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Issuance of Amendment No. 186, Adoption of TSTF-505, Revision 2, Provide Risk-Informed Extended Completion Times - RITSTF Initiative 4B
	ML21082A221
Person / Time
Site:	Nine Mile Point
Issue date:	04/29/2021
From:	Marshall M; Plant Licensing Branch 1
To:	Rhoades D; Exelon Nuclear, Exelon Generation Co
	Marshall M, NRR/DORL/LPL, 415-2871
References
	EPID L-2019-LLA-0234
	Download: ML21082A221 (174)
	v • d • e

April 29, 2021 Mr. David P. Rhoades Senior Vice President Exelon Generation Company, LLC President and Chief Nuclear Officer Exelon Nuclear 4300 Winfield Road Warrenville, IL 60555

SUBJECT:

NINE MILE POINT NUCLEAR STATION, UNIT 2 - ISSUANCE OF AMENDMENT NO. 186 TO ADOPT TECHNICAL SPECIFICATIONS TASK FORCE TRAVELER TSTF-505, REVISION 2, PROVIDE RISK-INFORMED EXTENDED COMPLETION TIMES - RITSTF INITIATIVE 4B (EPID L-2019-LLA-0234)

Dear Mr. Rhoades:

The U.S. Nuclear Regulatory Commission (the Commission) has issued the enclosed Amendment No. 186 to Renewed Facility Operating License No. NPF-69 for the Nine Mile Point Nuclear Station, Unit No. 2 (Nine Mile Point 2). The amendment consists of changes to the technical specifications in response to your application dated October 31, 2019 (Agencywide Documents Access and Management System (ADAMS) Accession No. ML19304B653), as supplemented by letters dated December 12, 2019, August 28, 2020, October 2, 2020 (two letters), October 22, 2020, and January 7, 2021 (ADAMS Accession Nos. ML19346F427, ML20241A044, ML20276A019, ML20276A020, ML20296A195, and ML21007A019, respectively).

The amendment revises Nine Mile Point 2 technical specification requirements to permit the use of risk-informed completion times for actions to be taken when limiting conditions for operation are not met. The proposed changes are based on Technical Specifications Task Force (TSTF)

Traveler TSTF-505, Revision 2, Provide Risk Informed Extended Completion Times - RITSTF Initiative 4b, dated July 2, 2018 (ADAMS Accession No. ML18183A493).

D. Rhoades A copy of the related Safety Evaluation is also enclosed. Notice of Issuance will be included in the Commissions monthly Federal Register notice.

Sincerely,

/RA/

Michael L. Marshall, Jr., Senior Project Manager Plant Licensing Branch I Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket No. 50-410

Enclosures:

1. Amendment No. 186 to NPF-69

2. Safety Evaluation cc: Listserv

NINE MILE POINT NUCLEAR STATION, LLC LONG ISLAND LIGHTING COMPANY EXELON GENERATION COMPANY, LLC DOCKET NO. 50-410 NINE MILE POINT NUCLEAR STATION, UNIT 2 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 186 Renewed License No. NPF-69

1. The U.S. Nuclear Regulatory Commission (the Commission) has found that:

A. The application for amendment by Exelon Generation Company, LLC (Exelon, the licensee) dated October 31, 2019, as supplemented by letters dated December 12, 2019, August 28, 2020, October 2, 2020 (two letters), October 22, 2020, and January 7, 2021, 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.

Enclosure 1

2. Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Renewed Facility Operating License No. NPF-69 is hereby amended to read as follows:

(2) Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A and the Environmental Protection Plan contained in Appendix B, both of which are attached hereto, as revised through Amendment No. 186, are hereby incorporated into this license. Exelon Generation shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

In addition, the license is amended by changes as indicated in the attachment to this license amendment, and new paragraph 2.C.(29) of Renewed Facility Operating License No. NPF-69 will read as follows:

(29) Adoption of Risk Informed Completion Times TSTF-505, Revision 2, Provide Risk-Informed Extension Completion Times -

RITSTF Initiative 4b Exelon is approved to implement TSTF-505, Revision 2, modifying the Technical Specification requirements related to Completion Times (CT) for Required Actions to provide the option to calculate a longer, risk-informed CT (RICT). The methodology for using the new Risk-Informed Completion Time Program is described in NEI 06-09-A, Risk-Informed Technical Specifications Initiative 4b, Risk-Managed Technical Specifications (RMTS) Guidelines, Revision 0, which was approved by the NRC on May 17, 2007.

Exelon will complete the implementation items listed in Attachment 6 of Exelon Letter to the NRC dated October 31, 2019, prior to implementation of the RICT Program. All issues identified in the attachment will be addressed and any associated changes will be made, focused-scope peer reviews will be performed on changes that are PRA upgrades as defined in the PRA standard (ASME/ANS RA-Sa-2009, as endorsed by RG 1.200, Revision 2), and any findings will be resolved and reflected in the PRA of record prior to the implementation of the RICT Program.

3. This license amendment is effective as of the date of its issuance and shall be implemented within 180 days or following completion of the probabilistic risk assessment implementation items specified in Attachment 6 to the application dated October 31, 2019, whichever is later.

FOR THE NUCLEAR REGULATORY COMMISSION Digitally signed by Jennifer Jennifer C. Tobin Date: 2021.04.29 C. Tobin 08:12:56 -04'00' James G. Danna, Chief Plant Licensing Branch I Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the Renewed Facility Operating License and Technical Specifications Date of Issuance: April 29, 2021

ATTACHMENT TO LICENSE AMENDMENT NO. 186 NINE MILE POINT NUCLEAR STATION, UNIT 2 RENEWED FACILITY OPERATING LICENSE NO. NPF-69 DOCKET NO. 50-410 Replace the following pages of the Renewed Facility Operating License with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change.

Remove Page Insert Page 4 4 15 15 16 16 17 17 18 18 19 19 Replace the following pages of Appendix A, Technical Specifications, with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change.

Remove Page Insert Page Remove Page Insert Page 1.3-13 1.3-13 3.3.5.1-5 3.3.5.1-5

-- 1.3-14

-- 1.3-15 3.3.5.1-6 3.3.5.1-6 3.1.7-1 3.1.7-1 3.3.5.1-7 3.3.5.1-7 3.3.1.1-1 3.3.1.1-1 3.3.5.1-8 3.3.5.1-8 3.3.1.1-2 3.3.1.1-2 3.3.5.1-9 3.3.5.1-9 3.3.1.1-3 3.3.1.1-3 3.3.5.1-10 3.3.5.1-10 3.3.1.1-4 3.3.1.1-4 3.3.5.1-11 3.3.5.1-11 3.3.1.1-5 3.3.1.1-5 3.3.5.1-12 3.3.5.1-12 3.3.1.1-6 3.3.1.1-6 3.3.5.1-13 3.3.5.1-13 3.3.1.1-7 3.3.1.1-7 -- 3.3.5.1-14 3.3.1.1-8 3.3.1.1-8 3.3.5.3-1 3.3.5.3-1 3.3.1.1-9 3.3.1.1-9 3.3.5.3-2 3.3.5.3-2 3.3.1.1-10 3.3.1.1-10 3.3.5.3-3 3.3.5.3-3

-- 3.3.1.1-11 3.3.5.3-4 3.3.5.3-4

-- 3.3.1.1-12 -- 3.3.5.3-5 3.3.2.2-1 3.3.2.2-1 3.3.6.1-1 3.3.6.1-1 3.3.4.1-1 3.3.4.1-1 3.3.6.1-2 3.3.6.1-2 3.3.4.1-2 3.3.4.1-2 3.3.6.1-3 3.3.6.1-3 3.3.4.2-1 3.3.4.2-1 3.3.6.1-4 3.3.6.1-4 3.3.4.2-2 3.3.4.2-2 3.3.6.1-5 3.3.6.1-5 3.3.4.2-3 3.3.4.2-3 3.3.6.1-6 3.3.6.1-6

-- 3.3.4.2-4 3.3.6.1-7 3.3.6.1-7 3.3.5.1-3 3.3.5.1-3 3.3.6.1-8 3.3.6.1-8 3.3.5.1-4 3.3.5.1-4 3.3.6.1-9 3.3.6.1-9

Remove Page Insert Page Remove Page Insert Page 3.3.6.1-10 3.3.6.1-10 3.6.1.7-1 3.6.1.7-1

-- 3.3.6.1-11 3.6.2.3-1 3.6.2.3-1 3.3.7.2-1 3.3.7.2-1 3.6.2.4-1 3.6.2.4-1 3.3.7.2-2 3.3.7.2-2 3.7.1-1 3.7.1-1 3.3.7.2-3 3.3.7.2-3 3.7.1-2 3.7.1-2 3.3.8.1-1 3.3.8.1-1 3.7.1-3 3.7.1-3 3.5.1-1 3.5.1-1 3.7.1-4 3.7.1-4 3.5.1-2 3.5.1-2 -- 3.7.1-5 3.5.3-1 3.5.3-1 3.7.5-1 3.7.5-1 3.6.1.2-4 3.6.1.2-4 3.8.1-2 3.8.1-2 3.6.1.3-1 3.6.1.3-1 3.8.1-3 3.8.1-3 3.6.1.3-2 3.6.1.3-2 3.8.1-4 3.8.1-4 3.6.1.3-3 3.6.1.3-3 3.8.4-1 3.8.4-1 3.6.1.3-7 3.6.1.3-7 3.8.7-1 3.8.7-1 3.6.1.3-8 3.6.1.3-8 3.8.8-1 3.8.8-1 3.6.1.3-9 3.6.1.3-9 3.8.8-2 3.8.8-2 3.6.1.6-1 3.6.1.6-1 5.5-13 5.5-13

-- 5.5-14

(1) Maximum Power Level Exelon Generation is authorized to operate the facility at reactor core power levels not in excess of 3988 megawatts thermal (100 percent rated power) in accordance with the conditions specified herein.

(2) Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A and the Environmental Protection Plan contained in Appendix B, both of which are attached hereto, as revised through Amendment No. 186, are hereby incorporated into this license. Exelon Generation shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

(3) Fuel Storage and Handling (Section 9.1.SSER 4)*

a. Fuel assemblies, when stored in their shipping containers, shall be stacked no more than three containers high.

b. When not in the reactor vessel, no more than three fuel assemblies shall be allowed outside of their shipping containers or storage racks in the New Fuel Vault or Spent Fuel Storage Facility.

c. The above three fuel assemblies shall maintain a minimum edge-to-edge spacing of twelve (12) inches from the shipping container array and approved storage rack locations.

d. The New Fuel Storage Vault shall have no more than ten fresh fuel assemblies uncovered at any one time.

(4) Turbine System Maintenance Program (Section 3.5.1.3.10 SER)

The operating licensee shall submit for NRC approval by October 31, 1989, a turbine system maintenance program based on the manufacturers calculations of missile generation probabilities.

(Submitted by NMPC letter dated October 30, 1989 from C.D. Terry and approved by NRC letter dated March 15, 1990 from Robert Martin to Mr.

Lawrence Burkhardt, III).

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

Renewed License No. NPF-69 Amendment 117 through 140, 141, 143, 144, 145, 146, 147, 150, 151, 152, 154, 156, 157, 158, 159, 160, 161, 163, 164, 165, 166, 167, 168, 169, 170, 172, 174, 175, 176, 178, 179, 181, 182, 184, 185, 186

(25) Within 14 days of the license transfers, Exelon Generation shall submit to the NRC the Nuclear Operating Services Agreement reflecting the terms set forth in the application dated August 6, 2013. Section 7.1 of the Nuclear Operating Services Agreement may not be modified in any material respect related to financial arrangements that would adversely impact the ability of the licensee to fund safety-related activities authorized by the license without the prior written consent of the Director of the Office of Nuclear Reactor Regulation.

(26) Within 10 days of the license transfers, Exelon Generation shall submit to the NRC the amended CENG Operating Agreement reflecting the terms set forth in the application dated August 6, 2013. The amended and restated Operating Agreement may not be modified in any material respect concerning decision making authority over safety, security and reliability without the prior written consent of the Director of the Office of Nuclear Reactor Regulation.

(27) At least half the members of the CENG Board of Directors must be U.S. citizens.

(28) The CENG Chief Executive Officer, Chief Nuclear Officer, and Chairman of the CENG Board of Directors must be U.S. citizens. These individuals shall have the responsibility and exclusive authority to ensure and shall ensure that the business and activities of CENG with respect to the facilitys license are at all times conducted in a manner consistent with the public health and safety and common defense and security of the United States.

(29) Adoption of Risk Informed Completion Times TSTF-505, Revision 2, "Provide Risk-Informed Extension Completion Times - RITSTF Initiative 4b" Exelon is approved to implement TSTF-505, Revision 2, modifying the Technical Specification requirements related to Completion Times (CT) for Required Actions to provide the option to calculate a longer, risk-informed CT (RICT). The methodology for using the new Risk-Informed Completion Time Program is described in NEI 06-09-A, "Risk-Informed Technical Specifications Initiative 4b, Risk-Managed Technical Specifications (RMTS) Guidelines," Revision 0, which was approved by the NRC on May 17, 2007.

Exelon will complete the implementation items listed in Attachment 6 of Exelon Letter to the NRC dated October 31, 2019, prior to implementation of the RICT Program. All issues identified in the attachment will be addressed and any associated changes will be made, focused-scope peer reviews will be performed on changes that are PRA upgrades as defined in the PRA standard (ASME/ANS RA-Sa -2009, as endorsed by RG 1.200, Revision 2), and any findings will be resolved and reflected in the PRA of record prior to the implementation of the RICT Program.

Renewed License No. NPF-69 Amendment 140, 144, 183, 186

(30) Exelon is approved to implement 10 CFR 50.69 using the processes for categorization of Risk-Informed Safety Class (RISC)-1, RISC-2, RISC-3, and RISC-4 Structures, Systems, and Components (SSCs) using: Probabilistic Risk Assessment (PRA) models to evaluate risk associated with internal events, including internal flooding, and internal fire; the shutdown safety assessment process to assess shutdown risk; the Arkansas Nuclear One, Unit 2 (ANO-2) passive categorization method to assess passive component risk for Class 2 and Class 3 and non-Class SSCs and their associated supports; the results of the non-PRA evaluations that are based on the IPEEE Screening Assessment for External Hazards updated using the external hazard screening significance process identified in ASME/ANS PRA Standard RA-Sa-2009 for other external hazards except seismic; and the alternative seismic approach described in Exelon's submittal letter dated December 26, 2019, and all its subsequent associated supplements as specified in License Amendment No. 183 dated January 29, 2021.

Exelon will complete the items listed in Attachment 7 of Exelon letter to NRC dated December 26, 2019, prior to implementation of 10 CFR 50.69. All issues identified in the attachment will be addressed and any associated changes will be made, focused-scope peer reviews will be performed on changes that are PRA upgrades as defined in the PRA standard (ASME/ANS RA-Sa-2009, as endorsed by RG 1.200, Revision 2), and any findings will be resolved and reflected in the PRA of record prior to implementation of the 10 CFR 50.69 categorization process.

Prior NRC approval, under 10 CFR 50.90, is required for a change to the categorization process specified above (e.g., change from a seismic margins approach to a seismic probabilistic risk assessment approach).

D. The facility requires exemptions from certain requirements of 10 CFR Part 50 and 10 CFR Part 70.

i) An exemption from the critically alarm requirements of 10 CFR Part 70.24 was granted in the Special Nuclear Materials License No. SNM-1895 dated November 27, 1985. This exemption is described in Section 9.1 of Supplement 4 to the SER. This previously granted exemption is continued in this operating license.

ii) Exemptions to certain requirements of Appendix J to 10 CFR Part 50 are described in Supplements 3, 4, and 5 to the SER. These include (a) (this item left intentionally blank); (b) an exemption from the requirement of Option B of Appendix J, exempting main steam isolation valve measured leakage from the combined leakage rate limit of 0.6 La. (Section 6.2.6 of SSER 5)*; (c) an exemption from Option B of Appendix J, exempting the

The parenthetical notation following the discussion of each exemption denotes the section of the Safety Evaluation Report (SER) and/or its supplements wherein the safety evaluation of the exemption is discussed.

Renewed License No. NPF-69 Amendment 140, 144, 183, 186

hydraulic control system for the reactor recirculation flow control valves from Type A and Type C leak testing (Section 6.2.6 of SSER 3);

(d) an exemption from Option B of Appendix J, exempting Type C testing on traversing incore probe system shear valves. (Section 6.2.6 SSER 4) iii) An exemption to Appendix A to 10 CFR Part 50 exempting the Control Rod Drive (CRD) hydraulic lines to the reactor recirculation pump seal purge equipment from General Design Criterion (GDC) 55. The CRD hydraulic lines to the reactor recirculation pump seal purge equipment use two simple check valves for the isolation outside containment (one side). (Section 6.2.4, SSER 3) iv) A schedular exemption to GDC 2, Appendix A to 10 CFR Part 50, until the first refueling outage, to demonstrate the adequacy of the downcomer design under the plant faulted condition. This exemption permits additional analysis and/or modifications, as necessary, to be completed by the end of the first refueling outage. (Section 6.2.1.7.4, SSER 3) v) A schedular exemption to GDC 50, Appendix A to 10 CFR Part 50 to allow the operating licensee until start-up following the "mini-outage, which is to occur within 12 months of commencing power operation (entering Operational Condition 1), to install redundant fuses in circuits that use transformers for redundant penetration protection in accordance with their letter of August 29, 1986 (NMP2L 0860). (Section 8.4.2, SSER 5) vi) A schedular exemption to 10 CFR 50.55a(h) for the Neutron Monitoring System until completion of the first refueling outage to allow the operating licensee to provide qualified isolation devices for Class 1 E/non-1E interfaces described in their letters of June 23, 1987 (NMP2L 1057) and June 25, 1987 (NMP2L 1058). (Section 7.2.2.10, SSER 6).

For the schedular exemptions in iv), v), and vi), above, the operating licensee, in accordance with its letter of October 31, 1986, shall certify that all systems, components, and modifications have been completed to meet the requirements of the regulations for which the exemptions have been granted and shall provide a summary description of actions taken to ensure that the regulations have been met. This certification and summary shall be provided 10 days prior to the expiration of each exemption period as described above.

The exemptions set forth in this Section 2.D are authorized by law, will not present an undue risk to public health and safety, and are consistent with the common defense and security. These exemptions are hereby granted. The special circumstances regarding each exemption are identified in the referenced section of the Safety Evaluation Report and the supplements thereto. The exemptions in ii) through vi) are granted pursuant to 10 CFR 50.12.

Renewed License No. NPF-69 Amendment 140, 144, 186

With these exemptions, the facility will operate to the extent authorized herein, in conformity with the application, as amended, the provisions of the Act, and the rules and regulations of the Commission.

E. Exelon Generation shall fully implement and maintain in effect all provisions of the Commission-approved physical security, training and qualification, and safeguards contingency plans, including amendments made pursuant to provisions of the Miscellaneous Amendments and Search Requirements revisions to 10 CFR 73.55 (51 FR 27817 and 27822) and to the authority of 10 CFR 50.90 and 10 CFR 50.54(p). The combined set of plans, which contain Safeguards Information protected under 10 CFR 73.21 is entitled Nine Mile Point Nuclear Station, LLC Physical Security, Safeguards Contingency, and Security Training and Qualification Plan, Revision 1, and was submitted by letter dated April 26, 2006. Changes made in accordance with 10 CFR 73.55 shall be implemented in accordance with the schedule set forth therein.

Exelon Generation shall fully implement and maintain in effect all provisions of the Commission-approved cyber security plan (CSP), including changes made pursuant to the authority of 10 CFR 50.90 and 10 CFR 50.54(p).

The Nine Mile Point Nuclear Stations CSP was approved by License Amendment No. 137 and modified by License Amendment No. 149. The licensee has obtained Commission authorization to use Section 161A preemption authority under 42 U.S.C. 2201a for weapons at its facility.

F. Exelon Generation shall implement and maintain in effect all provisions of the approved fire protection program as described in the Final Safety Analysis Report for the facility through Amendment No. 27 and as described in submittals dated March 25, May 7 and 9, June 10 and 25. July 11 and 16, August 19 and 22, September 5, 12, and 23, October 10, 21, and 22, and December 9, 1986, and April 10 and May 20, 1987, and as approved in the SER dated February 1985 (and Supplements 1 through 6) subject to the following provision:

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

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

H. This license is effective as of the date of issuance and shall expire at midnight on October 31, 2046.

I. The UFSAR supplement, as revised, submitted pursuant to 10 CFR 54.21(d), shall be included in the next scheduled update to the USAR required by 10 CFR 50.71(e)(4) following the issuance of this renewed operating license. Until that update is complete, the licensee may make changes to the programs and activities described in the supplement without prior Commission approval, provided that the Renewed License No. NPF-69 Amendment 140, 144, 149, 154, 186

licensee evaluates such changes pursuant to the criteria set forth in 10 CFR 50.59 and otherwise complies with the requirements in that section.

J. The UFSAR supplement, as revised, describes certain future activities to be completed prior to the period of extended operation. the licensee shall complete these activities in accordance with Appendix A of NUREG-1900, Safety Evaluation Report Related to the License Renewal of Nine Mile Point Nuclear Station, Units 1 and 2, dated September 2006, and shall notify the NRC in writing when implementation of these activities is complete and can be verified by NRC inspection.

K. For the renewed license term, all capsules in the reactor vessel that are removed and tested must meet the test procedures and reporting requirements of the most recent NRC-approved version of the Boiling Water Reactor Vessels and Internals Project (BWRVIP) Integrated Surveillance Program (ISP) appropriate for the configuration of the specimens in the capsule. All capsules placed in storage must be maintained for future insertion. Any changes to storage requirements must be approved by the NRC, as required by 10 CFR Part 50, Appendix H.

FOR THE NUCLEAR REGULATORY COMMISSION Original Signed by J. E. Dyer, Director Office of Nuclear Reactor Regulation

Enclosures:

1. Appendix A - Technical Specifications (NUREG-1253)

2. Appendix B - Environmental Protection Plan Date of Issuance: October 31, 2006 Renewed License No. NPF-69 Amendment 140, 144, 186

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-7 (continued) is met after Condition B is entered, Condition B is exited and operation may continue in accordance with Condition A, provided the Completion Time for Required Action A.2 has not expired.

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

(continued)

NMP2 1.3-13 Amendment 91, 186

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-8 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One A.1 Restore subsystem 7 days subsystem to OPERABLE inoperable. status. OR In accordance with the Risk Informed Completion Time Program B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and associated AND Completion Time not B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months met.

When a subsystem is declared inoperable, Condition A is entered. The 7 day Completion Time may be applied as discussed in Example 1.3-2.

However, the licensee may elect to apply the Risk Informed Completion Time Program which permits calculation of a Risk Informed Completion Time (RICT) that may be used to complete the Required Action beyond the 7 day Completion Time. The RICT cannot exceed 30 days. After the 7 day Completion Time has expired, the subsystem must be restored to OPERABLE status within the RICT or Condition B must also be entered.

The Risk Informed Completion Time Program requires recalculation of the RICT to reflect changing plant conditions. For planned changes, the revised RICT must be determined prior to implementation of the change in configuration. For emergent conditions, the revised RICT must be determined within the time limits of the Required Action Completion Time (i.e., not the RICT) or 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after the plant configuration change, whichever is less.

(continued)

NMP2 1.3-14 Amendment 186

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-8 (continued)

If the 7 day Completion Time clock of Condition A has expired and subsequent changes in plant condition result in exiting the applicability of the Risk Informed Completion Time Program without restoring the inoperable subsystem to OPERABLE status, Condition B is also entered and the Completion Time clocks for Required Actions B.1 and B.2 start.

If the RICT expires or is recalculated to be less than the elapsed time since the Condition was entered and the inoperable subsystem has not been restored to OPERABLE status, Condition B is also entered and the Completion Time clocks for Required Actions B.1 and B.2 start. If the inoperable subsystems are restored to OPERABLE status after Condition B is entered, Condition A is exited, and therefore, the Required Actions of Condition B may be terminated.

NMP2 1.3-15 Amendment 186

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

APPLICABILITY: MODES 1, 2, and 3.

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

OR In accordance with the Risk Informed Completion Time Program B. Two SLC subsystems B.1 Restore one SLC 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months inoperable. subsystem to OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AND C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.1 Verify available volume of sodium In accordance with pentaborate solution is within the limits the Surveillance of Figure 3.1.7-1. Frequency Control Program (continued)

NMP2 3.1.7-1 Amendment 91, 125, 152, 186

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

APPLICABILITY: According to Table 3.3.1.1-1.

ACTIONS

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

1. Separate Condition entry is allowed for each channel.

2. When Functions 2.b and 2.c channels are inoperable due to the calculated power exceeding the APRM output by more than 2% RTP while operating at 23% RTP, entry into associated Conditions and Required Actions may be delayed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

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

OR

NOTE---------

Not applicable when when trip capability is not maintained.

In accordance with the Risk Informed Completion Time Program (continued)

NMP2 3.3.1.1-1 Amendment 9/1/, 92, 175, 186

RPS Instrumentation 3.3.1.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) OR A.2 Place associated trip 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months system in trip.

OR

NOTE---------

Not applicable when when trip capability is not maintained.

In accordance with the Risk Informed Completion Time Program B. --------------NOTE--------------

Not applicable for Functions 2.a, 2.b, 2.c, 2.d, and 2.e.

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

required channels OR inoperable in both trip systems. ---------NOTE---------

Not applicable when when trip capability is not maintained.

In accordance with the Risk Informed Completion Time Program (continued)

NMP2 3.3.1.1-2 Amendment 9/1/, 92, 175, 186

RPS Instrumentation 3.3.1.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) OR B.2 Place one trip system 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months in trip.

OR

NOTE---------

Not applicable when trip capability is not maintained.

In accordance with the Risk Informed Completion Time Program C. One or more Functions C.1 Restore RPS trip 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with RPS trip capability.

capability not maintained.

D. Required Action and D.1 Enter the Condition Immediately associated Completion referenced in Time of Condition A, Table 3.3.1.1-1 for the B, or C not met. channel.

E. As required by E.1 Reduce THERMAL POWER to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Required Action D.1 < 26% RTP.

and referenced in Table 3.3.1.1-1.

F. As required by F.1 Initiate action to implement the Immediately Required Action D.1 Manual BSP Regions defined and referenced in in the COLR.

Table 3.3.1.1-1.

(continued)

NMP2 3.3.1.1-3 Amendment 9/1/, 92, 175, 186

RPS Instrumentation 3.3.1.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. (continued) AND F.2 Implement the Automated BSP 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Scram Region using the modified APRM Simulated Thermal Power-High scram setpoints defined in the COLR.

AND F.3 Initiate action in accordance Immediately with Specification 5.6.8.

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

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

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

J. Required Action and J.1 Initiate action to implement Immediately associated Completion the Manual BSP Regions Time of Condition F not defined in the COLR.

met.

AND J.2 Reduce operation to below 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months the BSP Boundary defined in the COLR.

(continued)

NMP2 3.3.1.1-4 Amendment 91, 92, 140, 151, 186

RPS Instrumentation 3.3.1.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME J. (continued) AND J.3 --------------NOTE-------------- 120 days LCO 3.0.4 is not applicable Restore required channel to OPERABLE.

K. Required Action and K.1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion Time to less than 18% RTP.

of Condition J not met.

NMP2 3.3.1.1-5 Amendment 91, 92, 151, 186

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS

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

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

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

SURVEILLANCE FREQUENCY SR 3.3.1.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.2 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.3 ----------------------------- NOTE------------------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER 23% RTP.

Verify the calculated power does not exceed the In accordance with average power range monitor (APRM) channels by the Surveillance greater than 2% RTP while operating at Frequency Control 23% RTP. Program SR 3.3.1.1.4 ----------------------------- NOTE------------------------------

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

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program (continued)

NMP2 3.3.1.1-6 Amendment 91, 92, 123, 140, 151,152, 175, 186

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

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

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

Verify the IRM and APRM channels overlap. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.7 Calibrate the local power range monitors. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.8 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.9 Calibrate the trip units. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.10 ---------------------------- NOTES-----------------------------

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

2. For Function 2.e, the CHANNEL FUNCTIONAL TEST only requires toggling the appropriate outputs of In accordance with the APRM.

the Surveillance Frequency Control Perform CHANNEL FUNCTIONAL TEST.

Program (continued)

NMP2 3.3.1.1-7 Amendment 91, 92, 151, 152, 186

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.11 Perform CHANNEL CALIBRATION In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.12 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.13 ---------------------------- NOTES-----------------------------

1. Neutron detectors are excluded.

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

3. For Function 2.e, the CHANNEL CALIBRATION only requires a verification of OPRM-Upscale setpoints in the APRM by the review of the "Show Parameters" display.

Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.14 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.15 Verify Turbine Stop Valve - Closure, and In accordance with Turbine Control Valve Fast Closure, Trip the Surveillance Oil Pressure - Low Functions are not Frequency Control bypassed when THERMAL POWER is 26% RTP. Program (continued)

NMP2 3.3.1.1-8 Amendment 91, 92, 152, 186

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.16 Deleted SR 3.3.1.1.17 ---------------------------- NOTES----------------------------

1. Function 2.f digital electronics are excluded.

2. For Functions 3 and 4, the sensor response time may be assumed to be the design sensor response time.

3. Deleted.

4. For Function 9, the RPS RESPONSE TIME is measured from start of turbine control valve fast closure.

Verify the RPS RESPONSE TIME is within limits.

In accordance with the Surveillance Frequency Control Program NMP2 3.3.1.1-9 Amendment 91, 92, 152, 186

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

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

1. Intermediate Range Monitors

a. Neutron Flux Upscale 2 3 H SR 3.3.1.1.1 122/125 SR 3.3.1.1.4 divisions SR 3.3.1.1.5 of full SR 3.3.1.1.6 scale SR 3.3.1.1.13 SR 3.3.1.1.14 5(a) 3 I SR 3.3.1.1.1 122/125 SR 3.3.1.1.4 divisions SR 3.3.1.1.13 of full SR 3.3.1.1.14 scale

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

2. Average Power Range Monitors

a. Neutron Flux - Upscale, 2 3 per logic H SR 3.3.1.1.2 20% RTP Setdown channel SR 3.3.1.1.6 SR 3.3.1.1.7 SR 3.3.1.1.10 SR 3.3.1.1.13

b. Flow Biased Simulated 1 3 per logic G SR 3.3.1.1.2 0.61W +

Thermal Power - Upscale channel SR 3.3.1.1.3 63.4% RTP SR 3.3.1.1.7 and 115.5%

SR 3.3.1.1.10 RTP(b)(e)

SR 3.3.1.1.13(c)(d)

c. Fixed Neutron 1 3 per logic G SR 3.3.1.1.2 120% RTP Flux - Upscale channel SR 3.3.1.1.3 SR 3.3.1.1.7 SR 3.3.1.1.10 SR 3.3.1.1.13

d. Inop 1,2 3 per logic H SR 3.3.1.1.7 NA channel SR 3.3.1.1.10 (continued)

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

(b) Allowable Value is .50(W - 5%) + 53.5% RTP when reset for single loop operation per LCO 3.4.1, "Recirculation Loops Operating."

(c) If the As-Found channel setpoint is outside its predefined As-Found tolerances, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service.

(d) The instrument channel setpoint shall be reset to a value within the As-Left tolerance around the nominal trip setpoint at the completion of the surveillance; otherwise, the channel shall be declared inoperable. Setpoints more conservative than the nominal trip setpoint are acceptable provided that the As-Found and As-Left tolerances apply to the actual setpoint implemented in the surveillance procedures to confirm channel performance. The nominal trip setpoint and the methodologies used to determine the As-Found and the As-Left tolerances are specified in the Bases associated with the specified function.

(e) With OPRM Upscale (function 2.e) inoperable, reset the APRM-STP High scram setpoint to the values defined by the COLR to Implement the automated BSP Scram Region in accordance with Action F.2 of this Specification.

NMP2 3.3.1.1-10 Amendment 91, 92, 123, 140, 151, 186

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

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

2. Average Power Range Monitors (continued)

e. OPRM-Upscale 18% RTP(f) 3 per logic F SR 3.3.1.1.2 NA channel SR 3.3.1.1.7 SR 3.3.1.1.10 SR 3.3.1.1.13

f. 2-Out-Of-4 Voter 1,2 2 H SR 3.3.1.1.2 NA SR 3.3.1.1.10 SR 3.3.1.1.14 SR 3.3.1.1.17

3. Reactor Vessel Steam Dome 1,2 2 H SR 3.3.1.1.1 1072 psig Pressure - High SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.13 SR 3.3.1.1.14 SR 3.3.1.1.17

4. Reactor Vessel Water 1,2 2 H SR 3.3.1.1.1 157.8 inches Level - Low, Level 3 SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.13 SR 3.3.1.1.14 SR 3.3.1.1.17

5. Main Steam Isolation 1 8 G SR 3.3.1.1.8 12% closed Valve - Closure SR 3.3.1.1.13 SR 3.3.1.1.14 SR 3.3.1.1.17

6. Drywell Pressure - High 1,2 2 H SR 3.3.1.1.1 1.88 psig SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.13 SR 3.3.1.1.14 (continued)

(f) Following DSS-CD implementation, DSS-CD is not required to be armed while in the DSS-CD Armed Region during the first reactor startup and during the first controlled shutdown that passes completely through the DSS-CD Armed Region. However, DSS-CD is considered OPERABLE and shall be maintained OPERABLE and capable of automatically arming for operation at recirculation drive flow rates above the DSS-CD Armed Region NMP2 3.3.1.1-11 Amendment 91, 92, 123, 140, 151, 186 Corrected Letter Dated 11/23/15

RPS Instrumentation 3.3.1.1 APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCE OTHER CHANNELS D FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

7. Scram Discharge Volume Water Level - High

a. Transmitter/Trip Unit 1,2 2 H SR 3.3.1.1.1 49.5 SR 3.3.1.1.8 inches SR 3.3.1.1.9 SR 3.3.1.1.11 SR 3.3.1.1.14 5(a) 2 I SR 3.3.1.1.1 49.5 SR 3.3.1.1.8 Inches SR 3.3.1.1.9 SR 3.3.1.1.11 SR 3.3.1.1.14

b. Float Switch 1,2 2 H SR 3.3.1.1.8 49.5 SR 3.3.1.1.13 Inches SR 3.3.1.1.14 5(a) 2 I SR 3.3.1.1.8 49.5 SR 3.3.1.1.13 Inches SR 3.3.1.1.14

8. Turbine Stop 26% RTP 4 E SR 3.3.1.1.8 7% closed Valve - Closure SR 3.3.1.1.13 SR 3.3.1.1.14 SR 3.3.1.1.15 SR 3.3.1.1.17

9. Turbine Control Valve 26% RTP 2 E SR 3.3.1.1.8 465 psig Fast Closure, Trip Oil SR 3.3.1.1.13 Pressure - Low SR 3.3.1.1.14 SR 3.3.1.1.15 SR 3.3.1.1.17

10. Reactor Mode 1,2 2 H SR 3.3.1.1.12 NA Switch - Shutdown Position SR 3.3.1.1.14 5(a) 2 I SR 3.3.1.1.12 NA SR 3.3.1.1.14

11. Manual Scram 1,2 4 H SR 3.3.1.1.4 NA SR 3.3.1.1.14 5(a) 4 I SR 3.3.1.1.4 NA SR 3.3.1.1.14 (a) With any control rod withdrawn from a core cell containing one or more fuel assemblies.

NMP2 3.3.1.1-12 Amendment 91, 92, 123, 140, 151, 186

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

APPLICABILITY: THERMAL POWER 23% RTP.

ACTIONS

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

Separate Condition entry is allowed for each channel.

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

water level trip OR channel inoperable.

NOTE---------

Not applicable when trip capability is not maintained.

In accordance with the Risk Informed Completion Time Program B. Two or more feedwater B.1 Restore feedwater 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months system and main system and main turbine high water turbine high water level trip channels level trip inoperable. capability.

(continued)

NMP2 3.3.2.2-1 Amendment 91, 140, 186

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

1. Turbine Stop Valve (TSV) - Closure; and

2. Turbine Control Valve (TCV) Fast Closure, Trip Oil Pressure - Low.

OR

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

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

APPLICABILITY: THERMAL POWER 26% RTP with any recirculation pump in fast speed.

ACTIONS

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

Separate Condition entry is allowed for each channel.

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

OR OR

NOTE---------

Not applicable when trip capability is not maintained.

In accordance with the Risk Informed Completion Time Program (continued)

NMP2 3.3.4.1-1 Amendment 91, 140, 186

EOC-RPT Instrumentation 3.3.4.1 ACTIONS (continued)

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

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

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

OR

NOTE--------

Not applicable when trip capability is not maintained.

In accordance with the Risk Informed Completion Time Program B. One or more Functions B.1 Restore EOC-RPT trip 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months with EOC-RPT trip capability.

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

made applicable.

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

OR C.2 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months to < 26% RTP.

NMP2 3.3.4.1-2 Amendment 91, 140, 186

ATWS-RPT Instrumentation 3.3.4.2 3.3 INSTRUMENTATION 3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) Instrumentation LCO 3.3.4.2 Two channels per trip system for each ATWS - RPT instrumentation Function listed below shall be OPERABLE:

a. Reactor Vessel Water Level - Low Low, Level 2; and

b. Reactor Vessel Steam Dome Pressure - High.

APPLICABILITY: MODE 1.

ACTIONS

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Restore channel to 14 days inoperable. OPERABLE status.

OR

NOTE---------

Not applicable when trip capability is not maintained.

In accordance with the Risk Informed Completion Time Program (continued)

NMP2 3.3.4.2-1 Amendment 91, 186

ATWS-RPT Instrumentation 3.3.4.2 ACTIONS (continued)

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

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

Place channel in 14 days trip.

OR

NOTE---------

Not applicable when trip capability is not maintained.

In accordance with the Risk Informed Completion Time Program B. One Function with B.1 Restore ATWS-RPT trip 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months ATWS-RPT trip capability.

capability not maintained.

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

maintained.

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

OR D.2 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months NMP2 3.3.4.2-2 Amendment 91, 152, 186

ATWS-RPT Instrumentation 3.3.4.2 SURVEILLANCE REQUIREMENTS

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

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

SURVEILLANCE FREQUENCY SR 3.3.4.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.4.2.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.4.2.3 Calibrate the analog trip modules. In accordance with the Surveillance Frequency Control Program SR 3.3.4.2.4 Verify, for the Reactor Vessel Steam Dome In accordance Pressure - High Function, the low with the frequency motor generator trip is not Surveillance bypassed for > 29 seconds when THERMAL Frequency POWER is > 5% RTP. Control Program SR 3.3.4.2.5 Perform CHANNEL CALIBRATION. The In accordance Allowable Values shall be: with the Surveillance

a. Reactor Vessel Water Level - Low Low, Frequency Level 2: 101.8 inches; and Control Program

b. Reactor Vessel Steam Dome Pressure - High: 1080 psig.

(continued)

NMP2 3.3.4.2-3 Amendment 91, 152, 186

ATWS-RPT Instrumentation 3.3.4.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.4.2.6 Perform LOGIC SYSTEM FUNCTIONAL TEST, In accordance including breaker actuation. with the Surveillance Frequency Control Program NMP2 3.3.4.2-4 Amendment 91, 152, 186

ECCS Instrumentation 3.3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.3.1 Place channel in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for trip. Functions 1.a, 1.d, 2.a, and 2.d AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for Functions other than Functions 1.a, 1.d, 2.a, and 2.d OR

NOTE---------

Not applicable when trip capability is not maintained.

In accordance with the Risk Informed Completion Time Program OR B.3.2 ------------NOTE------------

Only applicable for Functions 1.a, 1.d, 2.a, and 2.d.

Isolate the affected 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months flow path(s).

(continued)

NMP2 3.3.5.1-3 Amendment 91, 186

ECCS Instrumentation 3.3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. As required by C.1 ------------NOTE------------

Required Action A.1 Only applicable and referenced in for Functions Table 3.3.5.1-1. 1.e, 1.f, 1.g, 1.h, 1.i, 1.j, 2.e, 2.f, 2.g, 2.h, and 2.i.

Declare supported 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from feature(s) inoperable discovery of when its redundant loss of feature ECCS initiation initiation capability capability for is inoperable. feature(s) in both divisions AND C.2 Restore channel to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE status.

OR

NOTE---------

Not applicable when trip capability is not maintained.

In accordance with the Risk Informed Completion Time Program D. As required by D.1 ------------NOTE-------------

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

(continued)

NMP2 3.3.5.1-4 Amendment 91, 168, 186

ECCS Instrumentation 3.3.5.1 ACTIONS (continued)

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

OR OR

NOTE---------

Not applicable when trip capability is not maintained.

In accordance with the Risk Informed Completion Time Program D.2.2 Align the HPCS pump 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months suction to the suppression pool.

E. As required by E.1 ------------NOTE------------

Required Action A.1 Only applicable and referenced in for Functions Table 3.3.5.1-1. 1.k, 1.l, and 2.j.

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

NMP2 3.3.5.1-5 Amendment 91, 168, 186

ECCS Instrumentation 3.3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. (continued) E.2 Restore channel to 7 days OPERABLE status.

OR

NOTE---------

Not applicable when trip capability is not maintained.

In accordance with the Risk Informed Completion Time Program F. As required by F.1 Declare Automatic 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Required Action A.1 Depressurization discovery of and referenced in System (ADS) valves loss of ADS Table 3.3.5.1-1. inoperable. initiation capability in both trip systems AND F.2 Place channel in 96 hours0.00111 days 0.0267 hours 1.587302e-4 weeks 3.6528e-5 months or in trip. accordance with the Risk Informed Completion Time Program from discovery of inoperable channel concurrent with HPCS or reactor core isolation cooling (RCIC) inoperable AND (continued)

NMP2 3.3.5.1-6 Amendment 91, 186

ECCS Instrumentation 3.3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. (continued) 8 days OR

NOTE---------

Not applicable when trip capability is not maintained.

In accordance with the Risk Informed Completion Time Program G. As required by G.1 ------------NOTE------------

Required Action A.1 Only applicable for and referenced in Functions 4.b, 4.d, Table 3.3.5.1-1. 4.e, 5.b, and 5.d.

Declare ADS valves 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from inoperable. discovery of loss of ADS initiation capability in both trip systems AND G.2 Restore channel to 96 hours0.00111 days 0.0267 hours 1.587302e-4 weeks 3.6528e-5 months or in OPERABLE status. accordance with the Risk Informed Completion Time Program from discovery of inoperable channel concurrent with HPCS or RCIC inoperable AND (continued)

NMP2 3.3.5.1-7 Amendment 91, 186

ECCS Instrumentation 3.3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME G. (continued) 8 days OR

NOTE---------

Not applicable when trip capability is not maintained.

In accordance with the Risk Informed Completion Time Program H. Required Action and H.1 Declare associated Immediately associated Completion supported feature(s)

Time of Condition B, inoperable.

C, D, E, F, or G not met.

NMP2 3.3.5.1-8 Amendment 91, 186

ECCS Instrumentation 3.3.5.1 SURVEILLANCE REQUIREMENTS

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

1. Refer to Table 3.3.5.1-1 to determine which SRs apply for each ECCS Function.

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

SURVEILLANCE FREQUENCY SR 3.3.5.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.5.1.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program*

SR 3.3.5.1.3 Calibrate the trip unit. In accordance with the Surveillance Frequency Control Program SR 3.3.5.1.4 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.5.1.5 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program*

SR 3.3.5.1.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program*

Following return to OPERABILITY of the HPCS System, the past due Surveillances will be completed by January 11, 2019.

NMP2 3.3.5.1-9 Amendment 91, 152,168, 174, 186

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

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

1. Low Pressure Coolant Injection-A (LPCI) and Low Pressure Core Spray (LPCS)

Subsystems

a. Reactor Vessel Water 1,2,3 2 B SR 3.3.5.1.1 157.8 Level - Low, Level 3 SR 3.3.5.1.2 inches SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

b. Reactor Vessel Water 1,2,3 2(a) B SR 3.3.5.1.1 10.8 inches Level - Low Low Low, SR 3.3.5.1.2 Level 1 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

c. Drywell Pressure - High 1,2,3 2(a) B SR 3.3.5.1.1 1.88 psig SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1 6

d. Drywell Pressure - High 1,2,3 2 B SR 3.3.5.1.1 1.88 psig (Boundary Isolation) SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

e. LPCS Pump Start - Time 1,2,3 1 C SR 3.3.5.1.2 12 seconds Delay Relay (Normal SR 3.3.5.1.5 Power) SR 3.3.5.1.6

f. LPCI Pump A 1,2,3 1 C SR 3.3.5.1.2 7 seconds Start - Time Delay SR 3.3.5.1.5 Relay (Normal Power) SR 3.3.5.1.6

g. LPCS Pump Start - Time 1,2,3 1 C SR 3.3.5.1.2 6.75 Delay Relay (Emergency SR 3.3.5.1.5 seconds Power) SR 3.3.5.1.6

h. LPCI Pump A 1,2,3 1 C SR 3.3.5.1.2 2 seconds Start - Time Delay SR 3.3.5.1.5 Relay (Emergency SR 3.3.5.1.6 Power)

i. LPCS Differential 1,2,3 1 C SR 3.3.5.1.1 40 psid and Pressure - Low SR 3.3.5.1.2 98 psid (Injection Permissive) SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 (continued)

(a) Also required to initiate the associated diesel generator (DG).

NMP2 3.3.5.1-10 Amendment 91, 168, 186

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

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

1. LPCI A and LPCS Subsystems (continued)

j. LPCI A Differential 1,2,3 1 C SR 3.3.5.1.1 70 psid and Pressure - Low SR 3.3.5.1.2 150 psid (Injection Permissive) SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

k. LPCS Pump Discharge 1,2,3 1 E SR 3.3.5.1.1 1000 gpm Flow Low (Bypass) SR 3.3.5.1.2 and SR 3.3.5.1.3 1440 gpm SR 3.3.5.1.5 SR 3.3.5.1.6

l. LPCI Pump A Discharge 1,2,3 1 E SR 3.3.5.1.1 770 gpm and Flow - Low (Bypass) SR 3.3.5.1.2 930 gpm SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

m. Manual Initiation 1,2,3 2 C SR 3.3.5.1.6 NA

2. LPCI B and LPCI C Subsystems

a. Reactor Vessel Water 1,2,3 2 B SR 3.3.5.1.1 157.8 Level - Low, Level 3 SR 3.3.5.1.2 inches SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

b. Reactor Vessel Water 1,2,3 2(a) B SR 3.3.5.1.1 10.8 inches Level - Low Low Low, SR 3.3.5.1.2 Level 1 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

c. Drywell Pressure - High 1,2,3 2(a) B SR 3.3.5.1.1 1.88 psig SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 (continued)

(a) Also required to initiate the associated DG NMP2 3.3.5.1-11 Amendment 91, 168, 186

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

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

2. LPCI B and LPCI C Subsystems (continued)

d. Drywell Pressure - High 1,2,3 2 B SR 3.3.5.1.1 1.88 psig (Boundary Isolation) SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

e. LPCI Pump B 1,2,3 1 C SR 3.3.5.1.2 7 seconds Start - Time Delay SR 3.3.5.1.5 Relay (Normal Power) SR 3.3.5.1.6

f. LPCI Pump C 1,2,3 1 C SR 3.3.5.1.2 12 seconds Start Time Delay SR 3.3.5.1.5 Relay (Normal Power) SR 3.3.5.1.6

g. LPCI Pump B 1,2,3 1 C SR 3.3.5.1.2 2 second Start - Time Delay SR 3.3.5.1.5 Relay (Emergency SR 3.3.5.1.6 Power)

h. LPCI Pump C 1,2,3 1 C SR 3.3.5.1.2 7 second Start - Time Delay SR 3.3.5.1.5 Relay (Emergency SR 3.3.5.1.6 Power)

i. LPCI B and C 1,2,3 1 per valve C SR 3.3.5.1.1 70 psid and Differential SR 3.3.5.1.2 150 psid Pressure - Low SR 3.3.5.1.3 (Injection Permissive) SR 3.3.5.1.5 SR 3.3.5.1.6

j. LPCI Pump B and LPCI 1,2,3 1 per pump E SR 3.3.5.1.1 770 gpm Pump C Discharge SR 3.3.5.1.2 and Flow - Low (Bypass) SR 3.3.5.1.3 930 gpm SR 3.3.5.1.5 SR 3.3.5.1.6

k. Manual Initiation 1,2,3 2 C SR 3.3.5.1.6 NA (continued)

NMP2 3.3.5.1-12 Amendment 91, 168, 186

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

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

3. High Pressure Core Spray (HPCS) System

a. Reactor Vessel Water 1,2,3 4(a) B SR 3.3.5.1.1 101.8 Level - Low Low, SR 3.3.5.1.2 Inches Level 2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

b. Drywell Pressure - High (b) 1,2,3 4(a) B SR 3.3.5.1.1 1.88 psig SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

c. Reactor Vessel Water 1,2,3 4 C SR 3.3.5.1.1 209.3 Level - High, Level 8 SR 3.3.5.1.2 inches SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

d. Pump Suction 1,2,3 2 D SR 3.3.5.1.1 94.5 inches Pressure - Low SR 3.3.5.1.2 H2O SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

e. Pump Suction 1,2,3 1 D SR 3.3.5.1.2 5.5 seconds Pressure - Timer SR 3.3.5.1.5 SR 3.3.5.1.6

f. Suppression Pool Water 1,2,3 2 D SR 3.3.5.1.1 200.7 ft Level - High SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

g. HPCS Pump Discharge 1,2,3 1 E SR 3.3.5.1.1 220 psig Pressure - High SR 3.3.5.1.2 (Bypass) SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

h. HPCS System Flow 1,2,3 1 E SR 3.3.5.1.1 580 gpm and Rate - Low (Bypass) SR 3.3.5.1.2 720 gpm SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

i. Manual Initiation (b) 1,2,3 2 C SR 3.3.5.1.6 NA (continued)

(a) Also required to initiate the associated DG.

(b) The injection functions of Drywell Pressure-High and Manual Initiation are not required to be OPERABLE with reactor steam dome pressure less than 600 psig.

NMP2 3.3.5.1-13 Amendment 160, 168, 186

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

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

4. Automatic Depressurization System (ADS) Trip System A

a. Reactor Vessel Water 1,2(d),3(d) 2 F SR 3.3.5.1.1 10.8 inches Level - Low Low Low, SR 3.3.5.1.2 Level 1 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

b. ADS Initiation Timer 1,2(d),3(d) 1 G SR 3.3.5.1.2 117 seconds SR 3.3.5.1.4 SR 3.3.5.1.6

c. Reactor Vessel Water 1,2(d),3(d) 1 F SR 3.3.5.1.1 157.8 Level - Low, Level 3 SR 3.3.5.1.2 inches (Permissive) SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

d. LPCS Pump Discharge 1,2(d),3(d) 2 G SR 3.3.5.1.1 125 psig Pressure - High SR 3.3.5.1.2 and SR 3.3.5.1.3 150 psig SR 3.3.5.1.5 SR 3.3.5.1.6

e. LPCI Pump A Discharge 1,2(d),3(d) 2 G SR 3.3.5.1.1 115 psig Pressure - High SR 3.3.5.1.2 and SR 3.3.5.1.3 130 psig SR 3.3.5.1.5 SR 3.3.5.1.6

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

5. ADS Trip System B

a. Reactor Vessel Water 1,2(d),3(d) 2 F SR 3.3.5.1.1 10.8 inches Level - Low Low Low, SR 3.3.5.1.2 Level 1 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

b. ADS Initiation Timer 1,2(d),3(d) 1 G SR 3.3.5.1.2 117 seconds SR 3.3.5.1.4 SR 3.3.5.1.6

c. Reactor Vessel Water 1,2(d),3(d) 1 F SR 3.3.5.1.1 157.8 Level - Low, Level 3 SR 3.3.5.1.2 inches (Permissive) SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

d. LPCI Pumps B & C 1,2(d),3(d) 2 per pump G SR 3.3.5.1.1 115 psig Discharge SR 3.3.5.1.2 and Pressure - High SR 3.3.5.1.3 130 psig SR 3.3.5.1.5 SR 3.3.5.1.6

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

NMP2 3.3.5.1-14 Amendment 91, 186

RCIC System Instrumentation 3.3.5.3 3.3 INSTRUMENTATION 3.3.5.3 Reactor Core Isolation Cooling (RCIC) System Instrumentation LCO 3.3.5.3 The RCIC System instrumentation for each Function in Table 3.3.5.3-1 shall be OPERABLE.

APPLICABILITY:

MODE 1, MODES 2 and 3 with reactor steam dome pressure > 150 psig.

ACTIONS

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

1. Separate Condition entry is allowed for each channel.

2. When the Function 2 channels are placed in an inoperable status solely for performance of SR 3.5.3.4, entry into associated Conditions and Required Actions is not required.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable. referenced in Table 3.3.5.3-1 for the channel.

B. As required by B.1 Declare RCIC System 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Required Action A.1 inoperable. discovery of and referenced in loss of RCIC Table 3.3.5.3-1. initiation capability AND B.2 Place channel in 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months trip.

OR (continued)

NMP2 3.3.5.3-1 Amendment 91, 168, 186

RCIC System Instrumentation 3.3.5.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) ---------NOTE---------

Not applicable when trip capability is not maintained.

In accordance with the Risk Informed Completion Time Program C. As required by C.1 Restore channel to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Required Action A.1 OPERABLE status.

and referenced in Table 3.3.5.3-1.

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

Required Action A.1 Only applicable if and referenced in RCIC pump suction is Table 3.3.5.3-1. not aligned to the suppression pool.

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

OR OR

NOTE---------

Not applicable when trip capability is not maintained.

In accordance with the Risk Informed Completion Time Program (continued)

NMP2 3.3.5.3-2 Amendment 91, 168, 186

RCIC System Instrumentation 3.3.5.3 ACTIONS (conditions)

CONDITION REQUIRED ACTION COMPLETION TIME D. (continued) D.2.2 Align RCIC pump 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months suction to the suppression pool.

E. Required Action and E.1 Declare RCIC System Immediately associated Completion inoperable.

Time of Condition B, C, or D not met.

NMP2 3.3.5.3-3 Amendment 91, 168, 186

RCIC System Instrumentation 3.3.5.3 SURVEILLANCE REQUIREMENTS

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

1. Refer to Table 3.3.5.3-1 to determine which SRs apply for each RCIC Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed as follows: (a) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Functions 4 and 5; and (b) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Functions 1, 2, and 3 provided the associated Function maintains RCIC initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.5.3.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.5.3.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.5.3.3 Calibrate the trip units. In accordance with the Surveillance Frequency Control Program SR 3.3.5.3.4 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.5.3.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program NMP2 3.3.5.3-4 Amendment 91, 152, 168, 186

RCIC System Instrumentation 3.3.5.3 Table 3.3.5.3.1 (page 1 of 1)

Reactor Core Isolation Cooling System Instrumentation CONDITIONS REQUIRED REFERENCED CHANNELS PER FROM REQUIRED SURVEILLANCE ALLOWABLE FUNCTION FUNCTION ACTION A.1 REQUIREMENTS VALUE

1. Reactor Vessel Water 4 B SR 3.3.5.3.1 101.8 inches Level - Low Low, Level 2 SR 3.3.5.3.2 SR 3.3.5.3.3 SR 3.3.5.3.4 SR 3.3.5.3.5

2. Reactor Vessel Water 4 B SR 3.3.5.3.1 209.3 inches Level - High, Level 8 SR 3.3.5.3.2 SR 3.3.5.3.3 SR 3.3.5.3.4 SR 3.3.5.3.5

3. Pump Suction 2 D SR 3.3.5.3.1 101 inches Wg Pressure - Low SR 3.3.5.3.2 SR 3.3.5.3.3 SR 3.3.5.3.4 SR 3.3.5.3.5

4. Pump Suction 1 D SR 3.3.5.3.2 12.3 seconds Pressure - Timer SR 3.3.5.3.4 SR 3.3.5.3.5

5. Manual Initiation (a) 2 C SR 3.3.5.3.5 NA (a) The injection function of Manual Initiation is not required to be OPERABLE with reactor steam dome pressure less than 600 psig.

NMP2 3.3.5.3-5 Amendment 160, 168, 186

Primary Containment Isolation Instrumentation 3.3.6.1 3.3 INSTRUMENTATION 3.3.6.1 Primary Containment Isolation Instrumentation LCO 3.3.6.1 The primary containment isolation instrumentation for each Function in Table 3.3.6.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.6.1-1.

ACTIONS

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Place channel in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for inoperable. trip. Functions 2.b, 5.b, and 5.c OR

NOTE---------

Not applicable when trip capability is not maintained.

In accordance with the Risk Informed Completion Time Program AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for Functions other than Functions 2.b, 5.b, and 5.c OR (continued)

NMP2 3.3.6.1-1 Amendment 91, 186

Primary Containment Isolation Instrumentation 3.3.6.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)

NOTE---------

Not applicable when trip capability is not maintained.

In accordance with the Risk Informed Completion Time Program B. One or more automatic B.1 Restore isolation 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Functions with capability.

isolation capability not maintained.

C. Required Action and C.1 Enter the Condition Immediately associated Completion referenced in Time of Condition A Table 3.3.6.1-1 for or B not met. the channel.

D. As required by D.1 Isolate associated 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Required Action C.1 main steam line and referenced in (MSL).

Table 3.3.6.1-1.

OR D.2.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND D.2.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E. As required by E.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Required Action C.1 and referenced in Table 3.3.6.1-1.

(continued)

NMP2 3.3.6.1-2 Amendment 91, 186

Primary Containment Isolation Instrumentation 3.3.6.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. As required by F.1 Isolate the affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Required Action C.1 penetration flow and referenced in path(s).

Table 3.3.6.1-1.

G. As required by G.1 Isolate the affected 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Required Action C.1 penetration flow and referenced in path(s).

Table 3.3.6.1-1.

H. Required Action and H.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition F or AND G not met.

H.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR As required by Required Action C.1 and referenced in Table 3.3.6.1-1.

I. As required by I.1 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Required Action C.1 standby liquid and referenced in control (SLC)

Table 3.3.6.1-1. subsystem inoperable.

OR I.2 Isolate the Reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Water Cleanup (RWCU)

System.

J. As required by J.1 Initiate action to Immediately Required Action C.1 restore channel to and referenced in OPERABLE status.

Table 3.3.6.1-1.

OR (continued)

NMP2 3.3.6.1-3 Amendment 91, 186

Primary Containment Isolation Instrumentation 3.3.6.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME J. (continued) J.2 Initiate action to Immediately isolate the Residual Heat Removal (RHR)

Shutdown Cooling (SDC) System.

NMP2 3.3.6.1-4 Amendment 91, 186

Primary Containment Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS

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

1. Refer to Table 3.3.6.1-1 to determine which SRs apply for each Primary Containment Isolation Function.

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

SURVEILLANCE FREQUENCY SR 3.3.6.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.2 Deleted SR 3.3.6.1.3 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.4 Calibrate the trip unit. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.5 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program (continued)

NMP2 3.3.6.1-5 Amendment 91, 147, 152, 186

Primary Containment Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.6.1.7 -------------------------------- NOTE------------------------------

The sensor response time may be assumed to be the design sensor response time.

Verify the ISOLATION SYSTEM RESPONSE TIME In accordance with is within limits. the Surveillance Frequency Control Program NMP2 3.3.6.1-6 Amendment 91, 152, 186

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 1 of 5)

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

1. Main Steam Line Isolation

a. Reactor Vessel Water 1,2,3 2 D SR 3.3.6.1.1 10.8 inches Level - Low Low Low, SR 3.3.6.1.3 Level 1 SR 3.3.6.1.4 SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7

b. Main Steam Line Pressure 1 2 E SR 3.3.6.1.1 814 psig

- Low SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7

c. Main Steam Line 1,2,3 2 per MSL D SR 3.3.6.1.1 184.4 psid Flow - High SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7

d. Condenser Vacuum - Low 1,2(a), 2 D SR 3.3.6.1.1 7.6 inches SR 3.3.6.1.3 Hg vacuum SR 3.3.6.1.4 3(a) SR 3.3.6.1.5 SR 3.3.6.1.6

e. Main Steam Line 1,2,3 2 D SR 3.3.6.1.1 170.6F Tunnel SR 3.3.6.1.3 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6

f. Main Steam Line 1,2,3 2 D SR 3.3.6.1.1 71.7F Tunnel Differential SR 3.3.6.1.3 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6

g. Main Steam Line 1,2,3 2 per area D SR 3.3.6.1.1 175.6F(b)

Tunnel Lead Enclosure SR 3.3.6.1.3 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6

h. Manual Initiation 1,2,3 4 G SR 3.3.6.1.6 NA (continued)

(a) With any turbine stop valve not closed.

NMP2 3.3.6.1-7 Amendment 91, 140, 147, 164, 186

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 2 of 5)

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

2. Primary Containment Isolation

a. Reactor Vessel Water 1,2,3 2 H SR 3.3.6.1.1 101.8 inches Level - Low Low, SR 3.3.6.1.3 Level 2 SR 3.3.6.1.4 SR 3.3.6.1.5 SR 3.3.6.1.6

b. Drywell 1,2,3 2 H SR 3.3.6.1.1 1.88 psig Pressure - High SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 SR 3.3.6.1.6

c. Standby Gas Treatment 1,2,3 1 F SR 3.3.6.1.3 1.0 x 10-2 (SGT) System Exhaust SR 3.3.6.1.5 µCi/cc with Radiation - High SR 3.3.6.1.6 time delay 18.5 seconds

d. Manual Initiation 1,2,3 4 G SR 3.3.6.1.6 NA

3. Reactor Core Isolation Cooling (RCIC) System Isolation

a. RCIC Steam Line 1,2,3 1 F SR 3.3.6.1.1 175.6 inches Flow - High SR 3.3.6.1.3 water SR 3.3.6.1.4 SR 3.3.6.1.5 SR 3.3.6.1.6

b. RCIC Steam Line 1,2,3 1 F SR 3.3.6.1.3 13 seconds Flow - Timer SR 3.3.6.1.5 SR 3.3.6.1.6

c. RCIC Steam Supply 1,2,3 2 F SR 3.3.6.1.1 70 psia Pressure - Low SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 SR 3.3.6.1.6

d. RCIC Turbine Exhaust 1,2,3 2 F SR 3.3.6.1.1 20 psig Diaphragm SR 3.3.6.1.3 Pressure - High SR 3.3.6.1.4 SR 3.3.6.1.5 SR 3.3.6.1.6

e. RCIC Equipment Room 1,2,3 1 F SR 3.3.6.1.1 140.5F Area SR 3.3.6.1.3 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6

f. RCIC Steam Line 1,2,3 1 F SR 3.3.6.1.1 140.5F Tunnel SR 3.3.6.1.3 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6 (continued)

NMP2 3.3.6.1-8 Amendment 91, 186

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 3 of 5)

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

3. RCIC System Isolation (continued)

g. RHR Equipment Room 1,2,3 1 per area F SR 3.3.6.1.1 144.5F Area SR 3.3.6.1.3 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6

h. Reactor Building Pipe 1,2,3 1 per area F SR 3.3.6.1.1 Chase Area SR 3.3.6.1.3 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6 El. 319 ft. 144.5F El. 292 ft. 140.5F El. 266 ft. 140.5F El. 227 ft. 140.5F

i. Reactor Building 1,2,3 1 per area F SR 3.3.6.1.1 134F General Area SR 3.3.6.1.3 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6

j. Area 1,2,3 1 F SR 3.3.6.1.3 1.15 seconds Temperature - Timer SR 3.3.6.1.5 SR 3.3.6.1.6

k. RCIC/RHR Steam 1,2,3 1 F SR 3.3.6.1.1 40.73 inches Flow - High SR 3.3.6.1.3 water SR 3.3.6.1.4 SR 3.3.6.1.5 SR 3.3.6.1.6

l. RCIC/RHR Steam 1,2,3 1 F SR 3.3.6.1.3 13 seconds Flow - Timer SR 3.3.6.1.5 SR 3.3.6.1.6

m. Manual Initiation 1,2,3 1(c) G SR 3.3.6.1.6 NA

4. Reactor Water Cleanup (RWCU) System Isolation

a. Differential 1,2,3 1 F SR 3.3.6.1.1 165.5 gpm Flow - High SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6

b. Differential 1,2,3 1 F SR 3.3.6.1.3 47 seconds Flow - Timer SR 3.3.6.1.5 SR 3.3.6.1.6 (continued)

(c) Only inputs into one of the two trip systems.

NMP2 3.3.6.1-9 Amendment 91, 186

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 4 of 5)

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

4. RWCU System Isolation (continued)

c. Heat Exchanger Room 1,2,3 1 F SR 3.3.6.1.1 140.5F Temperature - High SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6

d. Pump Room 1,2,3 1 per room F SR 3.3.6.1.1 Temperature - High SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 Pump Room A 144.5F Pump Room B 159.5F

e. Reactor Building Pipe 1,2,3 1 per area F SR 3.3.6.1.1 Chase Area SR 3.3.6.1.3 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6 El. 319 ft. 144.5F El. 292 ft. 140.5F El. 266 ft. 140.5F El. 227 ft. 140.5F

f. Reactor Vessel Water 1,2,3 2 F SR 3.3.6.1.1 101.8 inches Level - Low Low, Level SR 3.3.6.1.3 2 SR 3.3.6.1.4 SR 3.3.6.1.5 SR 3.3.6.1.6

g. SLC System Initiation 1,2 1 I SR 3.3.6.1.6 NA

h. Manual Initiation 1,2,3 4 G SR 3.3.6.1.6 NA

5. RHR SDC System Isolation

a. RHR Equipment Room 3 1 per area F SR 3.3.6.1.1 144.5F Area SR 3.3.6.1.3 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6 (continued)

NMP2 3.3.6.1-10 Amendment 91, 186

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 5 of 5)

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

5. RHR SDC System Isolation (continued)

b. Reactor Vessel Water 3 2 J SR 3.3.6.1.1 157.8 inches Level - Low, Level 3 SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 SR 3.3.6.1.6

c. Reactor Vessel 1,2,3 2 F SR 3.3.6.1.1 148 psig Pressure - High SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 SR 3.3.6.1.6

d. Reactor Building Pipe 3 1 per area F SR 3.3.6.1.1 Chase Area SR 3.3.6.1.3 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6 El. 319 ft. 144.5F El. 292 ft. 140.5F El. 266 ft. 140.5F El. 227 ft. 140.5F

e. Reactor Building 3 1 per area F SR 3.3.6.1.1 134F General Area SR 3.3.6.1.3 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6

f. Manual Initiation 1,2,3 4 G SR 3.3.6.1.6 NA NMP2 3.3.6.1-11 Amendment 91, 168, 186

Mechanical Vacuum Pump Isolation Instrumentation 3.3.7.2 3.3 INSTRUMENTATION 3.3.7.2 Mechanical Vacuum Pump Isolation Instrumentation LCO 3.3.7.2 Four channels of Main Steam Line Radiation - High Function for the mechanical vacuum pump isolation shall be OPERABLE.

APPLICABILITY: MODES 1 and 2 with any mechanical vacuum pump in service and any main steam line not isolated.

ACTIONS

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Restore channel to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months inoperable. OPERABLE status.

OR

NOTE---------

Not applicable when trip capability is not maintained.

In accordance with the Risk Informed Completion Time Program OR A.2 ------------NOTE------------

Not applicable if inoperable channel is the result of an inoperable isolation valve or mechanical vacuum pump breaker.

(continued)

NMP2 3.3.7.2-1 Amendment 91, 186

Mechanical Vacuum Pump Isolation Instrumentation 3.3.7.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) Place channel in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months trip.

OR

NOTE---------

Not applicable when trip capability is not maintained.

In accordance with the Risk Informed Completion Time Program B. Mechanical vacuum pump B.1 Restore isolation 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months isolation capability capability.

not maintained.

C. Required Action and C.1 Isolate the 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion associated mechanical Time not met. vacuum pump(s).

OR C.2 Remove the associated 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months mechanical vacuum pump breaker(s) from service.

OR C.3 Isolate the main 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months steam lines.

OR C.4 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months NMP2 3.3.7.2-2 Amendment 91, 152, 186

Mechanical Vacuum Pump Isolation Instrumentation 3.3.7.2 SURVEILLANCE REQUIREMENTS

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

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

SURVEILLANCE FREQUENCY SR 3.3.7.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.7.2.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.7.2.3 Perform CHANNEL CALIBRATION. The In accordance Allowable Value shall be 3.6 x full with the power background. Surveillance Frequency Control Program SR 3.3.7.2.4 Perform LOGIC SYSTEM FUNCTIONAL TEST In accordance including isolation valve and mechanical with the vacuum pump breakers actuation. Surveillance Frequency Control Program NMP2 3.3.7.2-3 Amendment 91, 152, 186

LOP Instrumentation 3.3.8.1 3.3 INSTRUMENTATION 3.3.8.1 Loss of Power (LOP) Instrumentation LCO 3.3.8.1 The LOP instrumentation for each Function in Table 3.3.8.1-1 shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, When the associated diesel generator (DG) is required to be OPERABLE by LCO 3.8.2, "AC Sources - Shutdown."

ACTIONS

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Place channel in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months channels inoperable. trip.

OR

NOTE---------

Not applicable when trip capability is not maintained.

In accordance with the Risk Informed Completion Time Program B. Required Action and B.1 Declare associated DG Immediately associated Completion inoperable.

Time not met.

NMP2 3.3.8.1-1 Amendment 91, 186

ECCS - Operating 3.5.1 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.1 ECCS - Operating LCO 3.5.1 Each ECCS injection/spray subsystem and the Automatic Depressurization System (ADS) function of six safety/relief valves shall be OPERABLE.

APPLICABILITY: MODE 1, MODES 2 and 3, except ADS valves are not required to be OPERABLE with reactor steam dome pressure 150 psig.

ACTIONS

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

LCO 3.0.4.b is not applicable to HPCS.

CONDITION REQUIRED ACTION COMPLETION TIME A. One low pressure ECCS A.1 Restore low pressure 7 days injection/spray ECCS injection/spray subsystem inoperable. subsystem to OPERABLE OR status.

In accordance with the Risk Informed Completion Time Program B. High Pressure Core B.1 Verify by administrative Immediately Spray (HPCS) System means RCIC System is inoperable. OPERABLE when RCIC is required to be OPERABLE.

AND B.2 Restore HPCS System 14 days to OPERABLE status.

OR In accordance with the Risk Informed Completion Time Program (continued)

NMP2 3.5.1-1 Amendment 91, 109, 168, 174, 186

ECCS - Operating 3.5.1 ACTIONS (continued)

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

In accordance with One ECCS injection and the Risk Informed one ECCS spray Completion Time subsystem inoperable. Program D. Required Action and D.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A, AND B, or C not met.

D.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E. One required ADS valve E.1 Restore ADS valve to 14 days inoperable. OPERABLE status.

OR In accordance with the Risk Informed Completion Time Program F. One required ADS valve F.1 Restore ADS valve to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. OPERABLE status.

OR AND In accordance with One low pressure ECCS the Risk Informed injection/spray Completion Time subsystem inoperable. Program OR F.2 Restore low pressure 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months ECCS injection/spray subsystem to OPERABLE OR status.

In accordance with the Risk Informed Completion Time Program (continued)

NMP2 3.5.1-2 Amendment 91, 186

RCIC System 3.5.3 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.3 RCIC System LCO 3.5.3 The RCIC System shall be OPERABLE.

APPLICABILITY: MODE 1, MODES 2 and 3 with reactor steam dome pressure > 150 psig.

ACTIONS

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

LCO 3.0.4.b is not applicable to RCIC.

CONDITION REQUIRED ACTION COMPLETION TIME A. RCIC System A.1 Verify by Immediately inoperable. administrative means High Pressure Core Spray System is OPERABLE.

AND A.2 Restore RCIC System 14 days to OPERABLE status.

OR In accordance with the Risk Informed Completion Time Program B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AND B.2 Reduce reactor steam 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months dome pressure to 150 psig.

NMP2 3.5.3-1 Amendment 91, 109, 168, 186

Primary Containment Air Locks 3.6.1.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more primary C.1 Initiate action to Immediately containment air locks evaluate primary inoperable for reasons containment overall other than Condition A leakage rate per or B. LCO 3.6.1.1, using current air lock test results.

AND C.2 Verify a door is 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months closed in the affected air lock.

AND C.3 Restore air lock to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE status.

OR

NOTE---------

Not applicable if leakage exceeds limits or if loss of function.

In accordance with the Risk Informed Completion Time Program D. Required Action and D.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AND D.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months NMP2 3.6.1.2-4 Amendment 91, 186

PCIVs 3.6.1.3 3.6 CONTAINMENT SYSTEMS 3.6.1.3 Primary Containment Isolation Valves (PCIVs)

LCO 3.6.1.3 Each PCIV and each Secondary Containment Bypass Leakage Valve shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, When associated instrumentation is required to be OPERABLE per LCO 3.3.6.1, "Primary Containment Isolation Instrumentation."

ACTIONS

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

1. Penetration flow paths may be unisolated intermittently under administrative controls.

2. Separate Condition entry is allowed for each penetration flow path.

3. Enter applicable Conditions and Required Actions for systems made inoperable by PCIVs.

4. Enter applicable Conditions and Required Actions of LCO 3.6.1.1, "Primary Containment," when PCIV leakage results in exceeding overall containment leakage rate acceptance criteria.

CONDITION REQUIRED ACTION COMPLETION TIME A. -------------NOTE-------------- A.1 Isolate the affected 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months except Only applicable to penetration flow path for main steam penetration flow paths by use of at least line with two or more one closed and PCIVs. de-activated OR

automatic valve, closed manual valve, In accordance One or more blind flange, or with the Risk penetration flow paths check valve with flow Informed with one PCIV through the valve Completion Time inoperable except due secured. Program to leakage not within limit. AND (continued)

NMP2 3.6.1.3-1 Amendment 91, 156, 186

PCIVs 3.6.1.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) AND 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months for main steam line OR In accordance with the Risk Informed Completion Time Program A.2 -------------NOTES-----------

1. Isolation devices in high radiation areas may be verified by use of administrative means.

2. Isolation devices that are locked, sealed, or otherwise secured may be verified by use of administrative means.

Verify the affected Once per 31 days penetration flow path following isolation is isolated. for isolation devices outside primary containment AND Prior to entering MODE 2 or 3 from MODE 4 (continued)

NMP2 3.6.1.3-2 Amendment 91, 186

PCIVs 3.6.1.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) if primary containment was de-inerted while in MODE 4, if not performed within the previous 92 days, for isolation devices inside primary containment B. -------------NOTE-------------- B.1 Isolate the affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Only applicable to penetration flow path penetration flow paths by use of at least with two or more one closed and PCIVs. de-activated

automatic valve, closed manual valve, One or more or blind flange.

penetration flow paths with two or more PCIVs inoperable except due to leakage not within limit.

C. -------------NOTE-------------- C.1 Isolate the affected 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months except Only applicable to penetration flow path for excess flow penetration flow paths by use of at least check valves with only one PCIV. one closed and (EFCVs) and

de-activated penetrations automatic valve, with a closed One or more closed manual valve, system penetration flow paths or blind flange.

with one PCIV AND inoperable except due to leakage not within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for limit. EFCVs and penetrations with a closed system AND (continued)

NMP2 3.6.1.3-3 Amendment 91, 186

PCIVs 3.6.1.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. (continued) D.3 Perform SR 3.6.1.3.6 Once per 92 days for the resilient seal purge supply valves closed to comply with Required Action D.1.

E. One or more E.1 Isolate the affected 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months penetration flow paths penetration flow path with one or more by use of at least OR containment purge one closed and exhaust valves not de-activated ---------NOTE---------

within purge valve automatic valve, Not applicable if leakage limits. closed manual valve, there is a loss of or blind flange. function.

AND In accordance with the Risk Informed Completion Time Program (continued)

NMP2 3.6.1.3-7 Amendment 91, 186

PCIVs 3.6.1.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. (continued) E.2 -----------NOTES----------

1. Isolation devices in high radiation areas may be verified by use of administrative means.

2. Isolation devices that are locked, sealed, or otherwise secured may be verified by use of administrative means.

Verify the affected Once per 31 days penetration flow path following isolation is isolated. for isolation devices outside containment AND Prior to entering MODE 2 or 3 from MODE 4 if primary containment was de-inerted while in MODE 4, if not performed within the previous 92 days, for isolation devices inside containment AND (continued)

NMP2 3.6.1.3-8 Amendment 91, 186

PCIVs 3.6.1.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. (continued) E.3 Perform SR 3.6.1.3.6 Once per 92 days for the resilient following isolation seal purge exhaust valves closed to comply with Required Action E.1.

F. Required Action and F.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A, AND B, C, D, or E not met in MODE 1, 2, or 3. F.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months G. Required Action and G.1 Initiate action to Immediately associated Completion restore valve(s) to Time of Condition A, OPERABLE status.

B, C, D, or E not met .

for PCIV(s) required to be OPERABLE during MODE 4 or 5.

NMP2 3.6.1.3-9 Amendment 91, 168, 186

RHR Drywell Spray 3.6.1.6 3.6 CONTAINMENT SYSTEMS 3.6.1.6 Residual Heat Removal (RHR) Drywell Spray System LCO 3.6.1.6 Two RHR drywell spray subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR drywell spray A.1 Restore RHR drywell 7 days subsystem inoperable. spray subsystem to OPERABLE status. OR In accordance with the Risk Informed Completion Time Program B. Two RHR drywell spray B.1 Restore one RHR 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months subsystems inoperable. drywell spray subsystem to OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AND C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months NMP2 3.6.1.6-1 Amendment 91, 186

Suppression Chamber-to-Drywell Vacuum Breakers 3.6.1.7 3.6 CONTAINMENT SYSTEMS 3.6.1.7 Suppression Chamber-to-Drywell Vacuum Breakers LCO 3.6.1.7 Each suppression chamber-to-drywell vacuum breaker shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One line with one or A.1 Restore the vacuum 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months more suppression breaker(s) to chamber-to-drywell OPERABLE status. OR vacuum breakers inoperable for In accordance with opening. the Risk Informed Completion Time Program B. -------------NOTE------------- B.1 Close the open vacuum 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Separate Condition breaker.

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

One or more lines with one suppression chamber-to-drywell vacuum breaker not closed.

(continued)

NMP2 3.6.1.7-1 Amendment 91, 186

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

APPLICABILITY: MODES 1, 2, and 3.

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

In accordance with the Risk Informed Completion Time Program B. Two RHR suppression B.1 Restore one RHR 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months pool cooling suppression pool subsystems inoperable. cooling subsystem to OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AND C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months NMP2 3.6.2.3-1 Amendment 91, 186

RHR Suppression Pool Spray 3.6.2.4 3.6 CONTAINMENT SYSTEMS 3.6.2.4 Residual Heat Removal (RHR) Suppression Pool Spray LCO 3.6.2.4 Two RHR suppression pool spray subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

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

In accordance with the Risk Informed Completion Time Program B. Two RHR suppression B.1 Restore one RHR 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months pool spray subsystems suppression pool inoperable. spray subsystem to OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AND C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months NMP2 3.6.2.4-1 Amendment 91, 186

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

LCO 3.7.1 a. Division 1 and 2 SW subsystems and UHS shall be OPERABLE.

AND b.1 Four OPERABLE SW pumps shall be in operation when water temperature of one or two SW subsystem supply headers is 82°F.

OR b.2 Five OPERABLE SW pumps shall be in operation when water temperature of one or two SW subsystem supply headers is > 82°F and 84°F.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SW supply header A.1 Open the SW supply 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months cross connect valve header cross connect inoperable. valve.

AND A.2 Restore the SW supply 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months header cross connect valve to OPERABLE OR status.

In accordance with the Risk Informed Completion Time Program B. One or more non-safety B.1 Isolate the affected 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months related SW flow paths non-safety related SW with one SW isolation flow path(s).

valve inoperable.

(continued)

NMP2 3.7.1-1 Amendment 91, 119, 186

SW System and UHS 3.7.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One SW subsystem C.1 Restore SW subsystem 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable for reasons to OPERABLE status.

other than Conditions OR A and B.

In accordance with the Risk Informed Completion Time Program D. One division of intake D.1 Restore intake deicer 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months deicer heaters heater division to inoperable. OPERABLE status. OR In accordance with the Risk Informed Completion Time Program E. One required SW pump E.1 Restore required SW 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months not in operation. pump to operation.

OR In accordance with the Risk Informed Completion Time Program F. Two or more required F.1 Restore all but one 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SW pumps not in required SW pump to operation. operation. OR

NOTE---------

Not applicable when loss of function can occur.

In accordance with the Risk Informed Completion Time Program (continued)

NMP2 3.7.1-2 Amendment 91, 119, 186

SW System and UHS 3.7.1 ACTIONS (continued)

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

associated Completion Enter applicable Conditions Time of Condition A, and Required Actions of B, C, D, E, or F not LCO 3.4.9, "Residual Heat met. Removal (RHR) Shutdown Cooling System - Hot OR Shutdown," for RHR Shutdown Cooling subsystem(s) made Both SW subsystems inoperable by SW System or inoperable for reasons UHS.

other than --------------------------------------------

Conditions A, B, and C. G.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months OR AND UHS inoperable G.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months for reasons other than Condition D.

NMP2 3.7.1-3 Amendment 91, 119, 186

SW System and UHS 3.7.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1.1 -------------------------------- NOTE ------------------------------

Not required to be met if SR 3.7.1.5 and SR 3.7.1.8 satisfied.

Verify the water temperature of the intake In accordance with tunnels is 38°F. the Surveillance Frequency Control Program SR 3.7.1.2 Verify the water level in the SW pump In accordance with intake bay is 233.1 ft. the Surveillance Frequency Control Program SR 3.7.1.3 Verify the water temperature of In accordance with each SW subsystem supply header is 84°F. the Surveillance Frequency Control Program AND 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months when supply header water temperature is 78°F SR 3.7.1.4 Verify each required SW pump is in In accordance with operation. the Surveillance Frequency Control Program (continued)

NMP2 3.7.1-4 Amendment 91, 119, 152, 186

SW System and UHS 3.7.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.1.5 -------------------------------- NOTE ------------------------------

Not required to be met if SR 3.7.1.1 satisfied.

Verify, for each intake deicer heater In accordance with division, the current of each required the Surveillance heater feeder cable is within the limit. Frequency Control Program SR 3.7.1.6 -------------------------------- NOTE ------------------------------

Isolation of flow to individual components does not render SW System inoperable.

Verify each SW subsystem manual, power In accordance with operated, and automatic valve in the flow the Surveillance path servicing safety related systems or Frequency Control components, that is not locked, sealed, or Program otherwise secured in position, is in the correct position.

SR 3.7.1.7 Verify each SW subsystem actuates on an In accordance with actual or simulated initiation signal. the Surveillance Frequency Control Program SR 3.7.1.8 -------------------------------- NOTE ------------------------------

Not required to be met if SR 3.7.1.1 satisfied.

Verify, for each intake deicer heater In accordance with division, the resistance of each required the Surveillance heater feeder cable and associated heater Frequency Control elements is within the limit. Program NMP2 3.7.1-5 Amendment 91, 152, 186

Main Turbine Bypass System 3.7.5 3.7 PLANT SYSTEMS 3.7.5 Main Turbine Bypass System LCO 3.7.5 The Main Turbine Bypass System shall be OPERABLE.

OR LCO 3.2.2, "MINIMUM CRITICAL POWER RATIO (MCPR)," limits for an inoperable Main Turbine Bypass System, as specified in the COLR, are made applicable.

APPLICABILITY: THERMAL POWER 23% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the A.1 Satisfy the 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months LCO not met. requirements of the LCO. OR In accordance with the Risk Informed Completion Time Program B. Required Action and B.1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion to < 23% RTP.

Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 Perform a system functional test. In accordance with the Surveillance Frequency Control Program SR 3.7.5.2 Verify the TURBINE BYPASS SYSTEM RESPONSE In accordance with TIME is within limits. the Surveillance Frequency Control Program NMP2 3.7.5-1 Amendment 91, 140, 152, 186

AC Sources - Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 Declare required 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months from feature(s) with no discovery of no offsite power offsite power available inoperable to one division when the redundant concurrent with required feature(s) inoperability are inoperable. of redundant required feature(s)

AND A.3 Restore required 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months offsite circuit to OPERABLE status. OR In accordance with the Risk Informed Completion Time Program AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months from discovery of both HPCS and Low Pressure Core Spray (LPCS) Systems with no offsite power OR In accordance with the Risk Informed Completion Time Program B. One required DG B.1 Perform SR 3.8.1.1 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. for OPERABLE required offsite circuit(s). AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND (continued)

NMP2 3.8.1-2 Amendment 91, 138, 159, 186

AC Sources - Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2 Declare required 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from feature(s), supported discovery of by the inoperable DG, Condition B inoperable when the concurrent with redundant required inoperability feature(s) are of redundant inoperable. required feature(s)

AND B.3.1 Determine OPERABLE 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months DG(s) are not inoperable due to common cause failure.

OR B.3.2 Perform SR 3.8.1.2 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for OPERABLE DG(s).

AND B.4 Restore required DG 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months from to OPERABLE status. discovery of an inoperable Division 3 DG OR In accordance with the Risk Informed Completion Time Program AND 14 days OR In accordance with the Risk Informed Completion Time Program (continued)

NMP2 3.8.1-3 Amendment 91, 138, 159, 186

AC Sources - Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Two required offsite C.1 Declare required 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months from circuits inoperable. feature(s) inoperable discovery of when the redundant Condition C required feature(s) concurrent with are inoperable. inoperability of redundant required feature(s)

AND C.2 Restore one required 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months offsite circuit to OPERABLE status. OR In accordance with the Risk Informed Completion Time Program D. One required offsite ------------------NOTE-------------------

circuit inoperable. Enter applicable Conditions and Required Actions of AND LCO 3.8.8, "Distribution Systems - Operating," when One required DG Condition D is entered with inoperable. no AC power source to any division.

D.1 Restore required 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months offsite circuit to OPERABLE status. OR OR In accordance with the Risk Informed Completion Time Program D.2 Restore required DG 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months to OPERABLE status.

OR In accordance with the Risk Informed Completion Time Program (continued)

NMP2 3.8.1-4 Amendment 91, 186

DC Sources - Operating 3.8.4 3.8 ELECTRICAL POWER SYSTEMS 3.8.4 DC Sources - Operating LCO 3.8.4 The Division 1, Division 2, and Division 3 DC electrical power subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Division 1 or 2 DC A.1 Restore Division 1 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months electrical power and 2 DC electrical subsystem inoperable. power subsystems to OR OPERABLE status.

In accordance with the Risk Informed Completion Time Program B. Division 3 DC B.1 Declare High Pressure Immediately electrical power Core Spray System subsystem inoperable. inoperable.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AND C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months NMP2 3.8.4-1 Amendment 91, 186

Inverters - Operating 3.8.7 3.8 ELECTRICAL POWER SYSTEMS 3.8.7 Inverters - Operating LCO 3.8.7 The Division 1 and Division 2 emergency uninterruptible power supply (UPS) inverters shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One emergency UPS A.1 -----------NOTE--------------

inverter inoperable. Enter applicable Conditions and Required Actions of LCO 3.8.8, Distribution Systems - Operating with any 120 VAC uninterruptible panel de-energized.

Restore emergency UPS 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months inverters to OPERABLE status. OR In accordance with the Risk Informed Completion Time Program B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months NMP2 3.8.7-1 Amendment 91, 186

Distribution Systems - Operating 3.8.8 3.8 ELECTRICAL POWER SYTEMS 3.8.8 Distribution Systems - Operating LCO 3.8.8 The following AC and DC electrical power distribution subsystems shall be OPERABLE:

a. Division 1 and Division 2 AC electrical power distribution subsystems;

b. Division 1 and Division 2 120 VAC uninterruptible electrical power distribution subsystems;

c. Division 1 and Division 2 DC electrical power distribution subsystems; and

d. Division 3 AC and DC electrical power distribution subsystems.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or both Division 1 A.1 Restore Division 1 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months and 2 AC electrical and 2 AC electrical power distribution power distribution OR subsystems inoperable. subsystem(s) to OPERABLE status. ---------NOTE---------

Not applicable when loss of function can occur.

In accordance with the Risk Informed Completion Time Program (continued)

NMP2 3.8.8-1 Amendment 91, 159, 186

Distribution Systems - Operating 3.8.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or both Division 1 B.1 Restore Division 1 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months and 2 120 VAC and 2 120 VAC uninterruptible uninterruptible OR electrical power electrical power distribution distribution ---------NOTE---------

subsystems inoperable. subsystem(s) to Not applicable when OPERABLE status. loss of function can occur.

In accordance with the Risk Informed Completion Time Program C. One or both Division 1 C.1 Restore Division 1 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and 2 DC electrical and 2 DC electrical power distribution power distribution OR subsystems inoperable. subsystem(s) to OPERABLE status. ---------NOTE---------

Not applicable when loss of function can occur.

In accordance with the Risk Informed Completion Time Program D. Required Action and D.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A, AND B, or C not met.

D.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E. One or both Division 3 E.1 Declare High Pressure Immediately AC and DC electrical Core Spray System power distribution inoperable.

subsystems inoperable.

(continued)

NMP2 3.8.8-2 Amendment 91, 159, 186

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.13 Control Room Envelope Habitability Program (continued)

e. The quantitative limits on unfiltered air inleakage into the CRE. These limits shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph c.

The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of DBA consequences.

Unfiltered air inleakage limits for hazardous chemicals must ensure that exposure of CRE occupants to these hazards will be within the assumptions in the licensing basis.

f. The provisions of SR 3.0.2 are applicable to the Frequencies for assessing CRE habitability, determining CRE unfiltered inleakage, and measuring CRE pressure and assessing the CRE boundary as required by paragraphs c and d, respectively.

5.5.14 Surveillance Frequency Control Program This program provides controls for the Surveillance Frequencies. The Program shall ensure that Surveillance Requirements specified in the Technical Specifications are performed at intervals sufficient to assure the associated Limiting Conditions for Operation are met.

a. The Surveillance Frequency Control Program shall contain a list of Frequencies of the Surveillance Requirements for which the Frequency is controlled by the program.

b. Changes to the Frequency listed in the Surveillance Frequency Control Program shall be made in accordance with NEI 04-10, Risk-Informed Method for Control of Surveillance Frequency, Revision 1.

c. The provision of Surveillance Requirements 3.0.2 and 3.0.3 are applicable to the Frequencies established in the Surveillance Frequency Control Program.

(continued)

NMP2 5.5-13 Amendment 126, 152, 186

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.15 Risk Informed Completion Time Program This program provides controls to calculate a Risk Informed Completion Time (RICT) and must be implemented in accordance with NEI 06-09-A, Revision 0, "Risk-Managed Technical Specifications (RMTS) Guidelines."

The program shall include the following:

a. The RICT may not exceed 30 days;

b. A RICT may only be utilized in MODE 1, 2;

c. When a RICT is being used, any change to the plant configuration, as defined in NEI 06-09-A, Appendix A, must be considered for the effect on the RICT.

1. For planned changes, the revised RICT must be determined prior to implementation of the change in configuration.

2. For emergent conditions, the revised RICT must be determined within the time limits of the Required Action Completion Time (i.e., not the RICT) or 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after the plant configuration change, whichever is less.

3. Revising the RICT is not required if the plant configuration change would lower plant risk and would result in a longer RICT.

d. For emergent conditions, if the extent of condition evaluation for inoperable structures, systems, or components (SSCs) is not complete prior to exceeding the Completion Time, the RICT shall account for the increased possibility of common cause failure (CCF) by either:

1. Numerically accounting for the increased possibility of CCF in the RICT calculation; or

2. Risk Management Actions (RMAs) not already credited in the RICT calculation shall be implemented that support redundant or diverse SSCs that perform the function(s) of the inoperable SSCs, and, if practicable, reduce the frequency of initiating events that challenge the function(s) performed by the inoperable SSCs.

e. The risk assessment approaches and methods shall be acceptable to the NRC. The plant PRA shall be based on the as-built, as-operated, and maintained plant; and reflect the operating experience at the plant, as specified in Regulatory Guide 1.200, Revision 2. Methods to assess the risk from extending the Completion Times must be PRA methods used to support License Amendment No. 186, or other methods approved by the NRC for generic use; and any change in the PRA methods to assess risk that are outside these approval boundaries require prior NRC approval.

NMP2 5.5-14 Amendment 186

SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION RELATED TO AMENDMENT NO. 186 TO RENEWED FACILITY OPERATING LICENSE NO. NPF-69 NINE MILE POINT NUCLEAR STATION, LLC LONG ISLAND LIGHTING COMPANY EXELON GENERATION COMPANY, LLC.

NINE MILE POINT NUCLEAR STATION, UNIT 2 DOCKET NO. 50-410

1.0 INTRODUCTION

By application dated October 31, 2019 (Reference 1), as supplemented by letters dated December 12, 2019 (Reference 2), August 28, 2020 (Reference 3), October 2, 2020 (two letters) (Reference 4) and (Reference 5), October 22, 2020 (Reference 6), and January 7, 2021 (Reference 7), Exelon Generation Company, LLC (the licensee) submitted a license amendment request (LAR) for Nine Mile Point Nuclear Station Unit 2 (Nine Mile Point 2).

The supplemental letters dated December 12, 2019, August 28, 2020, October 2, 2020 (two letters), October 22, 2020, and January 7, 2021, 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 or the Commission) staffs initial proposed no significant hazards consideration determination published in the Federal Register on February 11, 2020 (85 FR 7792).

The proposed amendment would revise technical specification (TS) requirements to permit the use of risk-informed completion times (RICTs) for actions to be taken when limiting conditions for operation (LCOs) are not met. The proposed changes are based on Technical Specifications Task Force (TSTF) Traveler TSTF-505, Revision 2, Provide Risk-Informed Extended Completion Times - RITSTF Initiative 4b, dated July 2, 2018 (Reference 8). The NRC issued a final model safety evaluation (SE) approving TSTF-505, Revision 2, on November 21, 2018 (Reference 9). The licensee has proposed variations from the TS changes described in TSTF-505, Revision 2.

During May 2020, the NRC staff and contractors from the Pacific Northwest National Laboratory participated in a regulatory audit. The NRC staff performed the audit to ascertain the information needed to support its review of the application and develop requests for additional information (RAIs), as needed. By electronic mail dated July 30, 2020 (Reference 10),

Enclosure 2

September 2, 2020 (Reference 11), September 28, 2020 (two emails) (Reference 12) and (Reference 13), and December 15, 2020 (Reference 14), the NRC sent the licensee RAIs. By letters dated August 28, 2020, October 2, 2020 (two letters), October 22, 2020, and January 7, 2021, the licensee responded to the RAIs.

2.0 REGULATORY EVALUATION

2.1 DESCRIPTION

OF RISK-INFORMED COMPLETION TIME PROGRAM The TS LCOs are the lowest functional capability or performance levels of equipment required for safe operation of the facility. When an LCO is not met, the licensee must shut down the reactor or follow any remedial or required action (e.g., testing, maintenance, or repair activity) permitted by the TSs until the condition can be met. The remedial actions associated with an LCO contain conditions that typically describe the ways in which the requirements of the LCO can fail to be met. Specified with each stated condition are required action(s) and completion times (CTs). The CTs are referred to as the front stops in the context of this SE. For certain conditions, the TS require exiting the mode of applicability of an LCO (i.e., shut down the reactor).

2.2 DESCRIPTION

OF TS CHANGES The licensees submittal requested approval to add a RICT Program to the Administrative Controls section of the TSs, and modify selected CTs to permit extending the CTs, provided risk is assessed and managed as described in Nuclear Energy Institute (NEI) topical report NEI 06-09, Revision 0-A, Risk-Informed Technical Specifications Initiative 4b: Risk-Managed Technical Specifications (RMTS) Guidelines, dated October 2012 (Reference 15), and the associated final safety evaluation (SE) dated May 17, 2007 (Reference 16). The licensees application for the changes proposed to use NEI 06-09, Revision 0-A, and included documentation regarding the technical adequacy of the probabilistic risk assessment (PRA) models for the RICT Program, consistent with the guidance of Regulatory Guide (RG) 1.200, Revision 2, An Approach for Determining the Technical Adequacy of Probabilistic Risk Assessment Results for Risk-Informed Activities, dated March 2009 (Reference 17).

2.2.1 TS 1.0, Use and Application Example 1.3-8, would be added to TS 1.3, Completion Times, and reads as follows:

EXAMPLE 1.3-8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One A.1 Restore subsystem 7 days subsystem to OPERABLE inoperable. status. OR In accordance with the Risk Informed Completion Time Program B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and associated AND Completion Time not B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

met.

When a subsystem is declared inoperable, Condition A is entered.

The 7 day Completion Time may be applied as discussed in Example 1.3-2. However, the licensee may elect to apply the Risk Informed Completion Time Program which permits calculation of a Risk Informed Completion Time (RICT) that may be used to complete the Required Action beyond the 7 day Completion Time.

The RICT cannot exceed 30 days. After the 7 day Completion Time has expired, the subsystem must be restored to OPERABLE status within the RICT or Condition B must also be entered.

The Risk Informed Completion Time Program requires recalculation of the RICT to reflect changing plant conditions. For planned changes, the revised RICT must be determined prior to implementation of the change in configuration. For emergent conditions, the revised RICT must be determined within the time limits of the Required Action Completion Time (i.e., not the RICT) or 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after the plant configuration change, whichever is less.

If the 7 day Completion Time clock of Condition A has expired and subsequent changes in plant condition result in exiting the applicability of the Risk Informed Completion Time Program without restoring the inoperable subsystem to OPERABLE status, Condition B is also entered and the Completion Time clocks for Required Actions B.1 and B.2 start.

If the RICT expires or is recalculated to be less than the elapsed time since the Condition was entered and the inoperable subsystem has not been restored to OPERABLE status, Condition B is also entered and the Completion Time clocks for Required Actions B.1 and B.2 start. If the inoperable subsystems are restored to OPERABLE status after Condition B is entered, Conditions A and B are exited, and therefore, the required actions of Condition B may be terminated.

2.2.2 TS 5.5.15, Risk Informed Completion Time Program TS 5.5.15, which describes the RICT Program, would be added to the TS and read as follows:

Risk Informed Completion Time Program This program provides controls to calculate a Risk Informed Completion Time (RICT) and must be implemented in accordance with NEI 06-09, Revision 0-A, Risk-Managed Technical Specifications (RMTS) Guidelines.

The program shall include the following:

a. The RICT may not exceed 30 days;

b. A RICT may only be utilized in MODE 1, 2;

c. When a RICT is being used, any change to the plant configuration, as defined in NEI 06-09-A, Appendix A, must be considered for the effect on the RICT.

1. For planned changes, the revised RICT must be determined prior to implementation of the change in configuration.

2. For emergent conditions, the revised RICT must be determined within the time limits of the Required Action Completion Time (i.e., not the RICT) or 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after the plant configuration change, whichever is less.

3. Revising the RICT is not required if the plant configuration change would lower plant risk and would result in a longer RICT.

d. For emergent conditions, if the extent of condition evaluation for inoperable structures, systems, or components (SSCs) is not complete prior to exceeding the Completion Time, the RICT shall account for the increased possibility of common cause failure (CCF) by either:

1. Numerically accounting for the increased possibility of CCF in the RICT calculation; or

2. Risk Management Actions (RMAs) not already credited in the RICT calculation shall be implemented that support redundant or diverse SSCs that perform the function(s) of the inoperable SSCs, and, if

practicable, reduce the frequency of initiating events that challenge the function(s) performed by the inoperable SSCs.

e. The risk assessment approaches and methods shall be acceptable to the NRC. The plant PRA shall be based on the as-built, as operated, and maintained plant; and reflect the operating experience at the plant, as specified in Regulatory Guide 1.200, Revision 2. Methods to assess the risk from extending the Completion Times must be PRA methods used to support License Amendment No. [186], or other methods approved by the NRC for generic use; and any change in the PRA methods to assess risk that are outside these approval boundaries require prior NRC approval.

2.2.3 Application of the RICT Program to Existing LCOs and Action Statements The typical CT is modified by the application of the RICT Program as shown in the following example. The changed portion is indicated in italics.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One subsystem A.1 Restore subsystem 7 days inoperable. to OPERABLE status. OR In accordance with the Risk Informed Completion Time Program Where necessary, conforming changes are made to CTs to make them accurate following use of a RICT. For example, most TSs have requirements to close/isolate containment isolation devices if one or more containment penetrations have inoperable devices. This is followed by a requirement to periodically verify the penetration is isolated. By adding the flexibility to use a RICT to determine a time to isolate the penetration, the periodic verifications must then be based on the time following isolation.

Individual LCO required actions and CTs modified by the proposed change are identified below.

TS 3.1.7 Standby Liquid Control (SLC) System Action A.1 With one SLC subsystem inoperable, restore SLC subsystem to operable status within 7 days or in accordance with the Risk Informed Completion Time Program.

TS 3.5.1 ECCS [Emergency Core Cooling System] - Operating Action A.1 With one low pressure ECCS injection/spray subsystem inoperable, restore low pressure ECCS injection/spray subsystem to operable status within 7 days or in accordance with the Risk Informed Completion Time Program.

Action B.2 With High Pressure Core Spray (HPCS) System inoperable, restore HPCS system to operable status within 14 days or in accordance with the Risk Informed Completion Time Program.

Action C.1 With two ECCS injections subsystems inoperable or one ECCS injection and one ECCS spray subsystem inoperable, restore one ECCS injection/spray subsystem to operable status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or in accordance with the Risk Informed Completion Time Program.

Action E.1 With one required ADS [automatic depressurization system] valve inoperable, restore ADS valve to operable status within 14 days or in accordance with the Risk Informed Completion Time Program.

Action F.1 With one required ADS valve inoperable and one low pressure ECCS injection/spray subsystem inoperable, restore ADS valve to operable status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or in accordance with the Risk Informed Completion Time Program.

Action F.2 Restore low pressure ECCS injection/spray subsystem to operable status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or in accordance with the Risk Informed Completion Time Program.

TS 3.5.3 RCIC [Reactor Core Isolation Cooling] System Action A.2 With RCIC System inoperable, restore RCIC system to operable status within 14 days or in accordance with the Risk Informed Completion Time Program.

TS 3.6.1.2 Primary Containment Air Locks Action C.3 With one or more primary containment air locks inoperable for reasons other than Condition A or B, restore air lock to operable status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or in accordance with the Risk Informed Completion Time Program.

Note Not applicable if leakage exceeds limits or if loss of function.

TS 3.6.1.3 Primary Containment Isolation Valves (PCIVs)

Action A.1 With one or more penetration flow paths with one PCIV inoperable except due to leakage not within limit, isolate the affected penetration flow path by use of at least one closed and de-activated automatic valve, closed manual valve, blind flange, or check valve with flow through the valve secured within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months except for main steam line or in accordance with

the Risk Informed Completion Time Program, and within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months for main steam line or in accordance with the Risk Informed Completion Time Program.

Action A.2 The CT for the required action to verify the affected penetration flow path is isolated, has been modified by adding the words following isolation after once per 31 days.

Action E.1 With one or more penetration flow paths with one or more containment purge exhaust valves not within purge valve leakage limits, isolate the affected penetration flow path by use of at least one closed and de-activated automatic valve, closed manual valve, or blind flange within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or in accordance with the Risk Informed Completion Time Program.

Note Not applicable if there is a loss of function.

Action E.2 The CT for the required action to verify the affected penetration flow path is isolated, has been modified by adding the words following isolation after once per 31 days.

Action E.3 The CT for the required action to verify the affected penetration flow path is isolated, has been modified by adding the words following isolation after once per 92 days.

TS 3.6.1.6 Residual Heat Removal (RHR) Drywell Spray System Action A.1 With one RHR drywell spray subsystem inoperable, restore RHR drywell spray subsystem to operable status within 7 days or in accordance with the Risk Informed Completion Time Program.

TS 3.6.1.7 Suppression Chamber-to-Drywell Vacuum Breakers Action A.1 With one line with one or more suppression chamber-to-drywell vacuum breakers inoperable for opening, restore the vacuum breaker(s) to operable status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or in accordance with the Risk Informed Completion Time Program.

TS 3.6.2.3 Residual Heat Removal (RHR) Suppression Pool Cooling Action A.1 With one RHR suppression pool cooling subsystem inoperable, restore RHR suppression pool cooling subsystem to operable status within 7 days or in accordance with the Risk Informed Completion Time Program.

TS 3.6.2.4 Residual Heat Removal (RHR) Suppression Pool Spray Action A.1 With one RHR suppression pool spray subsystem inoperable, restore RHR suppression pool spray subsystem to operable status within 7 days or in accordance with the Risk Informed Completion Time Program.

TS 3.7.1 Service Water (SW) System and Ultimate Heat Sink (UHS)

Action C.1 With one SW subsystem inoperable for reasons other than Conditions A and B, restore SW subsystem to operable status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or in accordance with the Risk Informed Completion Time Program.

TS 3.7.5 Main Turbine Bypass System Action A.1 With requirements of the LCO not met, satisfy the requirements of the LCO within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months or in accordance with the Risk Informed Completion Time Program.

TS 3.8.1 AC [Alternating Current] Sources - Operating Action A.3 With one required offsite circuit inoperable, restore required offsite circuit to operable status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or in accordance with the Risk Informed Completion Time Program and within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months from discovery of both HPCS and Low Pressure Core Spray (LPCS) Systems with no offsite power or in accordance with the Risk Informed Completion Time Program.

Action C.2 With two required offsite circuits inoperable, restore one required offsite circuit to operable status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or in accordance with the Risk Informed Completion Time Program.

Action D.1 With one required offsite circuit inoperable and one required DG [diesel generator] inoperable, restore required offsite circuit to operable status within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months or in accordance with the Risk Informed Completion Time Program.

Action D.2 Restore required DG to operable status within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months or in accordance with the Risk Informed Completion Time Program.

TS 3.8.4 DC [Direct Current] Sources - Operating Action A.1 With a Division 1 or 2 DC electrical power subsystem inoperable, restore Division 1 and 2 DC electrical power subsystems to operable status within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months or in accordance with the Risk Informed Completion Time Program.

TS 3.8.7 Inverters - Operating Action A.1 With one emergency UPS [uninterruptible power supply] inverter inoperable, restore emergency UPS inverters to operable status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or in accordance with the Risk Informed Completion Time Program.

TS 3.8.8 Distribution Systems - Operating Action A.1 With one or both Division 1 and 2 AC electrical power distribution subsystems inoperable, restore Division 1 and 2 AC electrical power

distribution subsystem(s) to operable status within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or in accordance with the Risk Informed Completion Time Program.

Note Not applicable when loss of function can occur.

Action B.1 With one or both Division 1 and 2 120 VAC [Volts alternating current]

uninterruptible electrical power distribution subsystems inoperable, restore Division 1 and 2 120 VAC uninterruptible electrical power distribution subsystem(s) to operable status within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or in accordance with the Risk Informed Completion Time Program.

Note Not applicable when loss of function can occur.

Action C.1 With one or both Division 1 and 2 DC electrical power distribution subsystems inoperable, restore Division 1 and 2 DC electrical power distribution subsystem(s) to operable status within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months or in accordance with the Risk Informed Completion Time Program.

Note Not applicable when loss of function can occur.

2.2.4 Variations from TSTF-505, Revision 2 2.2.4.1 Application of the RICT Program to Modified Action Statements The following Conditions are modified to permit the application of a RICT:

TS 3.3.1.1 Reactor Protection System (RPS) Instrumentation Action A.1 With one or more required channels inoperable, place channel in trip within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months or in accordance with the Risk Informed Completion Time Program.