3.1 and SR 3.3.3.3 apply to each PAM instrumentation Function in Table 3.3.3-1 except SR 3.3.3.3 does not apply to Item 10. SR 3.3.3.4 applies only to Item 10.
SURVEILLANCE FREQUENCY SR 3.3.3.1 Perform CHANNEL CHECK for each required In. accordance instrumentation channel that is normally with the energized. Surveillance Frequency Control Program SR 3.3.3.2 Not Used SR 3.3.3.3 -------------------NOTE-------------------
Neutron detectors are excluded from CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.3.4 Perform TADOr. In accordance with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.3.3-2 Amendments 262 and 243
Remote Shutdown System 3.3.4 3.3 INSTRUMENTATION 3.3.4 Remote Shutdown System LCO 3.3.4 The Remote Shutdown System Functions shall be OPERABLE.
APPLICABILITY: MODES 1. 2, and 3.
ACTIONS
- - - - - - - - - - NOTE - - - -
Separate Condition entry is allowed for each Function.
CONDITION REQU I RED ACTI ON COMPLETION TIME A. One or more required A.I Restore required 30 days Functions inoperable. Function to OPERABLE status.
B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Ii me not met. AND B.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.3.4.1 Perform CHANNEL CHECK for each required In accordance instrumentation channel that is normally with the energized. . Surveillance Frequency Control Program SR 3.3.4.2 Verify each required control circuit and In accordance transfer switch is capable of performing with the the intended function. Surveillance Frequency Control Program North Anna Units 1 and 2 3.3.4-1 Amendments 262 and 243
Remote Shutdown System 3.3.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.4.3 Perform CHANNEL CALIBRATION for each In accordance required instrumentation channel. with the Surveillance Frequency Control Program North Anna Units 1 and 2 Amendments 262 and 243
LOP EDG Start Instrumentation 3.3.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.I Enter applicable Immediately associated Completion Condition(s) and Time not met. Required Action(s) for the associated EDG made inoperable by LOP EDG start instrumentation.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.5.1 -~------------------NOTE-------------
Verification of setpoint is not required.
Perform TADOT for LCO 3.3.5.a and In accordance with LCO 3.3.5.b Functions. the Surveil 1ance Frequency Control Program SR 3.3.5.2 Perform CHANNEL CALIBRATION wi th In accordance with Allowable Values as follows: the Surveillance Frequency Control
- a. Loss of voltage Allowable Values Program
~ 2935 V and ~ 3225 Vwith a time delay of 2 +/-I seconds for LCO 3.3.S.a and LCO 3.3.5.b Functions.
- b. Degraded voltage Allowable Values
~ 3720 V and ~ 3772 V with:
I. A time delay of 7.5 +/-1.S seconds with a Safety Injection (SI) signal for LCO 3.3.5.a Function; and
- 2. A time delay of 56 +/-7 seconds without an SI signal for LCO 3.3.5.a and LCO 3.3.S.b Functions.
North Anna Units 1 and 2 3.3.5-2 Amendments 262 and 243
LOP EOG Start Instrumentation 3.3.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.5.3 Verify ESF RESPONSE TIMES are within In accordance with limit for LCO 3.3.5.a and LCO 3.3.5.b the Surveillance Functions. Frequency Control Program North Anna Units 1 and 2 3.3.5-3 Amendments 262 and 243
MCR/ESGR Envelope Isolation Actuation Instrumentation 3.3.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.6.1 --------------------NOTE------------------
Verification of setpoint is not required.
Perform TADOT. In accordance with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.3.6-2 Amendments 262 and 243
Res Pressure~ Temperature, and Flow DNB Limits 3.4.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.4.1.1 Verify pressurizer pressure is greater than In accordance or equal to the limit specified in the with the COLR. Survei 11 ance Frequency Control Program SR 3.4.1.2 Verify RCS average temperature is less than In accordance or equal to the limit specified in the with the COLR. Surveillance Frequency Control Program SR 3.4.1.3 Verify RCS total flow rate is In accordance
~ 295,000 gpm and is greater than or equal with the to the limit specified in the COLR. Surveillance Frequency Control Program SR 3.4.1.4 -------------------NOTE-------------------
Not required to be performed until 30 days after ~ 90% RTP.
Verify by precision heat balance that ReS In accordance total flow rate is ~ 295,000 gpm and is with the greater than or equal to the limit Surveillance specified in the COLR. Frequency Control Program North Anna Units 1 and 2 3.4.1-2 Amendments 262 and 243
RCS Minimum Temperature for Criticality 3.4.2 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.2 RCS Minimum Temperature for Criticality LCO 3.4.2 Each ReS loop average temperature (Tavg) shall be ~ 541°F.
APPLICABILITY: MODE 1, MODE 2 with keff ~ 1. O.
ACTIONS CONDITION REQU IRED ACTI ON COMPLETION TIME A. Tav in one or more A.l Be in MODE 2 with 30 minutes RC5 loops not withi n keff < 1. O.
1imi t.
SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.4.2.1 Verify RCS Tavg in each loop ~ 541°F. In accordance with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.4.2-1 Amendments 262 and 243
RCS PIT Limits 3.4.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. ---------NOTE-------- C.l Initiate action to Immediately Required Action C.2 restore parameter(s) shall be completed to within limits.
whenever this Condition is entered. AND C.2 Determine ReS ;s Prior to Requirements of LCO acceptable for entering MODE 4 not met any time in continued operation.
other than MODE 1, 2, 3, or 4.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.3.1 -------------------NOTE-------------------
Only required to be performed during RCS heatup and cool down operations and RCS inservice leak and hydrostatic testing.
Verify RCS pressure, ReS temperature, and In accordance RCS heatup and cool down rates are within with the 1imits. Surveillance Frequency Control Program North Anna Units 1 and 2 3.4.3-2 Amendments 262 and 243
RCS Loops-MODES 1 and 2 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.4 RCS Loops-MODES 1 and 2 LCO 3.4.4 Three RCS loops shall be OPERABLE and in operation.
APPLICABILITY: MODES 1 and 2.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of LCO A.l Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> not met.
SURVEILLANCE REQUIREMENTS SU RV EI LLANCE FREQUENCY SR 3.4.4.1 Verify each RCS loop is in operation. In accordance with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.4.4-1 Amendments 262 and 243
RCS Loops-MODE 3 3.4.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Two required RCS loops C.1 Place the Rod Control Il1111ediately inoperable. System in a condition incapable of rod OR withdrawal.
Required RCS loop not AND in operation.
C.2 Suspend operations Il1111ediately that would cause introduction into the ReS. coolant with boron concentration less than required to meet SDM of LCO 3.1.1.
AND C.3 Initiate action to Immediately restore one ReS loop to OPERABLE status and operation.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.5.1 Verify required RCS loops are in operation. In accordance with the Surveillance Frequency Control Program SR 3.4.5.2 Verify steam generator secondary side water In accordance levels are ~ 17% for required RCS loops. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.4.5-2 Amendments 262 and 243
RCS Loops-MODE 3 3.4.5*
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.5.3 -------------------NOTE-------------------
Not required to be performed until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after a required pump is not in operation.
Verify correct breaker alignment and In accordance indicated power are available to the with the required pump not in operation. Surveillance Frequency Control Program North Anna Units 1 and 2 3.4.5-3 Amendments 262 and 243
RCS Loops-MODE 4 3.4.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. Two required loops B.1 Suspend operations Immediately inoperable. that would cause introduction into the OR RCS, coolant with boron concentration Required loop not in less than required to operation. meet SDM of LCO 3.1.1.
AND B.2 Initiate action to Immediately restore one loop to OPERABLE status and operation.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 Verify required RHR or RCS loop is in In accordance operation. with the Surveillance Frequency Control Program SR 3.4.6.2 Verify SG secondary side water levels are In accordance
~ 17% for required RCS loops. with the Surveillance Frequency Control Program SR 3.4.6.3 -------------------NOTE-------------------
Not required to be performed until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after a required pump is not in operation.
Verify correct breaker alignment and In accordance indicated power are available to the with the required pump not in operation. Surveillance Frequency Cont ro 1 Program North Anna Units 1 and 2 3.4.6-2 Amendments 262 and 243
RCS loops-MODE 5, loops Filled 3.4.7 SURVEILLANCE REQUIREMENTS SURVEIllANCE FREQUENCY SR 3.4.7.1 Verify required RHR loop is in operation. In accordance with the Surveillance Frequency Control Program SR 3.4.7.2 Verify SG secondary side water level is In accordance
~ 17% in required SG. with the Surveillance Frequency Control Program SR 3.4.7.3 -------------------NOTE-------------------
Not required to be performed until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after a required pump is not in operation.
Verify correct breaker alignment and In accordance indicated power are available to the with the required RHR pump not in operation. Surveillance Frequency Control Program North Anna Units 1 and 2 3.4.7-3 Amendments 262 and 243
RCS Loops-MODE 5, Loops Not Filled 3.4.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. No required RHR loop B.1 Suspend operations Immediately OPERABLE. that would cause introduction into the OR RCS, coolant with boron concentration Required RHR loop not less than required to in operation. meet SDM of LCO 3.1.1.
B.2 Initiate action to Immediately restore one RHR loop to OPERABLE status and*
operation.
,
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify required RHR loop is in operation. In accordance with the Surveillance Frequency Control Program SR 3.4.8.2 -------------------NOTE-------------------
Not required to be performed until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after a required pump is not ;n operation.
Verify correct breaker alignment and In accordance indicated power are available to the with the required RHR pump not in operation. Surveillance Frequency Control Program North Anna Units 1 and 2 3.4.8-2 Amendments 262 and 243
Pressurizer 3.4.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify pressurizer water level is ~ 93%. In accordance with the Surveillance Frequency Contro1 Program SR 3.4.9.2 Verify capacity of each required group of In accordance pressurizer heaters is ~ 125 kW. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.4.9-2 Amendments 262 and 243
Pressurizer PORVs 3.4.11 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME G. Two block valves G.1 ---------NOTE--------
inoperable. Required Action G.1 does not apply when block valve is inoperable solely as a result of complying with Required Action C.2.
Restore one block 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> valve to OPERABLE status.
H. Required Action and H.i Be in MOOE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition G AND not met.
H.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.4.11.1 Verify PORV backup nitrogen supply pressure In accordance is within limit. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.4.11-3 Amendments 262 and 243
Pressurizer PORVs 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.2 -------------------NOTES--------------
- 1. Not requ; red to be performed with block valve closed in accordance with the Required Actions of this LCO.
- 2. Only required to be performed in MODES 1 and 2.
Perform a complete cycle of each block In accordance valve. with the Surveillance Frequency Control Program SR 3.4.11.3 --------------------NOTE--------------
Only required to be performed in MODES 1 and 2.
Perform a complete cycle of each PORV. In accordance with the Surveillance Frequency Control Program SR .3.4.11.4 Perform a complete cycle of each solenoid In accordance control valve and check valve on the with the accumulators in PORV control systems. Surveillance Frequency Control Program North Anna Units 1 and 2 3.4.11-4 Amendments 262 and 243
LTDP System 3.4.12 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME G. Two required PORVs G.1 Depressurize RCS and In accordance inoperable. establish RCS vent of with the
~ 2.07 square inches. Surveillance Frequency Control Program Required Action and associated Completion Time of Condition A, B, D, E, or F not met.
OR LTOP System i noperab 1e for any reason other than Condition At B.
C, D, E, or F.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Verify a maximum of one LHSI pump is In accordance with capable of injecting into the RCS. the Surveillance Frequency Control Program SR 3.4.12.2 Verify a maximum of one charging pump is In accordance with capable of injecting into the RCS. the Surveillance Frequency Control Program SR 3.4.12.3 -------------------NOTE-----------------
Only required to be met if accumulator pressure is greater than PORV lift setting.
Verify each accumulator is isolated and power is removed from the accumulator In accordance wi th isolation 'valve operator. the Surveillance
\
Frequency Control Program North Anna Units 1 and 2 3.4.12-3 Amendments 262 and 243
LTOP System 3.4.12 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.4.12.4 Verify required RCS vent 2 2.07 square 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for inches open. unlocked open vent valve(s)
AND In accordance with the Surveillance Frequency Control Program SR 3.4.12.5 Verify PORV block valve is open for each I n accordance wi th required PORV and PORV keyswitch is in the Surveillance AUTO. Frequency Control Program SR 3.4.12.6 Verify required PORV backup nitrogen In accordance wi th supply pressure is within limit. the Surveillance Frequency Control Program SR 3.4.12.7 -------------------NOTE-----------------
Not required to be met until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after decreasing RCS cold leg temperature to : :; 280°F.
Perform a COT on each required PORV. I n accordance \'Ii th excluding actuation. the Survei 11 ance Frequency Control Program SR 3.4.12.8 Perform CHANNEL CALIBRATION for each In accordance with required PORV actuation channel. the Surveillance Frequency Control Program North Anna Units 1 and 2 3.4.12-4 Amendments 262 and 243
RCS Operational LEAKAGE 3.4.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.13.1 ----NN-------------NOTES------------------
- 1. Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after establishment of steady state operation.
- 2. Not applicable to primary to secondary LEAKAGE.
Verify RCS operational L.EAKAGE is within In accordance limits by performance of ReS water with the inventory balance. Surveillance Frequency Contro 1 Program SR 3.4.13.2 -------------------NOTE-------------------
Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after establishment of steady state operation.
Verify primary to secondary LEAKAGE is In accordance
< 150 gallons per day through anyone SG. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.4.13-2 Amendments 262 and 243
RCS PIV Leakage 3.4.14 SURVEIL~ANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.14.1 -------------------NOTES-----------------
- 1. Not required to be performed in MODES 3 and 4.
- 2. Not required to be performed on any RCS PIVs required to be tested located in the RHR flow path when in the shutdown cooling mode of operation.
- 3. RCS PIVs actuated during the performance of this Surveillance are not required to be tested more than once if a repetitive testing loop cannot be avoided.
Verify leakage from each ReS PIV required In accordance to be tested is equivalent to ~ 0.5 gpm with the per nominal inch of valve size up to a Inservice Testing maximum of 5 gpm at an RCS pressure Program. and in
~ 2215 psig and ~ 2255 psig. accordance with the Surveillance Frequency Control Program AND Prior to entering MODE 2 whenever the unit has been
- n MODE 5 for 7 days or more.
if 1eakage testing has not been performed in the previous 9 months Within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> fo 11 owi ng valve actuation due to automatic or manual action or flow through the valve North Anna Units 1 and 2 3.4.14-2 Amendments 262 and 243
RCS Leakage Detection Instrumentation 3.4.15 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.15.1 Perform CHANNEL CHECK of the required In accordance containment atmosphere radioactivity with the monitor. Surveillance Frequency Control Program SR 3.4.15.2 Perform COT of the required containment In accordance atmosphere radioactivity monitor. with the Surveillance Frequency Control Program SR 3.4.15.3 Perform CHANNEL CALIBRATION of the required In accordance containment sump monitor. with the Surveillance Frequency Control Program SR 3.4.15.'4 Perform CHANNEL CALIBRATION of the required In accordance containment atmosphere radioactivity with the monitor. Surveillance Frequency Control Program North Anna Units 1 and 2 3.4.15-3 Amendments 262 and 243
RCS Specific Activity 3.4.16 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1 Verify reactor coolant DOSE EQUIVALENT XE In accordance 133 specific activity ~ 197 ~Ci/gm. with the Surveillance Frequency Control Program SR 3.4.16.2 Verify reactor coolant DOSE EQUIVALENT In accordance 1-131 specific activity ~ 1.0 ~Ci/gm. with the Surveillance Frequency Control Program Between 2 and 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> after a THERMAL POWER change of
~ 15% RTP within a 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period North Anna Units 1 and 2 3.4.16-2 Amendments 262 and 243
RCS Loop Isolation Valves 3.4.17 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.17.2 Verify power removed from each Res loop In accordance isolation valve. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.4.17-2 Amendments 262 and 243
RCS Loops-Test Exceptions 3.4.19 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.19 RCS Loops-Test Exceptions LCO 3.4.19 The requirements of LCO 3.4.4, "RCS Loops-MODES 1 and 2," may be suspended, with THERMAL POWER < P-7.
APPLICABILITY: MODES 1 and 2 during startup and PHYSICS TESTS.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. THERMAL POWER 2 P-7. A.l Open reactor trip Immediately breakers.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.19.1 Verify THERMAL POWER is < P-7. In accordance with the Surveillance Frequency Control Program SR 3.4.19.2 Perform a COT for each power range neutron Prior to flux-low channel, intermediate range i niti at; on of neutron flux channel, P-I0, and P-13. startup and PHYSICS TESTS SR 3.4.19.3 Perform an ACTUATION LOGIC TEST on P-7. Prior to initiation of startup and PHYSICS TESTS North Anna Units 1 and 2 3.4.19-1 Amendments 262 and 243
Accumulators 3.5.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.5.1.1 Verify each accumulator isolation valve I n accordance wi th is fully open. the Surveillance Frequency Control Program SR 3.5.1.2 Verify borated water volume in each In accordance wi th accumulator is ~ 7580 gallons and the Surveillance
~ 7756 ga 11 ons. Frequency Control Program SR 3.5.1.3 Verify nitrogen cover pressure in each In accordance with accumulator is ~ 599 pSig and the Survei 11 ance
~ 667 psig. Frequency Control Program SR 3.5.1.4 Verify boron concentration in each In accordance with accumulator is ~ 2500 ppm and the Surveillance
- <;; 2800 ppm. Frequency Control Program AND
NOTE-----
Only required to be performed for affected accumulators Once within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> after each solution volume increase of ~ 50%
of i ndi cated 1eve1 i that is not the
. result of additi on from the refuel i ng water storage tank SR 3.5.1. 5 Verify power is removed from each In accordance with accumulator isolation valve operator the Surveillance when ReS pressure is ~ 2000 psig. Frequency Control Program North Anna Units 1 and 2 3.5.1-2 Amendments 262 and 243
ECCS-Operating 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify the following valves are in the In accordance with listed position with power to the valve the Surveillance operator removed. Frequency Control Program Unit 1 Number Position Function 1-SI-MOV-1890A Closed LHSI to Hot Leg 1-SI-MOV-1890B Closed LHSI to Hot Leg 1-SI-MOV-1836 Closed HHSI Pump to Cold Leg 1-SI-MOV-1869A Closed HHSI Pump to Hot Leg 1-SI~MOV-1869B Closed HHSI Pump to Hot Leg Unit 2 Number Position Function 2-SI-MOV-2890A Closed LHSI to Hot Leg 2-SI-MOV-2890B Closed LHSI to Hot Leg 2-SI-MOV-2836 Closed HHSI Pump to Cold Leg 2-SI-MOV-2869A Closed HHSI Pump to Hot Leg 2-SI-MOV-2869B Closed HHSI Pump to Hot Leg SR 3.5.2.2 Verify each ECCS manual, power operated, In accordance wi th and automatic valve in the flow path, the Surveillance that is not locked, sealed. or otherwise Frequency Control secured in position, is in the correct Program position.
SR 3.5.2.3 Verify ECCS piping is sufficiently full In accordance wi th of water. the Surveillance Frequency Control Program SR 3.5.2.4 Verify each ECeS pump1s developed head at In accordance with the test flow point is greater than or the Inservice equal to the required developed head. Testing Program North Anna Units 1 and 2 3.5.2-2 Amendments 262 and 243
ECCS-Operating 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE I FREQUENCY SR 3.5.2.5 Verify each ECCS automatic valve in the : In accordance with flow path that is not locked, sealed, or the Survei 11 ance i
otherwise secured in position, actuates I Frequency Control to the correct position on an actual or'
- Program simulated actuation signal.
SR 3.5.2.6 Verify each ECCS pump capable of starting In accordance with automatically starts automatically on an the Surveillance actual or simulated actuation signal. Frequency Control Program SR 3.5.2.7 Verify each ECC5 throttle valve listed In accordance with below is secured in the correct position. the Surveillance Frequency Control Unit 1 Valve Number Unit 2 Valve Number Program 1-S1-188 2-S1-89 1-51-191 2-51-97 I-S1-193 2-51-103 I-S1-203 2-51-116 I-S1-204 : 2-51-111 1-51-205 2-51-123 SR 3.5.2.8 Verify, by visual inspection, each ECCS In accordance with train containment sump component ;s not the Surveillance restricted by debris and shows no Frequency Control evidence of structural distr,ess or Program abnormal corrosion.
North Anna Units 1 and 2 3.5.2-3 Amendments 262 and 243
RWST 3.5.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.4.1 Verify RWST borated water temperature is In accordance
~ 40°F and ~ 50°F. with the Surveillance Frequency Control Program SR 3.5.4.2 Verify RWST borated water volume is In accordance
~ 466.200 gallons and ~ 487.000 gallons. with the Surveillance Frequency Control Program SR 3.5.4.3 Verify RWST boron concentration is In accordance
~ 2600 ppm and ~ 2800 ppm. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.5.4-2 Amendments 262 and 243
Seal Injection Flow 3.5.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.5.1 -------------------NOTE-------------------
Not required to be performed until 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> after the Reactor Coolant System pressure stabilizes at ~ 2215 psig and ~ 2255 pSig.
Verify manual seal injection throttle In accordance valves are adjusted to give a flow within with the limit with RCS pressure ~ 2215 psig and Surveillance
~ 2255 psig and the seal, injection hand Frequency control valve full open. Control Program North Anna Units 1 and 2 3.5.5-2 Amendments 262 and 243
BIT 3.5.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.6.1 Verify BIT borated water temperature is In accordance 2 l1SQF. with the Surveillance Frequency Control Program SR 3.5.6.2 Verify BIT borated water volume ;s In accordance 2 900 gallons. with the Surveillance Frequency Control Program SR 3.5.6.3 Verify BIT boron concentration is In accordance 2 12.950 ppm and ~ 15,750 ppm. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.5.6-2 Amendments 262 and 243
Containment Air Locks 3.6.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.1 -------------------NOTES------------------
- 1. An inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test.
- 2. Results shall be evaluated against acceptance criteria applicable to SR 3.6.1.1.
Perform required air lock leakage rate In accordance testing in accordance with the Containment with the Leakage Rate Testing Program. Containment Leakage Rate Testing Program SR 3.6.2.2 Verify only one door in the air lock can be In accordance opened at a time. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.6.2-5 Amendments 262 and 243
Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.6.3.1 -------------------NOTE-------------------
Valves and blind flanges in high radiation areas may be verified by use of administrative controls.
Verify each containment isolation manual In accordance valve and blind flange that is located with the outside containment and not locked, sealed, Surveillance or otherwise secured and required to be Frequency closed during accident conditions is Control Program closed, except for containment isolation valves that are open under administrative controls.
SR 3.6.3.2 -------------------NOTE-------------------
Valves and blind flanges in high radiation areas may be verified by use of administrative means.
Verify each containment isolation manual Prior to valve and blind flange that is located entering MODE 4 inside containment and not locked, sealed, from MODE 5 if or otherwise secured and required to be not performed closed during accident conditions ;s within the closed, except for containment isolation previous 92 days valves that are open under administrative controls.
SR 3.6.3.3 Verify the isolation time of each automatic In accordance power operated containment isolation valve with the is within limits~ Inservice Testing Program SR 3.6.3.4 Perform leakage rate testing for Prior to containment purge valves with resilient entering MODE 4 seals. from MODE 5 after containment vacuum has been broken North Anna Units 1 and 2 3.6.3-5 Amendments 262 and 243
Containment Isolation Valves 3.6.3 SURVEI LLANCE REQU IREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.5 Verify each automatic containment isolation In accordance valve that is not locked, sealed or with the otherwise secured in position, actuates to Surveillance the isolation position on an actual or Frequency simulated actuation signal. Control Program SR 3.6.3.6 Cycle each weight or spring loaded check In accordance valve not testable during operation through with the one complete cycle of full travel, and Surveillance verify each check valve remains closed when Frequency the differential pressure in the direction Control Program of flow is < 1.2 psid and opens when the differential pressure in the direction of flow is ~ 1.2 psid and < 5.0 psid.
North Anna Units 1 and 2 3.6.3-6 Amendments 262 and 243
Containment Pressure 3.6.4 3.6 CONTAINMENT SYSTEMS 3.6.4 Containment Pressure LCO 3.6.4 Containment air partial pressure shall be within the acceptable operation range shown on Figure 3.6.4-1.
APPLICABILITY: MODES 1, 2, 3, and 4.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment air A.1 Restore containment 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> partial pressure not air partial pressure within limits. to within limits.
B. Required Action and B.1 Be in MODE 3. 6 hours associated Completion Ti me not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1 Verify containment air partial pressure is In accordance within limits. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.6.4-1 Amendments 262 and 243
Containment Air Temperature 3.6.5 3.6 CONTAINMENT SYSTEMS 3.6.5 Containment Air Temperature LCO 3.6.5 Containment average air temperature shall be ~ 86°F and
- :; 115°F.
APPLICABILITY: MODES 1, 2. 3, and 4.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment average A.1 Restore containment 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> air temperature not average air within 1imits. temperature to within 1imits.
B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1 Verify containment average air temperature In accordance is within limits. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.6.5-1 Amendments 262 and 243
QS System 3.6.6 3.6 CONTAINMENT SYSTEMS 3.6.6 Quench Spray (QS) System LCO 3.6.6 Two QS trains shall be OPERABLE.
APPLICABILITY: MODES 1, 2, 3, and 4.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME
..
A. One QS train A.1 Restore QS train to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable. OPERABLE status.
B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Ti me not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.1 Verify each QS manual, power operated, and In accordance automatic valve in the flow path that is with the not locked. sealed. or otherwise secured in Surveillance position is in the correct position. Frequency Control Program
!
SR 3.6.6.2 Verify each QS pump's developed head at the In accordance flow test point is greater than or equal to with the the required developed head. Inservice Testing Program North Anna Units 1 and 2 3.6.6-1 Amendments 262 and 243
QS System 3.6.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.3 Verify each QS automatic valve in the flow In accordance path that is not locked, sealed, or with the otherwise secured in position, actuates to Surveillance the correct position on an actual or Frequency simulated actuation signal. Control Program SR 3.6.6.4 Verify each QS pump starts automatically on In accordance an actual or simulated actuation signal. with the Surveillance Frequency Control Program SR 3.6.6.5 Verify each spray nozzle is unobstructed. Fall OWl ng maintenance which could cause nozzle blockage North Anna Units 1 and 2 3.6.6-2 Amendments 262 and 243
RS System 3.6.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME F. One outside RS F.l Enter LCO 3.0.3. Immediately subsystem and one inside RS subsystem
, inoperable and not in the same train.
Three or more RS subsystems inoperable.
Two outside RS subsystems inoperable.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.7.1 Verify casing cooling tank temperature is In accordance
~ 35°F and ~ 50°F. with the Surveillance Frequency Control Program SR 3.6.7.2 Verify casing cooling tank contained In accordance borated water volume is ~ 116,500 gal. with the Surveillance Frequency Control Program SR 3.6.7.3 Verify casing cooling tank boron In accordance concentration is ~ 2600 ppm and ~ 2800 ppm. with the Surveillance Frequency Control Program North Anna Units 1 and 2 Amendments 262 and 243
RS System 3.6.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.7.4 Verify each RS and casing cooling manual. In accordance power operated. and automatic valve in the with the flow path that is not locked, sealed. or Surveillance otherwise secured in position is in the Frequency correct position. Control Program SR 3.6.7.5 Verify each RS and casing cooling pump's In accordance developed head at the flow test point is with the greater than or equal to the required Inservice developed head. Testing Program SR 3.6.7.6 Verify on an actual or simulated actuation In accordance signal (s): with the Surveillance
- a. Each RS automatic valve in the flow path Frequency that is not locked. sealed, or otherwise Control Program secured in position, actuates to the correct position;
- b. Each RS pump starts automatically; and
- c. Each casing cooling pump starts automat; ca 11 y.
SR 3.6.7.7 Verify. by visual inspection, each RS train In accordance containment sump component is not with the restricted by debris and shows no evidence Surveillance of structural distress or abnormal Frequency corrosion. Control Program SR 3.6.7.8 Verify each spray nozzle is unobstructed. Foll owing
- maintenance which could cause nozzle I blockage North Anna Units 1 and 2 3.6.7-3 Amendments 262 and 243
Chemical Addition System 3.6.8 3.6 CONTAINMENT SYSTEMS 3.6.8 Chemical Addition System LCO 3.6.8 The Chemical Addition System shall be OPERABLE.
APPLICABILITY: MODES 1, 2, 3, and 4.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Chemical Addition A.l Restore Chemical 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> System inoperable. Addition System to OPERABLE status.
B. Required Action and B.l Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 5. 84 hours9.722222e-4 days <br />0.0233 hours <br />1.388889e-4 weeks <br />3.1962e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.8.1 Verify each Chemical Addition System In accordance manual. power operated, and automatiC valve with the in the flow path that is not locked, Surveillance sealed, or otherwise secured in position is Frequency in the correct position. Control Program SR 3.6.8.2 Verify chemical addition tank solution In accordance volume is ~ 4800 gal and ~ 5500 gal. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.6.8-1 Amendments 262 and 243
Chemical Addition System 3.6.8 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.6.8.3 Verify chemical addition tank NaOH solution In accordance concentration is ~ 12% and ~ 13% by with th'e wei ght. Surveillance Frequency Contro 1 Program SR 3.6.8.4 Verify each Chemical Addition System In accordance automatic valve in the flow path that is with the not locked, sealed, or otherwise secured in Surveillance position, actuates to the correct position . Frequency on an actual or simulated actuation signal. Control Program SR 3.6.8.5 Verify Chemical Addition System flow from In accordance each solutionis flow path. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.6.8-2 Amendments 262 and 243
MSTVs 3.7.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1 -------------------NOTE-------------------
Only required to be performed in MODES 1 and 2.
Verify isolation time of each MSTV is In accordance
- 5 seconds. with the Inservice Testing Program SR 3.7.2.2 -------------------NOTE-------------------
Only required to be performed in MODES 1 and 2.
Verify each MSTV actuates to the isolation In accordance position on an actual or simulated with the actuation signal. Surveillance Frequency Control Program North Anna Units 1 and 2 3.7.2-2 Amendments262 and 243
MFIVs, MFPDVs, MFRVs, and MFRBVs 3.7.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. One or more MFPDV 0.1 Close or isolate 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable. MFPDV.
AND 0.2 Verify MFPDV is closed ! Once per 7 days or isolated.
E. Two valves in the same E.1 Isolate affected flow 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> flow path inoperable . path.
F. . Required Action and F.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND F.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 Verify the isolation time of each MFIV, In accordance MFRV, and MFRBV is ~ 6.98 seconds and the with the isolation time of each MFPDV is Inservice
~ 60 seconds. i Test; n9 Program SR 3.7.3.2 Verify each MFIV, MFPOV, MFRV, and MFRBV In accordance actuates to the isolation position on an with the actual or Simulated actuation signal. Surveillance Frequency Control Program North Anna Units 1 and 2 3.7.3-2 Amendments 262 and 243
SG PORVs 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Steam Generator Power Operated Relief Valves (SG PORVs)
LCO 3.7.4 Three SG PORV lines shall be OPERABLE.
APPLICABILITY: MODES 1, 2, and 3, MODE 4 when steam generator is relied upon for heat removal.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required SG PORV A.1 Restore required SG 7 days 1ine inoperable. PORV line to OPERABLE status.
B. Two or more required B.1 Restore all but one SG SG PORV lines PORV line to OPERABLE inoperable. status. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND C.2 Be in MODE 4 without 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> reliance upon steam generator for heat removal.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify one complete cycle of each SG In accordance with PORV. , the Surveil 1ance I Frequency Control Program North Anna Units 1 and 2 3.7.4-1 Amendments 262 and 243
SG PORVs 3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.2 Verify one complete cycle of each 5G In accordance with PORV manua1 isolation valve. the Surveillance Frequency Control Program North Anna Units 1 and 2 Amendments 262 and 243
AFW System 3.7 .5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time for Condition A AND or B not met.
C.2 Be in MODE 4. 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> OR Two AFW trains inoperable in MODE 1, 2, or 3.
D. Three AFW trains 0.1 ---------NOTE-------
inoperable in MODE 1, LCO 3.0.3 and all 2, or 3. other LCO Required Actions requiring MODE changes are suspended until one AFW train is restored to OPERABLE status.
Initiate action to Immediately restore one AFW train to OPERABLE status.
E. Required AFW train E.1 Initiate action to Immediately inoperable in MODE 4. restore AFW train to OPERABLE status.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 Verify each AFW manual, power operated, and, In accordance automatic valve in each water flow path, with the and in both steam supply flow paths to the Surveillance steam turbine driven pump, that is not Frequency locked. sealed, or otherwise secured in Control Program position, is in the correct position.
North Anna Units 1 and 2 3.7.5-2 Amendments 262 and 243
AFW System 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.2 -------------------NOTE-----------------
Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after ~ 1005 psig in the steam generator.
Verify the developed head of each AFW pump In accordance at the flow test point is greater than or with the equal to the required developed head. Inservice Testing Program SR 3.7.5.3 -------------------NOTE-------------------
Not applicable in MODE 4 when steam generator is relied upon for heat removal.
Verify each AFW automatic valve that is not In accordance locked, sealed. or otherwise secured in with the position. actuates to the correct position . Survei 11 ance on an actual or simulated actuation signal. Frequency Control Program SR 3.7.5.4 --------------------NOTES-----------------
- 1. Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after ~ 1005 psig in the steam generator.
- 2. Not applicable in MODE 4 when steam generator is relied upon for heat removal.
Verify each AFW pump starts automatically In accordance on an actual or simulated actuation signal. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.7.5-3 Amendments 262 and 243
AFW System 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.5 Verify proper a1ignment of the required AFW Prior to flow paths by verifying flow from the enter; ng MODE 3, emergency condensate storage tank to each whenever unit steam generator. has been in MODE 5, 6, or defueled for a cumulative period> 30 days North Anna Units 1 and 2 3.7.5-4 Amendments 262 and 243
ECST 3.7.6 3.7 PLANT SYSTEMS 3.7.6 Emergency Condensate Storage Tank (ECST)
LCO 3.7.6 The ECST shall be OPERABLE.
APPLICABILITY: MODES 1, 2, and 3, MODE 4 when steam generator is relied upon for heat removal.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ECST inoperable. A.l Verify by 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> administrative means OPERABILITY of AND Condensate Storage Tank. Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter AND A.2 Restore ECST to 7 days OPERABLE status.
B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 4, without 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> reliance on steam generator for heat removal.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify the ECST contains In accordance with the
- .; 110,000 gal. Surveillance Frequency Control Program North Anna Units 1 and 2 3.7.6-1 Amendments 262 and 243
Secondary Specific Activity 3.7.7 3.7 PLANT SYSTEMS 3.7.7 Secondary Specific Activity LCO 3.7.7 The specific activity of the secondary coolant shall be
~ 0.10 ~Ci/gm DOSE EQUIVALENT 1-131.
APPLICABILITY: MODES 1. 2, 3. and 4.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. 'Specific activity not A.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> withi n 1imit.
Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1 Verify the specific activity of the In accordance secondary coolant is ~ 0.10 ~Ci/gm DOSE with the EQUIVALENT 1-131. Surveillance' Frequency Cont ro1 Program North Anna Units 1 and 2 3.7.7-1 Amendments 262 and 243
SW System 3.7.8 SURVEILLANCE REMENTS SURVEILLANCE FREQUENCY SR 3.7.8.1 ------------ft------NOTE------------------ft-Isolation of SW flow to individual components does not render the SW System inoperable.
Verify each SW System manual, power In accordance operated, and automatic valve in the flow with the path servicing safety related equipment, Surveillance that is not locked, sealed, or otherwise Frequency secured in position, is in the correct Control Program position.
SR 3.7.8.2 Verify each SW System automatic valve in In accordance the flow path that is not locked, sealed, with the or otherwise secured in position, actuates Surveillance to the correct position on an actual or Frequency simulated actuation signal. Control Program North Anna Units 1 and 2 3.7.8-3 Amendments 262 and 243
S\~ System 3.7.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.8.3 Verify each SW pump starts automatically on In accordance an actual or simulated actuation signal. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.7.8-4 Amendments 262 and 243
UHS 3.7.9 3.7 PLANT SYSTEMS 3.7.9 Ultimate Heat Sink (UHS)
LCO 3.7.9 The UHS shall be OPERABLE.
APPLICABILITY: MODES 1, 2, 3, and 4.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. UHS inoperable. A.I Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> AND A.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEI LLANC E FREQUENCY SR 3.7.9.1 Verify water level of the Service Water In accordance Reservoir is ~ 313 ft mean sea level. with the Surveillance Frequency Control Program SR 3.7.9.2 Verify average water temperature of the In accordance Service Water Reservoir is ~ 95°F. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.7.9-1 Amendments 262 and 243
MCR/ESGR EVS I 3.7.10 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. (continued)
OR Two required MCR/ESGR EVS trains inoperable during movement of recently irradiated fuel assemblies for reasons other than Condition B.
F. Two required MCR/ESGR F.l Enter LCO 3.0.3. Immediately EVS trains inoperable in MODE 1, 2, 3, or 4 for reasons other than Condition B.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.10.1 Operate each required MCR/ESGR EVS train In accordance for ~ 10 continuous hours with the heaters with the operating. Surveillance Frequency Control Program SR 3.7.10.2 Perform required MCR/ESGR EVS filter In accordance testing in accordance with the Ventilation with VFTP Filter Testing Program (VFTP).
SR 3.7.10.3 Not Used North Anna Units 1 and 2 3.7.10-3 Amendments 262 and 243
MCR/ESGR ACS 3.7.11 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. Less than 100% of the E.1 Enter LCO 3.0.3. Immediately MCR/ESGR ACS cooling equivalent to a single OPERABLE MCR/ESGR ACS subsystem available in MODE 1, 2, 3, or 4.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.11.1 Verify each required MCR/ESGR ACS chiller In accordance has the capability to remove the assumed with the heat load. Surveillance Frequency Control Program North Anna Units 1 and 2 3.7.11-2 Amendments 262 and 243
Eees PREACS 3.7.12 ACTIONS CONDITION REQUIRED ACTION TION TIME D. Two ECCS PREACS trains 0.1.1 Verify ECCS leakage 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> inoperable due to log is less than the inoperable ECeS pump room maximum allowable boundary affecting unfiltered leakage.
filtration capability.
AND 0.1.2 Verify by field Once per walkdown that ECCS 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> leakage is less than thereafter the maximum allowable unfiltered leakage.
AND D.1.3 Restore ECCS pump room 14 days boundary to OPERABLE status.
OR 0.2 Restore ECCS pump room 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> boundary to OPERABLE status.
E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND E.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.12.1 Operate each ECCS PREACS train for In accordance with the
~ 10 continuous hours with the Surveillance Frequency heaters operating. Control Program North Anna Units 1 and 2 3.7.12-4 Amendments 262 and 243
ECCS PREACS 3.7 .12 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.12.2 Actuate each ECCS PREACS train by In accordance with the aligning Safeguards Area exhaust Surveillance Frequency flow and Auxiliary Building Central Control Program exhaust flow through the Auxiliary Building HEPA filter and charcoal adsorber assembly.
SR 3.7.12.3 Perform required ECCS PREACS filter In accordance with the testing in accordance with the VFTP Ventilation Filter Testing Program (VFTP) .
SR 3.7.12.4 Verify Safeguards Area exhaust flow In accordance with the is diverted and each Auxiliary Surveillance Frequency Building filter bank is actuated on Control Program an actual or simulated actuation signal.
SR 3.7.12.5 Verify one ECCS PREACS train can In accordance with the maintain a negative pressure Surveillance Frequency relative to adjacent areas during Control Program post accident mode of operation.
North Anna Units 1 and 2 3.7.12-5 Amendments 262 and 243
FBVS 3.7.15 3.7 PLANT SYSTEMS 3.7.15 Fuel Building Ventilation System (FBVS)
LCO 3.7.15 The FBVS shall be OPERABLE and in operation.
- - - - - - - - - - NOTE The fuel building boundary may be opened intermittently under administrative control.
APPLICABILITY: During movement of recently irradiated fuel assemblies in the fuel building.
ACTIONS
- - - - - - - - - - - - - - - - NOTE - - - - - -
LCO 3.0.3 is not applicable.
CONDITION REQUIRED ACTION COMPLETION TIME A. FBVS inoperable. A.l Suspend movement of Immediately recently irradiated OR fuel assemblies in the fuel building.
FBVS not in operation.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.15.1 Verify the FBVS can maintain a pressure In accordance
~ -0.125 inches water gauge with respect with the to atmospheric pressure. Survei 11 ance Frequency Control Program North Anna Units 1 and 2 3.7.15-1 Amendments 262 and 243
Fuel Storage Pool Water Level 3.7.16 3.7 PLANT SYSTEMS 3.7.16 Fuel Storage Pool Water Level LCO 3.7.16 The fuel storage pool water level shall be ~ 23 ft over the top of irradiated fuel assemb1ies seated in the storage racks.
APPLICABILITY: During movement of irradiated fuel assemblies in the fuel storage poo1.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel storage pool A.l --------NOTE--------
water level not within LCO 3.0.3 is not limit. applicable.
Suspend movement of Immediately i rradi ated fuel assemblies in the fuel storage pool.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.16.1 Verify the fuel storage pool water level is In accordance
~ 23 ft above the top of the irradiated with the fuel assemblies seated in the storage Surveillance racks. Frequency Control Program North Anna Units 1 and 2 3.7.16-1 Amendments262 and 243
Fuel Storage Pool Boron Concentration 3.7.17 3.7 PLANT SYSTEMS 3.7.17 Fuel Storage Pool Boron Concentration LCO 3.7.17 The fuel storage pool boron concentration shall be
- : 2600 ppm.
APPLICABILITY: When fuel assemblies are stored in the fuel storage pool.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel storage pool :------------NOTE------------
boron concentration LCO 3.0.3 is not applicable.
not within limit.
A.l Suspend movement of Immediately fuel assemblies in the fuel storage pool.
AND A.2 Initiate action to Immediately restore fuel storage pool boron concentration to within limit.
SURVEILLANCE REMENTS
,
SURVEILLANCE FREQUENCY SR 3.7.17.1 Verify the fuel storage pool boron In accordance concentration is within limit. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.7.17-1 Amendments 262 and 243
CC System 3.7.19 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.19.1 Verify each CC manual. power operated, and In accordance automatic valve in the flow path servicing with the the residual heat removal system, that is Surveillance not locked, sealed, or otherwise secured in Frequency position, is in the correct position. Control Program North Anna Units 1 and 2 3.7.19-2 Amendments 262 and 243
AC Sources-Operating 3.B.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and In accordance indicated power availability for each with the required offsite circuit. Survei 11 ance Frequency Control Program SR 3.8.1.2 -------------------NOTES--------------
- 1. All EOG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.
- 2. A modified EOG start involving idling and gradual accelerat i on to synchronous speed may be used for this SR as recommended by the manufacturer. When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.7 must be met.
Verify each required EOG starts from In accordance standby conditions and achieves steady with the state voltage ~ 3740 V and ~ 4580 V, and Surveillance frequency ~ 59.5 Hz and ~ 60.5 Hz. Frequency Cont ro 1 Program North Anna Units 1 and 2 3.8.1-8 Amendments 262 and 243
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.8.1.3 -------------------NOTES--------------
- 1. EDG loadings may include gradual loading as recommended by the manufacturer.
- 2. Momentary transients outside the load range do not invalidate this test.
- 3. This Surveillance shall be conducted on only one EDG at a time.
- 4. This SR shall be preceded by and immediately follow without shutdown a successful performance of SR 3.8.1.2 or SR 3.8.1.7.
Verify each required EDG is synchronized In accordance and loaded and operates for ~ 60 minutes with the at a load ~ 2500 kW and ~ 2600 kW. Surveillance Frequency Control Program SR 3.8.1.4 Verify each required day tank contains In accordance
~ 450 gal of fuel oil. with the Surveillance Frequency Control Program SR 3.8.1.5 Check for and remove accumulated water I In accordance from each required day tank. with the Surveillance Frequency Control Program SR 3.8.1.6 Verify each required fuel oil transfer In accordance pump operates to transfer fuel oil from with the the storage tank to the day tank. Surveillance Frequency Control Program North Anna Units 1 and 2 3.8.1-9 Amendments 262 and 243
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1. 7 -------------------NOTE---------------
All EDG starts may be preceded by an engine prelube period.
Verify each required EDG starts from In accordance standby* condition and achieves with the Surveillance
- a. In ~ 10 seconds. voltage ~ 3960 V and Frequency Control frequency ~ 59.5 Hz; and Program
- b. Steady state voltage ~ 3740 V and
~ 4580 V, and frequency ~ 59.5 Hz and
~ 60.5 Hz.
SR 3.8.1.8 -------------------NOTES-------------
- 1. This Surveillance is only applicable to Unit 1.
- 2. This Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the unit is maintained or enhanced.
Verify manual transfer of AC power sources In accordance from the normal offsite circuit to the with the alternate required offsite circuit. Surveillance Frequency Contra 1 Program North Anna Units 1 and 2 3.8.1-10 Amendments 262 and 243
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.9 -------------------NOTE---------------
If performed with EDG synchronized with offsite power, it shall be performed at a power factor ~ 0.9. However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition, the power factor shall be maintained as close to the limit as practicable.
Verify each required EDG rejects a load In accordance greater than or equal to its associated with the single largest post-accident load, and: Surve'j 11 ance Frequency Control
- a. Following load rejection, the frequency Program is ~ 66 Hz;
- b. Within 3 seconds following load rejection, the voltage is ~ 3740 V and
~ 4580 V; and
- c. Within 3 seconds following load rejection, the frequency is ~ 59.5 Hz and ~ 60.5 Hz.
North Anna Units 1 and 2 3.8.1-11 Amendments 262 and 243
AC Sources-operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.10 -------------------NOTES--------------
- 1. All EDG starts may be preceded by an engine prelube period.
- 2. This Surveillance shall not normally be performed in MODE I, 2, 3, or 4.
However. portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the unit is maintained or enhanced.
Verify on an actual or simulated loss of In accordance offsite power signal: with the Surveillance
- a. De-energization of emergency buses; Frequency Control Program
- b. Load shedding from emergency buses;
- c. Each required EDG auto-starts from standby condition and:
- 1. energizes permanently connected loads in s 10 seconds,
- 2. energizes auto-connected shutdown loads through sequencing timing relays,
- 3. maintains steady state voltage
~ 3740 V and s 4580 V,
- 4. maintains steady state frequency
~ 59.5 Hz and ~ 60.5 Hz, and
- 5. supplies permanently connected and auto-connected shutdown loads for
~ 5 minutes.
North Anna Units 1 and 2' 3.8.1-12 Amendments 262 and 243
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.11 -------------------NOTES--------------
- 1. All EDG starts may be preceded by prelube period.
- 2. This Surveillance shall not normally be performed in MODE 1 or 2. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the unit is maintained or enhanced.
Verify on an actual or simulated In accordance Engineered Safety Feature (ESF) actuation with the signal each LCO 3.8.1.b EDG auto-starts Surveillance from standby condition and: Frequency Contra 1 Program
- a. In ~ 10 seconds after auto-start and during tests, achieves voltage
~ 3960 V and frequency ~ 59.5 Hz;
- b. Achieves steady state voltage ~ 3740 V and ~ 4580 V and frequency ~ 59.5 Hz and ~ 60.5 Hz;
- c. Operates for ~ 5 minutes;
- d. Permanently connected loads remain energized from the offsite power system; and
- e. Emergency loads are energized or auto-connected through the sequencing timing relays from the offsite power system.
North Anna Units 1 and 2 3.8.1-13 Amendments 262 and 243
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.12 ---------~---------NOTE----------------
This Surveillance shall not normally be performed in MODE 1 or 2. However. this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the unit is maintained or enhanced.
Verify each required EDG's automatic trips In accordance are bypassed on actual or simulated with the automatic start signals except: Surveillance Frequency Contra1
- a. Engine overspeed; and Program
- b. Generator differential current.
North Anna Units 1 and 2 3.8.1-14 Amendments 262 and 243
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.B.l.13 -------------------NOTES--------------
- 1. Momentary transients outside the load and power factor ranges do not invalidate this test.
- 2. This Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the unit is maintained or enhanced.
- 3. If performed with EDG synchronized with offsite power. it shall be performed at a power factor ~ 0.9. However. if grid conditions do not permit. the power factor limit is not required to be met.
Under this condition the power factor shall be maintained as close to the limit as practicable.
Verify each required EDG operates for In accordance
~ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />! with the Surveillance
- a. For ~ 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> loaded ~ 2900 kW and Frequency Control S; 3000 kW; and Program
- b. For the remaining hours of the test loaded ~ 2500 kW and s; 2600 kW.
North Anna Units 1 and 2 3.B.I-15 Amendments 262 and 243
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.14 -------------------NOTES-----------------
- 1. This Surveillance shall be performed within 5 minutes of shutting down the EDG after the EDG has operated
~ 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> loaded ~ 2500 kW and
~ 2600 kW or after operating temperatures have stabilized.
Momentary transients outside of load range do'not invalidate this test.
- 2. All EDG starts may be preceded by an engine prelube period.
Verify each required EDG starts and In accordance achieves with the Surveillance
- a. In ~ 10 seconds, voltage ~ 3960 V and Frequency Contro 1 frequency ~ 59.5 Hz; and Program
- b. Steady state voltage ~ 3740 V, and
~ 4580 V and frequency ~ 59.5 Hz and
~ 60.5 Hz.
SR 3.8.1.15 -------------------NOTE------------------
This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the unit is maintained or enhanced.
Verify each required EOG: In accordance with the
- a. Synchronizes with offsite power source Surveil 1ance while loaded with emergency loads upon Frequency Control a simulated restoration of offsite Program power;
- b. Transfers loads to offsite power source; and
- c. Returns to ready-to-load .operation.
North Anna Units 1 and 2 3.8.1-16 Amendments 262 and 243
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.16 -------------------NOTE------------------
This Surveillance shall not normally be performed in MODE 1. 2. 3, or 4. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the unit is maintained or enhanced.
Verify each required sequencing timing In accordance relay is within the design tolerance. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.8.1-17 Amendments 262 and 243
AC Sources-Operating 3.B.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.B.1.17 ------------------NOTES------------------
- 1. All EDG starts may be preceded by an engine prelube period.
- 2. This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4.
However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the unit is maintained or enhanced.
Verify on an actual or simulated loss of In accordance offsite power signal in conjunction with with the an actual or simulated ESF actuation Surveillance signal: Frequency Control Program
- a. De-energization of emergency buses;
- b. Load shedding from emergency buses; and
- c. Each LeO 3.8.1.b EDG auto-starts from standby condition and:
- 1. energizes permanently connected loads in ~ 10 seconds,
- 2. energizes auto-connected emergency loads through load sequencing timing relays,
- 3. achieves steady state voltage
~ 3740 V and ~ 4580 V,
- 4. achieves steady state frequency
~ 59.5 Hz and ~ 60.5 Hz. and
- 5. supplies permanently connected and auto-connected emergency loads for
~ 5 minutes.
North Anna Units 1 and 2 3.8.1-18 Amendments 262 and 243
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.8.1.18 -------------------NOTE------------------
All EDG starts may be preceded by an engine prelube period.
~--------------------------
Verify when started simultaneously from In accordance standby condition. each LCO 3.B.1.b EDG with the achieves: Surveillance Frequency Control
- a. in $ 10 seconds, voltage ~ 3960 V and Program frequency ~ 59.5 Hz; and
- b. steady state voltage~ 3740 V and
$ 4580 V, and frequency ~ 59.5 Hz and
$ 60.5 Hz.
North Anna Units 1 and 2 3.8.1-19 Amendments 262 and 243
Diesel Fuel Oil and Starting Air 3.8.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME F. Required Action and F.l Declare associated Immediately associated Completion EDG(s) inoperable.
Time not met.
One or more EDGs diesel fuel oil or starting air subsystem not within limits for reasons other than Condition A, B, C, 0, or E.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify fuel oil inventory ~ 90,000 gal. In accordance
- wi th the Surveillance Frequency Control Program SR 3.8.3.2 Verify fuel oil properties of new and In accordance stored fuel oil are tested in accordance wi th the Oi ese 1 with, and maintained within the limits of, Fuel Oil the Diesel Fuel Oil Testing Program. Testing Program SR 3.8.3.3 Verify each EOG air start receiver pressure In accordance is ~ 175 psig. with the Surveillance Frequency Control Program SR 3.8.3.4 Check for and remove accumulated water from In accordance each stored fuel oil storage tank. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.8.3-3 Amendments 262 and 243
DC Sources-Operating 3.8.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. --------NOTE--------- 0.1 Declare associated Immediately Separate Condition shared component{s) entry is allowed for inoperable.
each DC subsystem.
One or more required LCO 3.8.4.c DC electrical power subsystem(s) inoperable.
SURVEILLANCE REQUIREMENTS SURVEILLANCE I FREQUENCY SR 3.8.4.1 Verify for each required Station and EOG In accordance battery, terminal voltage is ~ 129 V on with the float charge. Surveillance Frequency Control Program SR 3.8.4.2 Verify for each required Station and EDG In accordance battery, there is no visible corrosion at with the battery terminals and connectors. Surveillance Frequency OR Control Program Verify battery connection resistance is
~ 1.5E-4 ohm for inter-cell connections.
~ 1.5E-4 ohm for inter-rack connections.
~ 1.5E-4 ohm for inter-tier connections.
and ~ 1.5E-4 ohm for terminal conn~ctions.
SR 3.8.4.3 Verify for each required Station and EDG In accordance battery, cells, cell plates, and racks with the show no visual indication of physical Surveillance damage or abnormal deterioration that Frequency could degrade battery performance. Control Program North Anna Units 1 and 2 3.8.4-2 Amendments 262 and 243
DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.8.4.4 For. each required Station and EDG battery, In accordance remove visible terminal corrosion, verify with the battery cell to cell and terminal Surveillance connections are clean and coated with Frequency anti-corrosion material. Control Program SR 3.8.4.5 Verify for each required Station and EDG In accordance battery, connection resistance is with the
~ 1.5E-4 ohm for inter-cell connections, Surveil 1ance
~ 1.5E-4 ohm for inter-rack connections, Frequency
~ 1.5E-4 ohm for inter-tier connections, Control Program and ~ 1.5E-4 ohm for terminal connections.
SR 3.8.4.6 Verify each required Station battery In accordance charger supplies ~ 270 amps at ~ 125 V with the for ~ 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />. Surveillance Frequency Control Program SR 3.8.4.7 Verify each required EDG battery charger In accordance supplies ~ 10 amps at ~ 125 V for with the
~ 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />. Survei 11 ance Frequency Control Program North Anna Units 1 and 2 3.8.4-3 Amendments 262 and 243
DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.8 -------------------NOTES-------------
- 1. The modified performance discharge test in SR 3.8.4.9 may be performed in lieu of the service test in SR 3.8.4.8.
- 2. The performance discharge test in SR 3.8.4.9 may be performed in lieu of the service test in SR 3.8.4.8.
- 3. This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4.
However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the unit is maintained or enhanced.
Verify for each required Station battery. In accordance capacity is adequate to supply, and with the maintain in OPERABLE status, the required Surveillance emergency loads for the design duty cycle Frequency when subjected to a battery service test. Control Program North Anna Units 1 and 2 3.8.4-4 Amendments 262 and 243
DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.9 -------------------NOTE--------------
This Surveillance shall not normally be performed in MODE 1, 2, 3~ or 4 for Station batteries. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the unit is maintained or enhanced.
Verify for each required Station and EOG In accordance battery~ capacity is ~ 80% of the with the manufacturer's rating when subjected to a Surveillance performance discharge test or a modified Frequency performance discharge test. Control Program 18 months when battery shows degradation or has reached 85%
of expected life North Anna Units 1 and 2 3.8.4-5 Amendments 262 and 243
Battery Cell Parameters 3.8.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3 Restore battery cell 31 days parameters to Table 3.8.6-1 Category A and B limits.
i B. Required Action and B.1 Declare associated Immediately associated Completion battery inoperable.
Time of Condition A not met.
OR One or more Station batteries with average electrolyte temperature of the representative cells
< 60°F.
OR One or more Station or EDG batteries with one or more battery cell parameters not within Table 3.8.6-1 Category C values.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 Verify for each required Station and EDG In accordance battery cell parameters meet Table 3.8.6-1 with the Category A limits. Surveillance Frequency Control Program North Anna Units 1 and 2 3.8.6-2 Amendments 262 and 243
Battery Cell Parameters 3.8.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.2 Verify for each required Station and EDG In accordance battery cell parameters meet Table 3.8.6-1 with the Category B limits. Surveil 1ance Frequency Control Program AND Once within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after a battery discharge
< 110 V Once within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after a battery overcharge
> 150 V SR 3.8.6.3 Verify average electrolyte temperature of I n accordance representative cells for each required with the Station battery ;s ~ 60°F. Surveillance Frequency Control Program North Anna Units 1 and 2 3.8.6-3 Amendments 262 and 243
Inverters-Operating 3.8.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. One or more inverters B.1 ---------NOTE-------
required by Enter applicable LCO 3.B.7.b Conditions and inoperable. Required Actions of LCO 3.8.9, 1I0istribution Systems-Operating" with any vital bus de-energized.
Declare associated 7 days shared components inoperable.
C. Required Action and C.l Be in MODE 3. 6 hours associated Completion Time of Condition A AND not met.
C.2 Be in MODE 5. 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct inverter voltage and In accordance alignment to required AC vital buses. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.8.7-2 Amendments 262 and 243
Inverters-Shutdown 3.B.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct inverter voltage and In accordance alignments to required AC vital buses. with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.8.8-2 Amendments 262 and 243
Distribution Systems-Operating 3.8.9 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME F. --------NOTE--------- 'F.! Declare associated Immediately Separate Condition shared components entry is allowed for inoperable.
each AC vital subsystem.
One or more required LCO 3.B.9.b AC vital electrical power distribution subsystem{s) inoperable.
G. Required Action and G.! Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time for Condition At AND B, or C not met.
G.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> H. Two or more H.! Enter LCO 3.0.3. Immediately LCO 3.B.g.a electrical power distribution subsystems inoperable that result in a loss of safety function.
SURVEILLANCE REMENTS SURVEI lLANCE FREQUENCY SR 3.B.9.1 Verify correct breaker alignments and In accordance voltage to required AC, DC, and AC vital with the bus electrical power distribution Surveillance subsystems. Frequency Control Program North Anna Units 1 and 2 3.8.9-3 Amendments 262 and 243
Distribution Systems-Shutdown 3.8.10 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (conti nued) A.2.4 Initiate actions to Immediately restore required AC, DC, and AC vital bus electrical power distribution subsystems to OPERABLE status.
A.2.5 Declare associated Immediately required residual heat removal subsystem(s) inoperable and not in operation.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.10.1 Verify correct breaker alignments and In accordance voltage to required AC, DC, and AC vital with the bus electrical power distribution Surveillance subsystems. Frequency Control Program North Anna Units 1 and 2 3.8.10-2 Amendments 262 and 243
Boron Concentration 3.9.1 3.9 REFUELING OPERATIONS 3.9.1 Boron Concentration LCO 3.9.1 Boron concentrations of the Reactor Coolant System (RCS) , the refueling canal, and the refueling cavity shall be maintained within the limit specified in the COLR.
APPLICABILITY: MODE 6.
- - NOTE - - - - - - - -
Only applicable to the refueling canal and refueling cavity when connected to the RCS.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Boron concentration A.l Suspend CORE Immediately not within limit. ALTERATIONS.
AND A.2 Suspend positive Immediately reactivity additions.
AND A.3 Initiate action to Immediately restore boron concentration to within limit.
SURVEILLANCE IREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Verify boron concentration is within the In accordan ce wi th limit specified in the COLR. the Surveillance Frequency Control Program North Anna Units 1 and 2 3.9.1-1 Amendments 262 and 243
Nuclear Instrumentation 3.9.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.9.3.2 -------------------NOTE-------------------
Neutron detectors are excluded from CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program North Anna Units 1 and 2 3.9.3-2 Amendments 262 and 243
Containment Penetrations 3.9.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.4.1 Verify each required containment In accordance penetration ;s in the required status. with the Surveillance Frequency Control Program SR 3.9.4.2 -------------------NOTE-------------------
Not required to be met for containment purge and exhaust valve(s) in penetrations closed to comp1y with LCO 3.9.4.c.1.
Verify each required containment purge and In accordance exhaust valve actuates to the isolation with the position on manual initiation. Surveillance Frequency Control Program North Anna Units 1 and 2 Amendments 262 and 243
RHR and Coolant Circulation-High Water Level 3.9.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (conti nued) A.4 Close equipment hatch 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> and secure with four bolts.
AND A.S Close one door in each 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> installed air lock.
A.6.1 Close each penetration 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> providing direct access from the containment atmosphere to the outside atmosphere with a manual or automatic isolation valve, blind flange, or equivalent.
A.6.2 Verify each 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> penetration is capable of being closed by an OPERABLE Contaoi nment Purge and Exhaust Isolation System.
SURVEI LLANCE IREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify one RHR loop is in operation and In accordance circulating reactor coolant at a flow rate with the of ;:?! 3000 gpm. Survei 11 ance Frequency Control Program North Anna Units 1 and 2 3.9.5-2 Amendments 262 and 243
RHR and Coolant Circulation-Low Water Level 3.9.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.5.2 Verify each 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> penetration is capable of being closed by an OPERABLE Containment Purge and Exhaust Isolation System.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify one RHR loop is in operation and In accordance circulating reactor coolant at a flow rate with the of: Surveil 1ance Frequency
- a. ~ 3000 gpm. or Control Program
- b. ~ 2000 gpm if RCS temperature S 140°F and time since entry into MODE 3
~ 100 hours0.00116 days <br />0.0278 hours <br />1.653439e-4 weeks <br />3.805e-5 months <br />.
SR 3.9.6.2 -------------------NOTE-------------------
Not required to be performed until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after a required RHR pump is not in operation.
Verify correct breaker alignment and In accordance indicated power available to the required with the RHR pump that is not in operation. Surveillance Frequency Control Program North Anna Units 1 and 2 3.9.6-3 Amendments 262 and 243
Refueling Cavity Water Level 3.9.7 3.9 REFUELING OPERATIONS 3.9.7 Refueling Cavity Water Level LCO 3.9.7 Refueling cavity water level shall be maintained ~ 23 ft above the top of reactor vessel flange.
APPLICABILITY: During movement of irradiated fuel assemblies within containment.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refueling cavity water A.l Suspend movement of Immediately 1evel not within i rradi ated fuel 1imit. assemblies within containment.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify refueling cavity water 1evel is In accordance
~ 23 ft above the top of reactor vessel with the flange. Surveillance
- Frequency Control Program North Anna Units 1 and 2 3.9.7-1 Amendments 262 and 243
Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.16
- e. The quantitative limits on unfiltered air inleakage into the MCR/ESGR envelope. These limits shall be stated 1n a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph c. The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of design basis accident consequences. Unfiltered air inleakage limits for hazardous chemicals must ensure that exposure of MCR/ESGR envelope occupants to these hazards will be within the assumptions in the licensing basis.
- f. The provisions of SR 3.0.2 are applicable to the Frequencies for assessing MCR/ESGR envelope habitability, determining MCR/ESGR envelope unfiltered inleakage, and measuring MCR/ESGR envelope pressure and assessing the MCR/ESGR envelope boundary as required by paragraphs c and d, respectively.
5.5.17 Surveillance Frequency Control Program This program provides controls for Surveillance Frequencies. The program shall ensure that Surveillance Requirements specified in the Technical Specification are performed at interval sufficient to assure the associated Limiting Conditions for Operation are met.
- a. The Surveillance Frequency Control Program shall contain a list of Frequenci es of those Survei 11 ance Requi rements for whi c,h the Frequency is controlled by the program.
- b. Changes to the Frequencies listed in the Surveillance Frequency Control Program shall be made in accordance with NEI 04-10, IIRisk-Informed Method for Control of Surveillance Frequenc1es,1I Rev; s1 on 1.
- c. The provisions of Surveillance ReqUirements 3.0.2 and 3.0.3 are applicable to the Frequencies established in the Surveillance Frequency Control Program.
North Anna Units 1 and 2 5.5-17 Amendments 262 and 243
UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555*0001 SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION RELATED TO AMENDMENT NO. 262 TO RENEWED FACILITY OPERATING LICENSE NO. NPF-4 AND AMENDMENT NO. 243 TO RENEWED FACILITY OPERATING LICENSE NO. NPF-7 VIRGINIA ELECTRIC AND POWER COMPANY NORTH ANNA POWER STATION. UNITS 1 AND 2 DOCKET NOS. 50-338 AND 50-339
1.0 INTRODUCTION
By application dated March 30, 2010 (Agencywide Documents Access and Management System (ADAMS), Accession Nos. ML100900162, ML100900163, ML100900167), as supplemented by letters dated August 30, 2010 (ADAMS Accession No. ML102430462) and January 18, 2011 (ADAMS Accession No. ML110200451), Virginia Electric and Power Company (the licensee) submitted a request for changes to the North Anna Power Station, Unit Nos. 1 and 2 (NAPS 1 and 2), Technical Specifications (TSs). The requested change is to relocate specific surveillance frequencies to a licensee-controlled program with the implementation of Nuclear Energy Institute (NEI) 04-10, "Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies." The changes are consistent with NRC-approved Industry Technical Specification Task Force (TSTF) Standard Technical Specifications (STS) change TSTF-425, Revision 3. The supplemental letter provided additional information that clarified the application, did not expand the scope of the application as originally noticed, and did not change the U.S. Nuclear Regulatory Commission (NRC, the Commission) staff's original proposed no significant hazard consideration determination.
This safety evaluation (SE) documents the NRC staff's review of the impact of the proposed TS changes specifically address when implemented, TSTF-425 relocates most periodic frequencies of TS surveillances to a licensee controlled program, the Surveillance Frequency Control Program (SFCP), and provides requirements for the new program in the Administrative Controls section of the TS. All surveillance frequencies can be relocated except:
Frequencies that reference other approved programs for the specific interval (such as the In-Service Testing Program or the Primary Containment Leakage Rate Testing Program);
Frequencies that are purely event-driven {e.g., "each time the control rod is withdrawn to
- 2 the 'full out' position");
Frequencies that are event-driven, but have a time component for performing the surveillance on a one-time basis once the event occurs (e.g., "within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after thermal power reaching;;:: 95% RTP [rated thermal power]"); and Frequencies that are related to specific conditions (e.g., battery degradation, age and capacity) or conditions for the performance of a surveillance requirement (e.g., "drywell to suppression chamber differential pressure decrease").
A new program is added to the Administrative Controls of TS Section 5 as Specification 5.5.17.
The new program is called the SFCP and describes the requirements for the program to control changes to the relocated surveillance frequencies. The TS Bases for each of the affected surveillance requirements are revised to state that the frequency is set in accordance with the SFCP. Some surveillance requirements Bases do not contain a discussion of the frequency. In these cases, the Bases describing the current frequency were added to maintain consistency with the Bases for similar surveillances. These instances are noted in the markup along with the source of the text. The proposed licensee changes to the Administrative Controls of the TS to incorporate the SFCP include a specific reference to Nuclear Energy Institute (NEI) 04-10, "Risk-Informed Technical Specifications Initiative 5B, Risk-Informed Method for Control of Surveillance Frequencies," Revision 1, as the basis for making any changes to the surveillance frequencies once they are relocated out of the TS.
In a letter dated September 19, 2007, the NRC staff approved NEI 04-10, Revision 1 (ADAMS Accession No. ML072570267), as acceptable for referencing in licensing actions to the extent specified and under the limitations delineated in NEI 04-10, and the SE providing the basis for NRC acceptance of NEI 04-10.
2.0 REGULATORY EVALUATION
In the "Final Policy Statement: Technical Specifications for Nuclear Power Plants" published in the Federal Register (FR) (58 FR 39132, published July 22, 1993), the NRC addressed the use of Probabilistic Safety Analysis (PSA), currently referred to as Probabilistic Risk Assessment (PRA) in STS. In this 1993 FR publication, the NRC states, in part:
'The Commission believes that it would be inappropriate at this time to allow requirements which meet one or more of the first three criteria [of 10 CFR 50.36] to be deleted from technical specifications based solely on PSA (Criterion 4).
However, if the results ofPSA indicate that technical specifications can be relaxed or removed, a deterministic review will be performed. "
"The Commission Policy in this regard is consistent with its Policy Statement on
'Safety Goals for the operation of Nuclear Power Plants,' 51 FR 30028, published on August 21, 1986. The Policy Statement on Safety Goals states in part, probabilistic results should also be reasonably balanced and supported through use of deterministic arguments. In this way, judgments can be made about the degree of confidence to be given these [probabilistic] estimates and assumptions.
This is a key part of the process for determining the degree of regulatory conservatism that may be warranted for particular decisions. This
'defense-in-depth' approach is expected to continue to ensure the protection of public health and safety. "
- 3
'The Commission will continue to use PSA, consistent with its policy on Safety Goals, as a tool in evaluating specific line item improvements to Technical Specifications, new requirements, and industry proposals for risk-based Technical Specification changes. "
Approximately 2 years later the NRC provided additional detail concerning the use of PRA in the "Final Policy Statement: Use of Probabilistic Risk Assessment in Nuclear Regulatory Activities" published in the Federal Register (60 FR 42622, August 16,1995). In this FR publication, the NRC states, in part:
"The Commission believes that an overall policy on the use of PRA methods in nuclear regulatory activities should be established so that the many potential applications of PRA can be implemented in a consistent and predictable manner that would promote regulatory stability and efficiency. In addition, the Commission believes that the use of PRA technology in NRC regulatory activities should be increased to the extent supported by the state-of-the-art in PRA methods and data and in a manner that complements the NRC's deterministic approach. "
"PRA addresses a broad spectrum of initiating events by assessing the event frequency. Mitigating system reliability is then assessed, including the potential for multiple and common-cause failures. The treatment, therefore, goes beyond the single failure requirements in the deterministic approach. The probabilistic approach to regulation is, therefore, considered an extension and enhancement of traditional regulation by conSidering risk in a more coherent and complete manner. "
'Therefore, the Commission believes that an overall policy on the use of PRA in nuclear regulatory activities should be established so that the many potential applications of PRA can be implemented in a consistent and predictable manner that promotes regulatory stability and efficiency. This policy statement sets forth the Commission's intention to encourage the use of PRA and to expand the scope of PRA applications in aI/ nuclear regulatory matters to the extent supported by the state-of-the-art in terms of methods and data. "
'Therefore, the Commission adopts the fol/owing policy statement regarding the expanded NRC use of PRA:
(1) The use of PRA technology should be increased in aI/ regulatory matters to the extent supported by the state-of-the-art in PRA methods and data and in a manner that complements the NRC's deterministic approach and supports the NRC's traditional defense-in-depth philosophy.
(2) PRA and associated analyses (e.g., sensitivity studies, uncertainty analyses, and importance measures) should be used in regulatory matters, where practical within the bounds of the state-of-the-art, to reduce unnecessary conseNatism associated with current regulatory requirements, regulatory guides, license commitments, and staff practices. Where appropriate, PRA should be used to support the proposal for additional regulatory requirements in accordance with Title 10 of the Code of Federal Regulations (10 CFR) 50.109 (Backfit Rule). Appropriate procedures for including PRA in the process should be developed and followed. It is, of course, understood that the intent of this policy is that existing rules and regulations shall be complied with unless these rules and regulations are
-4 revised.
(3) PRA evaluations in support of regulatory decisions should be as realistic as practicable and appropriate supporting data should be publicly available for review.
(4) The Commission's safety goals for nuclear power plants and subsidiary numerical objectives are to be used with appropriate consideration of uncertainties in making regulatory judgments on the need for proposing and backfitting new generic requirements on nuclear power plant licensees. "
In 10 CFR 50.36, the NRC established its regulatory requirements related to the content of TSs.
Pursuant to 10 CFR 50.36, TSs are required to include items in the following five specific categories related to station operation: (1) safety limits, limiting safety system settings, and limiting control settings; (2) limiting conditions for operation; (3) surveillance requirements; (4) design features; and (5) administrative controls.
As stated in 10 CFR 50.36(c)(3), "Surveillance requirements are requirements relating to test, calibration, or inspection to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met." These categories will remain in the TSs. The new TS SFCP provides the necessary administrative controls to require that surveillance frequencies relocated to the SFCP are conducted at a frequency to assure that the necessary quality of systems and components are maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met. Changes to surveillance frequencies in the SFCP are made using the methodology contained in NEI 04-10, including qualitative considerations, results of risk analyses, sensitivity studies and any bounding analyses, and recommended monitoring of structures, systems, and components (SSCs), and required to be documented. Furthermore, changes to frequencies are subject to regulatory review and oversight of the SFCP implementation through the rigorous NRC review of safety-related SSC performance provided by the reactor oversight program.
Licensees are required by TS to perform surveillance test, calibration, or inspection on specific safety-related system equipment (e.g., reactivity control, power distribution, electrical, and instrumentation) to verify system operability. Surveillance frequencies, currently identified in TSs, are based primarily upon deterministic methods such as engineering jUdgment, operating experience, and manufacturer's recommendations. The licensee's use of NRC-approved methodologies identified in NEI 04-10 provides a way to establish risk-informed surveillance frequencies that complement the deterministic approach and support the NRC's traditional defense-in-depth philosophy.
The licensee's SFCP ensures that surveillance requirements specified in the TSs are performed at intervals sufficient to assure the above regulatory requirements are met. Existing regulatory requirements, such as 10 CFR 50.65, "Requirements for Monitoring the Effectiveness of Maintenance at Nuclear Power Plants," and 10 CFR 50, Appendix B (corrective action program),
require licensee monitoring of surveillance test failures and implementing corrective actions to address such failures. One of these actions may be to consider increasing the frequency at which a surveillance test is performed. In addition, the SFCP implementation guidance in NEI 04-10 requires monitoring the performance of SSCs for which surveillance frequencies are decreased to assure reduced testing does not adversely impact the SSCs. These requirements, and the monitoring required by NEI 04-10, ensure that surveillance frequencies are sufficient to assure that the requirements of 10 CFR 50.36 are satisfied and that any performance deficiencies will be identified and appropriate corrective actions taken.
- 5 Regulatory Guide (RG) 1.174, "An Approach for Using Probabilistic Risk Assessment in Risk-Informed Decisions on Plant-Specific Changes to the Licensing Basis," describes a risk-informed approach, acceptable to the NRC, for assessing the nature and impact of proposed permanent licensing-basis changes by considering engineering issues and applying risk insights. This RG also provides risk acceptance guidelines for evaluating the results of such evaluations.
In RG 1.177, "An Approach for Plant-Specific, Risk-Informed Decisionmaking: Technical Specifications," it describes an acceptable risk-informed approach specifically for assessing proposed permanent TS changes.
In RG 1.200, "An Approach for Determining the Technical Adequacy of Probabilistic Risk Assessment Results for Risk-Informed Activities," it describes an acceptable approach for determining whether the quality of the PRA, in total or the parts that are used to support an application, is sufficient to provide confidence in the results, such that the PRA can be used in regulatory decision making for light water-reactors.
3.0 TECHNICAL EVALUATION
The licensee's adoption of TSTF-425 for NAPS provides for administrative relocation of applicable surveillance frequencies, and provides for the addition of the SFCP to the administrative controls of TS. TSTF-425 also requires the application of NEI 04-10 for any changes to surveillance frequencies within the SFCP. The licensee's application for the changes proposed in TSTF--425 included documentation regarding the PRA technical adequacy consistent with the requirements of RG 1.200, "An Approach for Determining the Technical Adequacy of Probabilistic Risk Assessment Results for Risk-Informed Activities," Revision 1. In accordance with NEI 04-10 PRA methods are used, in combination with plant performance data and other considerations, to identify and justify modifications to the surveillance frequencies of equipment at nuclear power plants. This is in accordance with guidance provided in RG 1.174, "An Approach for Using Probabilistic Risk Assessment in Risk-Informed Decisions on Plant-Specific Changes to the Licensing Basis," and RG 1.177 in support of changes to surveillance test intervals.
3.1 RG 1.177 Five Key Safety Principles In RG 1.177 it identifies five key safety principles required for risk-informed changes to TSs. Each of these principles is addressed by the industry methodology document, NEI 04-10.
3.1.1 The Proposed Change Meets Current Regulations In 10 CFR 50.36(c)(3) it provides that TSs will include surveillances which are "requirements relating to test, calibration, or inspection to assure that necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met." In NEI 04-10 it provides guidance for relocating the surveillance frequencies from the TSs to a licensee-controlled program by providing an NRC-approved methodology for control of the surveillance frequencies. The surveillance category remains in the TSs, as required by 10 CFR 50.36(c)(3).
-6 This change is consistent with other NRC-approved TS changes in which the surveillance frequencies are relocated to licensee-controlled documents, such as surveillances performed in accordance with the In-service Testing Program or the Primary Containment Leakage Rate Testing Program. Thus, this proposed change meets the first key safety principle of RG 1.177 by complying with current regulations.
3.1.2 The Proposed Change Is Consistent With the Defense-in-Depth Philosophy Consistency with the defense-in-depth philosophy, the second key safety principle of RG 1.177, is maintained if:
- A reasonable balance is preserved among prevention of core damage, prevention of containment failure, and consequence mitigation.
- Over-reliance on programmatic activities to compensate for weaknesses in plant design is avoided.
- System redundancy, independence, and diversity are preserved commensurate with the expected frequency, consequences of challenges to the system, and uncertainties (e.g.,
no risk outliers). Because the scope of the proposed methodology is limited to revision of surveillance frequencies, the redundancy, independence, and diversity of plant systems are not impacted.
- Defenses against potential common cause failures are preserved, and the potential for the introduction of new common cause failure mechanisms is assessed.
- Independence of barriers is not degraded.
- Defenses against human errors are preserved.
- The intent of the General Design Criteria in 10 CFR Part 50, Appendix A, is maintained.
In TSTF-425, it requires the application of NEI 04-10 for any changes to surveillance frequencies within the SFCP. In NEI 04-10 it uses both the core damage frequency (CDF) and the large early release frequency (LERF) metrics to evaluate the impact of proposed changes to surveillance frequencies. The guidance of RG 1.174 and RG 1.177 for changes to CDF and LERF is achieved by evaluation using a comprehensive risk analysis, which assesses the impact of proposed changes including contributions from human errors and common cause failures.
Defense-in-depth is also included in the methodology explicitly as a qualitative consideration outside of the risk analysis, as is the potential impact on detection of component degradation that could lead to an increased likelihood of common cause failures. Both the quantitative risk analysis and the qualitative considerations assure a reasonable balance of defense-in-depth is maintained to ensure protection of public health and safety, satisfying the second key safety principle of RG 1.177.
3.1.3 The Proposed Change Maintains Sufficient Safety Margins The engineering evaluation that will be conducted by the licensee under the SFCP when frequencies are revised will assess the impact of the proposed frequency change with the principle that sufficient safety margins are maintained. The guidelines used for making that assessment will include ensuring the proposed surveillance test frequency change is not in conflict with approved industry codes and standards or adversely affects any assumptions or inputs to the safety analysis, or, if such inputs are affected, justification is provided to ensure
-7 sufficient safety margin will continue to exist.
The design, operation, testing methods, and acceptance criteria for SSCs, specified in applicable codes and standards (or alternatives approved for use by the NRC) will continue to be met as described in the plant licensing basis (including the Updated Final Safety Analysis Report and bases to TS), since these are not affected by changes to the surveillance frequencies. Similarly, there is no impact to safety analysis acceptance criteria as described in the plant licensing basis.
Thus, safety margins are maintained by the proposed methodology, and the third key safety principle of RG 1.177 is satisfied.
3.1.4 When Proposed Changes Result in an Increase in Core Damage Frequency or Risk, the Increases Should Be Small and Consistent With the Intent of the Commission's Safety Goal Policy Statement In RG 1.177 it provides a framework for evaluating the risk impact of proposed changes to surveillance frequencies. This requires the identification of the risk contribution from impacted surveillances, determination of the risk impact from the change to the proposed surveillance frequency, and performance of sensitivity and uncertainty evaluations. TSTF-425 requires application of NEI 04-10 in the SFCP. In NEI 04-10 it satisfies the intent of RG 1.177 requirements for evaluating the change in risk, and for assuring that such changes are small.
3.1.4.1 Quality of the PRA The quality of the NAPS PRA is compatible with the safety implications of the proposed TS change and the role the PRA plays in justifying the change. That is, the more the potential change in risk or the greater the uncertainty in that risk from the requested TS change, or both, the more rigor that must go into ensuring the quality of the PRA.
The licensee used RG 1.200 to address the technical adequacy of the NAPS PRA. RG 1.200 is NRC's developed regulatory guidance, which endorses with comments and qualifications the use of the American Society of Mechanical Engineers (ASME) RA-Sb-2005, "Addenda to ASME RA-S-002 Standard for Probabilistic Risk Assessment for Nuclear Power Plant Applications," NEI 00-02, "PRA Peer Review Process Guidelines," and NEI 05-04, "Process for Performing Follow-On PRA Peer Reviews Using the ASME PRA Standard." The licensee has performed an assessment of the PRA models used to support the SFCP against the requirements of RG 1.200 to assure that the PRA models are capable of determining the change in risk due to changes to surveillance frequencies of SSCs, using plant-specific data and models. Capability category II of ASME RA-Sb-2005 is applied as the standard, and any identified deficiencies to those requirements are assessed further to determine any impacts to proposed decreases to surveillance frequencies, including by the use of sensitivity studies where appropriate.
The NRC staff reviewed the licensee's assessment of the NAPS PRA and the remaining open deficiencies that do not conform to capability category II of the ASME PRA standard (Table 1 of of the license amendment request, as modified by a response to the NRC staffs request for additional information). The NRC staffs assessment of the remaining open "gaps," to assure that they may be addressed and dispositioned for each surveillance frequency evaluation per the NEI 04-10 methodology, is provided below.
Gap #1: The model for anticipated transient without scram (ATWS) uses a conservative unfavorable exposure time. The licensee identified that this conservative simplification assumes that pressure relief capacity is always insufficient, and that ATWS will be assessed in sensitivity studies when required. The NRC staff
- 8 concurs that assuming a conservative exposure time can be addressed per the methodology of NEI 04-10.
Gap#2: Support system initiating events fault tree include a multiplier which should be replaced with the newer methodology of Electric Power and Research Institute (EPRI) EPRI-TR-1013490, "Support System Initiating Events: Identification and Quantification Guideline." The licensee identified that this gap is important for changes involving the support systems and will be addressed using the EPRI methodology. The NRC staff concurs that this deficiency can be addressed per the methodology of NEI 04-10.
Gap #3: Operator action to restore Emergency Core Cooling System functions for station blackout is not addressed and the documentation does not reflect this required action. The licensee identified the impact as being a small nonconservatism and that a sensitivity analysis would include consideration of this human action. The NRC staff concurs that this deficiency can be addressed per the methodology of NEI04-10.
Gap #4: Consequential loss of reactor coolant pump seal cooling is not included in the model. Since this failure mode would require concurrent failure of two separate systems, the licensee stated that the impact should be comparable or lower than consequential pressurizer power-operated relief valve failures, which are modeled.
Sensitivity analyses will include consideration of this failure mode. The NRC staff concurs that this deficiency can be addressed per the methodology of NEI 04-10 by additional logic models when required.
Gap #5: Electrical bus cross-tie unavailability is not modeled. Additional modeling of this capability will be made to address the gap with sensitivity studies, and therefore the NRC staff concurs that this deficiency can be addressed per the methodology of NEI04-10.
Gap #6: Success criteria involving operator response is not discussed. The licensee identified this as a documentation issue, and therefore the NRC staff concurs that this deficiency can be addressed per the methodology of NEI 04-10.
Gap #7: Inadvertent safety injection actuation is not addressed in the PRA model. The licensee has identified that this deficiency has been addressed subsequent to the submittal to add this initiator and therefore this gap no longer exists. Therefore, the NRC staff finds this action acceptable.
Gap #8: No formal documentation of plant walkdowns and interviews with plant personnel.
The licensee has identified this as a documentation issue and therefore the NRC staff concurs that this deficiency can be addressed per the methodology of NEI04-10.
Gap #9: The PRA model does not distinguish between water relief and steam relief for pressurizer power-operated relief valves failure to reclose failure mode. The guidance of EPRI-1 011 047 will be used to develop sensitivity models. Therefore, the NRC staff concurs that this deficiency can be addressed per the methodology of NEI 04-10.
Gap #10: Time windows for successful completion of operator actions need to be updated.
The licensee identified similarities with other PRA models based on plant-specific analyses, and identified that a sensitivity study using a factor of two for the
-9 probability offailure of the action would be used. Therefore, the NRC staff concurs that this deficiency can be addressed per the methodology of NEI 04-10.
Gap#11: Required action times are based on similar actions for other PRA models rather than on time measurements from walkthroughs or simulator scenarios. The licensee does not expect any significant changes based on comparisons with other PRA models, and considers this to be a documentation issue. The NRC staff concurs that this deficiency can be addressed per the methodology of NEI 04-10.
Gaps #12, #13, #14, #15, #16: Deficiencies in documentation of human errors, key assumptions and key sources of uncertainty were identified. The NRC staff concurs that these deficiencies in documentation can be addressed per the methodology of NEI04-10.
Gap #17: A realistic evaluation of secondary side isolation capability for steam generator tube releases is required. The licensee identified that additional steam generator relief valve demands are not considered, and that a more realistic model will be developed to support sensitivity studies. The NRC staff concurs that this deficiency can be addressed per the methodology of NEI 04-10.
Based on the licensee's assessment using the applicable PRA standard and RG 1.200, the level of PRA quality, combined with the proposed evaluation and disposition of gaps, is sufficient to support the evaluation of changes proposed to surveillance frequencies within the SFCP, and is consistent with Regulatory Position 2.3.1 of RG 1.177.
3.1.4.2 Scope of the PRA The licensee is required to evaluate each proposed change to a relocated surveillance frequency using the guidance contained in NEI 04-10 to determine its potential impact on risk, due to impacts from internal events, fires, seismic, other external events, and from shutdown conditions.
Consideration is made of both CDF and LERF metrics. In cases where a PRA of sufficient scope or where quantitative risk models were unavailable, the licensee uses bounding analyses, or other conservative quantitative evaluations. A qualitative screening analysis may be used when the surveillance frequency impact on plant risk is shown to be negligible or zero.
The individual plant examination of external events (IPEEE) fire-induced vulnerability evaluation analysis, and the IPEEE seismic margins analysis, will be used to provide insights for fires and seismic events. Other external hazards were screened during the IPEEE assessment, and will therefore be qualitatively assessed for this application.
The licensee's evaluation methodology is sufficient to ensure the scope of the risk contribution of each surveillance frequency change is properly identified for evaluation, and is consistent with Regulatory Position 2.3.2 of RG 1.177.
3.1.4.3 PRA Modeling The licensee will determine whether the SSCs affected by a proposed change to a surveillance frequency are modeled in the PRA. Where the SSC is directly or implicitly modeled, a quantitative evaluation of the risk impact may be carried out. The methodology adjusts the failure probability of the impacted SSCs, including any impacted common cause failure modes, based on the proposed change to the surveillance frequency. Where the SSC is not modeled in the PRA, bounding analyses are performed to characterize the impact of the proposed change to the
- 10 surveillance frequency. Potential impacts on the risk analyses due to screening criteria and truncation levels are addressed by the requirements for PRA technical adequacy consistent with guidance contained in RG 1.200, and by sensitivity studies identified in NEI 04-10.
The licensee will perform quantitative evaluations of the impact of selected testing strategy (Le.,
staggered testing or sequential testing) consistently with the guidance of NUREG/CR-6141 and NUREG/CR-5497, as discussed in NEI 04-10.
Thus, through the application of NEI 04-10 the NAPS PRA modeling is sufficient to ensure an acceptable evaluation of risk for the proposed changes in surveillance frequency, and is consistent with Regulatory Position 2.3.3 of RG 1.177.
3.1.4.4 Assumptions for Time-Related Failure Contributions The failure probabilities of SSCs modeled in the NAPS PRA include a standby time-related contribution and a cyclic demand-related contribution. The NEI 04-10 criterion adjusts the time-related failure contribution of SSCs affected by the proposed change to surveillance frequency. This is consistent with RG 1.177, Section 2.3.3, which permits separation of the failure rate contributions into demand and standby for evaluation of surveillance requirements. If the available data does not support distinguishing between the time-related failures and demand failures, then the change to surveillance frequency is conservatively assumed to impact the total failure probability of the SSC, including both standby and demand contributions. The SSC failure rate (per unit time) is assumed to be unaffected by the change in test frequency, and will be confirmed by the required monitoring and feedback implemented after the change in surveillance frequency is implemented. The process requires consideration of qualitative sources of information with regards to potential impacts of test frequency on SSC performance, including industry and plant-specific operating experience, vendor recommendations, industry standards, and code-specified test intervals. Thus, the process is not reliant upon risk analyses as the sole basis for the proposed changes.
The potential beneficial risk impacts of reduced surveillance frequency, including reduced downtime, lesser potential for restoration errors, reduction of potential for test caused transients, and reduced test-caused wear of equipment, are identified qualitatively, but are conservatively not required to be quantitatively assessed. Thus, through the application of NEt 04-10, the licensee has employed reasonable assumptions with regard to extensions of surveillance test intervals, and is consistent with Regulatory Position 2.3.4 of RG 1.177.
3.1.4.5 Sensitivity and Uncertainty Analyses In NEI 04-10 it requires sensitivity studies to assess the impact of uncertainties from key assumptions of the PRA, uncertainty in the failure probabilities of the affected SSCs, impact to the frequency of initiating events, and of any identified deviations from capability category II of ASME PRA Standard (ASME RA-Sb-2005). Where the sensitivity analyses identify a potential impact on the proposed change, revised surveillance frequencies are considered, along with any qualitative considerations that may bear on the results of such sensitivity studies. Required monitoring and feedback of SSC performance once the revised surveillance frequencies are implemented will also be performed. Thus, through the application of NEI 04-10, the licensee has appropriately considered the possible impact of PRA model uncertainty and sensitivity to key assumptions and model limitations, and is consistent with regulatory position 2.3.5 of RG 1.177.
3.1.4.6 Acceptance Guidelines The licensee will quantitatively evaluate the change in total risk (including internal and external
~ 11 events contributions) in terms of CDF and LERF for both the individual risk impact of a proposed change in surveillance frequency and the cumulative impact from all individual changes to surveillance frequencies using the guidance contained in NRC-approved NEI 04-10 in accordance with the TS SFCP. Each individual change to surveillance frequency must show a risk impact below 1 E~6 per year for change to CDF, and below 1 E~7 per year for change to LERF.
These are consistent with the limits of RG 1.174 for very small changes in risk. Where the RG 1.174 limits are not met, the process either considers revised surveillance frequencies which are consistent with RG 1.174 or the process terminates without permitting the proposed changes.
Where quantitative results are unavailable to permit comparison to acceptance guidelines, appropriate qualitative analyses are required to demonstrate that the associated risk impact of a proposed change to surveillance frequency is negligible or zero. Otherwise, bounding quantitative analyses are required which demonstrate the risk impact is at least one order of magnitude lower than the RG 1.174 acceptance guidelines for very small changes in risk. In addition to assessing each individual SSC surveillance frequency change, the cumulative impact of all changes must result in a risk impact below 1E-S per year for change to CDF, and below 1E-6 per year for change to LERF. The total CDF and total LERF must be reasonably shown to be less than 1E-4 per year and 1 E~S per year, respectively. These are consistent with the limits of RG 1.174 for acceptable changes in risk, as referenced by RG 1.177 for changes to surveillance frequencies. The NRC staff interprets this assessment of cumulative risk as a requirement to calculate the change in risk from a baseline model utilizing failure probabilities based on the surveillance frequencies prior to implementation of the SFCP, compared to a revised model with failure probabilities based on changed surveillance frequencies. The NRC staff further notes that the licensee includes a provision to exclude the contribution to cumulative risk from individual changes to surveillance frequencies associated with insignificant risk increases (less than SE-8 CDF and SE-9 LERF) once the baseline PRA models are updated to include the effects of the revised surveillance frequencies.
The quantitative acceptance guidance of RG 1.174 is supplemented by qualitative information to evaluate the proposed changes to surveillance frequencies, including industry and plant-specific operating experience, vendor recommendations, industry standards, the results of sensitivity studies, and SSC performance data and test history.
The final acceptability of the proposed change is based on all of these considerations and not solely on the PRA results compared to numerical acceptance guidelines. Post implementation performance monitoring and feedback are also required to assure continued reliability of the components. The licensee's application of NEI 04-10 provides reasonable acceptance guidelines and methods for evaluating the risk increase of proposed changes to surveillance frequencies, consistent with Regulatory Position 2.4 of RG 1.177. Therefore, the proposed methodology satisfies the fourth key safety principle of RG 1.177 by assuring any increase in risk is small consistent with the intent of the Commission's Safety Goal Policy Statement.
3.1.S The Impact of the Proposed Change Should Be Monitored Using Performance Measurement Strategies The licensee's adoption of TSTF-42S requires application of NEI 04-10 in the SFCP. In NEI 04-10 it requires performance monitoring of SSCs whose surveillance frequency has been revised as part of a feedback process to assure that the change in test frequency has not resulted in degradation of equipment performance and operational safety. The monitoring and feedback includes consideration of maintenance rule monitoring of equipment performance. In the event of degradation of SSC performance, the surveillance frequency will be reassessed in accordance with the methodology, in addition to any corrective actions which may apply as part of the
- 12 maintenance rule requirements. The performance monitoring and feedback specified in NE 04-10 is sufficient to reasonably assure acceptable SSC performance and is consistent with regulatory position 3.2 of RG 1.177. Thus, the fifth key safety principle of RG 1.177 is satisfied.
3.2 Addition of Surveillance Frequency Control Program to Administrative Controls The licensee has included the SFCP and specific requirements into the Administrative Controls, TS Section 5.5.17, Surveillance Frequency Control Program, as follows:
This program provides controls for SUNeillance Frequencies. The program shall ensure that SUNeiJIance Requirements specified in the Technical Specifications are performed at inteNals sufficient to assure that the associated Limiting Conditions for Operation are met.
- a. The SUNeillance Frequency Control Program shall contain a list of Frequencies of the SUNeillance Requirements for which the Frequency is controlled by the program.
- b. Changes to the Frequencies listed in the SUNeillance Frequency Control Program shall be made in accordance with NEI04-10, "Risk-Informed Method for Control of SUNeiJIance Frequencies, " Revision 1.
- c. The provisions of SUNeillance Requirements 3.0.2 and 3.0.3 are applicable to the Frequencies established in the SUNeil/ance Frequency Control Program.
The proposed program is consistent with the model application of TSTF-425, and is therefore acceptable.
3.3 Summary The NRC staff has reviewed the licensee's proposed relocation of some surveillance frequencies to a licensee controlled document, and controlling changes to surveillance frequencies in accordance with a new program, the SFCP, identified in the administrative controls of TS. The SFCP and TS Section 5.5.17 references NEI 04-10, which provides a risk-informed methodology using plant-specific risk insights and performance data to revise surveillance frequencies within the SFCP. This methodology supports relocating surveillance frequencies from TS to a licensee-controlled document, provided those frequencies are changed in accordance with NEI 04-10 which is specified in the Administrative Controls of the TS.
The proposed licensee adoption of TSTF-425 and risk-informed methodology of NEI 04-10 as referenced in the Administrative Controls of TS, satisfies the key principles of risk-informed decision making applied to changes to TS as delineated in RG 1.177 and RG 1.174, in that:
The proposed change meets current regulations; The proposed change is consistent with defense-in-depth philosophy;
- The proposed change maintains sufficient safety margins; Increases in risk resulting from the proposed change are small and consistent with the Commission's Safety Goal Policy Statement; and
- The impact of the proposed change is monitored with performance measurement strategies.
In 10 CFR 50.36(c)(3) it states "[Technical specifications will include items in the following categories:] Surveillance Requirements. Surveillance Requirements are requirements relating to test, calibration, or inspection to assure that the necessary quality of systems and components is
- 13 maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met." The NRC staff finds that with the proposed relocation of surveillance frequencies to an owner-controlled document and administratively controlled in accordance with the TS SFCP, the licensee continues to meet the regulatory requirement of 10 CFR 50.36, and, specifically, 10 CFR 50.36(c)(3), surveillance requirements.
The NRC has concluded, on the basis of the considerations discussed above, that (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner, (2) such activities will be conducted in compliance with the NRC's regulations, and (3) the issuance of the amendments will not be inimical to the common defense and security or to the health and safety of the public.
4.0 STATE CONSULTATION
In accordance with the Commission's regulations, the Virginia State official was notified of the proposed issuance of the amendment. The State official had no comments.
5.0 ENVIRONMENTAL CONSIDERATION
The amendments change a requirement with respect to the installation or use of facility components within the restricted area as defined in 10 CFR Part 20. The NRC staff has determined that the amendments involve no significant increase in the amounts and no significant change in the types of any effluents that may be released offsite, and that there is no significant increase in individual or cumulative occupational radiation exposure. The Commission has previously issued a proposed finding that the amendments involve no significant hazards considerations, and there has been no public comment on such finding (75 FR 27833).
Accordingly, the amendments meet the eligibility criteria for categorical exclusion set forth in 10 CFR 51.22{c)(9). Pursuant to 10 CFR 51.22{b), no environmental impact statement or environmental assessment need be prepared in connection with the issuance of the amendments.
6.0 CONCLUSION
The license amendment request proposes TS changes that will revise the TSs by relocating specific surveillance frequencies to a licensee-controlled program with the implementation of NEI 04-10, "Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies." The changes are consistent with NRC-approved Industry TSTF Standard Technical Specifications change TSTF-425, Revision 3.
The NRC staff finds that with the proposed relocation of surveillance frequencies to an owner-controlled document and administratively controlled in accordance with the TS SFCP, the licensee continues to meet the regulatory requirement of 10 CFR 50.36, and specifically, 10 CFR 50.36(c)(3), surveillance requirements.
Therefore, the NRC staff has concluded, based on the considerations discussed above, that: (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner; (2) such activities will be conducted in compliance with the Commission's regulations; and, (3) the issuance of the amendment will not be inimical to the common defense and security or to the health and safety of the public.
Principal Contributors: Andrew Howe, NRRIDRA Date of Issuance: January 31, 2011
ML103140657 *S E input by memo dated 9-24-2010 OFFICE LPL2-1/PM LPL2-1/LA DRAlAPLAlBC DIRS/ITSB/BC OGC LPL2-1/BC LPL2-1/PM NAME IVSreenivas MO'Brien DHarrison* RElliott DRoth NLO GKulesa !VSreenivas SRohrer for)
~11/10/10 11/15/10 09/24/2010 11/17/10 11/29/10 1128111 1/31/11