ML15317A307: Difference between revisions

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| document type = Letter, License-Operating (New/Renewal/Amendments) DKT 50, Safety Evaluation, Technical Specifications
| document type = Letter, License-Operating (New/Renewal/Amendments) DKT 50, Safety Evaluation, Technical Specifications
| page count = 159
| page count = 159
| project = CAC:MF5364
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}}
=Text=
{{#Wiki_filter: Mr. Bryan President and Chief Nuclear Officer Exelon Nuclear Nine Mile Point Nuclear Station, LLC 4300 Winfield Road Warrenville, IL 60555 November 30, 2015
SUBJECT: NINE MILE POINT NUCLEAR STATION, UNIT 2 -ISSUANCE OF AMENDMENT RE: ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER 425 (CAC NO. MF5364)
==Dear Mr. Hanson:==
The Commission has issued the enclosed Amendment No. 152 to Renewed Facility Operating License No. NPF-69 for the Nine Mile Point Nuclear Station, Unit No. 2 (NMP2). The amendment consists of changes to the Technical Specifications (TSs) in response to your application dated November 19, 2014 (Agencywide Documents Access and Management System (ADAMS) Accession No. ML 14329A353), as supplemented by letters dated July 10, 2015 (ADAMS Accession No. ML 15191A013), September 10, 2015 (ADAMS Accession No. ML 15254A069), and September 24, 2015 (ADAMS Accession No. ML 15271A029). This amendment revises the TSs to require that changes to specific surveillance frequencies will be made in accordance with Nuclear Energy Institute 04-10, Revision 1, "Risk-Informed Technical Specifications Initiative Sb, Risk-Informed Method for Control of Surveillance Frequencies" (ADAMS Accession No. ML071360456). The change is the adoption of NRG-approved Technical Specification Task Force (TSTF) Standard Technical Specifications Change Traveler TSTF-425, Revision 3, "Relocate Surveillance Frequencies to Licensee Control -RITSTF [Risk-Informed TSTF] Initiative Sb" (ADAMS Accession No. ML090850642). The Federal Register(FR) notice published on July 6, 2009 (74 FR 31996), announced the availability of TSTF-425, Revision 3. A copy of the related Safety Evaluation is enclosed. A Notice of Issuance will be included in the Commission's next regular biweekly Federal Register notice. Docket No. 50-410
===Enclosures:===
1. Amendment No. 152 to NPF-69 2. Safety Evaluation cc w/encls: Distribution via Listserv
Sincerely,, Brenda L. Mozafari, Sr. Project Manager Plant Licensing Branch 1-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation NINE MILE POINT NUCLEAR STATION, LLC EXELON GENERATION COMPANY. LLC DOCKET NO. 50-410 NINE MILE POINT NUCLEAR STATION, UNIT 2 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 152 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 November 19, 2014, as supplemented by letters dated July 10, September 10, and September 24, 2015, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act) and the Commission's rules and regulations set forth in 10 CFR Chapter I; B. The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C. There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations; D. The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E. The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied. 2. 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 -(2) Technical Specifications 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. 152, are hereby incorporated into this license. Exelon Generation Company, LLC shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan. 3. This license amendment is effective as of the date of its issuance and shall be implemented within 120 days.
===Attachment:===
Changes to the License and Technical Specifications Date of Issuance: November 30, 201 5 FOR THE NUCLEAR REGULATORY COMMISSION Travis L. Tate, Chief Plant Licensing Branch 1-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation ATTACHMENT TO LICENSE AMENDMENT NO. 152 TO RENEWED FACILITY OPERATING LICENSE NO. NPF-69 DOCKET NO. 50-410 Replace the following page of the Renewed Facility Operating License with the attached revised page. The revised page is identified by amendment number and contains marginal lines indicating the areas of change. Remove Page Insert Page Page4 Page 4 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 3.1.3-3 3.1.3-4 3.1.4-2 3.1.5-3 3.1.6-2 3.1.7-1 3.1.7-2 3.1.7-3 3.1.8-2 3.2.1-1 3.2.2-1 3.2.3-1 3.3.1.1-4 3.3.1.1-5 3.3.1.1-6 3.3.1.1-7 3.3.1.2-3 3.3.1.2-4 3.3.1.2-5 3.3.2.1-3 3.3.2.1-4 3.3.2.1-5 3.3.2.2-2 3.3.2.2-3 3.3.3.1-2 3.3.3.1-3 3.3.3.2-2 3.3.4.1-3 Insert Page 3.1.3-3 3.1.3-4 3.1.4-2 3.1.5-3 3.1.6-2 3.1.7-1 3.1.7-2 3.1.7-3 3.1.8-2 3.2.1-1 3.2.2-1 3.2.3-1 3.3.1.1-4 3.3.1.1-5 3.3.1.1-6 3.3.1.1-7 3.3.1.2-3 3.3.1.2-4 3.3.1.2-5 3.3.2.1-3 3.3.2.1-4 3.3.2.1-5 3.3.2.2-2 3.3.2.2-3 3.3.3.1-2 3.3.3.1-3 3.3.3.2-2 3.3.4.1-3 Remove Page 3.3.4.1-4 3.3.4.2-2 3.3.4.2.3 3.3.5.1-8 3.3.5.2-3 3.3.6.1-4 3.3.6.1-5 3.3.6.2-2 3.3.6.2-3 3.3.7.1-3 3.3.7.2-2 3.3.7.2-3 3.3.8.1-2 3.3.8.2-4 3.3.8.3-2 3.3.8.3-3 3.4.1-3 3.4.2-1 3.4.2-2 3.4.3-2 3.4.5-2 3.4.7-3 3.4.8-2 3.4.9-3 3.4.10-2 3.4.11-2 3.4.11-4 3.4.11-5 3.4.12-1 3.5.1-4 3.5.1-5 3.5.1-6 3.5.2-2 3.5.2-3 3.5.2-4 3.5.3-2 3.5.3-3 3.6.1.1-3 3.6.1.2-5 3.6.1.3-10 3.6.1.3-11 3.6.1.3-12 3.6.1.4-1 3.6.1.5-1 3.6.1.6-2 3.6.1.7-3 -2 -Insert Page 3.3.4.1-4 3.3.4.2-2 3.3.4.2.3 3.3.5.1-8 3.3.5.2-3 3.3.6.1-4 3.3.6.1-5 3.3.6.2-2 3.3.6.2-3 3.3.7.1-3 3.3.7.2-2 3.3.7.2-3 3.3.8.1-2 3.3.8.2-4 3.3.8.3-2 3.3.8.3-3 3.4.1-3 3.4.2-1 3.4.2-2 3.4.3-2 3.4.5-2 3.4.7-3 3.4.8-2 3.4.9-3 3.4.10-2 3.4.11-2 3.4.11-4 3.4.11-5 3.4.12-1 3.5.1-4 3.5.1-5 3.5.1-6 3.5.2-2 3.5.2-3 3.5.2-4 3.5.3-2 3.5.3-3 3.6.1.1-3 3.6.1.2-5 3.6.1.3-10 3.6.1.3-11 3.6.1.3-12 3.6.1.4-1 3.6.1.5-1 3.6.1.6-2 3.6.1.7-3 Remove Page 3.6.2.1-3 3.6.2.2-1 3.6.2.3-2 3.6.2.4-2 3.6.3.2-1 3.6.4.1-2 3.6.4.1-3 3.6.4.2-4 3.6.4.3-3 3.7.1-3 3.7.1-4 3.7.2-3 3.7.3-4 3.7.4-2 3.7.5-1 3. 7.6-1 3.8.1-5 3.8.1-6 3.8.1-7 3.8.1-8 3.8.1-9 3.8.1-10 3.8.1-11 3.8.1-12 3.8.1-13 3.8.1-14 3.8.1-15 3.8.1-16 3.8.1-17 3.8.1-18 3.8.3-3 3.8.4-2 3.8.4-3 3.8.4-4 3.8.6-2 3.8.6-3 3.8.7-2 3.8.8-3 3.8.9-2 3.9.1-2 3.9.2-1 3.9.2-2 3.9.3-1 3.9.5-1 3.9.6-1 3.9.7-1 -3 -Insert Page 3.6.2.1-3 3.6.2.2-1 3.6.2.3-2 3.6.2.4-2 3.6.3.2-1 3.6.4.1-2 3.6.4.1-3 3.6.4.2-4 3.6.4.3-3 3.7.1-3 3.7.1-4 3.7.2-3 3.7.3-4 3.7.4-2 3.7.5-1 3.7.6-1 3.8.1-5 3.8.1-6 3.8.1-7 3.8.1-8 3.8.1-9 3.8.1-10 3.8.1-11 3.8.1-12 3.8.1-13 3.8.1-14 3.8.1-15 3.8.1-16 3.8.1-17 3.8.1-18 3.8.3-3 3.8.4-2 3.8.4-3 3.8.4-4 3.8.6-2 3.8.6-3 3.8.7-2 3.8.8-3 3.8.9-2 3.9.1-2 3.9.2-1 3.9.2-2 3.9.3-1 3.9.5-1 3.9.6-1 3.9.7-1 Remove Page 3.9.8-3 3.9.9-3 3.10.2-2 3.10.3-3 3.10.4-3 3.10.4-4 3.10.5-2 3.10.5-3 3.10.6-2 3.10.8-3 3.10.8-4 5.5-13 -4 -Insert Page 3.9.8-3 3.9.9-3 3.10.2-2 3.10.3-3 3.10.4-3 3.10.4-4 3.10.5-2 3.10.5-3 3.10.6-2 3.10.8-3 3.10.8-4 5.5-13
* -4-(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. 152 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 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 manufacturer's 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, Ill). 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 117through 140, 141, 143, 144, 146, 147, 148, 150, 151, 152 ACTIONS (continued) CONDITION REQUIRED ACTION D. --------------NOTE--------------D.1 Restore compliance Not applicable when with BPWS. THERMAL POWER > 10% ATP. OR ------------------------------------D.2 Restore control rod Two or more inoperable to OPERABLE status. control rods not in compliance with banked position withdrawal sequence (BPWS) and not separated by two or more OPERABLE control rods. E. Required Action and E.1 Be in MODE 3. associated Completion Time of Condition A, C, or D not met. OR Nine or more control rods inoperable. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.1.3.1 Determine the position of each control rod. NMP2 3.1.3-3 Control Rod OPERABILITY 3.1.3 COMPLETION TIME 4 hours 4 hours 12 hours FREQUENCY In accordance with the Surveillance Frequency Control Pro ram (continued) Amendment 9+, 152 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE SR 3.1.3.2 Deleted Control Rod OPERABILITY 3.1.3 FREQUENCY SR 3.1.3.3 ------------------------------NOTE ----------------------------SR 3.1.3.4 NMP2 Not required to be performed until 31 days after the control rod is withdrawn and THERMAL POWER is greater than the LPSP of the RWM. Insert each withdrawn control rod at least one notch. Verify each control rod scram time from fully withdrawn to notch position 05 is s; 7 seconds. 3.1.3-4 In accordance with the Surveillance Frequency Control Proqram. In accordance with SR 3.1.4.1, SR 3.1.4.2, SR 3.1.4.3, and SR 3.1.4.4 (continued) Amendment 91, 130, 152 SURVEILLANCE REQUIREMENTS (continued) SR 3.1.4.2 SR 3.1.4.3 SR 3.1.4.4 NMP2 SURVEILLANCE Verify, for a representative sample, each tested control rod scram time is within the limits of Table 3.1.4-1 with reactor steam dome pressure :2'. 800 psig. Verify each affected control rod scram time is within the limits of Table 3.1.4-1 with any reactor steam dome pressure. Verify each affected control rod scram time is within the limits of Table 3.1.4-1 with reactor steam dome pressure :2'. 800 psig. 3.1.4-2 Control Rod Scram Times 3.1.4 FREQUENCY In accordance with the Surveillance Frequency Control Program Prior to declaring control rod OPERABLE after work on control rod or CRD System that could affect scram time Prior to exceeding 40% ATP after fuel movement within the affected core cell Prior to exceeding 40% RTP after work on control rod or CRD System that could affect scram time Amendment 91, 132, 152 Control Rod Scram Accumulators 3.1.5 ACTIONS CONDITION REQUIRED ACTION C. (continued) C.2 Declare the associated control rod inoperable. D. Required Action B.1 or D.1 ------------NOTE------------C.1 and associated Not applicable if all Completion Time not inoperable control met. rod scram accumulators are associated with fully inserted control rods. --------------------------------Place the reactor mode switch in the shutdown position. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.1.5.1 NMP2 Verify each control rod scram accumulator pressure is;::: 940 psig. 3.1.5-3 COMPLETION TIME 1 hour Immediately FREQUENCY In accordance with the Surveillance Frequency Control Pro ram Amendment 9+, 152 ACTIONS (continued) CONDITION B. Nine or more OPERABLE control rods not in compliance with BPWS. SURVEILLANCE REQUIREMENTS B.1 AND B.2 REQUIRED ACTION ------------NOTE-----------RWM may be bypassed as allowed by LCO 3.3.2.1. . Suspend withdrawal of control rods. Place the reactor mode switch in the shutdown position. SURVEILLANCE SR 3.1.6.1 NMP2 Verify all OPERABLE control rods comply with BPWS. 3.1.6-2 Rod Pattern Control 3.1.6 COMPLETION TIME Immediately 1 hour FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment Q.:t-, 152 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 A. One SLC subsystem A.1 Restore SLC subsystem inoperable. to OPERABLE status. B. Two SLC subsystems B.1 Restore one SLC inoperable. subsystem to OPERABLE status. c. Required Action and C.1 Be in MODE 3. associated Completion Time not met. AND C.2 Be in MODE 4. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.1.7.1 NMP2 Verify available volume of sodium pentaborate solution is within the limits of Figure 3.1.7-1. 3.1.7-1 SLC System 3.1.7 COMPLETION TIME 7 days 8 hours 12 hours 36 hours FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 125, 152 SURVEILLANCE REQUIREMENTS (continued) SR 3.1.7.2 SR 3.1.7.3 SR 3.1.7.4 SR 3.1.7.5 SR 3.1.7.6 NMP2 SURVEILLANCE Verify temperature of sodium pentaborate solution is 2". 70&deg;F. Verify temperature of pump suction piping up to the pump suction valve is;::: 70''F. Verify continuity of explosive charge. Verify the concentration of sodium pentaborate in solution is within the limits of Figure 3.1.7-1. Verify each SLC subsystem manual, power operated, and automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position, or can be aligned to the correct position. 3.1.7-2 SLC System 3.1.7 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Once within 24 hours after water or sodium pentaborate is added to solution Once within 24 hours after solution temperature is restored to 2". 70&deg;F In accordance with the Surveillance Frequency Control Program (continued) Amendment 9-+, 152 SLC System 3.1.7 SURVEILLANCE REQUIREMENTS (continued) SR 3.1.7.7 SR 3.1.7.8 SR 3.1.7.9 SR 3.1.7.10 NMP2 SURVEILLANCE Verify each pump develops a flow rate ?. 41.2 gpm at a discharge pressure ?. 1335 psig. Verify flow through one SLC subsystem from pump into reactor pressure vessel. Verify all heat traced piping between storage tank and pump suction valve is unblocked. Verify sodium pentaborate enrichment 92 atom percent B-10. FREQUENCY In accordance with the lnservice Testing Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Once within 24 hours after piping temperature is restored to ?. 70&deg;F Prior to addition to SLC tank 3.1.7-3 Amendment 91, 111, 117, 123, 140, 143, 151, 152 SURVEILLANCE REQUIREMENTS SURVEILLANCE SDV Vent and Drain Valves 3.1.8 FREQUENCY SR 3.1.8.1 -------------------------------NOTE ------------------------------SR 3.1.8.2 SR 3.1.8.3 NMP2 Not required to be met on vent and drain valves closed during periormance of SR 3.1.8.2. Verify each SDV vent and drain valve is open. Cycle each SDV vent and drain valve to the fully closed and fully open position. Verify each SDV vent and drain valve: a. Closes in s; 30 seconds after receipt of an actual or simulated scram signal; and b. Opens when the actual or simulated scram signal is reset. 3.1.8-2 In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 3.2 POWER DISTRIBUTION LIMITS APLHGR 3.2.1 3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR) LCO 3.2.1 All APLHGRs shall be less than or equal to the limits specified in the COLA. APPLICABILITY: THERMAL POWER 23% ATP. ACTIONS CONDITION REQUIRED ACTION A. Any APLHGR not within A.1 Restore APLHGR(s) to limits. within limits. B. Required Action and B.1 Reduce THERMAL POWER associated Completion to< 23% ATP. Time not met. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.2.1.1 NMP2 Verify all APLHGRs are less than or equal to the limits specified in the COLA. 3.2.1-1 COMPLETION TIME 2 hours 4 hours FREQUENCY Once within 12 hours after 23% RTP In accordance with the Surveillance Frequency Control Program Amendment 91, 140, 152 3.2 POWER DISTRIBUTION LIMITS 3.2.2 MINIMUM CRITICAL POWER RATIO (MCPR) MCPR 3.2.2 LCO 3.2.2 All MCPRs shall be greater than or equal to the MCPR operating limits specified in the COLR. APPLICABILITY: THERMAL POWER 2 23% RTP. ACTIONS CONDITION REQUIRED ACTION A. Any MCPR not within A.1 Restore MCPR(s) to limits. within limits. B. Required Action and B.1 Reduce THERMAL POWER associated Completion to< 23% RTP. Time not met. SURVEILLANCE REQUIREMENTS SR 3.2.2.1 NMP2 SURVEILLANCE Verify all MCPRs are greater than or equal to the limits specified in the COLA. 3.2.2-1 COMPLETION TIME 2 hours 4 hours FREQUENCY Once within 12 hours after 223% ATP In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 140, 152 3.2 POWER DISTRIBUTION LIMITS 3.2.3 LINEAR HEAT GENERATION RATE (LHGR) LHGR 3.2.3 LCO 3.2.3 All LHGRs shall be less than or equal to the limits specified in the COLA. APPLICABILITY: THERMAL 23% RTP. ACTIONS CONDITION REQUIRED ACTION A. Any LHGR not within A.1 Restore LHGR(s) to limits. within limits. B. Required Action and B.1 Reduce THERMAL POWER associated Completion to< 23% RTP. Time not met. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.2.3.1 NMP2 Verify all LHGRs are less than or equal to the limits specified in the COLA. 3.2.3-1 COMPLETION TIME 2 hours 4 hours FREQUENCY Once within 12 hours after ;:::23% ATP In accordance with the Surveillance Frequency Control Program Amendment 91, 140, 152 SURVEILLANCE REQUIREMENTS RPS Instrumentation 3.3.1.1 ---------------------------------------------------------N 0 TE -----------------------------------------------------------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 hours provided the associated Function Maintains RPS trip capability. SR 3.3.1.1.1 SR 3.3.1.1.2 SR 3.3.1.1.3 SR 3.3.1.1.4 NMP2 SURVEILLANCE Perform CHANNEL CHECK. Perform CHANNEL CHECK. ---------------------------NOTE-----------------------------Not required to be performed until 12 hours after THERMAL POWER 23% ATP. Verify the absolute difference between the average power range monitor (APRM) channels and the calculated power ::; 2% RTP while operating at 23% RTP. ---------------------------NOTE-----------------------------For Functions 1.a and 1.b, not required to be performed when entering MODE 2 from MODE 1 until 12 hours after entering MODE 2. Perform CHANNEL FUNCTIONAL TEST. FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) 3.3.1.1-4 Amendment91, 92, 123, 140, 151, 152 SURVEILLANCE REQUIREMENTS (continued) SR 3.3.1. 1.5 SR 3.3.1 .1.6 SR 3.3.1.1.7 SR 3.3.1.1.8 SR 3.3.1 .1.9 SR 3.3.1. 1. 10 SURVEILLANCE Verify the source range monitor (SAM) and intermediate range monitor (IRM) channels overlap. ---------------------------NOTE-----------------------------Only required to be met during entry into MODE 2 from MODE 1. Verify the IRM and APRM channels overlap. Calibrate the local power range monitors. Perform CHANNEL FUNCTIONAL TEST. Calibrate the trip units. --------------------------NOTES----------------------------1. For Function 2.a, not required to be performed when entering MODE 2 from MODE 1 until 12 hours after entering MODE2. 2. For Function 2.e, the CHANNEL FUNCTIONAL TEST only requires toggling the appropriate outputs of the APRM. Perform CHANNEL FUNCTIONAL TEST. RPS Instrumentation 3.3.1.1 FREQUENCY Prior to fully Withdrawing SR Ms In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) NMP2 3.3.1.1-5 Amendment Q1, 92, 151,152 SURVEILLANCE REQUIREMENTS (continued) SR 3.3.1.1.11 SR 3.3.1.1.12 SR 3.3.1.1.13 SR 3.3.1.1.14 SR 3.3.1.1.15 NMP2 SURVEILLANCE Perform CHANNEL CALIBRATION Perform CHANNEL FUNCTIONAL TEST. ----------------------------N 0 TES ----------------------------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 hours 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. Perform LOGIC SYSTEM FUNCTIONAL TEST. Verify Turbine Stop Valve -Closure, and Turbine Control Valve Fast Closure, Trip Oil Pressure -Low Functions are not bypassed when THERMAL POWER 26% RTP. 3.3.1.1-6 RPS Instrumentation 3.3.1.1 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) 152 SURVEILLANCE REQUIREMENTS (continued) SR 3.3.1.1.16 SR 3.3.1.1.17 NMP2 SURVEILLANCE Deleted --------------------------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. 3.3.1.1-7 RPS Instrumentation 3.3.1.1 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9+,-9-2, 152 SURVEILLANCE REQUIREMENTS SRM Instrumentation 3.3.1.2 ---------------------------------------------------------N 0 TE -----------------------------------------------------------Refer to Table 3.3.1.2-1 to determine which SRs apply for each applicable MODE or other specified condition. SR 3.3.1.2.1 SR 3.3.1.2.2 SR 3.3.1.2.3 NMP2 SURVEILLANCE Perform CHANNEL CHECK. --------------------------NOTES----------------------------1. Only required to be met during CORE ALTERATIONS. 2. One SRM may be used to satisfy more than one of the following. Verify an OPERABLE SRM detector is located in: a. The fueled region; b. The core quadrant where CORE AL TERA TIONS are being performed when the associated SRM is included in the fueled region; and c. A core quadrant adjacent to where CORE ALTERATIONS are being performed, when the associated SRM is included in the fueled region. Perform CHANNEL CHECK. 3.3.1.2-3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 9+, 152 SURVEILLANCE REQUIREMENTS (continued} SA 3.3.1 .2.4 SR 3.3.1.2.5 SR 3.3.1.2.6 NMP2 SURVEILLANCE ---------------------------NOTE-----------------------------Not required to be met with less than or equal to four fuel assemblies adjacent to the SRM and no other fuel assemblies in the associated core quadrant. Verify count rate is: a. ?: 3.0 cps with a signal to noise ratio ?: 2: 1; or b. > 1.3 cps with a signal to noise ratio ?: 5: 1. ---------------------------NOTE-----------------------------The determination of signal to noise ratio is not required to be met with less than or equal to four fuel assemblies adjacent to the SRM and no other fuel assemblies in the associated core quadrant. Perform CHANNEL FUNCTIONAL TEST and determination of signal to noise ratio. ---------------------------NOTE-----------------------------Not required to be performed until 12 hours after IRMs on Range 2 or below. Perform CHANNEL FUNCTIONAL TEST and determination of signal to noise ratio. 3.3.1.2-4 SRM Instrumentation 3.3.1.2 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 94-, 152 SURVEILLANCE REQUIREMENTS continued SR 3.3.1.2.7 NMP2 SURVEILLANCE --------------------------NOTES----------------------------1. Neutron detectors are excluded. 2. Not required to be performed until 12 hours after IRMs on Range 2 or below. Perform CHANNEL CALIBRATION. 3.3.1.2-5 SRM Instrumentation 3.3.1.2 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9-1-,152 Control Rod Block Instrumentation 3.3.2.1 ACTIONS (continued) CONDITION E. One or more Reactor Mode Switch -Shutdown Position channels inoperable. SURVEILLANCE REQUIREMENTS E.1 AND E.2 REQUIRED ACTION Suspend control rod withdrawal. Initiate action to fully insert all insertable control rods in core cells containing one or more fuel assemblies. COMPLETION TIME Immediately Immediately --------------------------------------------------------N 0 TES ----------------------------------------------------------1. Refer to Table 3.3.2.1-1 to determine which SRs apply for each Control Rod Block Function. 2. When an RBM channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours provided the associated Function maintains control rod block capability. SR 3.3.2.1.1 NMP2 SURVEILLANCE ---------------------------NOTE-----------------------------Not required to be performed until 1 hour after any control rod is withdrawn at 10% RTP in MODE 2. Perform CHANNEL FUNCTIONAL TEST. 3.3.2.1-3 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment 9-+. 152 Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS (continued) SR 3.3.2.1.2 SR 3.3.2.1.3 SR 3.3.2. 1.4 NMP2 SURVEILLANCE ---------------------------NOTE-----------------------------Not required to be performed until 1 hour after THERMAL POWER is$; 10% ATP in MODE 1. Perform CHANNEL FUNCTIONAL TEST. Perform CHANNEL FUNCTIONAL TEST. ---------------------------NOTE-----------------------------Neutron detectors are excluded. Verify the ABM: a. Low Power Range -Upscale Function is not bypassed when APRM Simulated Thermal Power is 28% and < 63% ATP and a peripheral control rod is not selected. b. Intermediate Power Range -Upscale Function is not bypassed when APRM Simulated Thermal Power is 63% and < 83% ATP and a peripheral control rod is not selected. c. High Power Range -Upscale Function is not bypassed when APRM Simulated Thermal Power is 83% RTP and a peripheral control rod is not selected. 3.3.2.1-4 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 123, 152 Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS (continued) SR 3.3.2.1.5 SR 3.3.2.1.6 SR 3.3.2.1.7 SR 3.3.2.1.8 NMP2 SURVEILLANCE Verify the RWM is not bypassed when THERMAL POWER is::;; 10% RTP. ---------------------------NOTE-----------------------------Not required to be performed until 1 hour after reactor mode switch is in the shutdown position. Perform CHANNEL FUNCTIONAL TEST. ---------------------------NOTE-----------------------------Neutron detectors are excluded. Perform CHANNEL CALIBRATION. Verify control rod sequences input to the RWM are in conformance with BPWS. 3.3.2.1-5 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Prior to declaring RWM OPERABLE following loading of sequence into RWM Amendment 94-, 152 Feedwater System and Main Turbine High Water Level Trip Instrumentation 3.3.2.2 ACTIONS (continued) CONDITION C. Required Action and C.1 associated Completion Time not met. REQUIRED ACTION --------------NOTE--------------Only applicable if inoperable channel is the result of an inoperable feedwater pump breaker. Remove affected feedwater pump(s) from service. COMPLETION TIME 4 hours C.2 Reduce THERMAL POWER 4 hours to< 23% ATP. SURVEILLANCE REQUIREMENTS ---------------------------------------------------------N 0 TE --------------------------------------------------------------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 hours provided feedwater system and main turbine high water level trip capability is maintained. SURVEILLANCE SR 3.3.2.2.1 Perform CHANNEL CHECK. SR 3.3.2.2.2 Perform CHANNEL FUNCTIONAL TEST. NMP2 3.3.2.2-2 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 140,152 Feedwater System and Main Turbine High Water Level Trip Instrumentation 3.3.2.2 SURVEILLANCE REQUIREMENTS (continued) SR 3.3.2.2.3 SR 3.3.2.2.4 NMP2 SURVEILLANCE Perform CHANNEL CALIBRATION. The Allowable Value shall be 203.8 inches. Perform LOGIC SYSTEM FUNCTIONAL TEST, including breaker and valve actuation. 3.3.2.2-3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9+,152 ACTIONS (continued) CONDITION D. Required Action and D.1 associated Completion Time of Condition C not met. E. As required by E.1 Required Action D.1 and referenced in Table 3.3.3.1-1. F. As required by F.1 Required Action D.1 and referenced in Table 3.3.3.1-1. SURVEILLANCE REQUIREMENTS REQUIRED ACTION Enter the Condition referenced in Table 3.3.3.1-1 for the channel. Be in MODE3. Initiate action in accordance with Specification 5.6.6. PAM Instrumentation 3.3.3.1 COMPLETION TIME Immediately 12 hours Immediately --------------------------------------------------------NOTES ----------------------------------------------------------1. These SRs apply to each Function in Table 3.3.3.1-1, except where identified in the SR. 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 hours provided the other required channel in the associated Function is OPERABLE. SURVEILLANCE SR 3.3.3.1.1 Perform CHANNEL CHECK. NMP2 3.3.3.1-2 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment 9+,152 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE SR 3.3.3.1.2 Perform CHANNEL CALIBRATION. NMP2 3.3.3.1-3 PAM Instrumentation 3.3.3.1 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 91, 124,152 SURVEILLANCE REQUIREMENTS Remote Shutdown System 3.3.3.2 ---------------------------------------------------------N 0 TE -----------------------------------------------------------When an instrumentation 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 hours. SR 3.3.3.2. i SR 3.3.3.2.2 SR 3.3.3.2.3 NMP2 SURVEILLANCE Perform CHANNEL CHECK for each required instrumentation channel that is normally energized. Verify each required control circuit and transfer switch is capable of performing the intended functions. Perform CHANNEL CALIBRATION for each required instrumentation channel. 3.3.3.2-2 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9+,152 EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS ---------------------------------------------------------N 0 TE -------------------------------------------------------------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 hours provided the associated Function maintains EOC-RPT trip capability. SR 3.3.4.1.1 SR 3.3.4. 1.2 SR 3.3.4. 1.3 SR 3.3.4.1.4 SR 3.3.4.1.5 NMP2 SURVEILLANCE Perform CHANNEL FUNCTIONAL TEST. Perform CHANNEL CALIBRATION. The Allowable Values shall be: a. TSV -Closure: 7% closed; and b. TCV Fast Closure, Trip Oil Pressure -Low: ? 465 psig. Perform LOGIC SYSTEM FUNCTIONAL TEST, including breaker actuation. Verify TSV -Closure and TCV Fast Closure, Trip Oil Pressure -Low Functions are not bypassed when THERMAL POWER is? 26% ATP. ------------------------------NOTE-----------------------------Breaker arc suppression time may be assumed from the most recent performance of SR 3.3.4.1.6. Verify the EOC-RPT SYSTEM RESPONSE TIME is within limits. 3.3.4.1-3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 140,152 SURVEILLANCE REQUIREMENTS continued SR 3.3.4.1.6 NMP2 SURVEILLANCE Determine RPT breaker arc suppression time. 3.3.4.1-4 EOC-RPT Instrumentation 3.3.4.1 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9+,152 ACTIONS (continued) CONDITION B. One Function with B.1 ATWS-RPT trip capability not maintained. c. Both Functions with C.1 ATWS-RPT trip capability not maintained. D. Required Action and D.1 associated Completion Time not met. OR 0.2 SURVEILLANCE REQUIREMENTS ATWS-RPT Instrumentation 3.3.4.2 REQUIRED ACTION COMPLETION Tl ME Restore AlWS-RPT trip 72 hours capability. Restore AlWS-RPT trip 1 hour capability for one Function. Remove the associated 6 hours recirculation pump breaker(s) from service. 6 hours Be in MODE2. ---------------------------------------------------------N 0 TE -----------------------------------------------------------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 hours provided the associated Function maintains A TWS-RPT trip capability. SURVEILLANCE SR 3.3.4.2.1 Perform CHANNEL CHECK. NMP2 3.3.4.2-2 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment 9-+,152 ATWS-RPT Instrumentation 3.3.4.2 SURVEILLANCE REQUIREMENTS (continued) SR 3.3.4.2.2 SR 3.3.4.2.3 SR 3.3.4.2.4 SR 3.3.4.2.5 SR 3.3.4.2.6 NMP2 SURVEILLANCE Perform CHANNEL FUNCTIONAL TEST. Calibrate the analog trip modules. Verify, for the Reactor Vessel Steam Dome Pressure -High Function, the low frequency motor generator trip is not bypassed for> 29 seconds when THERMAL POWER is > 5% ATP. Perform CHANNEL CALIBRATION. The Allowable Values shall be: a. Reactor Vessel Water Level -Low Low, Level 2: 101.8 inches; and b. Reactor Vessel Steam Dome Pressure -High: ::;; 1080 psig. Perform LOGIC SYSTEM FUNCTIONAL TEST, including breaker actuation. 3.3.4.2-3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Su rvei I lance Frequency Control Program Amendment 9+,152 SURVEILLANCE REQUIREMENTS ECCS Instrumentation 3.3.5.1 --------------------------------------------------------N 0 TES ----------------------------------------------------------1. Refer to Table 3.3.5.1-1 to determine which SRs apply for each ECCS Function. 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed as follows: (a) for up to 6 hours for Functions 3.e, 3.g, 3.h, and 3.i; and (b) for up to 6 hours for Functions other than 3.e, 3.g, 3.h, and 3.i, 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 NMP2 3.3.5.1-8 Amendment 9+,152 RCIC System Instrumentation 3.3.5.2 SURVEILLANCE REQUIREMENTS --------------------------------------------------------N 0 TES ----------------------------------------------------------1. Refer to Table 3.3.5.2-1 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 hours for Functions 4 and 5; and (b) for up to 6 hours for Functions 1, 2, and 3 provided the associated Function maintains RCIC initiation capability. SURVEILLANCE FREQUENCY SR 3.3.5.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.5.2.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.5.2.3 Calibrate the trip units. In accordance with the Surveillance Frequency Control Program SR 3.3.5.2.4 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.5.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program NMP2 3.3.5.2-3 Amendment 9-1-,152 Primary Containment Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS --------------------------------------------------------N 0 TES ----------------------------------------------------------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 hours 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 3.3.6.1-4 Amendment 91, 147,152 Primary Containment Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS continued SR 3.3.6.1.7 NMP2 SURVEILLANCE -------------------------------NOTE-----------------------------The sensor response time may be assumed to be the design sensor response time. FREQUENCY Verify the ISOLATION SYSTEM RESPONSE TIME In accordance with is within limits. the Surveillance Frequency Control Program 3.3.6.1-5 Amendment 9+, 152 Secondary Containment Isolation Instrumentation 3.3.6.2 ACTIONS CONDITION C. (continued) SURVEILLANCE REQUIREMENTS REQUIRED ACTION C.1.2 AND C.2.1 OR C.2.2 Declare associated secondary containment isolation valves inoperable. Place the associated standby gas treatment (SGT) subsystem in operation. Declare associated SGT subsystem inoperable. COMPLETION TIME 1 hour 1 hour 1 hour --------------------------------------------------------N 0 TES ----------------------------------------------------------1. Refer to Table 3.3.6.2-1 to determine which SRs apply for each Secondary Containment Isolation Function. 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function maintains isolation capability. SURVEILLANCE SR 3.3.6.2.1 Perform CHANNEL CHECK. NMP2 3.3.6.2-2 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment 9-1-, 152 Secondary Containment Isolation Instrumentation 3.3.6.2 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE SR 3.3.6.2.2 Perform CHANNEL FUNCTIONAL TEST. SR 3.3.6.2.3 Calibrate the trip unit. SR 3.3.6.2.4 Perform CHANNEL CALIBRATION. SR 3.3.6.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. NMP2 3.3.6.2-3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9+,152 SURVEILLANCE REQUIREMENTS CREF System Instrumentation 3.3.7.1 --------------------------------------------------------N 0 TES ----------------------------------------------------------1. Refer to Table 3.3.7.1-1 to determine which SRs apply for each 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 hours provided the associated Function maintains CREF initiation capability. SURVEILLANCE FREQUENCY SR 3.3.7.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.7.1.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SA 3.3.7.1.3 Calibrate the trip units. In accordance with the Surveillance Frequency Control Program SR 3.3.7.1.4 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.7.1.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program NMP2 3.3.7.1-3 Amendment 9+,152 Mechanical Vacuum Pump Isolation Instrumentation 3.3.7.2 ACTIONS (continued) CONDITION C. Required Action and associated Completion Time not met. SURVEILLANCE REQUIREMENTS C.1 OR C.2 OR C.3 OR C.4 REQUIRED ACTION Isolate the associated mechanical vacuum pump(s). Remove the associated mechanical vacuum pump breaker(s) from service. Isolate the main steam lines. Be in MODE 3. COMPLETION TIME 12 hours 12 hours 12 hours 12 hours ---------------------------------------------------------N 0 TE -----------------------------------------------------------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 hours provided mechanical vacuum pump isolation capability is maintained. SURVEILLANCE SR 3.3. 7 .2.1 Perform CHANNEL CHECK. SR 3.3.7.2.2 Perform CHANNEL FUNCTIONAL TEST. NMP2 3.3.7.2-2 FREQUENCY In accordance with the Surveillance Frequency Control Proa ram In accordance with the Surveillance Frequency Control Program (continued) Amendment 9+, 152 Mechanical Vacuum Pump Isolation Instrumentation 3.3.7.2 SURVEILLANCE REQUIREMENTS (continued) SR 3.3.7.2.3 SR 3.3.7.2.4 NMP2 SURVEILLANCE Perform CHANNEL CALIBRATION. The Allowable Value shall be 3.6 x full power background. Perform LOGIC SYSTEM FUNCTIONAL TEST including isolation valve and mechanical vacuum pump breakers actuation. 3.3.7.2-3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 SURVEILLANCE REQUIREMENTS LOP Instrumentation 3.3.8.1 --------------------------------------------------------NOTES ----------------------------------------------------------1. Refer to Table 3.3.8.1-1 to determine which SRs apply for each LOP Function. 2. When.a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 2 hours provided the associated Function maintains LOP initiation capability. SURVEILLANCE SR 3.3.8.1.1 Perform CHANNEL FUNCTIONAL TEST. SR 3.3.8.1.2 Perform CHANNEL CALIBRATION. SR 3.3.8.1.3 Perform LOGIC SYSTEM FUNCTIONAL TEST. NMP2 3.3.8.1-2 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 RPS Electric Power Monitoring -Logic 3.3.8.2 SURVEILLANCE REQUIREMENTS ---------------------------------------------------------N 0 TE -----------------------------------------------------------When an RPS electric power monitoring assembly is placed in an inoperable status solely for performance of required Surveillances, entry into the associated Conditions and Required Actions may be delayed for up to 6 hours provided the other RPS electric power monitoring assembly for the associated RPS logic bus maintains trip capability. SURVEILLANCE FREQUENCY SR 3.3.8.2.1 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.8.2.2 Perform CHANNEL CALIBRATION. The In accordance Allowable Values shall be: with the Surveillance a. Overvoltage (with time delay set to Frequency Control :::;; 2.5 seconds) Program Bus A:::;; 130.2 V Bus B:::;; 129.8 V b. Undervoltage (with time delay set to :::;; 2.5 seconds) Bus A:::::: 115.5 V Bus B :::::: 114.2 V c. Underfrequency (with time delay set to s; 2.5 seconds) Bus A:::: 57.5 Hz Bus B 2 57.5 Hz SR 3.3.8.2.3 Perform a system functional test. In accordance with the Surveillance Frequency Control Program NMP2 3.3.8.2-4 Amendment 9+;-9-9, 152 ACTIONS (continued) CONDITION D. Required Action and associated Completion Time of Condition A or B not met in MODE 5 with any control rod withdrawn from a core cell containing one or more fuel assemblies. SURVEILLANCE REQUIREMENTS D.1 RPS Electric Power Monitoring -Scram Solenoids 3.3.8.3 REQUIRED ACTION Initiate action to fully insert all insertable control rods in core cells containing one or more fuel assemblies. COMPLETION TIME Immediately ---------------------------------------------------------N 0 TE -----------------------------------------------------------When an RPS electric power monitoring assembly is placed in an inoperable status solely for performance of required Surveillances, entry into the associated Conditions and Required Actions may be delayed for up to 6 hours provided the other RPS electric power monitoring assembly for the associated RPS scram solenoid bus maintains trip capability. SURVEILLANCE SR 3.3.8.3.1 Perform CHANNEL FUNCTIONAL TEST. NMP2 3.3.8.3-2 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment ff-1-,152 RPS Electric Power Monitoring -Scram Solenoids 3.3.8.3 SURVEILLANCE REQUIREMENTS (continued) SR 3.3.8.3.2 SR 3.3.8.3.3 NMP2 SURVEILLANCE Perform CHANNEL CALIBRATION. The Allowable Values shall be: a. Overvoltage (with time delay set to s 2.5 seconds) Bus As 127.6 V Bus B s 127.6 V b. Undervoltage (with time delay set to s 2.5 seconds) Bus A 113.0 V Bus B 113.6 V c. Underfrequency (with time delay set to s 2.5 seconds) Bus 57.5 Hz Bus B 57.5 Hz Perform a system functional test. 3.3.8.3-3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9+,-99, 152 SURVEILLANCE REQUIREMENTS SURVEILLANCE Recirculation Loops Operating 3.4.1 FREQUENCY SR 3.4.1.1 ------------------------------N 0 TE-----------------------------NMP2 Not required to be performed until 24 hours after both recirculation loops are in operation. Verify jet pump loop flow mismatch with both recirculation loops in operation is: a. $ 10% of rated core flow when operating at an effective core flow < 70% of rated core flow; and b. ::; 5% of rated core flow when operating at an effective core flow 70% of rated core flow. 3.4.1-3 In accordance with the Surveillance Frequency Control Program Amendment Q..:1.,-92, 152 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.2 Flow Control Valves (FCVs) FCVs 3.4.2 LCO 3.4.2 A recirculation loop FCV shall be OPERABLE in each operating recirculation loop. APPLICABILITY: MODES 1 and 2. ACTIONS ---------------------------------------------------------N 0 TE -----------------------------------------------------------Separate Condition entry is allowed for each FCV. CONDITION REQUIRED ACTION A. One or two required A.1 Lock up the FCV. FCVs inoperable. B. Required Action and B.1 Be in MODE 3. associated Completion Time not met. SURVEILLANCE REQUIREMENTS SR 3.4.2.1 NMP2 SURVEILLANCE Verify each FCV fails "as is" on loss of hydraulic pressure at the hydraulic unit. 3.4.2-1 COMPLETION TIME 4 hours 12 hours FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment 9-+, 152 SURVEILLANCE REQUIREMENTS continued SR 3.4.2.2 NMP2 SURVEILLANCE Verify average rate of each FCV movement is: a. ::; 11 % of stroke per second for opening; and b. :::; 11 % of stroke per second for closing. 3.4.2-2 FCVs 3.4.2 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 SURVEILLANCE REQUIREMENTS SR 3.4.3.1 NMP2 SURVEILLANCE -----------------------------1. Not required to be performed until 4 hours after associated recirculation loop is in operation. 2. Not required to be performed until 24 hours after> 23% RTP. Verify at least two of the following criteria (a, b, and c) are satisfied for each operating recirculation loop: a. Jet pump loop flow versus flow control valve position differs by $ 1 0% from established patterns. b. Jet pump loop flow versus recirculation loop drive flow differs by $ 10% from established patterns. c. Each jet pump diffuser to lower plenum differential pressure differs by $ 20% from established patterns. 3.4.3-2 Jet Pumps 3.4.3 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 91, 140, 152 ACTIONS (continued) CONDITION C. Required Action and associated Completion Time of Condition A or B not met. Pressure boundary LEAKAGE exists. REQUIRED ACTION C.1 Be in MODE 3. C.2 Be in MODE4. SURVEILLANCE REQUIREMENTS SR 3.4.5.1 NMP2 SURVEILLANCE Verify RCS unidentified and identified LEAKAGE and unidentified LEAKAGE increase are within limits. 3.4.5-2 RCS Operational LEAKAGE 3.4.5 COMPLETION TIME 12 hours 36 hours FREQUENCY In accordance with the SuNeillance Frequency Control Program Amendment 9+, 152 RCS Leakage Detection Instrumentation 3.4.7 SURVEILLANCE REQUIREMENTS ----------------------------------------------------------N 0 TE ----------------------------------------------------------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 hours provided the other required leakage detection instrumentation is OPERABLE. SURVEILLANCE FREQUENCY SR 3.4.7.1 Perform CHANNEL CHECK of required drywell In accordance atmospheric monitoring system. with the Surveillance Frequency Control Program SR 3.4.7.2 Perform CHANNEL FUNCTIONAL TEST of the In accordance drywall floor drain tank fill rate with the monitoring system. Surveillance Frequency Control Program SR 3.4.7.3 Perform source check of required drywell In accordance with atmospheric monitoring system. the Surveillance Frequency Control Program SR 3.4.7.4 Perform CHANNEL FUNCTIONAL TEST of required In accordance with drywell atmospheric monitoring system. the Surveillance Frequency Control Program SR 3.4.7.5 Perform CHANNEL CALIBRATION of required In accordance with leakage detection instrumentation. the Surveillance Frequency Control Program NMP2 3.4.7-3 Amendment 91 , 139, 152 ACTIONS CONDITION REQUIRED ACTION B. (continued) B.2.2.1 Be in MODE 3. B.2.2.2 Be in MODE 4. SURVEILLANCE REQUIREMENTS SR 3.4.8.1 NMP2 SURVEILLANCE ---------------------------NOTE-------------------------------Only required to be performed in MODE 1. Verify reactor coolant DOSE EQUIVALENT 1-131 specific activity is s; 0.2 &#xb5;Ci/gm. 3.4.8-2 RCS Specific Activity 3.4.8 COMPLETION TIME 12 hours 36 hours FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 RHR Shutdown Cooling System -Hot Shutdown 3.4.9 SURVEILLANCE REQUIREMENTS SR 3.4.9.1 SR 3.4.9.2 NMP2 SURVEILLANCE ---------------------------NOTE-----------------------------Not required to be met until 2 hours after reactor steam dome pressure is less than the AHR cut-in permissive pressure. Verify one AHR shutdown cooling subsystem or recirculation pump is operating. ---------------------------NOTE-----------------------------Not required to be performed until 12 hours after reactor steam dome pressure is less than the AHR cut-in permissive pressure. Verify AHR shutdown cooling subsystem Locations susceptible to gas accumulation are sufficiently filled with water. 3.4.9-3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 91, 150, 152 AHR Shutdown Cooling System -Cold Shutdown 3.4.10 ACTIONS (continued) CONDITION B. No AHR shutdown cooling subsystem in operation. No recirculation pump in operation. B.1 AND B.2 REQUIRED ACTION Verify reactor coolant circulating by an alternate method. Monitor reactor coolant temperature and pressure. SURVEILLANCE REQUIREMENTS SR 3.4.10.1 SR 3.4.10.2 NMP2 SURVEILLANCE Verify one RHR shutdown cooling subsystem or recirculation pump is operating. Verify AHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water. 3.4.10-2 COMPLETION TIME 1 hour from discovery of no reactor coolant circulation Once per 12 hours thereafter Once per hour FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 91, 150, 152 ACTIONS (continued) CONDITION REQUIRED ACTION C. -----------NOTE-----------------Required Action C.2 C.1 Initiate action to restore parameter(s) to within limits. shall be completed if this Condition is entered. ------------------------------------AND Requirements of the LCO not met in other than MODES 1 , 2, and 3. C.2 Determine RCS is acceptable for operation. SURVEILLANCE REQUIREMENTS SR 3.4.11.1 NMP2 SURVEILLANCE ---------------------------NOTE-----------------------------Only required to be performed during RCS heatup and cooldown operations, and RCS system leakage and hydrostatic testing. Verify: a. RCS pressure and RCS temperature are within the applicable limits specified in the PTLR; b. RCS heatup and cooldown rates are within limits specified in the PTLR; and c. RCS temperature change during system leakage and hydrostatic testing is maintained within limits specified in the PTLR. 3.4.11-2 RCS PIT Limits 3.4.11 COMPLETION TIME Immediately Prior to entering MODE 2 or3 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 145, 152 SURVEILLANCE REQUIREMENTS (continued} SR 3.4.11.5 SR 3.4.11.6 SR 3.4.11.7 NMP2 SURVEILLANCE ----------------------------NOTE-----------------------------Only required to be met in single loop operation with THERMAL POWER :s 30% ATP or the operating jet pump loop flow :s 50% rated jet pump loop flow. Verify the difference between the bottom head coolant temperature and the RPV coolant temperature is within limits specified in the PTLR. ----------------------------NOTE-----------------------------Only required to be met in single loop operation when the idle recirculation loop is not isolated from the APV, and with THERMAL POWER :s 30% ATP or the operating jet pump loop flow s 50% rated jet pump loop flow. Verify the difference between the reactor coolant temperature in the recirculation loop not in operation and the RPV coolant temperature is within limits specified in the PTLR. ----------------------------NOTE-----------------------------Only required to be performed when tensioning the reactor vessel head bolting studs. Verify reactor vessel flange and head flange temperatures are within limits specified in the PTLR. 3.4.11-4 RCS PIT Limits 3.4.11 FREQUENCY Once within 15 minutes prior to an increase in THERMAL POWER or an increase in jet pump loop flow Once within 15 minutes prior o an increase in THERMAL POWER or an increase in jet pump loop flow In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 145, 152 SURVEILLANCE REQUIREMENTS (continued) SR 3.4.11.8 SR 3.4.11.9 NMP2 SURVEILLANCE ----------------------------NOTE-----------------------------Not required to be performed until 30 minutes after RCS temperatures 80&deg;F in MODE 4. Verify reactor vessel flange and head flange temperatures are within limits specified in the PTLR. ----------------------------NOTE-----------------------------Not required to be performed until 12 hours after RCS temperature s 90&deg;F in MODE 4. Verify reactor vessel flange and head flange temperatures are within limits specified in the PTLR. 3.4.11-5 RCS Prr Limits 3.4.11 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 91, 145,152 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12 Reactor Steam Dome Pressure Reactor Steam Dome Pressure 3.4.12 LCO 3.4.12 The reactor steam dome pressure shall be ::; 1035 psig. APPLICABILITY: MODES 1 and 2. ACTIONS CONDITION REQUIRED ACTION A. Reactor steam dome A.1 Restore reactor steam pressure not within dome pressure to limit. within limit. 8. Required Action and B.1 Be in MODE 3. associated Completion Time not met. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.4.12.1 NMP2 Verify reactor steam dome pressure is ::; 1035 psig. 3.4.12-1 COMPLETION TIME 15 minutes 12 hours FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 SURVEILLANCE REQUIREMENTS SR 3.5.1.1 SR 3.5.1.2 SR 3.5.1.3 NMP2 SURVEILLANCE Verify, for each ECCS injection/spray subsystem, locations susceptible to gas accumulation are sufficiently filled with water. ---------------------------NOTE ----------------------------Low pressure coolant injection (LPCI) subsystems may be considered OPERABLE during alignment and operation for decay heat removal with reactor steam dome pressure less than the residual heat removal cut-in permissive pressure in MODE 3, if capable of being manually realigned and not otherwise inoperable. ---------------------------NOTE ----------------------------Not required to be met for system vent paths opened under administrative control Verify each ECCS injection/spray subsystem manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position. Verify: a. For each ADS nitrogen receiver discharge header, the pressure is 2'. 160 psig; and b. For each ADS nitrogen receiver tank, the pressure is 2'. 334 psig. 3.5.1-4 ECCS -Operating 3.5.1 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 150, 152 SURVEILLANCE REQUIREMENTS (continued) SR 3.5.1.4 SR 3.5.1.5 SR 3.5.1.6 SR 3.5.1.7 NMP2 SURVEILLANCE Verify each ECCS pump develops the specified flow rate with the specified developed head. SYSTEM LPCS LPCS A, B LPCIC HPCS TOTAL FLOW RATE DEVELOPED HEAD 2 6350 gpm 2 7450 gpm 2 7450 gpm 2 6350 gpm 2 284 psid 2 127 psid 2 140 psid 2. 327 psid -----------------------------NOTE-----------------------------Vessel injection/spray may be excluded. Verify each ECCS injection/spray subsystem actuates on an actual or simulated automatic initiation signal. -----------------------------NOTE------------------------------Valve actuation may be excluded. Verify the ADS actuates on an actual or simulated automatic initiation signal. -----------------------------NOTE------------------------------Not required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test. Verify each required ADS valve actuator strokes when manually actuated. 3.5.1-5 ECCS -Operating 3.5.1 FREQUENCY ln accordance with the lnservice Testing Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 9+, 152 SURVEILLANCE REQUIREMENTS continued SR 3.5.1.8 NMP2 SURVEILLANCE -----------------------------NOTE------------------------------1 nstrumentation response time may be assumed to be the design instrumentation response time. Verify the ECCS RESPONSE TIME for each ECCS injection/spray subsystem is within limits. 3.5.1-6 ECCS -Operating 3.5.1 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9-+, 152 ACTIONS (continued) CONDITION D. Required Action C.2 and associated Completion Time not met. D.1 REQUIRED ACTION Initiate action to restore secondary containment to OPERABLE status. ECCS -Shutdown 3.5.2 COMPLETION TIME Immediately D.2 Initiate action to Immediately restore one standby AND D.3 gas treatment subsystem to OPERABLE status. Initiate action to restore isolation capability in each required secondary containment penetration flow path not isolated. SURVEILLANCE REQUIREMENTS SR 3.5.2.1 NMP2 SURVEILLANCE Verify, for each required low pressure ECCS injection/spray subsystem, the suppression pool water level is 195 ft. 3.5.2-2 Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment 9-+,152 SURVEILLANCE REQUIREMENTS (continued) SR 3.5.2.2 SR 3.5.2.3 SR 3.5.2.4 NMP2 SURVEILLANCE Verify, for the required High Pressure Core Spray (HPCS) System, the: a. Suppression pool water level is 195 ft; or b. Condensate storage tank B water level 26.9 ft. Verify, for each required ECCS injection/ spray subsystem, locations susceptible to gas accumulation are sufficiently filled with water. ----------------------------NOTE----------------------------------One low pressure coolant injection (LPCI) subsystem may be considered OPERABLE during alignment and operation for decay heat removal, if capable of being manually realigned and not otherwise inoperable. ---------------------------NOTE----------------------------------Not required to be met for system vent flow paths opened under administrative control. Verify each required ECCS injection/spray subsystem manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position. 3.5.2-3 ECCS -Shutdown 3.5.2 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 150, 152 SURVEILLANCE REQUIREMENTS (continued) SR 3.5.2.5 SR 3.5.2.6 SR 3.5.2.7 NMP2 SURVEILLANCE Verify each required ECCS pump develops the specified flow rate with the specified developed head. SYSTEM LPCS LPCIA,B LPCIC HPCS FLOW RATE ;;::: 6350 gpm ;;::: 7450 gpm ;;::: 7450 gpm ;;::: 6350 gpm TOTAL DEVELOPED HEAD 2:: 284 psid ;;::: 127 psid ;;::: 140 psid ;;::: 327 psid ----------------------------NOTE----------------------------------Vessel injection/spray may be excluded. Verify each required ECCS injection/spray subsystem actuates on an actual or simulated automatic initiation signal. ----------------------------NOTE----------------------------------lnstrumentation response time may be assumed to be the design instrumentation response time. Verify the ECCS RESPONSE TIME for each ECCS injection/spray subsystem is within limits. 3.5.2-4 ECCS -Shutdown 3.5.2 FREQUENCY In accordance with the lnservice Testing Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9-+,152 SURVEILLANCE REQUIREMENTS SR 3.5.3.1 SR 3.5.3.2 SR 3.5.3.3 SR 3.5.3.4 NMP2 SURVEILLANCE Verify the RCIC System locations susceptible to gas accumulations are sufficiently filled with water. ---------------------------NOTE ------------------------------Not required to be met for system vent flow paths opened under administrative control. Verify each RCIC System manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position. ---------------------------NOTE ----------------------------Not required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test. Verify, with reactor pressure :s 1035 psig and 935 psig, the RCIC pump can develop a flow rate 600 gpm against a system head corresponding to reactor pressure. ---------------------------NOTE ----------------------------Not required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test. Verify, with reactor pressure :s 165 psig, the RCIC pump can develop a flow rate 600 gpm against a system head corresponding to reactor pressure. 3.5.3-2 RCIC System 3.5.3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 150,152 SURVEILLANCE REQUIREMENTS continued SR 3.5.3.5 NMP2 SU AVE I LLANCE ---------------------------NOTE ----------------------------Vessel injection may be excluded. Verify the RCIC System actuates on an actual or simulated automatic initiation signal. 3.5.3-3 RCIC System 3.5.3 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9+,152 SURVEILLANCE REQUIREMENTS (continued) SR 3.6.1.1.3 NMP2 SURVEILLANCE ----------------------------NOTE-------------------------------SR 3.6.1.1.2 may be performed in lieu of SR 3.6.1.1.3. Verify, at an initial differential pressure of<:: 3 psid: a. The leakage rate through each drywall-to-suppression chamber bypass leak path containing suppression chamber-to-drywell vacuum breakers is less than or equal to the equivalent through an orifice 0.000648 ft2; and b. The combined leakage rate through all four drywall-to-suppression chamber bypass leak paths containing suppression chamber-to-drywall vacuum breakers is less than or equal to the equivalent through an orifice 0.001296 ft2. 3.6.1.1-3 Primary Containment 3.6.1.1 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9-+, 152 Primary Containment Air Locks 3.6.1.2 SURVEILLANCE REQUIREMENTS SR 3.6.1 .2.1 SR 3.6.1.2.2 NMP2 SURVEILLANCE --------------------------NOTES----------------------------1. An inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test. 2. Results shall be evaluated against acceptance criteria applicable to SR 3.6.1 .1.1. Perform required primary containment air lock leakage rate testing in accordance with 1 O CFR 50 Appendix J Testing Program Plan. Verify only one door in the primary containment air lock can be opened at a time. 3.6.1.2-5 FREQUENCY In accordance with 1 O CFR 50 Appendix J Testing Program Plan In accordance with the Surveillance Frequency Control Program Amendment B+,152 SURVEILLANCE REQUIREMENTS SR 3.6.1.3.1 SR 3.6. 1.3.2 NMP2 SURVEILLANCE ---------------------------NOTE-----------------------------Not required to be met when the 12 inch and 14 inch primary containment purge valves are open for inerting, inerting, pressure control, ALARA or air quality considerations for personnel entry, or Surveillances that require the valves to be open, provided: a) the Standby Gas Treatment (SGT) System is OPERABLE; or b) the primary containment full flow line to the SGT System is isolated and one SGT subsystem is OPERABLE. Verify each 12 inch and 14 inch primary containment purge valve is closed. --------------------------NOTES----------------------------1. Valves and blind flanges in high radiation areas may be verified by use of administrative means. 2. Not required to be met for PCIVs that are open under administrative controls. Verify each primary containment isolation manual valve and blind flange that is located outside primary containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. 3.6.1.3-10 PC I Vs 3.6.1.3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment Q.:t.,152 SURVEILLANCE REQUIREMENTS (continued) SR 3.6.1 .3.3 SR 3.6.1.3.4 SR 3.6.1 .3.5 NMP2 SURVEILLANCE --------------------------N 0 TES----------------------------1. Valves and blind flanges in high radiation areas may be verified by use of administrative means. 2. Not required to be met for PCIVs that are open under administrative controls. Verify each primary containment isolation manual valve and blind flange that is located inside primary containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. Verify continuity of the traversing incore probe (TIP) shear isolation valve explosive charge. Verify the isolation time of each power operated, automatic PCIV, except MSIVs, is within limits. 3.6.1.3-11 PC I Vs 3.6.1.3 FREQUENCY 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 In accordance with the Surveillance Frequency Control Program In accordance with the lnservice Testing Program (continued) Amendment 9+, 152 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE SR 3.6.1.3.6 Perform leakage rate testing for each primary containment purge valve with resilient seals. SR 3.6.1.3.7 Verify the isolation time of each MSIV is ;::::: 3 seconds and 5 seconds. SR 3.6.1.3.8 Verify each automatic PCIV actuates to the isolation position on an actual or simulated isolation signal. SR 3.6.1.3.9 Verify a representative sample of reactor instrumentation line EFCVs actuates to the isolation position on an actual or simulated instrument line break signal. SR 3.6.1.3.10 Remove and test the explosive squib from each shear isolation valve of the TIP System. SR 3.6.1.3.11 Verify the leakage rate for the secondary containment bypass leakage paths is within the limits of Table 3.6.1.3-1 when pressurized to 2:: 40 psig. NMP2 3.6.1.3-12 PC I Vs 3.6.1.3 FREQUENCY In accordance with the Surveillance Frequency Control Program AND Once within 92 days after opening the valve In accordance with the lnservice Testing Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with 10 CFR 50 Appendix J Testing Program Plan (continued) Amendment 9-+,--Be, 152 Drywell and Suppression Chamber Pressure 3.6.1.4 3.6 CONTAINMENT SYSTEMS 3.6.1.4 Drywall and Suppression Chamber Pressure LCO 3.6.1.4 Drywett and suppression chamber pressure shalt be 14.2 psia and :::; 15.45 psia. APPLICABILITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION A. Drywall or suppression A.1 Restore drywall and chamber pressure not suppression chamber within limits. pressure to within limits. B. Required Action and B.1 Be in MODE 3. associated Completion Time not met. AND B.2 Be in MODE 4. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.6.1.4.1 NMP2 Verify drywell and suppression chamber pressure is within limits. 3.6.1.4-1 COMPLETION TIME 1 hour 12 hours 36 hours FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9-i,152 3.6 CONTAINMENT SYSTEMS 3.6.1.5 Drywall Air Temperature LCO 3.6.1.5 Drywall average air temperature shall be 150&deg;F. APPLICABILITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION A. Drywell average air A.1 Restore drywell temperature not within average air limit. temperature to within limit. B. Required Action and B.1 Be in MODE 3. associated Completion Time not met. AND B.2 Be in MODE 4. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.6.1.5.1 NMP2 Verify drywell average air temperature is within limit. 3.6.1.5-1 Drywell Air Temperature 3.6.1.5 COMPLETION TIME 8 hours 12 hours 36 hours FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9+,152 SURVEILLANCE REQUIREMENTS SR 3.6. 1 .6.1 SR 3.6.1.6.2 SR 3.6.1.6.3 NMP2 SURVEILLANCE Verify each AHR drywell spray subsystem manual and power operated valve in the flow path that is not locked, sealed, or otherwise secured in position, is in the correct position or can be aligned to the correct position. Verify, by administrative means, that each required AHR pump is OPERABLE. Verify each drywell spray nozzle is unobstructed. 3.6.1.6-2 RHR Drywell Spray 3.6.1.6 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Following maintenance that could result in nozzle blockage Amendment 91, 122, 152 Suppression Chamber-to-Drywell Vacuum Breakers 3.6.1.7 SURVEILLANCE REQUIREMENTS SR 3.6.1.7.1 SR 3.6.1.7.2 SR 3.6.1.7.3 NMP2 SURVEILLANCE --------------------------NOTES----------------------------1. Not required to be met for vacuum breakers that are open during Surveillances. 2. Not required to be met for vacuum breakers open when performing their intended function. Verify each vacuum breaker is closed. ---------------------------NOTE-----------------------------Not required to be met for vacuum breaker 21SC*RV36B for the remainder of Cycle 9. Perform a functional test of each vacuum breaker. Verify the opening setpoint of each vacuum breaker is$ 0.25 psid. FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Within 12 hours after any discharge of steam to the suppression chamber from the safety/relief valves In accordance with the Surveillance Frequency Control Program 3.6.1.7-3 Amendment 91, 98, 108,152 Suppression Pool Average Temperature 3.6.2.1 SURVEILLANCE REQUIREMENTS SR 3.6.2.1 . 1 NMP2 SURVEILLANCE Verify suppression pool average temperature is within the applicable limits. 3.6.2.1-3 FREQUENCY In accordance with the Surveillance Frequency Control Program 5 minutes when performing testing that adds heat to the suppression pool Amendment 9-+, 152 3.6 CONTAINMENT SYSTEMS 3.6.2.2 Suppression Pool Water Level Suppression Pool Water Level 3.6.2.2 LCO 3.6.2.2 Suppression pool water level shall be 199 ft 6 inches and ::; 201 ft APPLICABILITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION A. Suppression pool water A.1 Restore suppression level not within pool water level to limits. within limits. B. Required Action and B.1 Be in MODE 3. associated Completion Time not met. AND B.2 Be in MODE 4. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.6.2.2.1 NMP2 Verify suppression pool water level is within limits. 3.6.2.2-1 COMPLETION TIME 2 hours 12 hours 36 hours FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment f>>,152 AHR Suppression Pool Cooling 3.6.2.3 SURVEILLANCE REQUIREMENTS SR 3.6.2.3.1 SR 3.6.2.3.2 SR 3.6.2.3.3 NMP2 SURVEILLANCE Verify each AHR suppression pool cooling subsystem manual and power operated valve in the flow path that is not locked, sealed, or otherwise secured in position, is in the correct position or can be aligned to the correct position. Verify each required AHR pump develops a flow rate 2". 7 450 gpm through the associated heat exchanger while operating in the suppression pool cooling mode. Verify AHR suppression pool cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water. 3.6.2.3-2 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the lnservice Testing Program In accordance with the Surveillance Frequency Control Program Amendment 91, 150, 152 AHR Suppression Pool Spray 3.6.2.4 SURVEILLANCE REQUIREMENTS SR 3.6.2.4.1 SR 3.6.2.4.2 SR 3.6.2.4.3 NMP2 SURVEILLANCE Verify each AHR suppression pool spray subsystem manual and power operated valve in the flow path that is not locked, sealed, or otherwise secured in position, is in the correct position or can be aligned to the correct position. Verify each required RHR pump develops a flow rate 450 gpm while operating in the suppression pool spray mode. Verify AHR suppression pool spray subsystem locations susceptible to gas accumulation are sufficiently filled with water. 3.6.2.4-2 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the lnservice Testing Program In accordance with the Surveillance Frequency Control Program Amendment 91, 150, 152 Primary Containment Oxygen Concentration 3.6.3.2 3.6 CONTAINMENT SYSTEMS 3.6.3.2 Primary Containment Oxygen Concentration LCO 3.6.3.2 The primary containment oxygen concentration shall be < 4.0 volume percent. APPLICABILITY: MODE 1 during the time period: a. From 24 hours after THERMAL POWER is > 15% ATP following startup, to b. 24 hours prior to reducing THERMAL POWER to < 15% RTP prior to the next scheduled reactor shutdown. ACTIONS CONDITION REQUIRED ACTION A. Primary containment A.1 Restore oxygen oxygen concentration concentration to not within limit. within limit. B. Required Action and B.1 Reduce THERMAL POWER associated Completion 15% ATP. Time not met. SURVEILLANCE REQUIREMENTS SR 3.6.3.2.1 NMP2 SURVEILLANCE Verify primary containment oxygen concentration is within limits. 3.6.3.2-1 COMPLETION TIME 24 hours 8 hours FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 ACTIONS (continued) CONDITION C. Secondary containment C.1 inoperable during movement of recently irradiated fuel assemblies in the secondary containment REQUIRED ACTION -----------NO TE-----------LCO 3.0.3 is not applicable. Secondary Containment 3.6.4.1 COMPLETION TIME or during OPDRVs. Suspend movement of Immediately recently irradiated fuel assemblies in the secondary containment. C.2 Initiate action to suspend OPDAVs. SURVEILLANCE REQUIREMENTS SR 3.6.4.1.1 SR 3.6.4.1.2 NMP2 SURVEILLANCE Verify secondary containment vacuum is 0.25 inch of vacuum water gauge. Verify all secondary containment equipment hatches are closed and sealed. 3.6.4.1-2 Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 101, 152 SURVEILLANCE REQUIREMENTS (continued) SR 3.6.4.1.3 SR 3.6.4.1.4 SR 3.6.4.1.5 NMP2 SURVEILLANCE Verify one secondary containment access door in each access opening is closed. Verify the secondary containment can be drawn down to ;::::: 0.25 inch of vacuum water gauge in :::;; 66. 7 seconds using one standby gas treatment (SGT) subsystem. Verify the secondary containment can be maintained ;::::: 0.25 inch of vacuum water gauge for 1 hour using one SGT subsystem at a flow rate :::;; 2670 cfm. 3.6.4.1-3 Secondary Containment 3.6.4.1 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment B+, 152 SURVEILLANCE REQUIREMENTS SR 3.6.4.2.1 SR 3.6.4.2.2 SR 3.6.4.2.3 NMP2 SURVEILLANCE --------------------------NOTES----------------------------1. Valves and blind flanges in high radiation areas may be verified by use of administrative means. 2. Not required to be met for SCIVs that are open under administrative controls. Verify each secondary containment isolation manual valve and blind flange that is not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. Verify the isolation time of each power operated, automatic SCIV is within limits. Verify each automatic SCIV actuates to the isolation position on an actual or simulated automatic isolation signal. 3.6.4.2-4 SCI Vs 3.6.4.2 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 ACTIONS CONDITION REQUIRED ACTION E. (continued) E.3 Initiate action to suspend OPDRVs. SURVEILLANCE REQUIREMENTS SR 3.6.4.3.1 SR 3.6.4.3.2 SR 3.6.4.3.3 SR 3.6.4.3.4 NMP2 SURVEILLANCE Operate each SGT subsystem for ;::: 1 O continuous hours with heaters operating. Perform required SGT filter testing in accordance with the Ventilation Filter Testing Program (VFTP). Verify each SGT subsystem actuates on an actual or simulated initiation signal. Verify each SGT decay heat removal air inlet valve can be opened. 3.6.4.3-3 SGT System 3.6.4.3 COMPLETION TIME Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the VFTP In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 91, 101, 152 SURVEILLANCE REQUIREMENTS SR 3.7.1.1 SR 3.7.1.2 SR 3.7.1.3 SR 3.7.1.4 NMP2 SURVEILLANCE ------------------------------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 tunnels 38&deg;F. Verify the water level in the SW pump intake bay is 233.1 ft. Verify the water temperature of each SW subsystem supply header 84&deg;F. Verify each required SW pump is in operation. 3.7.1-3 SW System and UHS 3.7.1 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program 4 hours when supply header water temperature is ?.'. 78&deg;F In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 119,152 SURVEILLANCE REQUIREMENTS (continued) SR 3.7.1.5 SR 3.7.1.6 SR 3.7.1.7 SR 3.7.1.8 NMP2 SURVEILLANCE ------------------------------NOTE-----------------------------Not required to be met if SR 3. 7.1.1 satisfied. Verify, for each intake deicer heater division, the current of each required heater feeder cable is within the limit. ------------------------------NOTE-----------------------------lsolation of flow to individual components does not render SW System inoperable. Verify each SW subsystem manual, power operated, and automatic valve in the flow path servicing safety related systems or components, that is not locked, sealed, or otherwise secured in position, is in the correct position. Verify each SW subsystem actuates on an actual or simulated initiation signal. ------------------------------N 0 TE-----------------------------Not required to be met if SR 3.7.1.1 satisfied. Verify, for each intake deicer heater division, the resistance of each required heater feeder cable and associated heater elements is within the limit. 3.7.1-4 SW System and UHS 3.7.1 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9-+, 152 ACTIONS (continued) F. CONDITION Two CREF subsystems inoperable with safety function not maintained during movement of recently irradiated fuel assemblies in the secondary containment or during OPDRVs. REQUIRED ACTION ------------------NOTE------------------LCO 3.0.3 is not applicable. F .1 Suspend movement of recently irradiated fuel assemblies in the secondary containment. One or more CREF AND subsystems inoperable due to inoperable CRE boundary F.2 Initiate action to suspend during movement of recently OPDRVs. irradiated fuel assemblies in the secondary containment or during OPDRVs. SURVEILLANCE REQUIREMENTS SR 3.7.2.1 SR 3.7.2.2 SR 3.7.2.3 SURVEILLANCE Operate each CREF subsystem for 2 1 continuous hour. Perform required CREF System filter testing in accordance with the Ventilation Filter Testing Program (VFTP). Verify each CREF subsystem actuates on an actual or simulated initiation signal. CREF System 3.7.2 COMPLETION TIME Immediately Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the VFTP In accordance with the Surveillance Frequency Control Program (continued) NMP2 3.7.2-3 Amendment 91, 95, 97, 125, 126, 152 Control Room Envelope AC System 3.7.3 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME ------------------NOTE-------------------LCO 3.0.3 is not applicable. H. Required Action and associated Completion Time of Condition C or D not met during movement of recently irradiated fuel assemblies in the secondary containment or during OPDRVs. H.1 Suspend movement of Immediately AND H.2 recently irradiated fuel assemblies in the secondary containment. Initiate action to suspend OPDRVs. SURVEILLANCE REQUIREMENTS SR 3.7.3.1 NMP2 SURVEILLANCE Verify each control room envelope AC subsystem has the capability to remove the assumed heat load for the Main Control Room area and the Relay Room area. 3.7.3-4 Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program 152 SURVEILLANCE REQUIREMENTS SR 3.7.4.1 NMP2 SURVEILLANCE ------------------------------NOTE---------------------------Not required to be performed until 31 days after any main steam line not isolated and SJAE in operation. Verify the gross gamma activity rate of the noble gases is ::;; 350,000 &#xb5;Ci/second after decay of 30 minutes.
* 3.7.4-2 Main Condenser Offgas 3.7.4 FREQUENCY In accordance with the Surveillance Frequency Control Program Once within 4 hours after a ;::: 50% increase in the nominal steady state fission gas release after factoring out increases due to changes in THERMAL POWER level Amendment 9+, 152 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 23% ATP. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the A.1 Satisfy the 2 hours LCO not met. requirements of the LCO. B. Required Action and B.1 Reduce THERMAL POWER 4 hours associated Completion to< 23% ATP. Time not met. SURVEILLANCE REQUIREMENTS SR 3.7.5.1 SR 3.7.5.2 NMP2 SURVEILLANCE FREQUENCY Perform a system functional test. In accordance with the Surveillance Frequency Control Program Verify the TURBINE BYPASS SYSTEM RESPONSE In accordance with TIME is within limits. the Surveillance Frequency Control Program 3.7.5-1 Amendment91, 140,152 Spent Fuel Storage Pool Water Level 3.7.6 3. 7 PLANT SYSTEMS 3.7.6 Spent Fuel Storage Pool Water Level LCO 3.7.6 The spent fuel storage pool water level shall be 2:: 22 ft 3 inches over the top of irradiated fuel assemblies seated in the spent fuel storage pool racks. APPLICABILITY: During movement of irradiated fuel assemblies in the spent fuel storage pool, During movement of new fuel assemblies in the spent fuel storage pool with irradiated fuel assemblies seated in the spent fuel storage pool. ACTIONS CONDITION A. Spent fuel storage pool water level not within limit. A.1 SURVEILLANCE REQUIREMENTS REQUIRED ACTION ------------NOTE------------LCO 3.0.3 is not applicable. Suspend movement of fuel assemblies in the spent fuel storage pool. SURVEILLANCE SR 3.7.6.1 NMP2 Verify the spent fuel storage pool water level is :::::: 22 ft 3 inches over the top of irradiated fuel assemblies seated in the spent fuel storage pool racks. 3.7.6-1 COMPLETION TIME Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program Amendments+, 152 ACTIONS (continued) CONDITION REQUIRED ACTION E. Two required DGs E.1 Restore one required inoperable. DG to OPERABLE status. F. Required Action and F.1 Be in MODE 3. Associated Completion Time of Condition A, AND B, C, D, or E not met. F.2 Be in MODE 4. G. Three or more required G.1 Enter LCO 3.0.3. AC sources inoperable. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.8.1.1 NMP2 Verify correct breaker alignment and indicated power availability for each required otfsite circuit. 3.8.1-5 AC Sources -Operating 3.8.1 COMPLETION TIME 2 hours OR 24 hours if Division 3 DG is inoperable 12 hours 36 hours Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment 9+, 152 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.2 ------------------------------NOTE-----------------------------NMP2 All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading. Verify each required DG starts from standby conditions and achieves: a. In s; 1 O seconds, voltage;;:: 3950 V for Division 1 and 2 DGs and ;::: 3820 V for Division 3 DG, and frequency;;:: 58.8 Hz for Division 1 and 2 DGs and ;::: 58.0 Hz for Division 3 DG; and b. Steady state voltage ;;:: 3950 V and s; 4370 V and frequency ;::: 58.8 Hz and s; 61.2 Hz. 3.8.1-6 In accordance with the Surveillance Frequency Control Program (continued) Amendment 9-1-, 152 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.3 -----------------------------NOTES----------------------------SR 3.8.1.4 SR 3.8.1.5 SR 3.8.1.6 NMP2 1. DG loadings may include gradual loading as recommended by the manufacturer. 2. Momentary transients outside the load range do not invalidate this test. 3. This Surveillance shall be conducted on only one DG at a time. 4. This SR shall be preceded by, and immediately follow, without shutdown, a successful performance of SR 3.8.1.2. Verify each required DG is synchronized and loaded and operates for 2 60 minutes at a load 2 3960 kW and :::; 4400 kW for Division 1 and 2 DGs, and 2 2340 kW and $ 2600 kW for Division 3 DG. Verify each required day tank contains 2 403 gal of fuel oil for Division 1 and 2 DGs and 2 282 gal for Division 3 DG. Check for and remove accumulated water from each required day tank. Verify each required fuel oil transfer subsystem operates to automatically transfer fuel oil from the storage tank to the day tank. 3.8.1-7 In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 9+,152 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.7 -------------------------------NOTES-----------------------------NMP2 1. This Surveillance shall not be performed in MODE 1 or 2 (not applicable to Division 3 DG). However, credit may be taken for unplanned events that satisfy this SR. 2. If performed with DG synchronized with offsite power, it shall be performed within the power factor limit. However if grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable. Verify each required DG rejects a load greater than or equal to its associated single largest post-accident load, and following load rejection, the frequency is 64.5 Hz for Division 1 and 2 DGs and 66. 75 Hz for Division 3 DG. 3.8.1-8 In accordance with the Surveillance Frequency Control Program (continued) Amendment 133, 152 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.8 -----------------------------NOTES----------------------------NMP2 1 . This Surveillance shall not be performed in MODE 1 or 2 (not applicable to Division 3 DG). However, credit may be taken for unplanned events that satisfy this SR. 2. If grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable. Verify each required DG operating within the power factor limit does not trip and voltage is maintained: a. ::; 4576 V during and following a load rejection of a load 4400 kW for Division 1 and 2 DGs; and b. 5824 V during and following a load rejection of a load 2600 kW for Division 3 DG. 3.8.1-9 In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 133, 152 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.9 -----------------------------NOTES----------------------------NMP2 1 . All DG starts may be preceded by an engine prelube period. 2. This Surveillance shall not be performed in MODE 1, 2, or 3 (not applicable to Division 3 DG). However, credit may be taken for unplanned events that satisfy this SR. Verify on an actual or simulated loss of offsite power signal: a. De-energization of emergency buses; b. Load shedding from emergency buses for Divisions 1 and 2 only; and c. DG auto-starts from standby condition and: 1 . energizes permanently connected loads in s; 13.20 seconds, 2. energizes auto-connected shutdown loads for Division 1 and 2 DGs only, through the associated automatic load sequence time delay relays, 3. maintains steady state voltage 3950 V and s; 4370 V, 4. maintains steady state frequency 58.8 Hz and s; 61 .2 Hz, and 5. supplies permanently connected and auto-connected shutdown loads for :::: 5 minutes for Division 1 and 2 DGs and supplies permanently connected shutdown loads for :::: 5 minutes for Division 3 DG. 3.8.1-10 In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 133, 152 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.10 -----------------------------NOTES----------------------------NMP2 1 . All DG starts may be preceded by an engine prelube period. 2. This Surveillance shall not be performed in MODE 1 or 2 (not applicable to Division 3 DG). However, credit may be taken for unplanned events that satisfy this SR. Verify on an actual or simulated Emergency Core Cooling System (ECCS) initiation signal each required DG auto-starts from standby condition and: a. In:=; 1 O seconds after auto-start, achieves voltage ;::: 3950 V for Division 1 and 2 DGs and 2 3820 V for Division 3 DG, and frequency;::: 58.8 Hz for Division 1 and 2 DGs and 2 58.0 Hz for Division 3 DG; b. Achieves steady state voltage ;::: 3950 V and :=; 4370 V and frequency 2 58.8 Hz and:=; 61.2 Hz; c. Operates for 2 5 minutes; d. Permanently connected loads remain energized from the offsite power system for Divisions 1 and 2 only; and e. Emergency loads are auto-connected through the associated automatic load sequence time delay relays to the offsite power system for Divisions 1 and 2 only. 3.8.1-11 In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 133, 152 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.11 -------------------------------NOTE-----------------------------NMP2 This Surveillance shall not be performed in MODE 1, 2, or 3 (not applicable to Division 3 DG). However, credit may be taken for unplanned events that satisfy this SR. Verify each required DG's automatic trips are bypassed on actual or simulated loss of voltage signal on the emergency bus concurrent with an actual or simulated ECCS initiation signal except: a. Engine overspeed; and b. Generator differential current. 3.8.1-12 In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 133, 152 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.12 -----------------------------NOTES----------------------------NMP2 1. Momentary transients outside the load and power factor ranges do not invalidate this test. 2. This Surveillance shall not be performed in MODE 1 or 2 unless the other two DGs are OPERABLE. If either of the other two DGs become inoperable, this Surveillance shall be suspended. However, credit may be taken for unplanned events that satisfy this SR. 3. If grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable. Verify each required DG operating within the power factor limit operates for 2 24 hours: a. For 2 2 hours loaded 2 4620 kW and ::::: 4840 kW for Division 1 and 2 DGs, and 2 2730 kW and 2860 kW for Division 3 DG; and b. For the remaining hours of the test loaded 2 3960 kW and ::::: 4400 kW for Division 1 and 2 DGs, and 2 2340 kW 2600 kW for Division 3 DG. 3.8.1-13 In accordance with the Surveillance Frequency Control Program (continued) Amendment 9+, 152 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.13 -----------------------------NOTES----------------------------NMP2 1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated 2 2 hours loaded 3960 kW for Division 1 and 2 DGs, and 2 2340 kW for Division 3 DG. Momentary transients below the load limit do not invalidate this test. 2. All DG starts may be preceded by an engine prelube period. Verify each required DG starts and achieves: a. In $ 1 O seconds, voltage 3950 V for Division 1 and 2 DGs and 2 3820 V for Division 3 DG, and 58.8 Hz for Division 1 and 2 DGs and 2 58.0 Hz for Division 3 DG; and b. Steady state voltage 2 3950 V and s 4370 V and frequency 2 58.8 Hz ands 61.2 Hz. 3.8.1-14 In accordance with the Surveillance Frequency Control Program (continued) Amendment 9-1-, 152 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued) SR 3.8.1.14 SR 3.8.1.15 NMP2 SURVEILLANCE ------------------------------NOTE-----------------------------This Surveillance shall not be performed in MODE 1, 2, or 3 (not applicable to Division 3 DG). However, credit may be taken for unplanned events that satisfy this SR. Verify each required DG: a. Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power; b. Transfers loads to offsite power source; and c. Returns to ready-to-load operation. ------------------------------N 0 TE-----------------------------This Surveillance shall not be performed in MODE 1, 2, or 3 (not applicable to Division 3 DG). However, credit may be taken for unplanned events that satisfy this SR. Verify, with a DG operating in test mode and connected to its bus, an actual or simulated ECCS initiation signal overrides the test mode by: a. Returning DG to ready-to-load operation; and b. Automatically energizing the emergency load from offsite power. 3.8.1-15 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 133, 152 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.16 ------------------------------NOTE-----------------------------NMP2 This Surveillance shall not be performed in MODE 1, 2, or 3. However, credit may be taken for unplanned events that satisfy this SR. Verify interval between each sequenced load block, for the Division 1 and 2 DGs only, is 90% of the design interval for each automatic load sequence time delay relay. 3.8.1-16 In accordance with the Surveillance Frequency Control Program (continued) Amendment 9+, 152 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.17 -----------------------------NOTES----------------------------NMP2 1 . All DG starts may be preceded by an engine prelube period. 2. This Surveillance shall not be performed in MODE 1, 2, or 3 (not applicable to Division 3 DG). However, credit may be taken for unplanned events that satisfy this SR. Verify, on an actual or simulated loss of offsite power signal in conjunction with an actual or simulated ECCS initiation signal: a. De-energization of emergency buses; b. Load shedding from emergency buses for Divisions 1 and 2 only; and c. DG auto-starts from standby condition and: 1. energizes permanently connected loads in s 1 O seconds, 2. for Divisions 1 and 2, energizes auto-connected emergency loads through the associated automatic load sequence time delay relays and for Division 3, energizes auto-connected emergency loads, 3. maintains steady state voltage ;:::: 3950 V and ::;; 4370 V, 4. maintains steady state frequency ;:::: 58.8 Hz and::;; 61.2 Hz, and 5. supplies permanently connected and auto-connected emergency loads for ;:::: 5 minutes. 3.8.1-17 In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 133, 152 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.18 ------------------------------NOTE-----------------------------NMP2 All DG starts may be preceded by an engine prelube period. Verify, when started simultaneously from standby condition, each Division 1, 2, and 3 DG achieves, in ::; 1 O seconds, voltage 2 3950 V for Division 1 and 2 DGs and 2 3820 V for Division 3 DG, and frequency 2 58.8 Hz for Division 1 and 2 DGs and 2 58.0 Hz for Division 3 DG. 3.8.1-18 In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SR 3.8.3.1 SR 3.8.3.2 SR 3.8.3.3 SR 3.8.3.4 SR 3.8.3.5 NMP2 SURVEILLANCE Verify each fuel oil storage tank contains: a. 2 50,000 gal of fuel for Division 1 DG and Division 2 DG; and b. 2 35,342 gal of fuel for Division 3DG. Verify lube oil inventory is: a. 2 99 gal for Division 1 DG and Division 2 DG; and b. 2 168 gal for Division 3 DG. Verify fuel oil properties of new and stored fuel oil are tested in accordance with, and maintained within the limits of, the Diesel Fuel Oil Testing Program. Verify each DG air start receiver pressure is: a. 2 225 psig for Division 1 DG and Division 2 DG; and b. 2 190 psig for Division 3 DG. Check for and remove accumulated water from each fuel oil storage tank. 3.8.3-3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Diesel Fuel Oil Testing Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9-+, 152 SURVEILLANCE REQUIREMENTS SR 3.8.4.1 SR 3.8.4.2 SR 3.8.4.3 SR 3.8.4.4 SR 3.8.4.5 NMP2 SURVEILLANCE Verify battery terminal voltage is 130 V on float charge. Verify no visible corrosion at battery terminals and connectors. Verify battery connection resistance is 20% above the resistance as measured during installation for intercell and terminal connections. Verify battery cells, cell plates, and racks show no visual indication of physical damage or abnormal deterioration that could degrade battery performance. Remove visible corrosion and verify battery cell to cell and terminal connections are coated with anti-corrosion material. Verify battery connection resistance is :S 20% above the resistance as measured during installation for intercell and terminal connections. 3.8.4-2 DC Sources -Operating 3.8.4 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 9-1-, 152 SURVEILLANCE REQUIREMENTS (continued) SR 3.8.4.6 SURVEILLANCE Verify each required Division 1 and 2 battery charger supplies 300 amps and the required Division 3 battery charger supplies 40 amps at 130 V for 4 hours. DC Sources -Operating 3.8.4 FREQUENCY In accordance with the Surveillance Frequency Control Program SR 3.8.4.7 -----------------------------NOTES----------------------------NMP2 1 . The modified performance discharge test in SR 3.8.4.8 may be performed in lieu of the service test in SR 3.8.4. 7 provided the modified performance discharge test completely envelops the service test. 2. This Surveillance shall not be performed in MODE 1, 2, or 3 (not applicable to Division 3). However, credit may be taken for unplanned events that satisfy this SR. Verify battery capacity is adequate to supply, and maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test. 3.8.4-3 In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 136, 152 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE DC Sources -Operating 3.8.4 FREQUENCY SR 3.8.4.8 ------------------------------NOTE-----------------------------NMP2 This Surveillance shall not be performed in MODE 1, 2, or 3 (not applicable to Division 3). However, credit may be taken for unplanned events that satisfy this SR. Verify battery capacity is 80% of the manufacturer's rating when subjected to a performance discharge test or a modified performance discharge test. 3.8.4-4 In accordance with the Surveillance Frequency Control Program 12 months when battery shows degradation or has reached 85% of expected life with capacity < 100% of manufacture r's rating 24 months when battery has reached 85% of the expected life with capacity 100% of manufacturer's rating Amendment 91, 136, 152 ACTIONS (continued) CONDITION B. Required Action and associated Completion Time of Condition A not met. One or more batteries with average electrolyte temperature of the representative cells < 65&deg;F. One or more batteries with one or more battery cell parameters not within Table 3.8.6-1 Category C limits. B.1 REQUIRED ACTION Declare associated battery inoperable. SURVEILLANCE REQUIREMENTS SR 3.8.6.1 NMP2 SURVEILLANCE Verify battery cell parameters meet Table 3.8.6-1 Category A limits. 3.8.6-2 Battery Cell Parameters 3.8.6 COMPLETION TIME Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment 9+,152 SURVEILLANCE REQUIREMENTS (continued) SR 3.8.6.2 SR 3.8.6.3 NMP2 SURVEILLANCE Verify battery cell parameters meet Table 3.8.6-1 Category B limits. Verify average electrolyte temperature of representative cells is 65&deg;F. 3.8.6-3 Battery Cell Parameters 3.8.6 FREQUENCY In accordance with the Surveillance Frequency Control Program Once within 7 days after battery discharge < 107 v Once within 7 days after battery overcharge > 142 v In accordance with the Surveillance Frequency Control Program Amendment 9-+, 152 SURVEILLANCE REQUIREMENTS SR 3.8.7.1 NMP2 SURVEILLANCE Verify correct emergency UPS inverter voltage, frequency, and alignment to 120 VAC uninterruptible panels. 3.8.7-2 Inverters -Operating 3.8.7 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 ACTIONS (continued) CONDITION F. Two or more electrical power distribution subsystems inoperable that result in a loss of function. REQUIRED ACTION F.1 Enter LCO 3.0.3. SURVEILLANCE REQUIREMENTS SR 3.8.8.1 NMP2 SURVEILLANCE Verify correct breaker alignment and power availability to required AC, DC, and 120 VAC uninterruptible electrical power distribution subsystems. 3.8.8-3 Distribution Systems -Operating 3.8.8 COMPLETION TIME Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9-1-, 152 Distribution Systems -Shutdown 3.8.9 ACTIONS CONDITION REQUIRED ACTION A. (continued) A.2.3 A.2.4 A.2.5 Initiate action to suspend operations with a potential for draining the reactor vessel. Initiate actions to restore required AC, DC, and 120 VAC uninterruptible electrical power distribution subsystems to OPERABLE status. Declare associated required shutdown cooling subsystem(s) inoperable and not in operation. SURVEILLANCE REQUIREMENTS SR 3.8.9.1 NMP2 SURVEILLANCE Verify correct breaker alignments and power availability to required AC, DC, and 120 VAC uninterruptible electrical power distribution subsystems. 3.8.9-2 COMPLETION TIME Immediately Immediately Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9-+, 152 Refueling Equipment Interlocks 3.9.1 SURVEILLANCE REQUIREMENTS SR 3.9.1.1 NMP2 SURVEILLANCE Perform CHANNEL FUNCTIONAL TEST on each of the following required refueling equipment interlock inputs: a. All-rods-in, b. Refueling platform position, c. Refueling platform fuel grapple, fuel-loaded, d. Refueling platform monorail hoist, fuel-loaded, e. Refueling platform frame-mounted hoist, fuel-loaded, and f. Service platform hoist, fuel-loaded. 3.9.1-2 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9-+, 152 Refuel Position One-Rod-Out Interlock 3.9.2 3.9 REFUELING OPERATIONS 3.9.2 Refuel Position One-Rod-Out Interlock LCO 3.9.2 The refuel position one-rod-out interlock shall be OPERABLE. APPLICABILITY: MODE 5 with the reactor mode switch in the refuel position ACTIONS CONDITION A. Refuel position rod-out interlock inoperable. and any control rod withdrawn. A.1 AND A.2 REQUIRED ACTION Suspend control rod withdrawal. Initiate action to fully insert all insertable control rods in core cells containing one or more fuel assemblies. SURVEILLANCE REQUIREMENTS SR 3.9.2.1 NMP2 SURVEILLANCE Verify reactor mode switch locked in refuel position. 3.9.2-1 COMPLETION TIME Immediately Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment 9+, 152 Refuel Position One-Rod-Out Interlock 3.9.2 SURVEILLANCE REQUIREMENTS continued SR 3.9.2.2 NMP2 SURVEILLANCE ---------------------------NOTE-----------------------------Not required to be performed until 1 hour after any control rod is withdrawn. Perform CHANNEL FUNCTIONAL TEST. 3.9.2-2 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9-i, 152 3.9 REFUELING OPERATIONS 3.9.3 Control Rod Position LCO 3.9.3 All control rods shall be fully inserted. APPLICABILITY: When loading fuel assemblies into the core. ACTIONS CONDITION A. One or more control rods not fully inserted. A.1 REQUIRED ACTION Suspend loading fuel assemblies into the core. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.9.3.1 Verify all control rods are fully inserted. NMP2 3.9.3-1 Control Rod Position 3.9.3 COMPLETION TIME Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 Control Rod OPERABILITY -Refueling 3.9.5 3.9 REFUELING OPERATIONS 3.9.5 Control Rod OPERABILITY -Refueling LCO 3.9.5 Each withdrawn control rod shall be OPERABLE. APPLICABILITY: MODE 5. ACTIONS CONDITION REQUIRED ACTION A. One or more withdrawn control rods inoperable. A.1 Initiate action to fully insert inoperable withdrawn control rods. SURVEILLANCE REQUIREMENTS SR 3.9.5.1 SR 3.9.5.2 NMP2 SURVEILLANCE ---------------------------N 0 TE-------------------------------Not required to be performed until 7 days after the control rod is withdrawn. Insert each withdrawn control rod at least one notch. Verify each withdrawn control rod scram accumulator pressure is 940 psig. 3.9.5-1 COMPLETION TIME Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9-+, 152 RPV Water Level -Irradiated Fuel 3.9.6 3.9 REFUELING OPERATIONS 3.9.6 Reactor Pressure Vessel (RPV) Water Level -Irradiated Fuel LCO 3.9.6 RPV water level shall be 2:'. 22 ft 3 inches above the top of the RPV flange. APPLICABILITY: During movement of irradiated fuel assemblies within the ACTIONS CONDITION A. RPV water level not within limit. RPV. A.1 REQUIRED ACTION Suspend movement of irradiated fuel assemblies within the RPV. SURVEILLANCE REQUIREMENTS SR 3.9.6.1 NMP2 SURVEILLANCE Verify RPV water level is 2! 22 ft 3 inches above the top of the RPV flange. 3.9.6-1 COMPLETION TIME Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 RPV Water Level -New Fuel or Control Rods 3.9.7 3.9 REFUELING OPERATIONS 3.9.7 Reactor Pressure Vessel (RPV) Water Level -New Fuel or Control Rods LCO 3.9.7 RPV water level shall be<:: 22 ft 3 inches above the top of irradiated fuel assemblies seated within the RPV. APPLICABILITY: During movement of new fuel assemblies or handling of control rods within the RPV when irradiated fuel assemblies are seated within the RPV. ACTIONS CONDITION A. RPV water level not within limit. A.1 REQUIRED ACTION Suspend movement of new fuel assemblies and handling of control rods within the RPV. SURVEILLANCE REQUIREMENTS SR 3.9.7.1 NMP2 SURVEILLANCE Verify RPV water level is <:: 22 ft 3 inches above the top of irradiated fuel assemblies seated within the RPV. 3.9.7-1 COMPLETION TIME Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9-+, 152 AHR -High Water Level 3.9.8 SURVEILLANCE REQUIREMENTS SR 3.9.8.1 SR 3.9.8.2 NMP2 SURVEILLANCE Verify one AHR shutdown cooling subsystem is operating. Verify required AHR shutdown cooling subsystem locations susceptible to gas accumulations are sufficiently filled with water. 3.9.8-3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 91, 150, 152 AHR -Low Water Level 3.9.9 SURVEILLANCE REQUIREMENTS SR 3.9.9.1 SR 3.9.9.2 NMP2 SURVEILLANCE Verify one AHR shutdown cooling subsystem is operating. Verify AHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water. 3.9.9-3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 91, 150, 152 Reactor Mode Switch Interlock Testing 3.10.2 ACTIONS CONDITION REQUIRED ACTION A. (continued) A.3.1 OR Place the reactor mode switch in the shutdown position. A.3.2 -----------NOTE-------------Only applicable in MODE 5. Place the reactor mode switch in the refuel position. SURVEILLANCE REQUIREMENTS SR 3.10.2.1 SR 3.10.2.2 NMP2 SURVEILLANCE Verify all control rods are fully inserted in core cells containing one or more fuel assemblies. Verify no CORE ALTERATIONS are in progress. 3.10.2-2 COMPLETION TIME 1 hour 1 hour FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 Single Control Rod Withdrawal -Hot Shutdown 3.10.3 SURVEILLANCE REQUIREMENTS SR 3.10.3.1 SR 3.10.3.2 SR 3.10.3.3 NMP2 SURVEILLANCE Perform the applicable SRs for the required LC Os. ---------------------------N 0 TE--------------------------------Not required to be met if SR 3.10.3.1 is satisfied for LCO 3.10.3.d.1 requirements. Verify all control rods, other than the control rod being withdrawn, in a five by five array centered on the control rod being withdrawn, are disarmed. Verify all control rods, other than the control rod being withdrawn, are fully inserted. 3.10.3-3 FREQUENCY According to the applicable SRs In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment B+, 152 Single Control Rod Withdrawal -Cold Shutdown 3.10.4 ACTIONS {continued) CONDITION REQUIRED ACTION B. One or more of the above requirements not met with the affected control rod not insertable. B.1 Suspend withdrawal of the control rod and removal of associated CAD. B.2.1 OR B.2.2 Initiate action to fully insert all control rods. Initiate action to satisfy the requirements of this LCO. SURVEILLANCE REQUIREMENTS SR 3.10.4.1 SR 3.10.4.2 NMP2 SURVEILLANCE Perform the applicable SRs for the required LCOs. ------------------------------NOTE-----------------------------N ot required to be met if SR 3.10.4.1 is satisfied for LCO 3.10.4.c.1 requirements. Verify all control rods, other than the control rod being withdrawn, in a five by five array centered on the control rod being withdrawn, are disarmed. 3.10.4-3 COMPLETION TIME Immediately Immediately Immediately FREQUENCY According to applicable SRs In accordance with the Surveillance Frequency Control Program (continued) Amendment 9+, 152 Single Control Rod Withdrawal -Cold Shutdown 3.10.4 SURVEILLANCE REQUIREMENTS (continued) SR 3.10.4.3 SR 3.10.4.4 NMP2 SURVEILLANCE Verify all control rods, other than the control rod being withdrawn, are fully inserted. ------------------------------NOTE-----------------------------Not required to be met if SR 3.10.4. 1 is satisfied for LCO 3.10.4.b.1 requirements. Verify a control rod withdrawal block is inserted. 3.10.4-4 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendments+, 152 Single CRD Removal -Refueling 3.10.5 ACTIONS CONDITION REQUIRED ACTION A. (continued) A.2.1 OR A.2.2 Initiate action to fully insert all control rods. Initiate action to satisfy the requirements of this LCO. SURVEILLANCE REQUIREMENTS SR 3.10.5.1 SR 3.10.5.2 SR 3.10.5.3 NMP2 SURVEILLANCE Verify all controls rods, other than the control rod withdrawn for the removal of the associated CRD, are fully inserted. Verify all control rods, other than the control rod withdrawn for the removal of the associated CAD, in a five by five array centered on the control rod withdrawn for the removal of the associated CAD, are disarmed. Verify a control rod withdrawal block is inserted. 3.10.5-2 COMPLETION TIME Immediately Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 9-1-, 152 Single CRD Removal -Refueling 3.10.5 SURVEILLANCE REQUIREMENTS (continued) SR 3.10.5.4 SR 3.10.5.5 NMP2 SURVEILLANCE Perform SR 3.1.1.1. Verify no other CORE ALTERATIONS are in progress. 3.10.5-3 FREQUENCY According to SR 3.1.1.1 In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 Multiple Control Rod Withdrawal -Refueling 3.10.6 ACTIONS CONDITION REQUIRED ACTION A. (continued) A.3.1 OR A.3.2 Initiate action to fully insert all control rods in core cells containing one or more fuel assemblies. Initiate action to satisfy the requirements of this LCO. SURVEILLANCE REQUIREMENTS SR 3.10.6.1 SR 3.10.6.2 SR 3.10.6.3 NMP2 SURVEILLANCE Verify the four fuel assemblies are removed from core cells associated with each control rod or CRD removed. Verify all other control rods in core cells containing one or more fuel assemblies are fully inserted. ------------------------------NOTE-----------------------------Only required to be met during fuel loading. Verify fuel assemblies being loaded are in compliance with an approved spiral reload sequence. 3.10.6-2 COMPLETION TIME Immediately Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9-+, 152 SURVEILLANCE REQUIREMENTS (continued) SR 3.10.8.2 SR 3.10.8.3 SR 3.10.8.4 NMP2 SURVEILLANCE ------------------------------NOTE-----------------------------Not required to be met if SR 3.10.8.3 satisfied. Perform the MODE 2 applicable SRs for LCO 3.3.2.1, Function 2 of Table 3.3.2.1-1. ------------------------------NOTE-----------------------------Not required to be met if SR 3.10.8.2 satisfied. Verify movement of control rods is in compliance with the approved control rod sequence for the SOM test by a second licensed operator or other qualified member of the technical staff. Verify no other CORE ALTERATIONS are in progress. 3.10.8-3 SOM Test -Refueling 3.10.8 FREQUENCY According to the applicable SRs During control rod movement In accordance with the Surveillance Frequency Control Program (continued) Amendment 9-:1-, 152 SURVEILLANCE REQUIREMENTS (continued) SR 3.10.8.5 SR 3.10.8.6 NMP2 SURVEILLANCE Verify each withdrawn control rod does not go to the withdrawn overtravel position. Verify CRD charging water header pressure ::::: 940 psig. 3.10.8-4 SOM Test -Refueling 3.10.8 FREQUENCY Each time the control rod is withdrawn to "full out" position Prior to satisfying LCO 3.10.8.c requirement after work on control rod or CAD System that could affect coupling In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.13 5.5.14 NMP2 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 OBA 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. 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. 5.5-13 152 SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION RELATED TO AMENDMENT NO. 152 TO RENEWED FACILITY OPERATING LICENSE NO. NPF-69 NINE MILE POINT NUCLEAR STATION. LLC EXELON GENERATION COMPANY. LLC DOCKET NO. 50-410 NINE MILE POINT NUCLEAR STATION, UNIT 2 1.0 INTRODUCTION By application dated November 19, 2014, as supplemented by letters dated July 10, 2015, September 10, 2015, and September 24, 2015 (Agencywide Documents Access and Management System (ADAMS) Accession Nos. ML 14329A353, ML 15191A013, ML 15254A069 and ML 15271A029, respectively), Exelon Generation Company, LLC (the licensee) requested changes to the Technical Specifications (TSs) for Nine Mile Point Unit 2 (NMP2). The letters provided clarifying information that did not expand the scope of the application and did not change the staff's original proposed no significant hazards consideration (NSHC) determination as published in the Federal Register(FR) on March 17, 2015 (80 FR 13906). The proposed change would modify the NMP2, TSs by relocating specific surveillance requirement (SR) frequencies to a licensee-controlled program (i.e., the Surveillance Frequency Control Program (SFCP)) in accordance with Nuclear Energy Institute (NEI) 04-10, Revision 1, "Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies" (ADAMS Accession No. ML071360456). The proposed change is consistent with the adoption of U.S. Nuclear Regulatory Commission (NRC) approved Technical Specification Task Force (TSTF) Standard Technical Specifications (STS) Change Traveler TSTF-425, Revision 3, "Relocated Surveillance Frequencies to Licensee Control -RITSTF [Risk-Informed TSTF] Initiative 5b" (ADAMS Accession No. ML090850642). The FR notice published on July 6, 2009 (74 FR 31996), announced the availability of TSTF-425, Revision 3. When implemented, TSTF-425, Revision 3, relocates most periodic frequencies of TS surveillances to the SFCP, and provides requirements for the new program in the Administrative Controls section of the TSs. All surveillance frequencies can be relocated except:
* Frequencies that reference other approved programs for the specific interval (such as the In-Service Testing Program or the Primary Containment Leakage Rate Testing Program);
* Frequencies that are purely event-driven (e.g., "each time the control rod is withdrawn to the 'full out' position");
-2 -* Frequencies that are event-driven, but have a time component for performing the surveillance on a one-time basis once the event occurs (e.g., "within 24 hours after thermal power reaching;:::: 95% RTP" [rated thermal power]); and
* Frequencies that are related to specific conditions (e.g., battery degradation, age and capacity) or conditions for the performance of a surveillance requirement (e.g., "drywell to suppression chamber differential pressure decrease"). The licensee proposed to add the SFCP to TS Section 5.0, "Administrative Controls." The SFCP describes the requirements for the program to control changes to the relocated surveillance frequencies. The TS Bases for each affected surveillance are revised to state that the frequency is controlled under the SFCP. Various editorial changes have been made to the Bases to facilitate the addition of the Bases changes. The proposed changes to the Administrative Controls sections of the TSs to incorporate the SFCP include a specific reference to NEI 04-10, Revision 1, as the basis for making any changes to the surveillance frequencies once they are relocated out of the TSs. In a letter dated September 19, 2007 (ADAMS Accession No. ML072570267), the NRC staff approved NEI Topical Report (TR) NEI 04-10, Revision 1, as acceptable for referencing in licensing actions to the extent specified and under the limitations delineated in NEI 04-10, Revision 1, and the safety evaluation (SE) providing the basis for NRC acceptance of NEI 04-10, Revision 1. Other changes and deviations from TSTF-425, are discussed in Section 3.3 of this SE. 2.0 REGULATORY EVALUATION 2.1 Applicable Commission Policy Statements In the "Final Policy Statement: Technical Specifications for Nuclear Power Plants," dated July 22, 1993 (58 FR 39132) the NRC addressed the use of Probabilistic Safety Analysis {PSA, currently referred to as Probabilistic Risk Assessment or PRA) in STS. In this 1993 publication, the NRC states: The Commission believes that it would be inappropriate at this time to allow requirements which meet one or more of the first three criteria [of Title 10 of the Code of Federal Regulations (10 CFR), Section 50.36] to be deleted from Technical Specifications based solely on PSA (Criterion 4). However, if the results of PSA indicate that Technical Specifications can be relaxed or removed, a deterministic review will be performed .... The Commission Policy in this regard is consistent with its Policy Statement on "Safety Goals for the Operation of Nuclear Power Plants," 51 FR 30028, published on August 21, 1986. The Policy Statement on Safety Goals states in part, " ... probabilistic results should also be reasonably balanced and supported through use of deterministic arguments. In this way, judgments can be made ... about the degree of confidence to be given these [probabilistic] estimates and assumptions. This is a key part of the process for determining the degree of
-3 -regulatory conservatism that may be warranted for particular decisions. This defense-in-depth approach is expected to continue to ensure the protection of public health and safety." ... The Commission will continue to use PSA, consistent with its policy on Safety Goals, as a tool in evaluating specific line-item improvements to Technical Specifications, new requirements, and industry proposals for risk-based Technical Specification changes. Approximately two years later the NRC provided additional detail concerning the use of PRA in the "Final Policy Statement: Use of Probabilistic Risk Assessment in Nuclear Regulatory Activities," dated August 16, 1995 (60 FR 42622). In this publication, the NRC states: The Commission believes that an overall policy on the use of PRA methods in nuclear regulatory activities should be established so that the many potential applications of PRA can be implemented in a consistent and predictable manner that would promote regulatory stability and efficiency. In addition, the Commission believes that the use of PRA technology in NRC regulatory activities should be increased to the extent supported by the state-of-the-art in PRA methods and data and in a manner that complements the NRC's deterministic approach .... PRA addresses a broad spectrum of initiating events by assessing the event frequency. Mitigating system reliability is then assessed, including the potential for multiple and common cause failures. The treatment therefore goes beyond the single failure requirements in the deterministic approach. The probabilistic approach to regulation is, therefore, considered an extension and enhancement of traditional regulation by considering risk in a more coherent and complete manner .... Therefore, the Commission believes that an overall policy on the use of PRA in nuclear regulatory activities should be established so that the many potential applications of PRA can be implemented in a consistent and predictable manner that promotes regulatory stability and efficiency. This policy statement sets forth the Commission's intention to encourage the use of PRA and to expand the scope of PRA applications in all nuclear regulatory matters to the extent supported by the state-of-the-art in terms of methods and data .... Therefore, the Commission adopts the following policy statement regarding the expanded NRC use of PRA: (1) The use of PRA technology should be increased in all regulatory matters to the extent supported by the state-of-the-art in PRA methods and data and in a manner that complements the NRC's deterministic approach and supports the NRC's traditional defense-in-depth philosophy. (2) PRA and associated analyses (e.g., sensitivity studies, uncertainty analyses, and importance measures) should be used in regulatory matters, where
-4 -practical within the bounds of the state-of-the-art, to reduce unnecessary conservatism associated with current regulatory requirements, regulatory guides, license commitments, and staff practices. Where appropriate, PRA should be used to support the proposal for additional regulatory requirements in accordance with 10 CFR 50.109 (Backfit Rule). Appropriate procedures for including PRA in the process for changing regulatory requirements should be developed and followed. It is, of course, understood that the intent of this policy is that existing rules and regulations shall be complied with unless these rules and regulations are revised. (3) PRA evaluations in support of regulatory decisions should be as realistic as practicable and appropriate supporting data should be publicly available for review. (4) The Commission's safety goals for nuclear power plants and subsidiary numerical objectives are to be used with appropriate consideration of uncertainties in making regulatory judgments on the need for proposing and backfitting new generic requirements on nuclear power plant licensees. 2.2 Applicable Regulations Pursuant to 10 CFR 50.36, TSs are required to include items in the following five specific categories related to station operation: (1) safety limits, limiting safety system settings, and limiting control settings; (2) limiting conditions for operation (LCOs); (3) SRs; (4) design features; and (5) administrative controls. These categories will remain in the NMP2, TSs. Paragraph 50.36(c)(3) of 10 CFR states, "Surveillance requirements are requirements relating to test, calibration, or inspection to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met." The FR notice published on July 6, 2009 (74 FR 31996), which announced the availability of TSTF-425, Revision 3, states that the addition of the SFCP to the TSs provides the necessary administrative controls to require that surveillance frequencies relocated to the SFCP are conducted at a frequency to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met. The FR notice also states that changes to surveillance frequencies in the SFCP are made using the methodology contained in NEI 04-10, Revision 1, including qualitative considerations, results of risk analyses, sensitivity studies and any bounding analyses, and recommended monitoring of structures, systems, and components (SSCs), and are required to be documented. Existing regulatory requirements, such as 1 O CFR 50.65, "Requirements for Monitoring the Effectiveness of Maintenance at Nuclear Power Plants" (i.e., the Maintenance Rule), and 10 CFR 50, Appendix B, Criterion XVI, "Corrective Action," require licensee monitoring of surveillance test failures and implementing corrective actions to address such failures. Such failures can result in the licensee increasing the frequency at which a surveillance test is performed. In addition, the SFCP implementation guidance in NEI 04-10, Revision 1, requires monitoring the performance of SSCs for which surveillance frequencies are decreased to assure reduced testing does not adversely impact the SSCs.
-5 -2.3 Applicable NRC Regulatory Guides and Review Plans Regulatory Guide (RG) 1.17 4, "An Approach for Using Probabilistic Risk Assessment in Risk-Informed Decisions on Plant-Specific Changes to the Licensing Basis" Revision 2, (ADAMS Accession No. ML 100910006), describes an acceptable risk-informed approach for assessing the nature and impact of proposed permanent licensing-basis changes by considering engineering issues and applying risk insights. This regulatory guide also provides risk acceptance guidelines for evaluating the results of such evaluations. RG 1.177, "An Approach for Plant-Specific, Risk-Informed Decisionmaking: Technical Specifications," Revision 1, (ADAMS Accession No. ML 100910008), describes an acceptable risk-informed approach specifically for assessing proposed TS changes. RG 1.200, "An Approach for Determining the Technical Adequacy of Probabilistic Risk Assessment Results for Risk-Informed Activities," Revision 2, (ADAMS Accession No. ML090410014}, describes an acceptable approach for determining whether the quality of the PRA, in total or the parts that are used to support an application, is sufficient to provide confidence in the results, such that the PRA can be used in regulatory decision making for light water-reactors. General guidance for evaluating the technical basis for proposed risk-informed changes is provided in Chapter 19, Section 19.2, "Review of Risk Information Used to Support Permanent Plant-Specific Changes to the Licensing Basis: General Guidance" (ADAMS Accession No. ML071700658}, of NUREG-0800, "Standard Review Plan [SRP] for the Review of Safety Analysis Reports for Nuclear Power Plants: LWR Edition." Guidance on evaluating PRA technical adequacy is provided in the SRP, Chapter 19, Section 19.1, "Determining the Technical Adequacy of Probabilistic Risk Assessment for Risk-Informed License Amendment Requests After Initial Fuel Load," Revision 3, (ADAMS Accession No. ML 12193A107). More specific guidance related to risk-informed TS changes is provided in SRP, Chapter 16, Section 16.1, "Risk-Informed Decisionmaking: Technical Specifications," Revision 1, (ADAMS Accession No. ML070380228), which includes changes to Completion Times as part of risk-informed decision making. Section 19.2 of the SRP references the same criteria as RG 1.177, Revision 1, and RG 1.174, Revision 2, and states that a risk-informed application should be evaluated to ensure that the proposed changes meet the following key principles:
* The proposed change meets the current regulations, unless it explicitly relates to a requested exemption or rule change.
* The proposed change is consistent with the defense-in-depth philosophy.
* The proposed change maintains sufficient safety margins.
* When proposed changes result in an increase CDF or risk, the increase(s) should be small and consistent with the intent of the Commission's Safety Goal Policy Statement.
-6 -* The impact of the proposed change should be monitored using performance measurement strategies. 3.0 TECHNICAL EVALUATION The licensee's adoption of TSTF-425, Revision 3, provides for administrative relocation of applicable surveillance frequencies, and provides for the addition of the SFCP to the Administrative Controls of TSs. TSTF-425, Revision 3, also requires the application of NEI 04-10, Revision 1, for any changes to surveillance frequencies within the SFCP. The licensee's application for the changes proposed in TSTF-425, Revision 3, included documentation regarding the PRA technical adequacy consistent with the requirements of RG 1.200, Revision 2. In accordance with NEI 04-10, Revision 1, PRA methods are used, in combination with plant performance data and other considerations, to identify and justify modifications to the surveillance frequencies of equipment at nuclear power plants. This is in accordance with guidance provided in RG 1.17 4, Revision 2, and RG 1.177, Revision 1, in support of changes to surveillance test intervals. 3.1 Review Methodology RG 1.177, Revision 1, identifies five key safety principles required for risk-informed changes to TSs. Each of these principles is addressed by NEI 04-10, Revision 1. 3.1.1 The Proposed Change Meets Current Regulations Section 50.36(c)(3) of 10 CFR requires that TSs include surveillances which are "requirements relating to test, calibration, or inspection to assure that necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met." The licensee is required by its TSs to perform surveillance tests, calibration, or inspection on specific safety-related equipment (e.g., reactivity control, power distribution, electrical, and instrumentation) to verify system operability. Surveillance frequencies are based primarily upon deterministic methods such as engineering judgment, operating experience, and manufacturer's recommendations. The licensee's use of NRG-approved methodologies identified in NEI 04-10, Revision 1, provides a way to establish risk-informed surveillance frequencies that complements the deterministic approach and supports the NRC's traditional defense-in-depth philosophy. The SRs themselves are remaining in the TSs, as required by 10 CFR 50.36(c)(3). This change is analogous with other NRG-approved TS changes in which the SRs are retained in TSs, but the related surveillance frequencies are relocated to licensee-controlled documents, such as surveillances performed in accordance with the In-Service Testing Program and the Primary Containment Leakage Rate Testing Program. Thus, this proposed change complies with 10 CFR 50.36(c)(3) by retaining the requirements relating to test, calibration, or inspection to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met. The regulatory requirements in 10 CFR 50.65 and 10 CFR 50, Appendix B, and the monitoring required by NEI 04-10, Revision 1, ensure that surveillance frequencies are sufficient to assure that the requirements of 10 CFR 50.36 are satisfied and that any performance deficiencies will be identified and appropriate corrective actions taken. The licensee's SFCP ensures that SRs
-7 -specified in the TSs are performed at intervals sufficient to assure the above regulatory requirements are met. In light of the above, the NRC staff concludes that the proposed change meets the first key safety principle of RG 1.177 by complying with current regulations. 3.1.2 The Proposed Change Is Consistent With the Defense-in-Depth Philosophy The defense-in-depth philosophy (i.e., the second key safety principle of RG 1.177, Revision 1 ), is maintained if:
* A reasonable balance is preserved among prevention of core damage, prevention of containment failure, and consequence mitigation.
* Over-reliance on programmatic activities to compensate for weaknesses in plant design is avoided.
* System redundancy, independence, and diversity are preserved commensurate with the expected frequency, consequences of challenges to the system, and uncertainties (e.g., no risk outliers). (Because the scope of the proposed methodology is limited to revision of surveillance frequencies, the redundancy, independence, and diversity of plant systems are not impacted.)
* Defenses against potential common cause failures are preserved, and the potential for the introduction of new common cause failure mechanisms is assessed.
* Independence of barriers is not degraded.
* Defenses against human errors are preserved.
* The intent of the General Design Criteria in 10 CFR Part 50, Appendix A, is maintained. TSTF-425, Revision 3, requires the application of NEI 04-10, Revision 1, for any changes to surveillance frequencies within the SFCP. NEI 04-10, Revision 1, uses both the core damage frequency (CDF) and the large early release frequency (LERF) metrics to evaluate the impact of proposed changes to surveillance frequencies. The guidance of RG 1.17 4, Revision 2, and RG 1.177, Revision 1, for changes to CDF and LERF is achieved by evaluation using a comprehensive risk analysis, which assesses the impact of proposed changes including contributions from human errors and common cause failures (CCFs). Defense-in-depth is also included in the methodology explicitly as a qualitative consideration outside of the risk analysis, as is the potential impact on detection of component degradation that could lead to an increased likelihood of CCFs. The NRC staff concludes that both the quantitative risk analysis and the qualitative considerations assure that a reasonable balance of defense-in-depth is maintained to ensure protection of public health and safety, thus satisfying the second key safety principle of RG 1.177, Revision 1.
-8 -3.1.3 The Proposed Change Maintains Sufficient Safety Margins The engineering evaluation that will be conducted by the licensee under the SFCP when frequencies are revised will assess the impact of the proposed frequency change to assure that sufficient safety margins are maintained. The guidelines used for making that assessment will include ensuring the proposed surveillance test frequency change is not in conflict with approved industry codes and standards or adversely affects any assumptions or inputs to the safety analysis, or, if such inputs are affected, justification is provided to ensure sufficient safety margin will continue to exist. The design, operation, testing methods, and acceptance criteria for SSCs specified in applicable codes and standards (or alternatives approved for use by the NRC) will continue to be met as described in the plants' licensing bases, including the Updated Final Safety Analysis Report and TS Bases, because these are not affected by changes to the surveillance frequencies. Similarly, there is no impact to safety analysis acceptance criteria as described in the plant licensing basis. On this basis, the staff concludes that safety margins are maintained by the proposed methodology, and the third key safety principle of RG 1.177, Revision 1, is satisfied. 3.1.4 When Proposed Changes Result in an Increase in CDF or Risk. the Increases Should Be Small and Consistent with the Intent of the Commission's Safety Goal Policy Statement RG 1.177, Revision 1, provides a framework for evaluating the risk impact of proposed changes to surveillance frequencies which requires identification of the risk contribution from impacted surveillances, determination of the risk impact from the change to the proposed surveillance frequency, and performance of sensitivity and uncertainty evaluations. TSTF-425, Revision 3, provides for application of NEI 04-10, Revision 1, in the SFCP. NEI 04-10, Revision 1, satisfies the intent of RG 1.177, Revision 1, guidance for evaluation of the change in risk, and for assuring that such changes are small by providing the technical methodology to support risk-informed TSs for control of surveillance frequencies. 3.1.4.1 Quality of the PRA The quality of the licensee's PRA must be commensurate with the safety significance of the proposed TS change and the role the PRA plays in justifying the change. That is, the higher change in risk or the greater the uncertainty in that risk from the requested TS change, or both, the more rigor that must go into ensuring the quality of the PRA. RG 1.200, Revision 2, provides regulatory guidance for assessing the technical adequacy of a PRA. The current revision (i.e., Revision 2) of this RG endorses (with clarifications and qualifications) the use of (1) the American Society of Mechanical Engineers (ASME)/American Nuclear Society (ANS) RA-Sa-2009, "Addenda to ASME RA-S-2008 Standard for Level 1/Large Early Release Frequency Probabilistic Risk Assessment for Nuclear Power Plant Applications" (i.e., the PRA Standard), (2) NEI 00-02, "PRA Peer Review Process Guidance" (ADAMS Accession Nos. ML061510619 and ML063390593), and (3) NEI 05-04, "Process for Performing Internal Events PRA Peer Reviews Using the ASME/ANS PRA Standard" (ADAMS Accession No. ML083430462).
-9 -The licensee has performed an assessment of the PRA models used to support the SFCP using the guidance of RG 1.200, Revision 2, to assure that the PRA models are capable of determining the change in risk due to changes to surveillance frequencies of SSCs, using plant-specific data and models. Capability Category II of the endorsed PRA standard is the target capability level for supporting requirements for the internal events PRA for this application. Any identified deficiencies to those requirements are assessed further to determine any impacts to proposed decreases to surveillance frequencies, including the use of sensitivity studies where appropriate, in accordance with NEI 04-10, Revision 1. An internal events PRA peer review was performed in 2009, which, as clarified in response to PRA RAI 1 (ADAMS Accession Number ML 15191A013), was performed against the latest PRA standard ASME/ANS RA-Sa-2009, as endorsed by RG 1.200, Revision 2. The licensee stated that the peer review resulted in 18 findings, which did not meet Capability Category II, and 34 suggestions that met Capability Category II. In the LAR the licensee submitted all peer review Facts and Observations (F&Os) that were not addressed. In response to PRA RAI 2, the licensee provided the list of F&Os applicable to the TSTF-425 application. The NRC staff reviewed (1) the summary of the peer review finding, (2) the licensee's resolution to the finding, and (3) the licensee's assessment of the impact on this application for the submitted F&Os to ensure that any deficiency in not meeting Capability Category II will be addressed and dispositioned for each surveillance frequency evaluation per the NEI 04-10 methodology. The NRC staffs assessment for the F&Os is provided below. F&O 1-1, related to Supporting Requirement DA-C6, was created because the licensee did not include demands from causes other than surveillance tests in its plant specific estimation of demands on standby components. The Supporting Requirement directs the licensee to consider, in addition to surveillance tests, maintenance acts and operational demands. The NRC staff concludes that the inclusion of all of the sources of demands on standby components would assist the licensee in the estimation of the probability of failure on demand; however, outside of surveillance tests, which the licensee considered, this Supporting Requirement would minimally impact the calculation of change in CDF or LERF due to surveillance interval extensions. F&O 2-5, related to Supporting Requirement DA-01, was created because the peer review team observed that the licensee's documentation stated that a Bayesian analysis was not done when there are no plant-specific failures. The licensee stated that it updated the model and documentation with Bayesian analysis for zero events down to failure rates on the order of 1 E-3. The licensee further states that it will continue to perform the Bayesian update for events with zero plant specific failures. Since the licensee has addressed the concern over Bayesian analysis for no observed plant failures and included the updated information in its best practices, the NRC staff finds the disposition acceptable for the application. F&O 2-6, related to Supporting Requirement DA-04, was created because the peer review team did not find documentation that the licensee analyzed inconsistencies between the prior distribution and the plant-specific data in its Bayesian analysis. In response to the F&O, the licensee stated that it performed a review for inconsistencies and a few distributions were identified as potentially inconsistent. For these cases the licensee manipulated the prior distribution to be more representative of plant data; therefore, the NRC concludes that the licensee has properly addressed the F&O for this application.
-10 -F&O 5-2, related to Supporting Requirement IE-A6, was created because the licensee did not include routine system alignments in its calculation of initiating event frequencies. In the licensee's disposition, the licensee indicated that it performed a systematic evaluation that considered routine system alignments and provided documentation in the initiating events notebook. Therefore the NRC staff does not expect this to impact the determination of safety related component failure rates or establishment of surveillance intervals. F&O 6-5, related to Supporting Requirement AS-C1, was created because the peer review team observed that the licensee's Accident Sequence notebook did not contain the event tree top event fault trees. Supporting Requirement AS-C1 requires proper documentation to support the peer review and facilitate PRA upgrades. The licensee stated that this documentation issue will be corrected. As this is a documentation concern, the NRC staff concludes that this would not impact the risk calculations to support changes to surveillance test intervals. Based on the licensee's assessments using the currently applicable PRA standard and revision of RG 1.200, the NRC staff concludes that the level of PRA quality, combined with the proposed evaluation and disposition of gaps, is sufficient to support the evaluation of changes proposed to surveillance frequencies within the SFCP, and is consistent with Regulatory Position 2.3.1 of RG 1.177, Revision 1. 3.1.4.2 Scope of the PRA The licensee is required to evaluate each proposed change to a relocated surveillance frequency using the guidance contained in NEI 04-10, Revision 1, to determine its potential impact on risk (CDF and LERF) from internal events, fires, seismic, other external events, and shutdown conditions. In cases where a PRA of sufficient scope or quantitative risk models were unavailable, the licensee uses bounding analyses, or other conservative quantitative evaluations. A qualitative screening analysis may be used when the surveillance frequency impact on plant risk is shown to be negligible or zero. NMP2 has an internal events PRA model, which it will use to perform quantitative evaluations to support the development of changes to surveillance frequencies in the SFCP, in accordance with NEI 04-10, Revision 1. In Section 2.3 of the LAR, "External Event Considerations," the licensee stated that external hazards were evaluated in the Individual Plant Examination of External Events (IPEEE). Internal fire events were addressed by using the EPRI Fire Induced Vulnerability Evaluation (FIVE) methodology. The licensee noted that the IPEEE fire model was incorporated into the internal events PRA model in a 2009 PRA update. In section 2.3 of the LAR, the licensee stated that it does not have a seismic PRA and that the IPEEE seismic evaluations used the Electronic Power Research Institute (EPRI) Seismic Margins Analysis (SMA) methodology. The licensee stated that high winds, floods, and other (HFO) external hazards were determined in the NMP2 IPEEE to be negligible contributors to overall plant risk. Further, the licensee indicated that for the external hazards for which there is no PRA model, a qualitative or a bounding approach will be performed to provide justification for the acceptability of the proposed test interval change. The licensee's plan on addressing the fire risk and external events through use of qualitative or bounding analysis is an acceptable approach in accordance with NEI 04-10, Revision 1.
-11 -In the response to PRA RAI 3, provided in licensee's letter dated July 10, 2015, the licensee explained that it does not have a shutdown PRA model. The licensee further stated that changes to surveillance frequencies under the SFCP will consider low power and shutdown events in accordance with NEI 04-10, Revision 1, Section 4.0, Step 10. The NRC staff finds the licensee's plan to address low power and shutdown events through use of qualitative or bounding analyses acceptable, consistent with NEI 04-10, Revision 1, Section 4.0, Step 10. Thus, the NRC staff concludes that through the application of NEI 04-10, Revision 1, the licensee's evaluation methodology is sufficient to ensure the scope of the risk contribution of each surveillance frequency change is properly identified for evaluation and is consistent with Regulatory Position 2.3.2 of RG 1.177, Revision 1. 3.1.4.3 PRA Modeling The licensee's methodology includes the determination of whether the SSCs affected by a proposed change to a surveillance frequency are modeled in the PRA. Where the SSC is directly or implicitly modeled, a quantitative evaluation of the risk impact may be carried out. The methodology adjusts the failure probability of the impacted SSCs, including any impacted CCF modes, based on the proposed change to the surveillance frequency. Where the SSC is not modeled in the PRA, bounding analyses are performed to characterize the impact of the proposed change to the surveillance frequency. Potential impacts on the risk analyses due to screening criteria and truncation levels are addressed by the requirements for PRA technical adequacy consistent with guidance contained in RG 1.200, Revision 2, and by sensitivity studies identified in NEI 04-10, Revision 1. Thus, the staff concludes that through the application of NEI 04-10, Revision 1, the NMP2, PRA modeling is sufficient to ensure an acceptable evaluation of risk for the proposed changes in surveillance frequency, and is consistent with Regulatory Position 2.3.3 of RG 1.177, Revision 1. 3.1.4.4 Assumptions for Time Related Failure Contributions The failure probabilities of SSCs modeled in PRAs may include a standby time-related contribution and a cyclic demand-related contribution. In Section 2.2.4 of Attachment 2 to the LAR, the licensee explained that the standby time-related contribution evaluation will be performed. The criteria in NEI 04-10, Revision 1, adjusts the time-related failure contribution of SSCs affected by the proposed change to a surveillance frequency. This is consistent with RG 1.177, Revision 1, Section 2.3.3, which permits separation of the failure rate contributions into demand and standby for evaluation of SRs. If the available data do not support distinguishing between the time-related failures and demand failures, then the change to surveillance frequency is conservatively assumed to impact the total failure probability of the SSC, including both standby and demand contributions. The SSC failure rate (per unit time) is assumed to be unaffected by the change in test frequency, such that the failure probability is assumed to increase linearly with time, and will be confirmed by the required monitoring and feedback implemented after the change in surveillance frequency is implemented. The NEI 04-10 process also requires consideration of qualitative sources of information with regards to potential impacts of test frequency on SSC performance, including industry and plant-specific operating experience, vendor recommendations, industry standards, and code-specified test
-12 -intervals. Thus the process is not reliant upon risk analyses as the sole basis for the proposed changes. The potential benefits of a reduced surveillance frequency, including reduced downtime and reduced potential for restoration errors, test-caused transients, and test-caused wear of equipment, are identified qualitatively, but not quantitatively assessed. Thus, the NRC staff concludes that through the application of NEI 04-10, Revision 1, the licensee has employed reasonable assumptions with regard to extensions of surveillance test intervals, and is consistent with Regulatory Position 2.3.4 of RG 1.177, Revision 1. 3.1.4.5 Sensitivity and Uncertainty Analyses By having the TSs require that changes to the frequencies listed in the SFCP be made in accordance with NEI 04-10, Revision 1, the licensee will be required to have sensitivity studies to assess the impact of uncertainties from key assumptions of the PRA, uncertainty in the failure probabilities of the affected SSCs, impact on the frequency of initiating events, and any identified deviations from Capability Category II of the PRA standard. Where the sensitivity analyses identify a potential impact on the proposed change, revised surveillance frequencies are considered, along with any qualitative considerations that may bear on the results of such sensitivity studies. The licensee will also be required to perform monitoring and feedback of SSC performance once the revised surveillance frequencies are implemented. Thus, the NRC staff concludes that through the application of NEI 04-10, Revision 1, the licensee has appropriately considered the possible impact of PRA model uncertainty and sensitivity to key assumptions and model limitations and is consistent with Regulatory Position 2.3.5 of RG 1.177, Revision 1. 3.1.4.6 Acceptance Guidelines The licensee will be required to quantitatively evaluate the change in total risk (including internal and external events contributions) in terms of CDF and LERF for both the individual risk impact of a proposed change in surveillance frequency and the cumulative impact from all individual changes to surveillance frequencies using the guidance contained in NEI 04-10, Revision 1, in accordance with the TS SFCP. Each individual change to surveillance frequency must show a risk impact below 1 E-6 per year for change to CDF, and below 1 E-7 per year for change to LERF. These changes to CDF and LERF are consistent with the acceptance criteria of RG 1.17 4, Revision 2, for very small changes in risk. Where the RG 1.17 4, Revision 2, acceptance criteria are not met, the process either considers revised surveillance frequencies which are consistent with RG 1.17 4, Revision 2, or the process terminates without permitting the proposed changes. Where quantitative results are unavailable for comparison with the acceptance guidelines, appropriate qualitative analyses are required to demonstrate that the associated risk impact of a proposed change to surveillance frequency is negligible or zero. Otherwise, bounding quantitative analyses are required which demonstrate the risk impact is at least one order of magnitude lower than the RG 1.17 4, Revision 2, acceptance guidelines for very small changes in risk. In addition to assessing each individual SSC surveillance frequency change, the cumulative impact of all changes must result in a risk impact less than 1 E-5 per year for change to CDF, and less than 1 E-6 per year for change to LERF, and the total CDF and total LERF must be reasonably shown to be less than 1 E-4 per year and 1 E-5 per year,
-13 -respectively. These values are consistent with the acceptance criteria of RG 1.17 4, Revision 2, as referenced by RG 1.177, Revision 1, for changes to surveillance frequencies. Consistent with the NRC's SE dated September 19, 2007, for NEI 04-10, Revision 1, the licensee is required to calculate the total change in risk (i.e., the cumulative risk) by comparing a baseline model that uses failure probabilities based on surveillance frequencies prior to being changed per the SFCP to a revised model that uses failure probabilities based on the changed surveillance frequencies. The NRC staff further notes that the licensee includes a provision to exclude the contribution to cumulative risk from individual changes to surveillance frequencies associated with insignificant risk increases (i.e., less than 5E-8 CDF and 5E-9 LERF) once the baseline PRA models are updated to include the effects of the revised surveillance frequencies. The quantitative acceptance guidance of RG 1.174, Revision 2, is supplemented by qualitative information to evaluate the proposed changes to surveillance frequencies, including industry and plant-specific operating experience, vendor recommendations, industry standards, the results of sensitivity studies, and SSC performance data and test history. The final acceptability of the proposed change is based on all of these considerations and not solely on the PRA results. Post implementation performance monitoring and feedback are also required to assure continued reliability of the components. The licensee's application of NEI 04-10, Revision 1, provides acceptable methods for evaluating the risk increase associated with proposed changes to surveillance frequencies, consistent with Regulatory Position 2.4 of RG 1.177, Revision 1. Therefore, the NRC staff concludes that the proposed methodology satisfies the fourth key safety principle of RG 1.177, Revision 1, by assuring any increase in risk is small consistent with the intent of the Commission's Safety Goal Policy Statement. 3.1.5 The Impact of the Proposed Change Should Be Monitored Using Performance Measurement Strategies The licensee's adoption of TSTF-425, Revision 3, requires application of NEI 04-10, Revision 1, in the SFCP. NEI 04-10, Revision 1, requires performance monitoring of SSCs whose surveillance frequencies have been revised as part of a feedback process to assure that the change in test frequency has not resulted in degradation of equipment performance and operational safety. The monitoring and feedback includes consideration of Maintenance Rule monitoring of equipment performance. In the event of SSC performance degradation, the surveillance frequency will be reassessed in accordance with the methodology, in addition to any corrective actions which may be required by the Maintenance Rule. The performance monitoring and feedback specified in NEI 04-10, Revision 1, is sufficient to reasonably assure acceptable SSC performance and is consistent with Regulatory Position 3.2 of RG 1.177, Revision 1. Thus, the NRC staff concludes that the fifth key safety principle of RG 1.177, Revision 1, is satisfied. 3.2 Addition of Surveillance Frequency Control Program to Administrative Controls The licensee proposed including the SFCP and specific requirements into the NMP2, TSs, Section 5.5.14, as follows:
-14 -Surveillance Frequency Control Program This program provides controls for Surveillance Frequencies. The program shall ensure that Surveillance Requirements specified in the Technical Specifications are performed at intervals sufficient to assure that the associated Limiting Conditions for Operation are met. a. The Surveillance Frequency Control Program shall contain a list of Frequencies of those Surveillance Requirements for which the Frequency is controlled by the program. b. Changes to the Frequency listed in the Surveillance Frequency Controlled Program shall be made in accordance with NEI 04-10, "Risk-Informed Method for Control of Surveillance Frequencies," Revision 1. c. The provisions of Surveillance Requirements 3.0.2 and 3.0.3 are applicable to the frequencies established in the Surveillance Frequency Control Program. The proposed program is consistent with the model application of TSTF-425, and therefore, the NRC staff concludes that it is acceptable. 3.3 Deviations from TSTF-425 and Other Changes 3.3.1 Revised Clean TS Pages In its submittal dated November 19, 2014, the licensee only provided marked-up TS pages, but did not provide bases pages which provide reasons for such TS to assist in our review. Only providing mark-ups of the proposed TS changes satisfies the requirements of 10 CFR 50.90 "Application for amendment of license, construction permit, or early site permit," because the mark-ups fully describe the changes desired. The NRC staff finds that this is an administrative deviation from the NRC staff's model application for TSTF-425 implementation dated July 6, 2009 (74 FR 31996), but has no impact on the NRC staff's safety evaluation. 3.3.2 Definition of STAGGERED TEST BASIS In its submittal dated November 19, 2014, the licensee proposed to retain the definition of STAGGERED TEST BASIS in the TS Definition Section 1.1. This phrase is used in Administrative TS Section 5.5.13, "Control Room Habitability," which is not changed in this amendment. The NRC staff finds that this is an administrative deviation from the NRC staff's model application dated July 6, 2009 (74 FR 31996), but has no impact on the NRC staff's safety evaluation. 3.3.3 Differences between NMP2 TSs and NUREG-1433 In its submittal dated November 19, 2014, the licensee stated that the NMP2 TS SR numbers, and associated TS Bases numbers, differ from those in NUREG-1433, Revision 4, "Standard Technical Specifications -General Electric BWR/4 Plants," Volumes 1 and 2, and TSTF-425,
-15 -Revision 3. There are also surveillances contained in NUREG-1433 that are not contained in the NMP2 TSs. These surveillances identified in TSTF-425 for NUREG-1433 are not applicable to NMP2. These differences are administrative deviations from TSTF-425 that have no impact on the NRC staff's safety evaluation. In its submittal dated November 19, 2014, the licensee requested that plant specific surveillance frequencies be relocated to the SFCP. The relocation of the plant-specific surveillance frequencies is consistent with TSTF-425 and with the NRC staff's model SE dated July 6, 2009 (74 FR 31996), including the scope exclusions identified in Section 1.0, "Introduction," of the model SE because the plant-specific surveillance frequencies involved fixed period frequencies. Changes to the frequencies for these plant-specific surveillances would be controlled under the SFCP. Therefore, the NRC staff finds this acceptable. 3.3.4 TS Bases Variations In its submittal dated November 19, 2014, the licensee noted that the TSTF-425 TS Bases insert, "The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program," should be revised to state, "The Surveillance Frequency is controlled under the Surveillance Frequency Control Program." The licensee noted that this change is necessary because surveillance frequencies that were relocated, but not changed, under the SFCP may not have been based on operating experience, equipment reliability, or plant risk. The NRC agreed with the TSTF in a letter dated April 14, 2010 (ADAMS Accession No. ML 100990099), that the wording of the TSTF-425 TS Bases does not apply to SFs relocated to the SFCP but not changed. This is an administrative deviation from TSTF-425 that has no impact on the NRC staff's safety evaluation because the NRC staff does not approve TS Bases changes. 3.4 Summary and Conclusions The NRC staff has reviewed the licensee's proposed relocation of some surveillance frequencies to a licensee-controlled document, and controlling changes to surveillance frequencies in accordance with a new program, the SFCP, identified in the Administrative Controls of TSs. The NRC staff confirmed that this amendment does not relocate surveillance frequencies that reference other approved programs for the specific interval, are purely event-driven, are event-driven but have a time component for performing the surveillance on a one-time basis once the event occurs, or are related to specific conditions. The SFCP and TS Section 5.5.14 references NEI 04-10, Revision 1, which provides a risk-informed methodology using plant-specific risk insights and performance data to revise surveillance frequencies within the SFCP. This methodology supports relocating surveillance frequencies from TSs to a licensee-controlled document, provided those frequencies are changed in accordance with NEI 04-10, Revision 1, which is specified in the administrative controls of the TSs. The licensee's proposed adoption of TSTF-425, Revision 3, and risk-informed methodology of NEI 04-10, Revision 1, as referenced in the Administrative Controls of TSs, satisfies the key principles of risk-informed decision making applied to changes to TSs as delineated in RG 1.177, Revision 1, and RG 1.17 4, Revision 2, in that:
-16 -* The proposed change meets current regulations;
* The proposed change is consistent with defense-in-depth philosophy;
* The proposed change maintains sufficient safety margins;
* Increases in risk resulting from the proposed change are small and consistent with the Commission's Safety Goal Policy Statement; and
* The impact of the proposed change is monitored with performance measurement strategies. Section 50.36(c) of 10 CFR discusses the categories that will be included in TSs. Section 50.36(c)(3) of 10 CFR discusses the specific category of Surveillance Requirements and states, "Surveillance requirements are requirements relating to test, calibration, or inspection to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met." The NRC staff finds that with the proposed relocation of surveillance frequencies to a licensee-controlled document and administratively controlled in accordance with the TS SFCP, the licensee continues to meet 10 CFR 50.36(c)(3). 4.0 STATE CONSULTATION In accordance with the Commission's regulations, the New York State official was notified of the proposed issuance of the amendment. The State official had no comments. 5.0 ENVIRONMENTAL CONSIDERATION This amendment changes inspection or surveillance requirements or requirements with respect to installation or use of facility components located within the restricted area as defined in 10 CFR Part 20. The NRC staff determined that the amendment involves no significant change in the types or significant increase in the amounts of any effluents that may be released offsite, and that there is no significant increase in individual or cumulative occupational radiation exposure. By FR notice dated March 17, 2015 (80 FR 13906), the NRC issued a proposed finding that the amendment involves no significant hazards consideration, and there has been no public comment on these findings. Accordingly, the amendment meets the eligibility criteria for categorical exclusion set forth in 10 CFR 51.22(c)(9). Pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the issuance of the amendment.
-17 -6.0 CONCLUSION The staff has concluded, based on the considerations discussed above, that: (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner, (2) there is reasonable assurance that such activities will be conducted in compliance with the Commission's regulations, and (3) the issuance of the amendment will not be inimical to the common defense and security or to the health and safety of the public. Principal Contributors: Jonathan Evans, NRR/DRA Alice Erickson, NRR/DRA Mihaela Biro, NRR/DRA Date:November 30, 2015 A copy of the related Safety Evaluation is enclosed. A Notice of Issuance will be included in the Commission's next regular biweekly Federal Register notice. Docket No. 50-410
===Enclosures:===
1. Amendment No. 152 to NPF-69 2. Safety Evaluation cc w/encls: Distribution via Listserv DISTRIBUTION: PUBLIC LPLl-1 R/F RidsNrrDorlLPL 1-1 RidsNrrLAKGoldstein RidsNrrPMNineMilePoint J. Evans, NRR M. Biro, NRR
Sincerely,IRA! Brenda L. Mozafari, Sr. Project Manager Plant Licensing Branch 1-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation RidsNrrDraApla RidsNrrDssStsb RidsRgn1 MailCenter RidsACRS_MailCTR TDimitriadis, Region 1 P. Snyder, NRR A Erickson, NRR ADAMS A ccess1on N ML 15317A307 o.: *SE t "tt db ransm1 e ,y memo ML 15251A325 OFFICE NRR/DORL/LPLl-1 /PM NRR/DORL/LPLl-1 /LA NRR/DRA/APLA/BC NRR/DSS/STSB/BC NAME BMozafari KGoldstein SRosenberg* RElliott DATE 11/19/2015 11/17/2015 10/30/2015 11/19/2015 OFFICE OGC /NLO NRR/DORL/LPLl-1 /BC NRR/DORL/LPLl-1 /PM NAME Jlindell TTate BMozafari DATE 11/30/2015 11/30/2015 11/30/2015 OFFICIAL RECORD COPY}}

Revision as of 12:01, 15 March 2018

Nine Mile Point Nuclear Station, Unit 2 - Issuance of Amendment Adoption of Technical Specification Task Force Traveler 425(CAC No. MF5364)
ML15317A307
Person / Time
Site: Nine Mile Point Constellation icon.png
Issue date: 11/30/2015
From: Mozafari B L
Plant Licensing Branch 1
To: Bryan Hanson
Exelon Nuclear, Nine Mile Point
Mozafari B L
References
CAC MF5364
Download: ML15317A307 (159)
v • d • e


Text

Mr. Bryan President and Chief Nuclear Officer Exelon Nuclear Nine Mile Point Nuclear Station, LLC 4300 Winfield Road Warrenville, IL 60555 November 30, 2015

SUBJECT: NINE MILE POINT NUCLEAR STATION, UNIT 2 -ISSUANCE OF AMENDMENT RE: ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER 425 (CAC NO. MF5364)

Dear Mr. Hanson:

The Commission has issued the enclosed Amendment No. 152 to Renewed Facility Operating License No. NPF-69 for the Nine Mile Point Nuclear Station, Unit No. 2 (NMP2). The amendment consists of changes to the Technical Specifications (TSs) in response to your application dated November 19, 2014 (Agencywide Documents Access and Management System (ADAMS) Accession No. ML 14329A353), as supplemented by letters dated July 10, 2015 (ADAMS Accession No. ML 15191A013), September 10, 2015 (ADAMS Accession No. ML 15254A069), and September 24, 2015 (ADAMS Accession No. ML 15271A029). This amendment revises the TSs to require that changes to specific surveillance frequencies will be made in accordance with Nuclear Energy Institute 04-10, Revision 1, "Risk-Informed Technical Specifications Initiative Sb, Risk-Informed Method for Control of Surveillance Frequencies" (ADAMS Accession No. ML071360456). The change is the adoption of NRG-approved Technical Specification Task Force (TSTF) Standard Technical Specifications Change Traveler TSTF-425, Revision 3, "Relocate Surveillance Frequencies to Licensee Control -RITSTF [Risk-Informed TSTF] Initiative Sb" (ADAMS Accession No. ML090850642). The Federal Register(FR) notice published on July 6, 2009 (74 FR 31996), announced the availability of TSTF-425, Revision 3. A copy of the related Safety Evaluation is enclosed. A Notice of Issuance will be included in the Commission's next regular biweekly Federal Register notice. Docket No. 50-410

Enclosures:

1. Amendment No. 152 to NPF-69 2. Safety Evaluation cc w/encls: Distribution via Listserv

Sincerely,, Brenda L. Mozafari, Sr. Project Manager Plant Licensing Branch 1-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation NINE MILE POINT NUCLEAR STATION, LLC EXELON GENERATION COMPANY. LLC DOCKET NO. 50-410 NINE MILE POINT NUCLEAR STATION, UNIT 2 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 152 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 November 19, 2014, as supplemented by letters dated July 10, September 10, and September 24, 2015, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act) and the Commission's rules and regulations set forth in 10 CFR Chapter I; B. The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C. There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations; D. The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E. The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied. 2. 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 -(2) Technical Specifications 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. 152, are hereby incorporated into this license. Exelon Generation Company, LLC shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan. 3. This license amendment is effective as of the date of its issuance and shall be implemented within 120 days.

Attachment:

Changes to the License and Technical Specifications Date of Issuance: November 30, 201 5 FOR THE NUCLEAR REGULATORY COMMISSION Travis L. Tate, Chief Plant Licensing Branch 1-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation ATTACHMENT TO LICENSE AMENDMENT NO. 152 TO RENEWED FACILITY OPERATING LICENSE NO. NPF-69 DOCKET NO. 50-410 Replace the following page of the Renewed Facility Operating License with the attached revised page. The revised page is identified by amendment number and contains marginal lines indicating the areas of change. Remove Page Insert Page Page4 Page 4 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 3.1.3-3 3.1.3-4 3.1.4-2 3.1.5-3 3.1.6-2 3.1.7-1 3.1.7-2 3.1.7-3 3.1.8-2 3.2.1-1 3.2.2-1 3.2.3-1 3.3.1.1-4 3.3.1.1-5 3.3.1.1-6 3.3.1.1-7 3.3.1.2-3 3.3.1.2-4 3.3.1.2-5 3.3.2.1-3 3.3.2.1-4 3.3.2.1-5 3.3.2.2-2 3.3.2.2-3 3.3.3.1-2 3.3.3.1-3 3.3.3.2-2 3.3.4.1-3 Insert Page 3.1.3-3 3.1.3-4 3.1.4-2 3.1.5-3 3.1.6-2 3.1.7-1 3.1.7-2 3.1.7-3 3.1.8-2 3.2.1-1 3.2.2-1 3.2.3-1 3.3.1.1-4 3.3.1.1-5 3.3.1.1-6 3.3.1.1-7 3.3.1.2-3 3.3.1.2-4 3.3.1.2-5 3.3.2.1-3 3.3.2.1-4 3.3.2.1-5 3.3.2.2-2 3.3.2.2-3 3.3.3.1-2 3.3.3.1-3 3.3.3.2-2 3.3.4.1-3 Remove Page 3.3.4.1-4 3.3.4.2-2 3.3.4.2.3 3.3.5.1-8 3.3.5.2-3 3.3.6.1-4 3.3.6.1-5 3.3.6.2-2 3.3.6.2-3 3.3.7.1-3 3.3.7.2-2 3.3.7.2-3 3.3.8.1-2 3.3.8.2-4 3.3.8.3-2 3.3.8.3-3 3.4.1-3 3.4.2-1 3.4.2-2 3.4.3-2 3.4.5-2 3.4.7-3 3.4.8-2 3.4.9-3 3.4.10-2 3.4.11-2 3.4.11-4 3.4.11-5 3.4.12-1 3.5.1-4 3.5.1-5 3.5.1-6 3.5.2-2 3.5.2-3 3.5.2-4 3.5.3-2 3.5.3-3 3.6.1.1-3 3.6.1.2-5 3.6.1.3-10 3.6.1.3-11 3.6.1.3-12 3.6.1.4-1 3.6.1.5-1 3.6.1.6-2 3.6.1.7-3 -2 -Insert Page 3.3.4.1-4 3.3.4.2-2 3.3.4.2.3 3.3.5.1-8 3.3.5.2-3 3.3.6.1-4 3.3.6.1-5 3.3.6.2-2 3.3.6.2-3 3.3.7.1-3 3.3.7.2-2 3.3.7.2-3 3.3.8.1-2 3.3.8.2-4 3.3.8.3-2 3.3.8.3-3 3.4.1-3 3.4.2-1 3.4.2-2 3.4.3-2 3.4.5-2 3.4.7-3 3.4.8-2 3.4.9-3 3.4.10-2 3.4.11-2 3.4.11-4 3.4.11-5 3.4.12-1 3.5.1-4 3.5.1-5 3.5.1-6 3.5.2-2 3.5.2-3 3.5.2-4 3.5.3-2 3.5.3-3 3.6.1.1-3 3.6.1.2-5 3.6.1.3-10 3.6.1.3-11 3.6.1.3-12 3.6.1.4-1 3.6.1.5-1 3.6.1.6-2 3.6.1.7-3 Remove Page 3.6.2.1-3 3.6.2.2-1 3.6.2.3-2 3.6.2.4-2 3.6.3.2-1 3.6.4.1-2 3.6.4.1-3 3.6.4.2-4 3.6.4.3-3 3.7.1-3 3.7.1-4 3.7.2-3 3.7.3-4 3.7.4-2 3.7.5-1 3. 7.6-1 3.8.1-5 3.8.1-6 3.8.1-7 3.8.1-8 3.8.1-9 3.8.1-10 3.8.1-11 3.8.1-12 3.8.1-13 3.8.1-14 3.8.1-15 3.8.1-16 3.8.1-17 3.8.1-18 3.8.3-3 3.8.4-2 3.8.4-3 3.8.4-4 3.8.6-2 3.8.6-3 3.8.7-2 3.8.8-3 3.8.9-2 3.9.1-2 3.9.2-1 3.9.2-2 3.9.3-1 3.9.5-1 3.9.6-1 3.9.7-1 -3 -Insert Page 3.6.2.1-3 3.6.2.2-1 3.6.2.3-2 3.6.2.4-2 3.6.3.2-1 3.6.4.1-2 3.6.4.1-3 3.6.4.2-4 3.6.4.3-3 3.7.1-3 3.7.1-4 3.7.2-3 3.7.3-4 3.7.4-2 3.7.5-1 3.7.6-1 3.8.1-5 3.8.1-6 3.8.1-7 3.8.1-8 3.8.1-9 3.8.1-10 3.8.1-11 3.8.1-12 3.8.1-13 3.8.1-14 3.8.1-15 3.8.1-16 3.8.1-17 3.8.1-18 3.8.3-3 3.8.4-2 3.8.4-3 3.8.4-4 3.8.6-2 3.8.6-3 3.8.7-2 3.8.8-3 3.8.9-2 3.9.1-2 3.9.2-1 3.9.2-2 3.9.3-1 3.9.5-1 3.9.6-1 3.9.7-1 Remove Page 3.9.8-3 3.9.9-3 3.10.2-2 3.10.3-3 3.10.4-3 3.10.4-4 3.10.5-2 3.10.5-3 3.10.6-2 3.10.8-3 3.10.8-4 5.5-13 -4 -Insert Page 3.9.8-3 3.9.9-3 3.10.2-2 3.10.3-3 3.10.4-3 3.10.4-4 3.10.5-2 3.10.5-3 3.10.6-2 3.10.8-3 3.10.8-4 5.5-13

  • -4-(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. 152 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 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 manufacturer's 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, Ill). 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 117through 140, 141, 143, 144, 146, 147, 148, 150, 151, 152 ACTIONS (continued) CONDITION REQUIRED ACTION D. --------------NOTE--------------D.1 Restore compliance Not applicable when with BPWS. THERMAL POWER > 10% ATP. OR ------------------------------------D.2 Restore control rod Two or more inoperable to OPERABLE status. control rods not in compliance with banked position withdrawal sequence (BPWS) and not separated by two or more OPERABLE control rods. E. Required Action and E.1 Be in MODE 3. associated Completion Time of Condition A, C, or D not met. OR Nine or more control rods inoperable. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.1.3.1 Determine the position of each control rod. NMP2 3.1.3-3 Control Rod OPERABILITY 3.1.3 COMPLETION TIME 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> 4 hours 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> FREQUENCY In accordance with the Surveillance Frequency Control Pro ram (continued) Amendment 9+, 152 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE SR 3.1.3.2 Deleted Control Rod OPERABILITY 3.1.3 FREQUENCY SR 3.1.3.3 ------------------------------NOTE ----------------------------SR 3.1.3.4 NMP2 Not required to be performed until 31 days after the control rod is withdrawn and THERMAL POWER is greater than the LPSP of the RWM. Insert each withdrawn control rod at least one notch. Verify each control rod scram time from fully withdrawn to notch position 05 is s; 7 seconds. 3.1.3-4 In accordance with the Surveillance Frequency Control Proqram. In accordance with SR 3.1.4.1, SR 3.1.4.2, SR 3.1.4.3, and SR 3.1.4.4 (continued) Amendment 91, 130, 152 SURVEILLANCE REQUIREMENTS (continued) SR 3.1.4.2 SR 3.1.4.3 SR 3.1.4.4 NMP2 SURVEILLANCE Verify, for a representative sample, each tested control rod scram time is within the limits of Table 3.1.4-1 with reactor steam dome pressure :2'. 800 psig. Verify each affected control rod scram time is within the limits of Table 3.1.4-1 with any reactor steam dome pressure. Verify each affected control rod scram time is within the limits of Table 3.1.4-1 with reactor steam dome pressure :2'. 800 psig. 3.1.4-2 Control Rod Scram Times 3.1.4 FREQUENCY In accordance with the Surveillance Frequency Control Program Prior to declaring control rod OPERABLE after work on control rod or CRD System that could affect scram time Prior to exceeding 40% ATP after fuel movement within the affected core cell Prior to exceeding 40% RTP after work on control rod or CRD System that could affect scram time Amendment 91, 132, 152 Control Rod Scram Accumulators 3.1.5 ACTIONS CONDITION REQUIRED ACTION C. (continued) C.2 Declare the associated control rod inoperable. D. Required Action B.1 or D.1 ------------NOTE------------C.1 and associated Not applicable if all Completion Time not inoperable control met. rod scram accumulators are associated with fully inserted control rods. --------------------------------Place the reactor mode switch in the shutdown position. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.1.5.1 NMP2 Verify each control rod scram accumulator pressure is;::: 940 psig. 3.1.5-3 COMPLETION TIME 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Immediately FREQUENCY In accordance with the Surveillance Frequency Control Pro ram Amendment 9+, 152 ACTIONS (continued) CONDITION B. Nine or more OPERABLE control rods not in compliance with BPWS. SURVEILLANCE REQUIREMENTS B.1 AND B.2 REQUIRED ACTION ------------NOTE-----------RWM may be bypassed as allowed by LCO 3.3.2.1. . Suspend withdrawal of control rods. Place the reactor mode switch in the shutdown position. SURVEILLANCE SR 3.1.6.1 NMP2 Verify all OPERABLE control rods comply with BPWS. 3.1.6-2 Rod Pattern Control 3.1.6 COMPLETION TIME Immediately 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment Q.:t-, 152 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 A. One SLC subsystem A.1 Restore SLC subsystem inoperable. to OPERABLE status. B. Two SLC subsystems B.1 Restore one SLC inoperable. subsystem to OPERABLE status. c. Required Action and C.1 Be in MODE 3. associated Completion Time not met. AND C.2 Be in MODE 4. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.1.7.1 NMP2 Verify available volume of sodium pentaborate solution is within the limits of Figure 3.1.7-1. 3.1.7-1 SLC System 3.1.7 COMPLETION TIME 7 days 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> 12 hours 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 125, 152 SURVEILLANCE REQUIREMENTS (continued) SR 3.1.7.2 SR 3.1.7.3 SR 3.1.7.4 SR 3.1.7.5 SR 3.1.7.6 NMP2 SURVEILLANCE Verify temperature of sodium pentaborate solution is 2". 70°F. Verify temperature of pump suction piping up to the pump suction valve is;::: 70F. Verify continuity of explosive charge. Verify the concentration of sodium pentaborate in solution is within the limits of Figure 3.1.7-1. Verify each SLC subsystem manual, power operated, and automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position, or can be aligned to the correct position. 3.1.7-2 SLC System 3.1.7 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Once within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after water or sodium pentaborate is added to solution Once within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after solution temperature is restored to 2". 70°F In accordance with the Surveillance Frequency Control Program (continued) Amendment 9-+, 152 SLC System 3.1.7 SURVEILLANCE REQUIREMENTS (continued) SR 3.1.7.7 SR 3.1.7.8 SR 3.1.7.9 SR 3.1.7.10 NMP2 SURVEILLANCE Verify each pump develops a flow rate ?. 41.2 gpm at a discharge pressure ?. 1335 psig. Verify flow through one SLC subsystem from pump into reactor pressure vessel. Verify all heat traced piping between storage tank and pump suction valve is unblocked. Verify sodium pentaborate enrichment 92 atom percent B-10. FREQUENCY In accordance with the lnservice Testing Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Once within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after piping temperature is restored to ?. 70°F Prior to addition to SLC tank 3.1.7-3 Amendment 91, 111, 117, 123, 140, 143, 151, 152 SURVEILLANCE REQUIREMENTS SURVEILLANCE SDV Vent and Drain Valves 3.1.8 FREQUENCY SR 3.1.8.1 -------------------------------NOTE ------------------------------SR 3.1.8.2 SR 3.1.8.3 NMP2 Not required to be met on vent and drain valves closed during periormance of SR 3.1.8.2. Verify each SDV vent and drain valve is open. Cycle each SDV vent and drain valve to the fully closed and fully open position. Verify each SDV vent and drain valve: a. Closes in s; 30 seconds after receipt of an actual or simulated scram signal; and b. Opens when the actual or simulated scram signal is reset. 3.1.8-2 In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 3.2 POWER DISTRIBUTION LIMITS APLHGR 3.2.1 3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR) LCO 3.2.1 All APLHGRs shall be less than or equal to the limits specified in the COLA. APPLICABILITY: THERMAL POWER 23% ATP. ACTIONS CONDITION REQUIRED ACTION A. Any APLHGR not within A.1 Restore APLHGR(s) to limits. within limits. B. Required Action and B.1 Reduce THERMAL POWER associated Completion to< 23% ATP. Time not met. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.2.1.1 NMP2 Verify all APLHGRs are less than or equal to the limits specified in the COLA. 3.2.1-1 COMPLETION TIME 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> 4 hours FREQUENCY Once within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after 23% RTP In accordance with the Surveillance Frequency Control Program Amendment 91, 140, 152 3.2 POWER DISTRIBUTION LIMITS 3.2.2 MINIMUM CRITICAL POWER RATIO (MCPR) MCPR 3.2.2 LCO 3.2.2 All MCPRs shall be greater than or equal to the MCPR operating limits specified in the COLR. APPLICABILITY: THERMAL POWER 2 23% RTP. ACTIONS CONDITION REQUIRED ACTION A. Any MCPR not within A.1 Restore MCPR(s) to limits. within limits. B. Required Action and B.1 Reduce THERMAL POWER associated Completion to< 23% RTP. Time not met. SURVEILLANCE REQUIREMENTS SR 3.2.2.1 NMP2 SURVEILLANCE Verify all MCPRs are greater than or equal to the limits specified in the COLA. 3.2.2-1 COMPLETION TIME 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> 4 hours FREQUENCY Once within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after 223% ATP In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 140, 152 3.2 POWER DISTRIBUTION LIMITS 3.2.3 LINEAR HEAT GENERATION RATE (LHGR) LHGR 3.2.3 LCO 3.2.3 All LHGRs shall be less than or equal to the limits specified in the COLA. APPLICABILITY: THERMAL 23% RTP. ACTIONS CONDITION REQUIRED ACTION A. Any LHGR not within A.1 Restore LHGR(s) to limits. within limits. B. Required Action and B.1 Reduce THERMAL POWER associated Completion to< 23% RTP. Time not met. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.2.3.1 NMP2 Verify all LHGRs are less than or equal to the limits specified in the COLA. 3.2.3-1 COMPLETION TIME 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> 4 hours FREQUENCY Once within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after ;:::23% ATP In accordance with the Surveillance Frequency Control Program Amendment 91, 140, 152 SURVEILLANCE REQUIREMENTS RPS Instrumentation 3.3.1.1 ---------------------------------------------------------N 0 TE -----------------------------------------------------------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 <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the associated Function Maintains RPS trip capability. SR 3.3.1.1.1 SR 3.3.1.1.2 SR 3.3.1.1.3 SR 3.3.1.1.4 NMP2 SURVEILLANCE Perform CHANNEL CHECK. Perform CHANNEL CHECK. ---------------------------NOTE-----------------------------Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after THERMAL POWER 23% ATP. Verify the absolute difference between the average power range monitor (APRM) channels and the calculated power ::; 2% RTP while operating at 23% RTP. ---------------------------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 <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after entering MODE 2. Perform CHANNEL FUNCTIONAL TEST. FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) 3.3.1.1-4 Amendment91, 92, 123, 140, 151, 152 SURVEILLANCE REQUIREMENTS (continued) SR 3.3.1. 1.5 SR 3.3.1 .1.6 SR 3.3.1.1.7 SR 3.3.1.1.8 SR 3.3.1 .1.9 SR 3.3.1. 1. 10 SURVEILLANCE Verify the source range monitor (SAM) and intermediate range monitor (IRM) channels overlap. ---------------------------NOTE-----------------------------Only required to be met during entry into MODE 2 from MODE 1. Verify the IRM and APRM channels overlap. Calibrate the local power range monitors. Perform CHANNEL FUNCTIONAL TEST. Calibrate the trip units. --------------------------NOTES----------------------------1. For Function 2.a, not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after entering MODE2. 2. For Function 2.e, the CHANNEL FUNCTIONAL TEST only requires toggling the appropriate outputs of the APRM. Perform CHANNEL FUNCTIONAL TEST. RPS Instrumentation 3.3.1.1 FREQUENCY Prior to fully Withdrawing SR Ms In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) NMP2 3.3.1.1-5 Amendment Q1, 92, 151,152 SURVEILLANCE REQUIREMENTS (continued) SR 3.3.1.1.11 SR 3.3.1.1.12 SR 3.3.1.1.13 SR 3.3.1.1.14 SR 3.3.1.1.15 NMP2 SURVEILLANCE Perform CHANNEL CALIBRATION Perform CHANNEL FUNCTIONAL TEST. ----------------------------N 0 TES ----------------------------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 <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 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. Perform LOGIC SYSTEM FUNCTIONAL TEST. Verify Turbine Stop Valve -Closure, and Turbine Control Valve Fast Closure, Trip Oil Pressure -Low Functions are not bypassed when THERMAL POWER 26% RTP. 3.3.1.1-6 RPS Instrumentation 3.3.1.1 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) 152 SURVEILLANCE REQUIREMENTS (continued) SR 3.3.1.1.16 SR 3.3.1.1.17 NMP2 SURVEILLANCE Deleted --------------------------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. 3.3.1.1-7 RPS Instrumentation 3.3.1.1 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9+,-9-2, 152 SURVEILLANCE REQUIREMENTS SRM Instrumentation 3.3.1.2 ---------------------------------------------------------N 0 TE -----------------------------------------------------------Refer to Table 3.3.1.2-1 to determine which SRs apply for each applicable MODE or other specified condition. SR 3.3.1.2.1 SR 3.3.1.2.2 SR 3.3.1.2.3 NMP2 SURVEILLANCE Perform CHANNEL CHECK. --------------------------NOTES----------------------------1. Only required to be met during CORE ALTERATIONS. 2. One SRM may be used to satisfy more than one of the following. Verify an OPERABLE SRM detector is located in: a. The fueled region; b. The core quadrant where CORE AL TERA TIONS are being performed when the associated SRM is included in the fueled region; and c. A core quadrant adjacent to where CORE ALTERATIONS are being performed, when the associated SRM is included in the fueled region. Perform CHANNEL CHECK. 3.3.1.2-3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 9+, 152 SURVEILLANCE REQUIREMENTS (continued} SA 3.3.1 .2.4 SR 3.3.1.2.5 SR 3.3.1.2.6 NMP2 SURVEILLANCE ---------------------------NOTE-----------------------------Not required to be met with less than or equal to four fuel assemblies adjacent to the SRM and no other fuel assemblies in the associated core quadrant. Verify count rate is: a. ?: 3.0 cps with a signal to noise ratio ?: 2: 1; or b. > 1.3 cps with a signal to noise ratio ?: 5: 1. ---------------------------NOTE-----------------------------The determination of signal to noise ratio is not required to be met with less than or equal to four fuel assemblies adjacent to the SRM and no other fuel assemblies in the associated core quadrant. Perform CHANNEL FUNCTIONAL TEST and determination of signal to noise ratio. ---------------------------NOTE-----------------------------Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after IRMs on Range 2 or below. Perform CHANNEL FUNCTIONAL TEST and determination of signal to noise ratio. 3.3.1.2-4 SRM Instrumentation 3.3.1.2 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 94-, 152 SURVEILLANCE REQUIREMENTS continued SR 3.3.1.2.7 NMP2 SURVEILLANCE --------------------------NOTES----------------------------1. Neutron detectors are excluded. 2. Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after IRMs on Range 2 or below. Perform CHANNEL CALIBRATION. 3.3.1.2-5 SRM Instrumentation 3.3.1.2 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9-1-,152 Control Rod Block Instrumentation 3.3.2.1 ACTIONS (continued) CONDITION E. One or more Reactor Mode Switch -Shutdown Position channels inoperable. SURVEILLANCE REQUIREMENTS E.1 AND E.2 REQUIRED ACTION Suspend control rod withdrawal. Initiate action to fully insert all insertable control rods in core cells containing one or more fuel assemblies. COMPLETION TIME Immediately Immediately --------------------------------------------------------N 0 TES ----------------------------------------------------------1. Refer to Table 3.3.2.1-1 to determine which SRs apply for each Control Rod Block Function. 2. When an RBM channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the associated Function maintains control rod block capability. SR 3.3.2.1.1 NMP2 SURVEILLANCE ---------------------------NOTE-----------------------------Not required to be performed until 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after any control rod is withdrawn at 10% RTP in MODE 2. Perform CHANNEL FUNCTIONAL TEST. 3.3.2.1-3 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment 9-+. 152 Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS (continued) SR 3.3.2.1.2 SR 3.3.2.1.3 SR 3.3.2. 1.4 NMP2 SURVEILLANCE ---------------------------NOTE-----------------------------Not required to be performed until 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after THERMAL POWER is$; 10% ATP in MODE 1. Perform CHANNEL FUNCTIONAL TEST. Perform CHANNEL FUNCTIONAL TEST. ---------------------------NOTE-----------------------------Neutron detectors are excluded. Verify the ABM: a. Low Power Range -Upscale Function is not bypassed when APRM Simulated Thermal Power is 28% and < 63% ATP and a peripheral control rod is not selected. b. Intermediate Power Range -Upscale Function is not bypassed when APRM Simulated Thermal Power is 63% and < 83% ATP and a peripheral control rod is not selected. c. High Power Range -Upscale Function is not bypassed when APRM Simulated Thermal Power is 83% RTP and a peripheral control rod is not selected. 3.3.2.1-4 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 123, 152 Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS (continued) SR 3.3.2.1.5 SR 3.3.2.1.6 SR 3.3.2.1.7 SR 3.3.2.1.8 NMP2 SURVEILLANCE Verify the RWM is not bypassed when THERMAL POWER is::;; 10% RTP. ---------------------------NOTE-----------------------------Not required to be performed until 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after reactor mode switch is in the shutdown position. Perform CHANNEL FUNCTIONAL TEST. ---------------------------NOTE-----------------------------Neutron detectors are excluded. Perform CHANNEL CALIBRATION. Verify control rod sequences input to the RWM are in conformance with BPWS. 3.3.2.1-5 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Prior to declaring RWM OPERABLE following loading of sequence into RWM Amendment 94-, 152 Feedwater System and Main Turbine High Water Level Trip Instrumentation 3.3.2.2 ACTIONS (continued) CONDITION C. Required Action and C.1 associated Completion Time not met. REQUIRED ACTION --------------NOTE--------------Only applicable if inoperable channel is the result of an inoperable feedwater pump breaker. Remove affected feedwater pump(s) from service. COMPLETION TIME 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> C.2 Reduce THERMAL POWER 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> to< 23% ATP. SURVEILLANCE REQUIREMENTS ---------------------------------------------------------N 0 TE --------------------------------------------------------------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 <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided feedwater system and main turbine high water level trip capability is maintained. SURVEILLANCE SR 3.3.2.2.1 Perform CHANNEL CHECK. SR 3.3.2.2.2 Perform CHANNEL FUNCTIONAL TEST. NMP2 3.3.2.2-2 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 140,152 Feedwater System and Main Turbine High Water Level Trip Instrumentation 3.3.2.2 SURVEILLANCE REQUIREMENTS (continued) SR 3.3.2.2.3 SR 3.3.2.2.4 NMP2 SURVEILLANCE Perform CHANNEL CALIBRATION. The Allowable Value shall be 203.8 inches. Perform LOGIC SYSTEM FUNCTIONAL TEST, including breaker and valve actuation. 3.3.2.2-3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9+,152 ACTIONS (continued) CONDITION D. Required Action and D.1 associated Completion Time of Condition C not met. E. As required by E.1 Required Action D.1 and referenced in Table 3.3.3.1-1. F. As required by F.1 Required Action D.1 and referenced in Table 3.3.3.1-1. SURVEILLANCE REQUIREMENTS REQUIRED ACTION Enter the Condition referenced in Table 3.3.3.1-1 for the channel. Be in MODE3. Initiate action in accordance with Specification 5.6.6. PAM Instrumentation 3.3.3.1 COMPLETION TIME Immediately 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Immediately --------------------------------------------------------NOTES ----------------------------------------------------------1. These SRs apply to each Function in Table 3.3.3.1-1, except where identified in the SR. 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 <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the other required channel in the associated Function is OPERABLE. SURVEILLANCE SR 3.3.3.1.1 Perform CHANNEL CHECK. NMP2 3.3.3.1-2 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment 9+,152 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE SR 3.3.3.1.2 Perform CHANNEL CALIBRATION. NMP2 3.3.3.1-3 PAM Instrumentation 3.3.3.1 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 91, 124,152 SURVEILLANCE REQUIREMENTS Remote Shutdown System 3.3.3.2 ---------------------------------------------------------N 0 TE -----------------------------------------------------------When an instrumentation 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 <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />. SR 3.3.3.2. i SR 3.3.3.2.2 SR 3.3.3.2.3 NMP2 SURVEILLANCE Perform CHANNEL CHECK for each required instrumentation channel that is normally energized. Verify each required control circuit and transfer switch is capable of performing the intended functions. Perform CHANNEL CALIBRATION for each required instrumentation channel. 3.3.3.2-2 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9+,152 EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS ---------------------------------------------------------N 0 TE -------------------------------------------------------------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 <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the associated Function maintains EOC-RPT trip capability. SR 3.3.4.1.1 SR 3.3.4. 1.2 SR 3.3.4. 1.3 SR 3.3.4.1.4 SR 3.3.4.1.5 NMP2 SURVEILLANCE Perform CHANNEL FUNCTIONAL TEST. Perform CHANNEL CALIBRATION. The Allowable Values shall be: a. TSV -Closure: 7% closed; and b. TCV Fast Closure, Trip Oil Pressure -Low: ? 465 psig. Perform LOGIC SYSTEM FUNCTIONAL TEST, including breaker actuation. Verify TSV -Closure and TCV Fast Closure, Trip Oil Pressure -Low Functions are not bypassed when THERMAL POWER is? 26% ATP. ------------------------------NOTE-----------------------------Breaker arc suppression time may be assumed from the most recent performance of SR 3.3.4.1.6. Verify the EOC-RPT SYSTEM RESPONSE TIME is within limits. 3.3.4.1-3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 140,152 SURVEILLANCE REQUIREMENTS continued SR 3.3.4.1.6 NMP2 SURVEILLANCE Determine RPT breaker arc suppression time. 3.3.4.1-4 EOC-RPT Instrumentation 3.3.4.1 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9+,152 ACTIONS (continued) CONDITION B. One Function with B.1 ATWS-RPT trip capability not maintained. c. Both Functions with C.1 ATWS-RPT trip capability not maintained. D. Required Action and D.1 associated Completion Time not met. OR 0.2 SURVEILLANCE REQUIREMENTS ATWS-RPT Instrumentation 3.3.4.2 REQUIRED ACTION COMPLETION Tl ME Restore AlWS-RPT trip 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> capability. Restore AlWS-RPT trip 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> capability for one Function. Remove the associated 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> recirculation pump breaker(s) from service. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Be in MODE2. ---------------------------------------------------------N 0 TE -----------------------------------------------------------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 <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the associated Function maintains A TWS-RPT trip capability. SURVEILLANCE SR 3.3.4.2.1 Perform CHANNEL CHECK. NMP2 3.3.4.2-2 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment 9-+,152 ATWS-RPT Instrumentation 3.3.4.2 SURVEILLANCE REQUIREMENTS (continued) SR 3.3.4.2.2 SR 3.3.4.2.3 SR 3.3.4.2.4 SR 3.3.4.2.5 SR 3.3.4.2.6 NMP2 SURVEILLANCE Perform CHANNEL FUNCTIONAL TEST. Calibrate the analog trip modules. Verify, for the Reactor Vessel Steam Dome Pressure -High Function, the low frequency motor generator trip is not bypassed for> 29 seconds when THERMAL POWER is > 5% ATP. Perform CHANNEL CALIBRATION. The Allowable Values shall be: a. Reactor Vessel Water Level -Low Low, Level 2: 101.8 inches; and b. Reactor Vessel Steam Dome Pressure -High: ::;; 1080 psig. Perform LOGIC SYSTEM FUNCTIONAL TEST, including breaker actuation. 3.3.4.2-3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Su rvei I lance Frequency Control Program Amendment 9+,152 SURVEILLANCE REQUIREMENTS ECCS Instrumentation 3.3.5.1 --------------------------------------------------------N 0 TES ----------------------------------------------------------1. Refer to Table 3.3.5.1-1 to determine which SRs apply for each ECCS Function. 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed as follows: (a) for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for Functions 3.e, 3.g, 3.h, and 3.i; and (b) for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for Functions other than 3.e, 3.g, 3.h, and 3.i, 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 NMP2 3.3.5.1-8 Amendment 9+,152 RCIC System Instrumentation 3.3.5.2 SURVEILLANCE REQUIREMENTS --------------------------------------------------------N 0 TES ----------------------------------------------------------1. Refer to Table 3.3.5.2-1 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 <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for Functions 4 and 5; and (b) for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for Functions 1, 2, and 3 provided the associated Function maintains RCIC initiation capability. SURVEILLANCE FREQUENCY SR 3.3.5.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.5.2.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.5.2.3 Calibrate the trip units. In accordance with the Surveillance Frequency Control Program SR 3.3.5.2.4 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.5.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program NMP2 3.3.5.2-3 Amendment 9-1-,152 Primary Containment Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS --------------------------------------------------------N 0 TES ----------------------------------------------------------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 <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 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 3.3.6.1-4 Amendment 91, 147,152 Primary Containment Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS continued SR 3.3.6.1.7 NMP2 SURVEILLANCE -------------------------------NOTE-----------------------------The sensor response time may be assumed to be the design sensor response time. FREQUENCY Verify the ISOLATION SYSTEM RESPONSE TIME In accordance with is within limits. the Surveillance Frequency Control Program 3.3.6.1-5 Amendment 9+, 152 Secondary Containment Isolation Instrumentation 3.3.6.2 ACTIONS CONDITION C. (continued) SURVEILLANCE REQUIREMENTS REQUIRED ACTION C.1.2 AND C.2.1 OR C.2.2 Declare associated secondary containment isolation valves inoperable. Place the associated standby gas treatment (SGT) subsystem in operation. Declare associated SGT subsystem inoperable. COMPLETION TIME 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 1 hour 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> --------------------------------------------------------N 0 TES ----------------------------------------------------------1. Refer to Table 3.3.6.2-1 to determine which SRs apply for each Secondary Containment Isolation Function. 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, provided the associated Function maintains isolation capability. SURVEILLANCE SR 3.3.6.2.1 Perform CHANNEL CHECK. NMP2 3.3.6.2-2 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment 9-1-, 152 Secondary Containment Isolation Instrumentation 3.3.6.2 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE SR 3.3.6.2.2 Perform CHANNEL FUNCTIONAL TEST. SR 3.3.6.2.3 Calibrate the trip unit. SR 3.3.6.2.4 Perform CHANNEL CALIBRATION. SR 3.3.6.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. NMP2 3.3.6.2-3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9+,152 SURVEILLANCE REQUIREMENTS CREF System Instrumentation 3.3.7.1 --------------------------------------------------------N 0 TES ----------------------------------------------------------1. Refer to Table 3.3.7.1-1 to determine which SRs apply for each 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 <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the associated Function maintains CREF initiation capability. SURVEILLANCE FREQUENCY SR 3.3.7.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.7.1.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SA 3.3.7.1.3 Calibrate the trip units. In accordance with the Surveillance Frequency Control Program SR 3.3.7.1.4 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.7.1.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program NMP2 3.3.7.1-3 Amendment 9+,152 Mechanical Vacuum Pump Isolation Instrumentation 3.3.7.2 ACTIONS (continued) CONDITION C. Required Action and associated Completion Time not met. SURVEILLANCE REQUIREMENTS C.1 OR C.2 OR C.3 OR C.4 REQUIRED ACTION Isolate the associated mechanical vacuum pump(s). Remove the associated mechanical vacuum pump breaker(s) from service. Isolate the main steam lines. Be in MODE 3. COMPLETION TIME 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 12 hours 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 12 hours ---------------------------------------------------------N 0 TE -----------------------------------------------------------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 <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided mechanical vacuum pump isolation capability is maintained. SURVEILLANCE SR 3.3. 7 .2.1 Perform CHANNEL CHECK. SR 3.3.7.2.2 Perform CHANNEL FUNCTIONAL TEST. NMP2 3.3.7.2-2 FREQUENCY In accordance with the Surveillance Frequency Control Proa ram In accordance with the Surveillance Frequency Control Program (continued) Amendment 9+, 152 Mechanical Vacuum Pump Isolation Instrumentation 3.3.7.2 SURVEILLANCE REQUIREMENTS (continued) SR 3.3.7.2.3 SR 3.3.7.2.4 NMP2 SURVEILLANCE Perform CHANNEL CALIBRATION. The Allowable Value shall be 3.6 x full power background. Perform LOGIC SYSTEM FUNCTIONAL TEST including isolation valve and mechanical vacuum pump breakers actuation. 3.3.7.2-3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 SURVEILLANCE REQUIREMENTS LOP Instrumentation 3.3.8.1 --------------------------------------------------------NOTES ----------------------------------------------------------1. Refer to Table 3.3.8.1-1 to determine which SRs apply for each LOP Function. 2. When.a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> provided the associated Function maintains LOP initiation capability. SURVEILLANCE SR 3.3.8.1.1 Perform CHANNEL FUNCTIONAL TEST. SR 3.3.8.1.2 Perform CHANNEL CALIBRATION. SR 3.3.8.1.3 Perform LOGIC SYSTEM FUNCTIONAL TEST. NMP2 3.3.8.1-2 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 RPS Electric Power Monitoring -Logic 3.3.8.2 SURVEILLANCE REQUIREMENTS ---------------------------------------------------------N 0 TE -----------------------------------------------------------When an RPS electric power monitoring assembly is placed in an inoperable status solely for performance of required Surveillances, entry into the associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the other RPS electric power monitoring assembly for the associated RPS logic bus maintains trip capability. SURVEILLANCE FREQUENCY SR 3.3.8.2.1 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.8.2.2 Perform CHANNEL CALIBRATION. The In accordance Allowable Values shall be: with the Surveillance a. Overvoltage (with time delay set to Frequency Control :::;; 2.5 seconds) Program Bus A:::;; 130.2 V Bus B:::;; 129.8 V b. Undervoltage (with time delay set to :::;; 2.5 seconds) Bus A:::::: 115.5 V Bus B :::::: 114.2 V c. Underfrequency (with time delay set to s; 2.5 seconds) Bus A:::: 57.5 Hz Bus B 2 57.5 Hz SR 3.3.8.2.3 Perform a system functional test. In accordance with the Surveillance Frequency Control Program NMP2 3.3.8.2-4 Amendment 9+;-9-9, 152 ACTIONS (continued) CONDITION D. Required Action and associated Completion Time of Condition A or B not met in MODE 5 with any control rod withdrawn from a core cell containing one or more fuel assemblies. SURVEILLANCE REQUIREMENTS D.1 RPS Electric Power Monitoring -Scram Solenoids 3.3.8.3 REQUIRED ACTION Initiate action to fully insert all insertable control rods in core cells containing one or more fuel assemblies. COMPLETION TIME Immediately ---------------------------------------------------------N 0 TE -----------------------------------------------------------When an RPS electric power monitoring assembly is placed in an inoperable status solely for performance of required Surveillances, entry into the associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the other RPS electric power monitoring assembly for the associated RPS scram solenoid bus maintains trip capability. SURVEILLANCE SR 3.3.8.3.1 Perform CHANNEL FUNCTIONAL TEST. NMP2 3.3.8.3-2 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment ff-1-,152 RPS Electric Power Monitoring -Scram Solenoids 3.3.8.3 SURVEILLANCE REQUIREMENTS (continued) SR 3.3.8.3.2 SR 3.3.8.3.3 NMP2 SURVEILLANCE Perform CHANNEL CALIBRATION. The Allowable Values shall be: a. Overvoltage (with time delay set to s 2.5 seconds) Bus As 127.6 V Bus B s 127.6 V b. Undervoltage (with time delay set to s 2.5 seconds) Bus A 113.0 V Bus B 113.6 V c. Underfrequency (with time delay set to s 2.5 seconds) Bus 57.5 Hz Bus B 57.5 Hz Perform a system functional test. 3.3.8.3-3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9+,-99, 152 SURVEILLANCE REQUIREMENTS SURVEILLANCE Recirculation Loops Operating 3.4.1 FREQUENCY SR 3.4.1.1 ------------------------------N 0 TE-----------------------------NMP2 Not required to be performed until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after both recirculation loops are in operation. Verify jet pump loop flow mismatch with both recirculation loops in operation is: a. $ 10% of rated core flow when operating at an effective core flow < 70% of rated core flow; and b. ::; 5% of rated core flow when operating at an effective core flow 70% of rated core flow. 3.4.1-3 In accordance with the Surveillance Frequency Control Program Amendment Q..:1.,-92, 152 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.2 Flow Control Valves (FCVs) FCVs 3.4.2 LCO 3.4.2 A recirculation loop FCV shall be OPERABLE in each operating recirculation loop. APPLICABILITY: MODES 1 and 2. ACTIONS ---------------------------------------------------------N 0 TE -----------------------------------------------------------Separate Condition entry is allowed for each FCV. CONDITION REQUIRED ACTION A. One or two required A.1 Lock up the FCV. FCVs inoperable. B. Required Action and B.1 Be in MODE 3. associated Completion Time not met. SURVEILLANCE REQUIREMENTS SR 3.4.2.1 NMP2 SURVEILLANCE Verify each FCV fails "as is" on loss of hydraulic pressure at the hydraulic unit. 3.4.2-1 COMPLETION TIME 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> 12 hours FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment 9-+, 152 SURVEILLANCE REQUIREMENTS continued SR 3.4.2.2 NMP2 SURVEILLANCE Verify average rate of each FCV movement is: a. ::; 11 % of stroke per second for opening; and b. :::; 11 % of stroke per second for closing. 3.4.2-2 FCVs 3.4.2 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 SURVEILLANCE REQUIREMENTS SR 3.4.3.1 NMP2 SURVEILLANCE -----------------------------1. Not required to be performed until 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> after associated recirculation loop is in operation. 2. Not required to be performed until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after> 23% RTP. Verify at least two of the following criteria (a, b, and c) are satisfied for each operating recirculation loop: a. Jet pump loop flow versus flow control valve position differs by $ 1 0% from established patterns. b. Jet pump loop flow versus recirculation loop drive flow differs by $ 10% from established patterns. c. Each jet pump diffuser to lower plenum differential pressure differs by $ 20% from established patterns. 3.4.3-2 Jet Pumps 3.4.3 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 91, 140, 152 ACTIONS (continued) CONDITION C. Required Action and associated Completion Time of Condition A or B not met. Pressure boundary LEAKAGE exists. REQUIRED ACTION C.1 Be in MODE 3. C.2 Be in MODE4. SURVEILLANCE REQUIREMENTS SR 3.4.5.1 NMP2 SURVEILLANCE Verify RCS unidentified and identified LEAKAGE and unidentified LEAKAGE increase are within limits. 3.4.5-2 RCS Operational LEAKAGE 3.4.5 COMPLETION TIME 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 36 hours FREQUENCY In accordance with the SuNeillance Frequency Control Program Amendment 9+, 152 RCS Leakage Detection Instrumentation 3.4.7 SURVEILLANCE REQUIREMENTS ----------------------------------------------------------N 0 TE ----------------------------------------------------------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 <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the other required leakage detection instrumentation is OPERABLE. SURVEILLANCE FREQUENCY SR 3.4.7.1 Perform CHANNEL CHECK of required drywell In accordance atmospheric monitoring system. with the Surveillance Frequency Control Program SR 3.4.7.2 Perform CHANNEL FUNCTIONAL TEST of the In accordance drywall floor drain tank fill rate with the monitoring system. Surveillance Frequency Control Program SR 3.4.7.3 Perform source check of required drywell In accordance with atmospheric monitoring system. the Surveillance Frequency Control Program SR 3.4.7.4 Perform CHANNEL FUNCTIONAL TEST of required In accordance with drywell atmospheric monitoring system. the Surveillance Frequency Control Program SR 3.4.7.5 Perform CHANNEL CALIBRATION of required In accordance with leakage detection instrumentation. the Surveillance Frequency Control Program NMP2 3.4.7-3 Amendment 91 , 139, 152 ACTIONS CONDITION REQUIRED ACTION B. (continued) B.2.2.1 Be in MODE 3. B.2.2.2 Be in MODE 4. SURVEILLANCE REQUIREMENTS SR 3.4.8.1 NMP2 SURVEILLANCE ---------------------------NOTE-------------------------------Only required to be performed in MODE 1. Verify reactor coolant DOSE EQUIVALENT 1-131 specific activity is s; 0.2 µCi/gm. 3.4.8-2 RCS Specific Activity 3.4.8 COMPLETION TIME 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 36 hours FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 RHR Shutdown Cooling System -Hot Shutdown 3.4.9 SURVEILLANCE REQUIREMENTS SR 3.4.9.1 SR 3.4.9.2 NMP2 SURVEILLANCE ---------------------------NOTE-----------------------------Not required to be met until 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after reactor steam dome pressure is less than the AHR cut-in permissive pressure. Verify one AHR shutdown cooling subsystem or recirculation pump is operating. ---------------------------NOTE-----------------------------Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam dome pressure is less than the AHR cut-in permissive pressure. Verify AHR shutdown cooling subsystem Locations susceptible to gas accumulation are sufficiently filled with water. 3.4.9-3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 91, 150, 152 AHR Shutdown Cooling System -Cold Shutdown 3.4.10 ACTIONS (continued) CONDITION B. No AHR shutdown cooling subsystem in operation. No recirculation pump in operation. B.1 AND B.2 REQUIRED ACTION Verify reactor coolant circulating by an alternate method. Monitor reactor coolant temperature and pressure. SURVEILLANCE REQUIREMENTS SR 3.4.10.1 SR 3.4.10.2 NMP2 SURVEILLANCE Verify one RHR shutdown cooling subsystem or recirculation pump is operating. Verify AHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water. 3.4.10-2 COMPLETION TIME 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from discovery of no reactor coolant circulation Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter Once per hour FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 91, 150, 152 ACTIONS (continued) CONDITION REQUIRED ACTION C. -----------NOTE-----------------Required Action C.2 C.1 Initiate action to restore parameter(s) to within limits. shall be completed if this Condition is entered. ------------------------------------AND Requirements of the LCO not met in other than MODES 1 , 2, and 3. C.2 Determine RCS is acceptable for operation. SURVEILLANCE REQUIREMENTS SR 3.4.11.1 NMP2 SURVEILLANCE ---------------------------NOTE-----------------------------Only required to be performed during RCS heatup and cooldown operations, and RCS system leakage and hydrostatic testing. Verify: a. RCS pressure and RCS temperature are within the applicable limits specified in the PTLR; b. RCS heatup and cooldown rates are within limits specified in the PTLR; and c. RCS temperature change during system leakage and hydrostatic testing is maintained within limits specified in the PTLR. 3.4.11-2 RCS PIT Limits 3.4.11 COMPLETION TIME Immediately Prior to entering MODE 2 or3 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 145, 152 SURVEILLANCE REQUIREMENTS (continued} SR 3.4.11.5 SR 3.4.11.6 SR 3.4.11.7 NMP2 SURVEILLANCE ----------------------------NOTE-----------------------------Only required to be met in single loop operation with THERMAL POWER :s 30% ATP or the operating jet pump loop flow :s 50% rated jet pump loop flow. Verify the difference between the bottom head coolant temperature and the RPV coolant temperature is within limits specified in the PTLR. ----------------------------NOTE-----------------------------Only required to be met in single loop operation when the idle recirculation loop is not isolated from the APV, and with THERMAL POWER :s 30% ATP or the operating jet pump loop flow s 50% rated jet pump loop flow. Verify the difference between the reactor coolant temperature in the recirculation loop not in operation and the RPV coolant temperature is within limits specified in the PTLR. ----------------------------NOTE-----------------------------Only required to be performed when tensioning the reactor vessel head bolting studs. Verify reactor vessel flange and head flange temperatures are within limits specified in the PTLR. 3.4.11-4 RCS PIT Limits 3.4.11 FREQUENCY Once within 15 minutes prior to an increase in THERMAL POWER or an increase in jet pump loop flow Once within 15 minutes prior o an increase in THERMAL POWER or an increase in jet pump loop flow In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 145, 152 SURVEILLANCE REQUIREMENTS (continued) SR 3.4.11.8 SR 3.4.11.9 NMP2 SURVEILLANCE ----------------------------NOTE-----------------------------Not required to be performed until 30 minutes after RCS temperatures 80°F in MODE 4. Verify reactor vessel flange and head flange temperatures are within limits specified in the PTLR. ----------------------------NOTE-----------------------------Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after RCS temperature s 90°F in MODE 4. Verify reactor vessel flange and head flange temperatures are within limits specified in the PTLR. 3.4.11-5 RCS Prr Limits 3.4.11 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 91, 145,152 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12 Reactor Steam Dome Pressure Reactor Steam Dome Pressure 3.4.12 LCO 3.4.12 The reactor steam dome pressure shall be ::; 1035 psig. APPLICABILITY: MODES 1 and 2. ACTIONS CONDITION REQUIRED ACTION A. Reactor steam dome A.1 Restore reactor steam pressure not within dome pressure to limit. within limit. 8. Required Action and B.1 Be in MODE 3. associated Completion Time not met. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.4.12.1 NMP2 Verify reactor steam dome pressure is ::; 1035 psig. 3.4.12-1 COMPLETION TIME 15 minutes 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 SURVEILLANCE REQUIREMENTS SR 3.5.1.1 SR 3.5.1.2 SR 3.5.1.3 NMP2 SURVEILLANCE Verify, for each ECCS injection/spray subsystem, locations susceptible to gas accumulation are sufficiently filled with water. ---------------------------NOTE ----------------------------Low pressure coolant injection (LPCI) subsystems may be considered OPERABLE during alignment and operation for decay heat removal with reactor steam dome pressure less than the residual heat removal cut-in permissive pressure in MODE 3, if capable of being manually realigned and not otherwise inoperable. ---------------------------NOTE ----------------------------Not required to be met for system vent paths opened under administrative control Verify each ECCS injection/spray subsystem manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position. Verify: a. For each ADS nitrogen receiver discharge header, the pressure is 2'. 160 psig; and b. For each ADS nitrogen receiver tank, the pressure is 2'. 334 psig. 3.5.1-4 ECCS -Operating 3.5.1 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 150, 152 SURVEILLANCE REQUIREMENTS (continued) SR 3.5.1.4 SR 3.5.1.5 SR 3.5.1.6 SR 3.5.1.7 NMP2 SURVEILLANCE Verify each ECCS pump develops the specified flow rate with the specified developed head. SYSTEM LPCS LPCS A, B LPCIC HPCS TOTAL FLOW RATE DEVELOPED HEAD 2 6350 gpm 2 7450 gpm 2 7450 gpm 2 6350 gpm 2 284 psid 2 127 psid 2 140 psid 2. 327 psid -----------------------------NOTE-----------------------------Vessel injection/spray may be excluded. Verify each ECCS injection/spray subsystem actuates on an actual or simulated automatic initiation signal. -----------------------------NOTE------------------------------Valve actuation may be excluded. Verify the ADS actuates on an actual or simulated automatic initiation signal. -----------------------------NOTE------------------------------Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam pressure and flow are adequate to perform the test. Verify each required ADS valve actuator strokes when manually actuated. 3.5.1-5 ECCS -Operating 3.5.1 FREQUENCY ln accordance with the lnservice Testing Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 9+, 152 SURVEILLANCE REQUIREMENTS continued SR 3.5.1.8 NMP2 SURVEILLANCE -----------------------------NOTE------------------------------1 nstrumentation response time may be assumed to be the design instrumentation response time. Verify the ECCS RESPONSE TIME for each ECCS injection/spray subsystem is within limits. 3.5.1-6 ECCS -Operating 3.5.1 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9-+, 152 ACTIONS (continued) CONDITION D. Required Action C.2 and associated Completion Time not met. D.1 REQUIRED ACTION Initiate action to restore secondary containment to OPERABLE status. ECCS -Shutdown 3.5.2 COMPLETION TIME Immediately D.2 Initiate action to Immediately restore one standby AND D.3 gas treatment subsystem to OPERABLE status. Initiate action to restore isolation capability in each required secondary containment penetration flow path not isolated. SURVEILLANCE REQUIREMENTS SR 3.5.2.1 NMP2 SURVEILLANCE Verify, for each required low pressure ECCS injection/spray subsystem, the suppression pool water level is 195 ft. 3.5.2-2 Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment 9-+,152 SURVEILLANCE REQUIREMENTS (continued) SR 3.5.2.2 SR 3.5.2.3 SR 3.5.2.4 NMP2 SURVEILLANCE Verify, for the required High Pressure Core Spray (HPCS) System, the: a. Suppression pool water level is 195 ft; or b. Condensate storage tank B water level 26.9 ft. Verify, for each required ECCS injection/ spray subsystem, locations susceptible to gas accumulation are sufficiently filled with water. ----------------------------NOTE----------------------------------One low pressure coolant injection (LPCI) subsystem may be considered OPERABLE during alignment and operation for decay heat removal, if capable of being manually realigned and not otherwise inoperable. ---------------------------NOTE----------------------------------Not required to be met for system vent flow paths opened under administrative control. Verify each required ECCS injection/spray subsystem manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position. 3.5.2-3 ECCS -Shutdown 3.5.2 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 150, 152 SURVEILLANCE REQUIREMENTS (continued) SR 3.5.2.5 SR 3.5.2.6 SR 3.5.2.7 NMP2 SURVEILLANCE Verify each required ECCS pump develops the specified flow rate with the specified developed head. SYSTEM LPCS LPCIA,B LPCIC HPCS FLOW RATE ;;::: 6350 gpm ;;::: 7450 gpm ;;::: 7450 gpm ;;::: 6350 gpm TOTAL DEVELOPED HEAD 2:: 284 psid ;;::: 127 psid ;;::: 140 psid ;;::: 327 psid ----------------------------NOTE----------------------------------Vessel injection/spray may be excluded. Verify each required ECCS injection/spray subsystem actuates on an actual or simulated automatic initiation signal. ----------------------------NOTE----------------------------------lnstrumentation response time may be assumed to be the design instrumentation response time. Verify the ECCS RESPONSE TIME for each ECCS injection/spray subsystem is within limits. 3.5.2-4 ECCS -Shutdown 3.5.2 FREQUENCY In accordance with the lnservice Testing Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9-+,152 SURVEILLANCE REQUIREMENTS SR 3.5.3.1 SR 3.5.3.2 SR 3.5.3.3 SR 3.5.3.4 NMP2 SURVEILLANCE Verify the RCIC System locations susceptible to gas accumulations are sufficiently filled with water. ---------------------------NOTE ------------------------------Not required to be met for system vent flow paths opened under administrative control. Verify each RCIC System manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position. ---------------------------NOTE ----------------------------Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam pressure and flow are adequate to perform the test. Verify, with reactor pressure :s 1035 psig and 935 psig, the RCIC pump can develop a flow rate 600 gpm against a system head corresponding to reactor pressure. ---------------------------NOTE ----------------------------Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam pressure and flow are adequate to perform the test. Verify, with reactor pressure :s 165 psig, the RCIC pump can develop a flow rate 600 gpm against a system head corresponding to reactor pressure. 3.5.3-2 RCIC System 3.5.3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 150,152 SURVEILLANCE REQUIREMENTS continued SR 3.5.3.5 NMP2 SU AVE I LLANCE ---------------------------NOTE ----------------------------Vessel injection may be excluded. Verify the RCIC System actuates on an actual or simulated automatic initiation signal. 3.5.3-3 RCIC System 3.5.3 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9+,152 SURVEILLANCE REQUIREMENTS (continued) SR 3.6.1.1.3 NMP2 SURVEILLANCE ----------------------------NOTE-------------------------------SR 3.6.1.1.2 may be performed in lieu of SR 3.6.1.1.3. Verify, at an initial differential pressure of<:: 3 psid: a. The leakage rate through each drywall-to-suppression chamber bypass leak path containing suppression chamber-to-drywell vacuum breakers is less than or equal to the equivalent through an orifice 0.000648 ft2; and b. The combined leakage rate through all four drywall-to-suppression chamber bypass leak paths containing suppression chamber-to-drywall vacuum breakers is less than or equal to the equivalent through an orifice 0.001296 ft2. 3.6.1.1-3 Primary Containment 3.6.1.1 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9-+, 152 Primary Containment Air Locks 3.6.1.2 SURVEILLANCE REQUIREMENTS SR 3.6.1 .2.1 SR 3.6.1.2.2 NMP2 SURVEILLANCE --------------------------NOTES----------------------------1. An inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test. 2. Results shall be evaluated against acceptance criteria applicable to SR 3.6.1 .1.1. Perform required primary containment air lock leakage rate testing in accordance with 1 O CFR 50 Appendix J Testing Program Plan. Verify only one door in the primary containment air lock can be opened at a time. 3.6.1.2-5 FREQUENCY In accordance with 1 O CFR 50 Appendix J Testing Program Plan In accordance with the Surveillance Frequency Control Program Amendment B+,152 SURVEILLANCE REQUIREMENTS SR 3.6.1.3.1 SR 3.6. 1.3.2 NMP2 SURVEILLANCE ---------------------------NOTE-----------------------------Not required to be met when the 12 inch and 14 inch primary containment purge valves are open for inerting, inerting, pressure control, ALARA or air quality considerations for personnel entry, or Surveillances that require the valves to be open, provided: a) the Standby Gas Treatment (SGT) System is OPERABLE; or b) the primary containment full flow line to the SGT System is isolated and one SGT subsystem is OPERABLE. Verify each 12 inch and 14 inch primary containment purge valve is closed. --------------------------NOTES----------------------------1. Valves and blind flanges in high radiation areas may be verified by use of administrative means. 2. Not required to be met for PCIVs that are open under administrative controls. Verify each primary containment isolation manual valve and blind flange that is located outside primary containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. 3.6.1.3-10 PC I Vs 3.6.1.3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment Q.:t.,152 SURVEILLANCE REQUIREMENTS (continued) SR 3.6.1 .3.3 SR 3.6.1.3.4 SR 3.6.1 .3.5 NMP2 SURVEILLANCE --------------------------N 0 TES----------------------------1. Valves and blind flanges in high radiation areas may be verified by use of administrative means. 2. Not required to be met for PCIVs that are open under administrative controls. Verify each primary containment isolation manual valve and blind flange that is located inside primary containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. Verify continuity of the traversing incore probe (TIP) shear isolation valve explosive charge. Verify the isolation time of each power operated, automatic PCIV, except MSIVs, is within limits. 3.6.1.3-11 PC I Vs 3.6.1.3 FREQUENCY 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 In accordance with the Surveillance Frequency Control Program In accordance with the lnservice Testing Program (continued) Amendment 9+, 152 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE SR 3.6.1.3.6 Perform leakage rate testing for each primary containment purge valve with resilient seals. SR 3.6.1.3.7 Verify the isolation time of each MSIV is ;::::: 3 seconds and 5 seconds. SR 3.6.1.3.8 Verify each automatic PCIV actuates to the isolation position on an actual or simulated isolation signal. SR 3.6.1.3.9 Verify a representative sample of reactor instrumentation line EFCVs actuates to the isolation position on an actual or simulated instrument line break signal. SR 3.6.1.3.10 Remove and test the explosive squib from each shear isolation valve of the TIP System. SR 3.6.1.3.11 Verify the leakage rate for the secondary containment bypass leakage paths is within the limits of Table 3.6.1.3-1 when pressurized to 2:: 40 psig. NMP2 3.6.1.3-12 PC I Vs 3.6.1.3 FREQUENCY In accordance with the Surveillance Frequency Control Program AND Once within 92 days after opening the valve In accordance with the lnservice Testing Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with 10 CFR 50 Appendix J Testing Program Plan (continued) Amendment 9-+,--Be, 152 Drywell and Suppression Chamber Pressure 3.6.1.4 3.6 CONTAINMENT SYSTEMS 3.6.1.4 Drywall and Suppression Chamber Pressure LCO 3.6.1.4 Drywett and suppression chamber pressure shalt be 14.2 psia and :::; 15.45 psia. APPLICABILITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION A. Drywall or suppression A.1 Restore drywall and chamber pressure not suppression chamber within limits. pressure to within limits. B. Required Action and B.1 Be in MODE 3. associated Completion Time not met. AND B.2 Be in MODE 4. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.6.1.4.1 NMP2 Verify drywell and suppression chamber pressure is within limits. 3.6.1.4-1 COMPLETION TIME 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 12 hours 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9-i,152 3.6 CONTAINMENT SYSTEMS 3.6.1.5 Drywall Air Temperature LCO 3.6.1.5 Drywall average air temperature shall be 150°F. APPLICABILITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION A. Drywell average air A.1 Restore drywell temperature not within average air limit. temperature to within limit. B. Required Action and B.1 Be in MODE 3. associated Completion Time not met. AND B.2 Be in MODE 4. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.6.1.5.1 NMP2 Verify drywell average air temperature is within limit. 3.6.1.5-1 Drywell Air Temperature 3.6.1.5 COMPLETION TIME 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> 12 hours 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9+,152 SURVEILLANCE REQUIREMENTS SR 3.6. 1 .6.1 SR 3.6.1.6.2 SR 3.6.1.6.3 NMP2 SURVEILLANCE Verify each AHR drywell spray subsystem manual and power operated valve in the flow path that is not locked, sealed, or otherwise secured in position, is in the correct position or can be aligned to the correct position. Verify, by administrative means, that each required AHR pump is OPERABLE. Verify each drywell spray nozzle is unobstructed. 3.6.1.6-2 RHR Drywell Spray 3.6.1.6 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Following maintenance that could result in nozzle blockage Amendment 91, 122, 152 Suppression Chamber-to-Drywell Vacuum Breakers 3.6.1.7 SURVEILLANCE REQUIREMENTS SR 3.6.1.7.1 SR 3.6.1.7.2 SR 3.6.1.7.3 NMP2 SURVEILLANCE --------------------------NOTES----------------------------1. Not required to be met for vacuum breakers that are open during Surveillances. 2. Not required to be met for vacuum breakers open when performing their intended function. Verify each vacuum breaker is closed. ---------------------------NOTE-----------------------------Not required to be met for vacuum breaker 21SC*RV36B for the remainder of Cycle 9. Perform a functional test of each vacuum breaker. Verify the opening setpoint of each vacuum breaker is$ 0.25 psid. FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after any discharge of steam to the suppression chamber from the safety/relief valves In accordance with the Surveillance Frequency Control Program 3.6.1.7-3 Amendment 91, 98, 108,152 Suppression Pool Average Temperature 3.6.2.1 SURVEILLANCE REQUIREMENTS SR 3.6.2.1 . 1 NMP2 SURVEILLANCE Verify suppression pool average temperature is within the applicable limits. 3.6.2.1-3 FREQUENCY In accordance with the Surveillance Frequency Control Program 5 minutes when performing testing that adds heat to the suppression pool Amendment 9-+, 152 3.6 CONTAINMENT SYSTEMS 3.6.2.2 Suppression Pool Water Level Suppression Pool Water Level 3.6.2.2 LCO 3.6.2.2 Suppression pool water level shall be 199 ft 6 inches and ::; 201 ft APPLICABILITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION A. Suppression pool water A.1 Restore suppression level not within pool water level to limits. within limits. B. Required Action and B.1 Be in MODE 3. associated Completion Time not met. AND B.2 Be in MODE 4. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.6.2.2.1 NMP2 Verify suppression pool water level is within limits. 3.6.2.2-1 COMPLETION TIME 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> 12 hours 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment f>>,152 AHR Suppression Pool Cooling 3.6.2.3 SURVEILLANCE REQUIREMENTS SR 3.6.2.3.1 SR 3.6.2.3.2 SR 3.6.2.3.3 NMP2 SURVEILLANCE Verify each AHR suppression pool cooling subsystem manual and power operated valve in the flow path that is not locked, sealed, or otherwise secured in position, is in the correct position or can be aligned to the correct position. Verify each required AHR pump develops a flow rate 2". 7 450 gpm through the associated heat exchanger while operating in the suppression pool cooling mode. Verify AHR suppression pool cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water. 3.6.2.3-2 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the lnservice Testing Program In accordance with the Surveillance Frequency Control Program Amendment 91, 150, 152 AHR Suppression Pool Spray 3.6.2.4 SURVEILLANCE REQUIREMENTS SR 3.6.2.4.1 SR 3.6.2.4.2 SR 3.6.2.4.3 NMP2 SURVEILLANCE Verify each AHR suppression pool spray subsystem manual and power operated valve in the flow path that is not locked, sealed, or otherwise secured in position, is in the correct position or can be aligned to the correct position. Verify each required RHR pump develops a flow rate 450 gpm while operating in the suppression pool spray mode. Verify AHR suppression pool spray subsystem locations susceptible to gas accumulation are sufficiently filled with water. 3.6.2.4-2 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the lnservice Testing Program In accordance with the Surveillance Frequency Control Program Amendment 91, 150, 152 Primary Containment Oxygen Concentration 3.6.3.2 3.6 CONTAINMENT SYSTEMS 3.6.3.2 Primary Containment Oxygen Concentration LCO 3.6.3.2 The primary containment oxygen concentration shall be < 4.0 volume percent. APPLICABILITY: MODE 1 during the time period: a. From 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after THERMAL POWER is > 15% ATP following startup, to b. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> prior to reducing THERMAL POWER to < 15% RTP prior to the next scheduled reactor shutdown. ACTIONS CONDITION REQUIRED ACTION A. Primary containment A.1 Restore oxygen oxygen concentration concentration to not within limit. within limit. B. Required Action and B.1 Reduce THERMAL POWER associated Completion 15% ATP. Time not met. SURVEILLANCE REQUIREMENTS SR 3.6.3.2.1 NMP2 SURVEILLANCE Verify primary containment oxygen concentration is within limits. 3.6.3.2-1 COMPLETION TIME 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 8 hours FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 ACTIONS (continued) CONDITION C. Secondary containment C.1 inoperable during movement of recently irradiated fuel assemblies in the secondary containment REQUIRED ACTION -----------NO TE-----------LCO 3.0.3 is not applicable. Secondary Containment 3.6.4.1 COMPLETION TIME or during OPDRVs. Suspend movement of Immediately recently irradiated fuel assemblies in the secondary containment. C.2 Initiate action to suspend OPDAVs. SURVEILLANCE REQUIREMENTS SR 3.6.4.1.1 SR 3.6.4.1.2 NMP2 SURVEILLANCE Verify secondary containment vacuum is 0.25 inch of vacuum water gauge. Verify all secondary containment equipment hatches are closed and sealed. 3.6.4.1-2 Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 101, 152 SURVEILLANCE REQUIREMENTS (continued) SR 3.6.4.1.3 SR 3.6.4.1.4 SR 3.6.4.1.5 NMP2 SURVEILLANCE Verify one secondary containment access door in each access opening is closed. Verify the secondary containment can be drawn down to ;::::: 0.25 inch of vacuum water gauge in :::;; 66. 7 seconds using one standby gas treatment (SGT) subsystem. Verify the secondary containment can be maintained ;::::: 0.25 inch of vacuum water gauge for 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> using one SGT subsystem at a flow rate :::;; 2670 cfm. 3.6.4.1-3 Secondary Containment 3.6.4.1 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment B+, 152 SURVEILLANCE REQUIREMENTS SR 3.6.4.2.1 SR 3.6.4.2.2 SR 3.6.4.2.3 NMP2 SURVEILLANCE --------------------------NOTES----------------------------1. Valves and blind flanges in high radiation areas may be verified by use of administrative means. 2. Not required to be met for SCIVs that are open under administrative controls. Verify each secondary containment isolation manual valve and blind flange that is not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. Verify the isolation time of each power operated, automatic SCIV is within limits. Verify each automatic SCIV actuates to the isolation position on an actual or simulated automatic isolation signal. 3.6.4.2-4 SCI Vs 3.6.4.2 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 ACTIONS CONDITION REQUIRED ACTION E. (continued) E.3 Initiate action to suspend OPDRVs. SURVEILLANCE REQUIREMENTS SR 3.6.4.3.1 SR 3.6.4.3.2 SR 3.6.4.3.3 SR 3.6.4.3.4 NMP2 SURVEILLANCE Operate each SGT subsystem for ;::: 1 O continuous hours with heaters operating. Perform required SGT filter testing in accordance with the Ventilation Filter Testing Program (VFTP). Verify each SGT subsystem actuates on an actual or simulated initiation signal. Verify each SGT decay heat removal air inlet valve can be opened. 3.6.4.3-3 SGT System 3.6.4.3 COMPLETION TIME Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the VFTP In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 91, 101, 152 SURVEILLANCE REQUIREMENTS SR 3.7.1.1 SR 3.7.1.2 SR 3.7.1.3 SR 3.7.1.4 NMP2 SURVEILLANCE ------------------------------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 tunnels 38°F. Verify the water level in the SW pump intake bay is 233.1 ft. Verify the water temperature of each SW subsystem supply header 84°F. Verify each required SW pump is in operation. 3.7.1-3 SW System and UHS 3.7.1 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> when supply header water temperature is ?.'. 78°F In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 119,152 SURVEILLANCE REQUIREMENTS (continued) SR 3.7.1.5 SR 3.7.1.6 SR 3.7.1.7 SR 3.7.1.8 NMP2 SURVEILLANCE ------------------------------NOTE-----------------------------Not required to be met if SR 3. 7.1.1 satisfied. Verify, for each intake deicer heater division, the current of each required heater feeder cable is within the limit. ------------------------------NOTE-----------------------------lsolation of flow to individual components does not render SW System inoperable. Verify each SW subsystem manual, power operated, and automatic valve in the flow path servicing safety related systems or components, that is not locked, sealed, or otherwise secured in position, is in the correct position. Verify each SW subsystem actuates on an actual or simulated initiation signal. ------------------------------N 0 TE-----------------------------Not required to be met if SR 3.7.1.1 satisfied. Verify, for each intake deicer heater division, the resistance of each required heater feeder cable and associated heater elements is within the limit. 3.7.1-4 SW System and UHS 3.7.1 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9-+, 152 ACTIONS (continued) F. CONDITION Two CREF subsystems inoperable with safety function not maintained during movement of recently irradiated fuel assemblies in the secondary containment or during OPDRVs. REQUIRED ACTION ------------------NOTE------------------LCO 3.0.3 is not applicable. F .1 Suspend movement of recently irradiated fuel assemblies in the secondary containment. One or more CREF AND subsystems inoperable due to inoperable CRE boundary F.2 Initiate action to suspend during movement of recently OPDRVs. irradiated fuel assemblies in the secondary containment or during OPDRVs. SURVEILLANCE REQUIREMENTS SR 3.7.2.1 SR 3.7.2.2 SR 3.7.2.3 SURVEILLANCE Operate each CREF subsystem for 2 1 continuous hour. Perform required CREF System filter testing in accordance with the Ventilation Filter Testing Program (VFTP). Verify each CREF subsystem actuates on an actual or simulated initiation signal. CREF System 3.7.2 COMPLETION TIME Immediately Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the VFTP In accordance with the Surveillance Frequency Control Program (continued) NMP2 3.7.2-3 Amendment 91, 95, 97, 125, 126, 152 Control Room Envelope AC System 3.7.3 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME ------------------NOTE-------------------LCO 3.0.3 is not applicable. H. Required Action and associated Completion Time of Condition C or D not met during movement of recently irradiated fuel assemblies in the secondary containment or during OPDRVs. H.1 Suspend movement of Immediately AND H.2 recently irradiated fuel assemblies in the secondary containment. Initiate action to suspend OPDRVs. SURVEILLANCE REQUIREMENTS SR 3.7.3.1 NMP2 SURVEILLANCE Verify each control room envelope AC subsystem has the capability to remove the assumed heat load for the Main Control Room area and the Relay Room area. 3.7.3-4 Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program 152 SURVEILLANCE REQUIREMENTS SR 3.7.4.1 NMP2 SURVEILLANCE ------------------------------NOTE---------------------------Not required to be performed until 31 days after any main steam line not isolated and SJAE in operation. Verify the gross gamma activity rate of the noble gases is ::;; 350,000 µCi/second after decay of 30 minutes.
  • 3.7.4-2 Main Condenser Offgas 3.7.4 FREQUENCY In accordance with the Surveillance Frequency Control Program Once within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> after a ;::: 50% increase in the nominal steady state fission gas release after factoring out increases due to changes in THERMAL POWER level Amendment 9+, 152 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 23% ATP. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the A.1 Satisfy the 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> LCO not met. requirements of the LCO. B. Required Action and B.1 Reduce THERMAL POWER 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> associated Completion to< 23% ATP. Time not met. SURVEILLANCE REQUIREMENTS SR 3.7.5.1 SR 3.7.5.2 NMP2 SURVEILLANCE FREQUENCY Perform a system functional test. In accordance with the Surveillance Frequency Control Program Verify the TURBINE BYPASS SYSTEM RESPONSE In accordance with TIME is within limits. the Surveillance Frequency Control Program 3.7.5-1 Amendment91, 140,152 Spent Fuel Storage Pool Water Level 3.7.6 3. 7 PLANT SYSTEMS 3.7.6 Spent Fuel Storage Pool Water Level LCO 3.7.6 The spent fuel storage pool water level shall be 2:: 22 ft 3 inches over the top of irradiated fuel assemblies seated in the spent fuel storage pool racks. APPLICABILITY: During movement of irradiated fuel assemblies in the spent fuel storage pool, During movement of new fuel assemblies in the spent fuel storage pool with irradiated fuel assemblies seated in the spent fuel storage pool. ACTIONS CONDITION A. Spent fuel storage pool water level not within limit. A.1 SURVEILLANCE REQUIREMENTS REQUIRED ACTION ------------NOTE------------LCO 3.0.3 is not applicable. Suspend movement of fuel assemblies in the spent fuel storage pool. SURVEILLANCE SR 3.7.6.1 NMP2 Verify the spent fuel storage pool water level is :::::: 22 ft 3 inches over the top of irradiated fuel assemblies seated in the spent fuel storage pool racks. 3.7.6-1 COMPLETION TIME Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program Amendments+, 152 ACTIONS (continued) CONDITION REQUIRED ACTION E. Two required DGs E.1 Restore one required inoperable. DG to OPERABLE status. F. Required Action and F.1 Be in MODE 3. Associated Completion Time of Condition A, AND B, C, D, or E not met. F.2 Be in MODE 4. G. Three or more required G.1 Enter LCO 3.0.3. AC sources inoperable. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.8.1.1 NMP2 Verify correct breaker alignment and indicated power availability for each required otfsite circuit. 3.8.1-5 AC Sources -Operating 3.8.1 COMPLETION TIME 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> OR 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> if Division 3 DG is inoperable 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 36 hours Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment 9+, 152 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.2 ------------------------------NOTE-----------------------------NMP2 All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading. Verify each required DG starts from standby conditions and achieves: a. In s; 1 O seconds, voltage;;:: 3950 V for Division 1 and 2 DGs and ;::: 3820 V for Division 3 DG, and frequency;;:: 58.8 Hz for Division 1 and 2 DGs and ;::: 58.0 Hz for Division 3 DG; and b. Steady state voltage ;;:: 3950 V and s; 4370 V and frequency ;::: 58.8 Hz and s; 61.2 Hz. 3.8.1-6 In accordance with the Surveillance Frequency Control Program (continued) Amendment 9-1-, 152 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.3 -----------------------------NOTES----------------------------SR 3.8.1.4 SR 3.8.1.5 SR 3.8.1.6 NMP2 1. DG loadings may include gradual loading as recommended by the manufacturer. 2. Momentary transients outside the load range do not invalidate this test. 3. This Surveillance shall be conducted on only one DG at a time. 4. This SR shall be preceded by, and immediately follow, without shutdown, a successful performance of SR 3.8.1.2. Verify each required DG is synchronized and loaded and operates for 2 60 minutes at a load 2 3960 kW and :::; 4400 kW for Division 1 and 2 DGs, and 2 2340 kW and $ 2600 kW for Division 3 DG. Verify each required day tank contains 2 403 gal of fuel oil for Division 1 and 2 DGs and 2 282 gal for Division 3 DG. Check for and remove accumulated water from each required day tank. Verify each required fuel oil transfer subsystem operates to automatically transfer fuel oil from the storage tank to the day tank. 3.8.1-7 In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 9+,152 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.7 -------------------------------NOTES-----------------------------NMP2 1. This Surveillance shall not be performed in MODE 1 or 2 (not applicable to Division 3 DG). However, credit may be taken for unplanned events that satisfy this SR. 2. If performed with DG synchronized with offsite power, it shall be performed within the power factor limit. However if grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable. Verify each required DG rejects a load greater than or equal to its associated single largest post-accident load, and following load rejection, the frequency is 64.5 Hz for Division 1 and 2 DGs and 66. 75 Hz for Division 3 DG. 3.8.1-8 In accordance with the Surveillance Frequency Control Program (continued) Amendment 133, 152 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.8 -----------------------------NOTES----------------------------NMP2 1 . This Surveillance shall not be performed in MODE 1 or 2 (not applicable to Division 3 DG). However, credit may be taken for unplanned events that satisfy this SR. 2. If grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable. Verify each required DG operating within the power factor limit does not trip and voltage is maintained: a. ::; 4576 V during and following a load rejection of a load 4400 kW for Division 1 and 2 DGs; and b. 5824 V during and following a load rejection of a load 2600 kW for Division 3 DG. 3.8.1-9 In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 133, 152 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.9 -----------------------------NOTES----------------------------NMP2 1 . All DG starts may be preceded by an engine prelube period. 2. This Surveillance shall not be performed in MODE 1, 2, or 3 (not applicable to Division 3 DG). However, credit may be taken for unplanned events that satisfy this SR. Verify on an actual or simulated loss of offsite power signal: a. De-energization of emergency buses; b. Load shedding from emergency buses for Divisions 1 and 2 only; and c. DG auto-starts from standby condition and: 1 . energizes permanently connected loads in s; 13.20 seconds, 2. energizes auto-connected shutdown loads for Division 1 and 2 DGs only, through the associated automatic load sequence time delay relays, 3. maintains steady state voltage 3950 V and s; 4370 V, 4. maintains steady state frequency 58.8 Hz and s; 61 .2 Hz, and 5. supplies permanently connected and auto-connected shutdown loads for :::: 5 minutes for Division 1 and 2 DGs and supplies permanently connected shutdown loads for :::: 5 minutes for Division 3 DG. 3.8.1-10 In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 133, 152 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.10 -----------------------------NOTES----------------------------NMP2 1 . All DG starts may be preceded by an engine prelube period. 2. This Surveillance shall not be performed in MODE 1 or 2 (not applicable to Division 3 DG). However, credit may be taken for unplanned events that satisfy this SR. Verify on an actual or simulated Emergency Core Cooling System (ECCS) initiation signal each required DG auto-starts from standby condition and: a. In:=; 1 O seconds after auto-start, achieves voltage ;::: 3950 V for Division 1 and 2 DGs and 2 3820 V for Division 3 DG, and frequency;::: 58.8 Hz for Division 1 and 2 DGs and 2 58.0 Hz for Division 3 DG; b. Achieves steady state voltage ;::: 3950 V and :=; 4370 V and frequency 2 58.8 Hz and:=; 61.2 Hz; c. Operates for 2 5 minutes; d. Permanently connected loads remain energized from the offsite power system for Divisions 1 and 2 only; and e. Emergency loads are auto-connected through the associated automatic load sequence time delay relays to the offsite power system for Divisions 1 and 2 only. 3.8.1-11 In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 133, 152 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.11 -------------------------------NOTE-----------------------------NMP2 This Surveillance shall not be performed in MODE 1, 2, or 3 (not applicable to Division 3 DG). However, credit may be taken for unplanned events that satisfy this SR. Verify each required DG's automatic trips are bypassed on actual or simulated loss of voltage signal on the emergency bus concurrent with an actual or simulated ECCS initiation signal except: a. Engine overspeed; and b. Generator differential current. 3.8.1-12 In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 133, 152 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.12 -----------------------------NOTES----------------------------NMP2 1. Momentary transients outside the load and power factor ranges do not invalidate this test. 2. This Surveillance shall not be performed in MODE 1 or 2 unless the other two DGs are OPERABLE. If either of the other two DGs become inoperable, this Surveillance shall be suspended. However, credit may be taken for unplanned events that satisfy this SR. 3. If grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable. Verify each required DG operating within the power factor limit operates for 2 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />s: a. For 2 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> loaded 2 4620 kW and ::::: 4840 kW for Division 1 and 2 DGs, and 2 2730 kW and 2860 kW for Division 3 DG; and b. For the remaining hours of the test loaded 2 3960 kW and ::::: 4400 kW for Division 1 and 2 DGs, and 2 2340 kW 2600 kW for Division 3 DG. 3.8.1-13 In accordance with the Surveillance Frequency Control Program (continued) Amendment 9+, 152 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.13 -----------------------------NOTES----------------------------NMP2 1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated 2 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> loaded 3960 kW for Division 1 and 2 DGs, and 2 2340 kW for Division 3 DG. Momentary transients below the load limit do not invalidate this test. 2. All DG starts may be preceded by an engine prelube period. Verify each required DG starts and achieves: a. In $ 1 O seconds, voltage 3950 V for Division 1 and 2 DGs and 2 3820 V for Division 3 DG, and 58.8 Hz for Division 1 and 2 DGs and 2 58.0 Hz for Division 3 DG; and b. Steady state voltage 2 3950 V and s 4370 V and frequency 2 58.8 Hz ands 61.2 Hz. 3.8.1-14 In accordance with the Surveillance Frequency Control Program (continued) Amendment 9-1-, 152 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued) SR 3.8.1.14 SR 3.8.1.15 NMP2 SURVEILLANCE ------------------------------NOTE-----------------------------This Surveillance shall not be performed in MODE 1, 2, or 3 (not applicable to Division 3 DG). However, credit may be taken for unplanned events that satisfy this SR. Verify each required DG: a. Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power; b. Transfers loads to offsite power source; and c. Returns to ready-to-load operation. ------------------------------N 0 TE-----------------------------This Surveillance shall not be performed in MODE 1, 2, or 3 (not applicable to Division 3 DG). However, credit may be taken for unplanned events that satisfy this SR. Verify, with a DG operating in test mode and connected to its bus, an actual or simulated ECCS initiation signal overrides the test mode by: a. Returning DG to ready-to-load operation; and b. Automatically energizing the emergency load from offsite power. 3.8.1-15 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 133, 152 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.16 ------------------------------NOTE-----------------------------NMP2 This Surveillance shall not be performed in MODE 1, 2, or 3. However, credit may be taken for unplanned events that satisfy this SR. Verify interval between each sequenced load block, for the Division 1 and 2 DGs only, is 90% of the design interval for each automatic load sequence time delay relay. 3.8.1-16 In accordance with the Surveillance Frequency Control Program (continued) Amendment 9+, 152 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.17 -----------------------------NOTES----------------------------NMP2 1 . All DG starts may be preceded by an engine prelube period. 2. This Surveillance shall not be performed in MODE 1, 2, or 3 (not applicable to Division 3 DG). However, credit may be taken for unplanned events that satisfy this SR. Verify, on an actual or simulated loss of offsite power signal in conjunction with an actual or simulated ECCS initiation signal: a. De-energization of emergency buses; b. Load shedding from emergency buses for Divisions 1 and 2 only; and c. DG auto-starts from standby condition and: 1. energizes permanently connected loads in s 1 O seconds, 2. for Divisions 1 and 2, energizes auto-connected emergency loads through the associated automatic load sequence time delay relays and for Division 3, energizes auto-connected emergency loads, 3. maintains steady state voltage ;:::: 3950 V and ::;; 4370 V, 4. maintains steady state frequency ;:::: 58.8 Hz and::;; 61.2 Hz, and 5. supplies permanently connected and auto-connected emergency loads for ;:::: 5 minutes. 3.8.1-17 In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 133, 152 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.18 ------------------------------NOTE-----------------------------NMP2 All DG starts may be preceded by an engine prelube period. Verify, when started simultaneously from standby condition, each Division 1, 2, and 3 DG achieves, in ::; 1 O seconds, voltage 2 3950 V for Division 1 and 2 DGs and 2 3820 V for Division 3 DG, and frequency 2 58.8 Hz for Division 1 and 2 DGs and 2 58.0 Hz for Division 3 DG. 3.8.1-18 In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SR 3.8.3.1 SR 3.8.3.2 SR 3.8.3.3 SR 3.8.3.4 SR 3.8.3.5 NMP2 SURVEILLANCE Verify each fuel oil storage tank contains: a. 2 50,000 gal of fuel for Division 1 DG and Division 2 DG; and b. 2 35,342 gal of fuel for Division 3DG. Verify lube oil inventory is: a. 2 99 gal for Division 1 DG and Division 2 DG; and b. 2 168 gal for Division 3 DG. Verify fuel oil properties of new and stored fuel oil are tested in accordance with, and maintained within the limits of, the Diesel Fuel Oil Testing Program. Verify each DG air start receiver pressure is: a. 2 225 psig for Division 1 DG and Division 2 DG; and b. 2 190 psig for Division 3 DG. Check for and remove accumulated water from each fuel oil storage tank. 3.8.3-3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Diesel Fuel Oil Testing Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9-+, 152 SURVEILLANCE REQUIREMENTS SR 3.8.4.1 SR 3.8.4.2 SR 3.8.4.3 SR 3.8.4.4 SR 3.8.4.5 NMP2 SURVEILLANCE Verify battery terminal voltage is 130 V on float charge. Verify no visible corrosion at battery terminals and connectors. Verify battery connection resistance is 20% above the resistance as measured during installation for intercell and terminal connections. Verify battery cells, cell plates, and racks show no visual indication of physical damage or abnormal deterioration that could degrade battery performance. Remove visible corrosion and verify battery cell to cell and terminal connections are coated with anti-corrosion material. Verify battery connection resistance is :S 20% above the resistance as measured during installation for intercell and terminal connections. 3.8.4-2 DC Sources -Operating 3.8.4 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 9-1-, 152 SURVEILLANCE REQUIREMENTS (continued) SR 3.8.4.6 SURVEILLANCE Verify each required Division 1 and 2 battery charger supplies 300 amps and the required Division 3 battery charger supplies 40 amps at 130 V for 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />. DC Sources -Operating 3.8.4 FREQUENCY In accordance with the Surveillance Frequency Control Program SR 3.8.4.7 -----------------------------NOTES----------------------------NMP2 1 . The modified performance discharge test in SR 3.8.4.8 may be performed in lieu of the service test in SR 3.8.4. 7 provided the modified performance discharge test completely envelops the service test. 2. This Surveillance shall not be performed in MODE 1, 2, or 3 (not applicable to Division 3). However, credit may be taken for unplanned events that satisfy this SR. Verify battery capacity is adequate to supply, and maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test. 3.8.4-3 In accordance with the Surveillance Frequency Control Program (continued) Amendment 91, 136, 152 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE DC Sources -Operating 3.8.4 FREQUENCY SR 3.8.4.8 ------------------------------NOTE-----------------------------NMP2 This Surveillance shall not be performed in MODE 1, 2, or 3 (not applicable to Division 3). However, credit may be taken for unplanned events that satisfy this SR. Verify battery capacity is 80% of the manufacturer's rating when subjected to a performance discharge test or a modified performance discharge test. 3.8.4-4 In accordance with the Surveillance Frequency Control Program 12 months when battery shows degradation or has reached 85% of expected life with capacity < 100% of manufacture r's rating 24 months when battery has reached 85% of the expected life with capacity 100% of manufacturer's rating Amendment 91, 136, 152 ACTIONS (continued) CONDITION B. Required Action and associated Completion Time of Condition A not met. One or more batteries with average electrolyte temperature of the representative cells < 65°F. One or more batteries with one or more battery cell parameters not within Table 3.8.6-1 Category C limits. B.1 REQUIRED ACTION Declare associated battery inoperable. SURVEILLANCE REQUIREMENTS SR 3.8.6.1 NMP2 SURVEILLANCE Verify battery cell parameters meet Table 3.8.6-1 Category A limits. 3.8.6-2 Battery Cell Parameters 3.8.6 COMPLETION TIME Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment 9+,152 SURVEILLANCE REQUIREMENTS (continued) SR 3.8.6.2 SR 3.8.6.3 NMP2 SURVEILLANCE Verify battery cell parameters meet Table 3.8.6-1 Category B limits. Verify average electrolyte temperature of representative cells is 65°F. 3.8.6-3 Battery Cell Parameters 3.8.6 FREQUENCY In accordance with the Surveillance Frequency Control Program Once within 7 days after battery discharge < 107 v Once within 7 days after battery overcharge > 142 v In accordance with the Surveillance Frequency Control Program Amendment 9-+, 152 SURVEILLANCE REQUIREMENTS SR 3.8.7.1 NMP2 SURVEILLANCE Verify correct emergency UPS inverter voltage, frequency, and alignment to 120 VAC uninterruptible panels. 3.8.7-2 Inverters -Operating 3.8.7 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 ACTIONS (continued) CONDITION F. Two or more electrical power distribution subsystems inoperable that result in a loss of function. REQUIRED ACTION F.1 Enter LCO 3.0.3. SURVEILLANCE REQUIREMENTS SR 3.8.8.1 NMP2 SURVEILLANCE Verify correct breaker alignment and power availability to required AC, DC, and 120 VAC uninterruptible electrical power distribution subsystems. 3.8.8-3 Distribution Systems -Operating 3.8.8 COMPLETION TIME Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9-1-, 152 Distribution Systems -Shutdown 3.8.9 ACTIONS CONDITION REQUIRED ACTION A. (continued) A.2.3 A.2.4 A.2.5 Initiate action to suspend operations with a potential for draining the reactor vessel. Initiate actions to restore required AC, DC, and 120 VAC uninterruptible electrical power distribution subsystems to OPERABLE status. Declare associated required shutdown cooling subsystem(s) inoperable and not in operation. SURVEILLANCE REQUIREMENTS SR 3.8.9.1 NMP2 SURVEILLANCE Verify correct breaker alignments and power availability to required AC, DC, and 120 VAC uninterruptible electrical power distribution subsystems. 3.8.9-2 COMPLETION TIME Immediately Immediately Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9-+, 152 Refueling Equipment Interlocks 3.9.1 SURVEILLANCE REQUIREMENTS SR 3.9.1.1 NMP2 SURVEILLANCE Perform CHANNEL FUNCTIONAL TEST on each of the following required refueling equipment interlock inputs: a. All-rods-in, b. Refueling platform position, c. Refueling platform fuel grapple, fuel-loaded, d. Refueling platform monorail hoist, fuel-loaded, e. Refueling platform frame-mounted hoist, fuel-loaded, and f. Service platform hoist, fuel-loaded. 3.9.1-2 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9-+, 152 Refuel Position One-Rod-Out Interlock 3.9.2 3.9 REFUELING OPERATIONS 3.9.2 Refuel Position One-Rod-Out Interlock LCO 3.9.2 The refuel position one-rod-out interlock shall be OPERABLE. APPLICABILITY: MODE 5 with the reactor mode switch in the refuel position ACTIONS CONDITION A. Refuel position rod-out interlock inoperable. and any control rod withdrawn. A.1 AND A.2 REQUIRED ACTION Suspend control rod withdrawal. Initiate action to fully insert all insertable control rods in core cells containing one or more fuel assemblies. SURVEILLANCE REQUIREMENTS SR 3.9.2.1 NMP2 SURVEILLANCE Verify reactor mode switch locked in refuel position. 3.9.2-1 COMPLETION TIME Immediately Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment 9+, 152 Refuel Position One-Rod-Out Interlock 3.9.2 SURVEILLANCE REQUIREMENTS continued SR 3.9.2.2 NMP2 SURVEILLANCE ---------------------------NOTE-----------------------------Not required to be performed until 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after any control rod is withdrawn. Perform CHANNEL FUNCTIONAL TEST. 3.9.2-2 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9-i, 152 3.9 REFUELING OPERATIONS 3.9.3 Control Rod Position LCO 3.9.3 All control rods shall be fully inserted. APPLICABILITY: When loading fuel assemblies into the core. ACTIONS CONDITION A. One or more control rods not fully inserted. A.1 REQUIRED ACTION Suspend loading fuel assemblies into the core. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.9.3.1 Verify all control rods are fully inserted. NMP2 3.9.3-1 Control Rod Position 3.9.3 COMPLETION TIME Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 Control Rod OPERABILITY -Refueling 3.9.5 3.9 REFUELING OPERATIONS 3.9.5 Control Rod OPERABILITY -Refueling LCO 3.9.5 Each withdrawn control rod shall be OPERABLE. APPLICABILITY: MODE 5. ACTIONS CONDITION REQUIRED ACTION A. One or more withdrawn control rods inoperable. A.1 Initiate action to fully insert inoperable withdrawn control rods. SURVEILLANCE REQUIREMENTS SR 3.9.5.1 SR 3.9.5.2 NMP2 SURVEILLANCE ---------------------------N 0 TE-------------------------------Not required to be performed until 7 days after the control rod is withdrawn. Insert each withdrawn control rod at least one notch. Verify each withdrawn control rod scram accumulator pressure is 940 psig. 3.9.5-1 COMPLETION TIME Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9-+, 152 RPV Water Level -Irradiated Fuel 3.9.6 3.9 REFUELING OPERATIONS 3.9.6 Reactor Pressure Vessel (RPV) Water Level -Irradiated Fuel LCO 3.9.6 RPV water level shall be 2:'. 22 ft 3 inches above the top of the RPV flange. APPLICABILITY: During movement of irradiated fuel assemblies within the ACTIONS CONDITION A. RPV water level not within limit. RPV. A.1 REQUIRED ACTION Suspend movement of irradiated fuel assemblies within the RPV. SURVEILLANCE REQUIREMENTS SR 3.9.6.1 NMP2 SURVEILLANCE Verify RPV water level is 2! 22 ft 3 inches above the top of the RPV flange. 3.9.6-1 COMPLETION TIME Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 RPV Water Level -New Fuel or Control Rods 3.9.7 3.9 REFUELING OPERATIONS 3.9.7 Reactor Pressure Vessel (RPV) Water Level -New Fuel or Control Rods LCO 3.9.7 RPV water level shall be<:: 22 ft 3 inches above the top of irradiated fuel assemblies seated within the RPV. APPLICABILITY: During movement of new fuel assemblies or handling of control rods within the RPV when irradiated fuel assemblies are seated within the RPV. ACTIONS CONDITION A. RPV water level not within limit. A.1 REQUIRED ACTION Suspend movement of new fuel assemblies and handling of control rods within the RPV. SURVEILLANCE REQUIREMENTS SR 3.9.7.1 NMP2 SURVEILLANCE Verify RPV water level is <:: 22 ft 3 inches above the top of irradiated fuel assemblies seated within the RPV. 3.9.7-1 COMPLETION TIME Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment 9-+, 152 AHR -High Water Level 3.9.8 SURVEILLANCE REQUIREMENTS SR 3.9.8.1 SR 3.9.8.2 NMP2 SURVEILLANCE Verify one AHR shutdown cooling subsystem is operating. Verify required AHR shutdown cooling subsystem locations susceptible to gas accumulations are sufficiently filled with water. 3.9.8-3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 91, 150, 152 AHR -Low Water Level 3.9.9 SURVEILLANCE REQUIREMENTS SR 3.9.9.1 SR 3.9.9.2 NMP2 SURVEILLANCE Verify one AHR shutdown cooling subsystem is operating. Verify AHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water. 3.9.9-3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 91, 150, 152 Reactor Mode Switch Interlock Testing 3.10.2 ACTIONS CONDITION REQUIRED ACTION A. (continued) A.3.1 OR Place the reactor mode switch in the shutdown position. A.3.2 -----------NOTE-------------Only applicable in MODE 5. Place the reactor mode switch in the refuel position. SURVEILLANCE REQUIREMENTS SR 3.10.2.1 SR 3.10.2.2 NMP2 SURVEILLANCE Verify all control rods are fully inserted in core cells containing one or more fuel assemblies. Verify no CORE ALTERATIONS are in progress. 3.10.2-2 COMPLETION TIME 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 1 hour FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 Single Control Rod Withdrawal -Hot Shutdown 3.10.3 SURVEILLANCE REQUIREMENTS SR 3.10.3.1 SR 3.10.3.2 SR 3.10.3.3 NMP2 SURVEILLANCE Perform the applicable SRs for the required LC Os. ---------------------------N 0 TE--------------------------------Not required to be met if SR 3.10.3.1 is satisfied for LCO 3.10.3.d.1 requirements. Verify all control rods, other than the control rod being withdrawn, in a five by five array centered on the control rod being withdrawn, are disarmed. Verify all control rods, other than the control rod being withdrawn, are fully inserted. 3.10.3-3 FREQUENCY According to the applicable SRs In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment B+, 152 Single Control Rod Withdrawal -Cold Shutdown 3.10.4 ACTIONS {continued) CONDITION REQUIRED ACTION B. One or more of the above requirements not met with the affected control rod not insertable. B.1 Suspend withdrawal of the control rod and removal of associated CAD. B.2.1 OR B.2.2 Initiate action to fully insert all control rods. Initiate action to satisfy the requirements of this LCO. SURVEILLANCE REQUIREMENTS SR 3.10.4.1 SR 3.10.4.2 NMP2 SURVEILLANCE Perform the applicable SRs for the required LCOs. ------------------------------NOTE-----------------------------N ot required to be met if SR 3.10.4.1 is satisfied for LCO 3.10.4.c.1 requirements. Verify all control rods, other than the control rod being withdrawn, in a five by five array centered on the control rod being withdrawn, are disarmed. 3.10.4-3 COMPLETION TIME Immediately Immediately Immediately FREQUENCY According to applicable SRs In accordance with the Surveillance Frequency Control Program (continued) Amendment 9+, 152 Single Control Rod Withdrawal -Cold Shutdown 3.10.4 SURVEILLANCE REQUIREMENTS (continued) SR 3.10.4.3 SR 3.10.4.4 NMP2 SURVEILLANCE Verify all control rods, other than the control rod being withdrawn, are fully inserted. ------------------------------NOTE-----------------------------Not required to be met if SR 3.10.4. 1 is satisfied for LCO 3.10.4.b.1 requirements. Verify a control rod withdrawal block is inserted. 3.10.4-4 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendments+, 152 Single CRD Removal -Refueling 3.10.5 ACTIONS CONDITION REQUIRED ACTION A. (continued) A.2.1 OR A.2.2 Initiate action to fully insert all control rods. Initiate action to satisfy the requirements of this LCO. SURVEILLANCE REQUIREMENTS SR 3.10.5.1 SR 3.10.5.2 SR 3.10.5.3 NMP2 SURVEILLANCE Verify all controls rods, other than the control rod withdrawn for the removal of the associated CRD, are fully inserted. Verify all control rods, other than the control rod withdrawn for the removal of the associated CAD, in a five by five array centered on the control rod withdrawn for the removal of the associated CAD, are disarmed. Verify a control rod withdrawal block is inserted. 3.10.5-2 COMPLETION TIME Immediately Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment 9-1-, 152 Single CRD Removal -Refueling 3.10.5 SURVEILLANCE REQUIREMENTS (continued) SR 3.10.5.4 SR 3.10.5.5 NMP2 SURVEILLANCE Perform SR 3.1.1.1. Verify no other CORE ALTERATIONS are in progress. 3.10.5-3 FREQUENCY According to SR 3.1.1.1 In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 Multiple Control Rod Withdrawal -Refueling 3.10.6 ACTIONS CONDITION REQUIRED ACTION A. (continued) A.3.1 OR A.3.2 Initiate action to fully insert all control rods in core cells containing one or more fuel assemblies. Initiate action to satisfy the requirements of this LCO. SURVEILLANCE REQUIREMENTS SR 3.10.6.1 SR 3.10.6.2 SR 3.10.6.3 NMP2 SURVEILLANCE Verify the four fuel assemblies are removed from core cells associated with each control rod or CRD removed. Verify all other control rods in core cells containing one or more fuel assemblies are fully inserted. ------------------------------NOTE-----------------------------Only required to be met during fuel loading. Verify fuel assemblies being loaded are in compliance with an approved spiral reload sequence. 3.10.6-2 COMPLETION TIME Immediately Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment 9-+, 152 SURVEILLANCE REQUIREMENTS (continued) SR 3.10.8.2 SR 3.10.8.3 SR 3.10.8.4 NMP2 SURVEILLANCE ------------------------------NOTE-----------------------------Not required to be met if SR 3.10.8.3 satisfied. Perform the MODE 2 applicable SRs for LCO 3.3.2.1, Function 2 of Table 3.3.2.1-1. ------------------------------NOTE-----------------------------Not required to be met if SR 3.10.8.2 satisfied. Verify movement of control rods is in compliance with the approved control rod sequence for the SOM test by a second licensed operator or other qualified member of the technical staff. Verify no other CORE ALTERATIONS are in progress. 3.10.8-3 SOM Test -Refueling 3.10.8 FREQUENCY According to the applicable SRs During control rod movement In accordance with the Surveillance Frequency Control Program (continued) Amendment 9-:1-, 152 SURVEILLANCE REQUIREMENTS (continued) SR 3.10.8.5 SR 3.10.8.6 NMP2 SURVEILLANCE Verify each withdrawn control rod does not go to the withdrawn overtravel position. Verify CRD charging water header pressure ::::: 940 psig. 3.10.8-4 SOM Test -Refueling 3.10.8 FREQUENCY Each time the control rod is withdrawn to "full out" position Prior to satisfying LCO 3.10.8.c requirement after work on control rod or CAD System that could affect coupling In accordance with the Surveillance Frequency Control Program Amendment 9+, 152 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.13 5.5.14 NMP2 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 OBA 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. 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. 5.5-13 152 SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION RELATED TO AMENDMENT NO. 152 TO RENEWED FACILITY OPERATING LICENSE NO. NPF-69 NINE MILE POINT NUCLEAR STATION. LLC EXELON GENERATION COMPANY. LLC DOCKET NO. 50-410 NINE MILE POINT NUCLEAR STATION, UNIT 2 1.0 INTRODUCTION By application dated November 19, 2014, as supplemented by letters dated July 10, 2015, September 10, 2015, and September 24, 2015 (Agencywide Documents Access and Management System (ADAMS) Accession Nos. ML 14329A353, ML 15191A013, ML 15254A069 and ML 15271A029, respectively), Exelon Generation Company, LLC (the licensee) requested changes to the Technical Specifications (TSs) for Nine Mile Point Unit 2 (NMP2). The letters provided clarifying information that did not expand the scope of the application and did not change the staff's original proposed no significant hazards consideration (NSHC) determination as published in the Federal Register(FR) on March 17, 2015 (80 FR 13906). The proposed change would modify the NMP2, TSs by relocating specific surveillance requirement (SR) frequencies to a licensee-controlled program (i.e., the Surveillance Frequency Control Program (SFCP)) in accordance with Nuclear Energy Institute (NEI) 04-10, Revision 1, "Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies" (ADAMS Accession No. ML071360456). The proposed change is consistent with the adoption of U.S. Nuclear Regulatory Commission (NRC) approved Technical Specification Task Force (TSTF) Standard Technical Specifications (STS) Change Traveler TSTF-425, Revision 3, "Relocated Surveillance Frequencies to Licensee Control -RITSTF [Risk-Informed TSTF] Initiative 5b" (ADAMS Accession No. ML090850642). The FR notice published on July 6, 2009 (74 FR 31996), announced the availability of TSTF-425, Revision 3. When implemented, TSTF-425, Revision 3, relocates most periodic frequencies of TS surveillances to the SFCP, and provides requirements for the new program in the Administrative Controls section of the TSs. All surveillance frequencies can be relocated except:
  • Frequencies that reference other approved programs for the specific interval (such as the In-Service Testing Program or the Primary Containment Leakage Rate Testing Program);
  • Frequencies that are purely event-driven (e.g., "each time the control rod is withdrawn to the 'full out' position");

-2 -* Frequencies that are event-driven, but have a time component for performing the surveillance on a one-time basis once the event occurs (e.g., "within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after thermal power reaching;:::: 95% RTP" [rated thermal power]); and

  • Frequencies that are related to specific conditions (e.g., battery degradation, age and capacity) or conditions for the performance of a surveillance requirement (e.g., "drywell to suppression chamber differential pressure decrease"). The licensee proposed to add the SFCP to TS Section 5.0, "Administrative Controls." The SFCP describes the requirements for the program to control changes to the relocated surveillance frequencies. The TS Bases for each affected surveillance are revised to state that the frequency is controlled under the SFCP. Various editorial changes have been made to the Bases to facilitate the addition of the Bases changes. The proposed changes to the Administrative Controls sections of the TSs to incorporate the SFCP include a specific reference to NEI 04-10, Revision 1, as the basis for making any changes to the surveillance frequencies once they are relocated out of the TSs. In a letter dated September 19, 2007 (ADAMS Accession No. ML072570267), the NRC staff approved NEI Topical Report (TR) NEI 04-10, Revision 1, as acceptable for referencing in licensing actions to the extent specified and under the limitations delineated in NEI 04-10, Revision 1, and the safety evaluation (SE) providing the basis for NRC acceptance of NEI 04-10, Revision 1. Other changes and deviations from TSTF-425, are discussed in Section 3.3 of this SE. 2.0 REGULATORY EVALUATION 2.1 Applicable Commission Policy Statements In the "Final Policy Statement: Technical Specifications for Nuclear Power Plants," dated July 22, 1993 (58 FR 39132) the NRC addressed the use of Probabilistic Safety Analysis {PSA, currently referred to as Probabilistic Risk Assessment or PRA) in STS. In this 1993 publication, the NRC states: The Commission believes that it would be inappropriate at this time to allow requirements which meet one or more of the first three criteria [of Title 10 of the Code of Federal Regulations (10 CFR), Section 50.36] to be deleted from Technical Specifications based solely on PSA (Criterion 4). However, if the results of PSA indicate that Technical Specifications can be relaxed or removed, a deterministic review will be performed .... The Commission Policy in this regard is consistent with its Policy Statement on "Safety Goals for the Operation of Nuclear Power Plants," 51 FR 30028, published on August 21, 1986. The Policy Statement on Safety Goals states in part, " ... probabilistic results should also be reasonably balanced and supported through use of deterministic arguments. In this way, judgments can be made ... about the degree of confidence to be given these [probabilistic] estimates and assumptions. This is a key part of the process for determining the degree of

-3 -regulatory conservatism that may be warranted for particular decisions. This defense-in-depth approach is expected to continue to ensure the protection of public health and safety." ... The Commission will continue to use PSA, consistent with its policy on Safety Goals, as a tool in evaluating specific line-item improvements to Technical Specifications, new requirements, and industry proposals for risk-based Technical Specification changes. Approximately two years later the NRC provided additional detail concerning the use of PRA in the "Final Policy Statement: Use of Probabilistic Risk Assessment in Nuclear Regulatory Activities," dated August 16, 1995 (60 FR 42622). In this publication, the NRC states: The Commission believes that an overall policy on the use of PRA methods in nuclear regulatory activities should be established so that the many potential applications of PRA can be implemented in a consistent and predictable manner that would promote regulatory stability and efficiency. In addition, the Commission believes that the use of PRA technology in NRC regulatory activities should be increased to the extent supported by the state-of-the-art in PRA methods and data and in a manner that complements the NRC's deterministic approach .... PRA addresses a broad spectrum of initiating events by assessing the event frequency. Mitigating system reliability is then assessed, including the potential for multiple and common cause failures. The treatment therefore goes beyond the single failure requirements in the deterministic approach. The probabilistic approach to regulation is, therefore, considered an extension and enhancement of traditional regulation by considering risk in a more coherent and complete manner .... Therefore, the Commission believes that an overall policy on the use of PRA in nuclear regulatory activities should be established so that the many potential applications of PRA can be implemented in a consistent and predictable manner that promotes regulatory stability and efficiency. This policy statement sets forth the Commission's intention to encourage the use of PRA and to expand the scope of PRA applications in all nuclear regulatory matters to the extent supported by the state-of-the-art in terms of methods and data .... Therefore, the Commission adopts the following policy statement regarding the expanded NRC use of PRA: (1) The use of PRA technology should be increased in all regulatory matters to the extent supported by the state-of-the-art in PRA methods and data and in a manner that complements the NRC's deterministic approach and supports the NRC's traditional defense-in-depth philosophy. (2) PRA and associated analyses (e.g., sensitivity studies, uncertainty analyses, and importance measures) should be used in regulatory matters, where

-4 -practical within the bounds of the state-of-the-art, to reduce unnecessary conservatism associated with current regulatory requirements, regulatory guides, license commitments, and staff practices. Where appropriate, PRA should be used to support the proposal for additional regulatory requirements in accordance with 10 CFR 50.109 (Backfit Rule). Appropriate procedures for including PRA in the process for changing regulatory requirements should be developed and followed. It is, of course, understood that the intent of this policy is that existing rules and regulations shall be complied with unless these rules and regulations are revised. (3) PRA evaluations in support of regulatory decisions should be as realistic as practicable and appropriate supporting data should be publicly available for review. (4) The Commission's safety goals for nuclear power plants and subsidiary numerical objectives are to be used with appropriate consideration of uncertainties in making regulatory judgments on the need for proposing and backfitting new generic requirements on nuclear power plant licensees. 2.2 Applicable Regulations Pursuant to 10 CFR 50.36, TSs are required to include items in the following five specific categories related to station operation: (1) safety limits, limiting safety system settings, and limiting control settings; (2) limiting conditions for operation (LCOs); (3) SRs; (4) design features; and (5) administrative controls. These categories will remain in the NMP2, TSs. Paragraph 50.36(c)(3) of 10 CFR states, "Surveillance requirements are requirements relating to test, calibration, or inspection to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met." The FR notice published on July 6, 2009 (74 FR 31996), which announced the availability of TSTF-425, Revision 3, states that the addition of the SFCP to the TSs provides the necessary administrative controls to require that surveillance frequencies relocated to the SFCP are conducted at a frequency to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met. The FR notice also states that changes to surveillance frequencies in the SFCP are made using the methodology contained in NEI 04-10, Revision 1, including qualitative considerations, results of risk analyses, sensitivity studies and any bounding analyses, and recommended monitoring of structures, systems, and components (SSCs), and are required to be documented. Existing regulatory requirements, such as 1 O CFR 50.65, "Requirements for Monitoring the Effectiveness of Maintenance at Nuclear Power Plants" (i.e., the Maintenance Rule), and 10 CFR 50, Appendix B, Criterion XVI, "Corrective Action," require licensee monitoring of surveillance test failures and implementing corrective actions to address such failures. Such failures can result in the licensee increasing the frequency at which a surveillance test is performed. In addition, the SFCP implementation guidance in NEI 04-10, Revision 1, requires monitoring the performance of SSCs for which surveillance frequencies are decreased to assure reduced testing does not adversely impact the SSCs.

-5 -2.3 Applicable NRC Regulatory Guides and Review Plans Regulatory Guide (RG) 1.17 4, "An Approach for Using Probabilistic Risk Assessment in Risk-Informed Decisions on Plant-Specific Changes to the Licensing Basis" Revision 2, (ADAMS Accession No. ML 100910006), describes an acceptable risk-informed approach for assessing the nature and impact of proposed permanent licensing-basis changes by considering engineering issues and applying risk insights. This regulatory guide also provides risk acceptance guidelines for evaluating the results of such evaluations. RG 1.177, "An Approach for Plant-Specific, Risk-Informed Decisionmaking: Technical Specifications," Revision 1, (ADAMS Accession No. ML 100910008), describes an acceptable risk-informed approach specifically for assessing proposed TS changes. RG 1.200, "An Approach for Determining the Technical Adequacy of Probabilistic Risk Assessment Results for Risk-Informed Activities," Revision 2, (ADAMS Accession No. ML090410014}, describes an acceptable approach for determining whether the quality of the PRA, in total or the parts that are used to support an application, is sufficient to provide confidence in the results, such that the PRA can be used in regulatory decision making for light water-reactors. General guidance for evaluating the technical basis for proposed risk-informed changes is provided in Chapter 19, Section 19.2, "Review of Risk Information Used to Support Permanent Plant-Specific Changes to the Licensing Basis: General Guidance" (ADAMS Accession No. ML071700658}, of NUREG-0800, "Standard Review Plan [SRP] for the Review of Safety Analysis Reports for Nuclear Power Plants: LWR Edition." Guidance on evaluating PRA technical adequacy is provided in the SRP, Chapter 19, Section 19.1, "Determining the Technical Adequacy of Probabilistic Risk Assessment for Risk-Informed License Amendment Requests After Initial Fuel Load," Revision 3, (ADAMS Accession No. ML 12193A107). More specific guidance related to risk-informed TS changes is provided in SRP, Chapter 16, Section 16.1, "Risk-Informed Decisionmaking: Technical Specifications," Revision 1, (ADAMS Accession No. ML070380228), which includes changes to Completion Times as part of risk-informed decision making. Section 19.2 of the SRP references the same criteria as RG 1.177, Revision 1, and RG 1.174, Revision 2, and states that a risk-informed application should be evaluated to ensure that the proposed changes meet the following key principles:

  • The proposed change meets the current regulations, unless it explicitly relates to a requested exemption or rule change.
  • The proposed change is consistent with the defense-in-depth philosophy.
  • The proposed change maintains sufficient safety margins.
  • When proposed changes result in an increase CDF or risk, the increase(s) should be small and consistent with the intent of the Commission's Safety Goal Policy Statement.

-6 -* The impact of the proposed change should be monitored using performance measurement strategies. 3.0 TECHNICAL EVALUATION The licensee's adoption of TSTF-425, Revision 3, provides for administrative relocation of applicable surveillance frequencies, and provides for the addition of the SFCP to the Administrative Controls of TSs. TSTF-425, Revision 3, also requires the application of NEI 04-10, Revision 1, for any changes to surveillance frequencies within the SFCP. The licensee's application for the changes proposed in TSTF-425, Revision 3, included documentation regarding the PRA technical adequacy consistent with the requirements of RG 1.200, Revision 2. In accordance with NEI 04-10, Revision 1, PRA methods are used, in combination with plant performance data and other considerations, to identify and justify modifications to the surveillance frequencies of equipment at nuclear power plants. This is in accordance with guidance provided in RG 1.17 4, Revision 2, and RG 1.177, Revision 1, in support of changes to surveillance test intervals. 3.1 Review Methodology RG 1.177, Revision 1, identifies five key safety principles required for risk-informed changes to TSs. Each of these principles is addressed by NEI 04-10, Revision 1. 3.1.1 The Proposed Change Meets Current Regulations Section 50.36(c)(3) of 10 CFR requires that TSs include surveillances which are "requirements relating to test, calibration, or inspection to assure that necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met." The licensee is required by its TSs to perform surveillance tests, calibration, or inspection on specific safety-related equipment (e.g., reactivity control, power distribution, electrical, and instrumentation) to verify system operability. Surveillance frequencies are based primarily upon deterministic methods such as engineering judgment, operating experience, and manufacturer's recommendations. The licensee's use of NRG-approved methodologies identified in NEI 04-10, Revision 1, provides a way to establish risk-informed surveillance frequencies that complements the deterministic approach and supports the NRC's traditional defense-in-depth philosophy. The SRs themselves are remaining in the TSs, as required by 10 CFR 50.36(c)(3). This change is analogous with other NRG-approved TS changes in which the SRs are retained in TSs, but the related surveillance frequencies are relocated to licensee-controlled documents, such as surveillances performed in accordance with the In-Service Testing Program and the Primary Containment Leakage Rate Testing Program. Thus, this proposed change complies with 10 CFR 50.36(c)(3) by retaining the requirements relating to test, calibration, or inspection to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met. The regulatory requirements in 10 CFR 50.65 and 10 CFR 50, Appendix B, and the monitoring required by NEI 04-10, Revision 1, ensure that surveillance frequencies are sufficient to assure that the requirements of 10 CFR 50.36 are satisfied and that any performance deficiencies will be identified and appropriate corrective actions taken. The licensee's SFCP ensures that SRs

-7 -specified in the TSs are performed at intervals sufficient to assure the above regulatory requirements are met. In light of the above, the NRC staff concludes that the proposed change meets the first key safety principle of RG 1.177 by complying with current regulations. 3.1.2 The Proposed Change Is Consistent With the Defense-in-Depth Philosophy The defense-in-depth philosophy (i.e., the second key safety principle of RG 1.177, Revision 1 ), is maintained if:

  • A reasonable balance is preserved among prevention of core damage, prevention of containment failure, and consequence mitigation.
  • Over-reliance on programmatic activities to compensate for weaknesses in plant design is avoided.
  • System redundancy, independence, and diversity are preserved commensurate with the expected frequency, consequences of challenges to the system, and uncertainties (e.g., no risk outliers). (Because the scope of the proposed methodology is limited to revision of surveillance frequencies, the redundancy, independence, and diversity of plant systems are not impacted.)
  • Defenses against potential common cause failures are preserved, and the potential for the introduction of new common cause failure mechanisms is assessed.
  • Independence of barriers is not degraded.
  • Defenses against human errors are preserved.
  • The intent of the General Design Criteria in 10 CFR Part 50, Appendix A, is maintained. TSTF-425, Revision 3, requires the application of NEI 04-10, Revision 1, for any changes to surveillance frequencies within the SFCP. NEI 04-10, Revision 1, uses both the core damage frequency (CDF) and the large early release frequency (LERF) metrics to evaluate the impact of proposed changes to surveillance frequencies. The guidance of RG 1.17 4, Revision 2, and RG 1.177, Revision 1, for changes to CDF and LERF is achieved by evaluation using a comprehensive risk analysis, which assesses the impact of proposed changes including contributions from human errors and common cause failures (CCFs). Defense-in-depth is also included in the methodology explicitly as a qualitative consideration outside of the risk analysis, as is the potential impact on detection of component degradation that could lead to an increased likelihood of CCFs. The NRC staff concludes that both the quantitative risk analysis and the qualitative considerations assure that a reasonable balance of defense-in-depth is maintained to ensure protection of public health and safety, thus satisfying the second key safety principle of RG 1.177, Revision 1.

-8 -3.1.3 The Proposed Change Maintains Sufficient Safety Margins The engineering evaluation that will be conducted by the licensee under the SFCP when frequencies are revised will assess the impact of the proposed frequency change to assure that sufficient safety margins are maintained. The guidelines used for making that assessment will include ensuring the proposed surveillance test frequency change is not in conflict with approved industry codes and standards or adversely affects any assumptions or inputs to the safety analysis, or, if such inputs are affected, justification is provided to ensure sufficient safety margin will continue to exist. The design, operation, testing methods, and acceptance criteria for SSCs specified in applicable codes and standards (or alternatives approved for use by the NRC) will continue to be met as described in the plants' licensing bases, including the Updated Final Safety Analysis Report and TS Bases, because these are not affected by changes to the surveillance frequencies. Similarly, there is no impact to safety analysis acceptance criteria as described in the plant licensing basis. On this basis, the staff concludes that safety margins are maintained by the proposed methodology, and the third key safety principle of RG 1.177, Revision 1, is satisfied. 3.1.4 When Proposed Changes Result in an Increase in CDF or Risk. the Increases Should Be Small and Consistent with the Intent of the Commission's Safety Goal Policy Statement RG 1.177, Revision 1, provides a framework for evaluating the risk impact of proposed changes to surveillance frequencies which requires identification of the risk contribution from impacted surveillances, determination of the risk impact from the change to the proposed surveillance frequency, and performance of sensitivity and uncertainty evaluations. TSTF-425, Revision 3, provides for application of NEI 04-10, Revision 1, in the SFCP. NEI 04-10, Revision 1, satisfies the intent of RG 1.177, Revision 1, guidance for evaluation of the change in risk, and for assuring that such changes are small by providing the technical methodology to support risk-informed TSs for control of surveillance frequencies. 3.1.4.1 Quality of the PRA The quality of the licensee's PRA must be commensurate with the safety significance of the proposed TS change and the role the PRA plays in justifying the change. That is, the higher change in risk or the greater the uncertainty in that risk from the requested TS change, or both, the more rigor that must go into ensuring the quality of the PRA. RG 1.200, Revision 2, provides regulatory guidance for assessing the technical adequacy of a PRA. The current revision (i.e., Revision 2) of this RG endorses (with clarifications and qualifications) the use of (1) the American Society of Mechanical Engineers (ASME)/American Nuclear Society (ANS) RA-Sa-2009, "Addenda to ASME RA-S-2008 Standard for Level 1/Large Early Release Frequency Probabilistic Risk Assessment for Nuclear Power Plant Applications" (i.e., the PRA Standard), (2) NEI 00-02, "PRA Peer Review Process Guidance" (ADAMS Accession Nos. ML061510619 and ML063390593), and (3) NEI 05-04, "Process for Performing Internal Events PRA Peer Reviews Using the ASME/ANS PRA Standard" (ADAMS Accession No. ML083430462).

-9 -The licensee has performed an assessment of the PRA models used to support the SFCP using the guidance of RG 1.200, Revision 2, to assure that the PRA models are capable of determining the change in risk due to changes to surveillance frequencies of SSCs, using plant-specific data and models. Capability Category II of the endorsed PRA standard is the target capability level for supporting requirements for the internal events PRA for this application. Any identified deficiencies to those requirements are assessed further to determine any impacts to proposed decreases to surveillance frequencies, including the use of sensitivity studies where appropriate, in accordance with NEI 04-10, Revision 1. An internal events PRA peer review was performed in 2009, which, as clarified in response to PRA RAI 1 (ADAMS Accession Number ML 15191A013), was performed against the latest PRA standard ASME/ANS RA-Sa-2009, as endorsed by RG 1.200, Revision 2. The licensee stated that the peer review resulted in 18 findings, which did not meet Capability Category II, and 34 suggestions that met Capability Category II. In the LAR the licensee submitted all peer review Facts and Observations (F&Os) that were not addressed. In response to PRA RAI 2, the licensee provided the list of F&Os applicable to the TSTF-425 application. The NRC staff reviewed (1) the summary of the peer review finding, (2) the licensee's resolution to the finding, and (3) the licensee's assessment of the impact on this application for the submitted F&Os to ensure that any deficiency in not meeting Capability Category II will be addressed and dispositioned for each surveillance frequency evaluation per the NEI 04-10 methodology. The NRC staffs assessment for the F&Os is provided below. F&O 1-1, related to Supporting Requirement DA-C6, was created because the licensee did not include demands from causes other than surveillance tests in its plant specific estimation of demands on standby components. The Supporting Requirement directs the licensee to consider, in addition to surveillance tests, maintenance acts and operational demands. The NRC staff concludes that the inclusion of all of the sources of demands on standby components would assist the licensee in the estimation of the probability of failure on demand; however, outside of surveillance tests, which the licensee considered, this Supporting Requirement would minimally impact the calculation of change in CDF or LERF due to surveillance interval extensions. F&O 2-5, related to Supporting Requirement DA-01, was created because the peer review team observed that the licensee's documentation stated that a Bayesian analysis was not done when there are no plant-specific failures. The licensee stated that it updated the model and documentation with Bayesian analysis for zero events down to failure rates on the order of 1 E-3. The licensee further states that it will continue to perform the Bayesian update for events with zero plant specific failures. Since the licensee has addressed the concern over Bayesian analysis for no observed plant failures and included the updated information in its best practices, the NRC staff finds the disposition acceptable for the application. F&O 2-6, related to Supporting Requirement DA-04, was created because the peer review team did not find documentation that the licensee analyzed inconsistencies between the prior distribution and the plant-specific data in its Bayesian analysis. In response to the F&O, the licensee stated that it performed a review for inconsistencies and a few distributions were identified as potentially inconsistent. For these cases the licensee manipulated the prior distribution to be more representative of plant data; therefore, the NRC concludes that the licensee has properly addressed the F&O for this application.

-10 -F&O 5-2, related to Supporting Requirement IE-A6, was created because the licensee did not include routine system alignments in its calculation of initiating event frequencies. In the licensee's disposition, the licensee indicated that it performed a systematic evaluation that considered routine system alignments and provided documentation in the initiating events notebook. Therefore the NRC staff does not expect this to impact the determination of safety related component failure rates or establishment of surveillance intervals. F&O 6-5, related to Supporting Requirement AS-C1, was created because the peer review team observed that the licensee's Accident Sequence notebook did not contain the event tree top event fault trees. Supporting Requirement AS-C1 requires proper documentation to support the peer review and facilitate PRA upgrades. The licensee stated that this documentation issue will be corrected. As this is a documentation concern, the NRC staff concludes that this would not impact the risk calculations to support changes to surveillance test intervals. Based on the licensee's assessments using the currently applicable PRA standard and revision of RG 1.200, the NRC staff concludes that the level of PRA quality, combined with the proposed evaluation and disposition of gaps, is sufficient to support the evaluation of changes proposed to surveillance frequencies within the SFCP, and is consistent with Regulatory Position 2.3.1 of RG 1.177, Revision 1. 3.1.4.2 Scope of the PRA The licensee is required to evaluate each proposed change to a relocated surveillance frequency using the guidance contained in NEI 04-10, Revision 1, to determine its potential impact on risk (CDF and LERF) from internal events, fires, seismic, other external events, and shutdown conditions. In cases where a PRA of sufficient scope or quantitative risk models were unavailable, the licensee uses bounding analyses, or other conservative quantitative evaluations. A qualitative screening analysis may be used when the surveillance frequency impact on plant risk is shown to be negligible or zero. NMP2 has an internal events PRA model, which it will use to perform quantitative evaluations to support the development of changes to surveillance frequencies in the SFCP, in accordance with NEI 04-10, Revision 1. In Section 2.3 of the LAR, "External Event Considerations," the licensee stated that external hazards were evaluated in the Individual Plant Examination of External Events (IPEEE). Internal fire events were addressed by using the EPRI Fire Induced Vulnerability Evaluation (FIVE) methodology. The licensee noted that the IPEEE fire model was incorporated into the internal events PRA model in a 2009 PRA update. In section 2.3 of the LAR, the licensee stated that it does not have a seismic PRA and that the IPEEE seismic evaluations used the Electronic Power Research Institute (EPRI) Seismic Margins Analysis (SMA) methodology. The licensee stated that high winds, floods, and other (HFO) external hazards were determined in the NMP2 IPEEE to be negligible contributors to overall plant risk. Further, the licensee indicated that for the external hazards for which there is no PRA model, a qualitative or a bounding approach will be performed to provide justification for the acceptability of the proposed test interval change. The licensee's plan on addressing the fire risk and external events through use of qualitative or bounding analysis is an acceptable approach in accordance with NEI 04-10, Revision 1.

-11 -In the response to PRA RAI 3, provided in licensee's letter dated July 10, 2015, the licensee explained that it does not have a shutdown PRA model. The licensee further stated that changes to surveillance frequencies under the SFCP will consider low power and shutdown events in accordance with NEI 04-10, Revision 1, Section 4.0, Step 10. The NRC staff finds the licensee's plan to address low power and shutdown events through use of qualitative or bounding analyses acceptable, consistent with NEI 04-10, Revision 1, Section 4.0, Step 10. Thus, the NRC staff concludes that through the application of NEI 04-10, Revision 1, the licensee's evaluation methodology is sufficient to ensure the scope of the risk contribution of each surveillance frequency change is properly identified for evaluation and is consistent with Regulatory Position 2.3.2 of RG 1.177, Revision 1. 3.1.4.3 PRA Modeling The licensee's methodology includes the determination of whether the SSCs affected by a proposed change to a surveillance frequency are modeled in the PRA. Where the SSC is directly or implicitly modeled, a quantitative evaluation of the risk impact may be carried out. The methodology adjusts the failure probability of the impacted SSCs, including any impacted CCF modes, based on the proposed change to the surveillance frequency. Where the SSC is not modeled in the PRA, bounding analyses are performed to characterize the impact of the proposed change to the surveillance frequency. Potential impacts on the risk analyses due to screening criteria and truncation levels are addressed by the requirements for PRA technical adequacy consistent with guidance contained in RG 1.200, Revision 2, and by sensitivity studies identified in NEI 04-10, Revision 1. Thus, the staff concludes that through the application of NEI 04-10, Revision 1, the NMP2, PRA modeling is sufficient to ensure an acceptable evaluation of risk for the proposed changes in surveillance frequency, and is consistent with Regulatory Position 2.3.3 of RG 1.177, Revision 1. 3.1.4.4 Assumptions for Time Related Failure Contributions The failure probabilities of SSCs modeled in PRAs may include a standby time-related contribution and a cyclic demand-related contribution. In Section 2.2.4 of Attachment 2 to the LAR, the licensee explained that the standby time-related contribution evaluation will be performed. The criteria in NEI 04-10, Revision 1, adjusts the time-related failure contribution of SSCs affected by the proposed change to a surveillance frequency. This is consistent with RG 1.177, Revision 1, Section 2.3.3, which permits separation of the failure rate contributions into demand and standby for evaluation of SRs. If the available data do not support distinguishing between the time-related failures and demand failures, then the change to surveillance frequency is conservatively assumed to impact the total failure probability of the SSC, including both standby and demand contributions. The SSC failure rate (per unit time) is assumed to be unaffected by the change in test frequency, such that the failure probability is assumed to increase linearly with time, and will be confirmed by the required monitoring and feedback implemented after the change in surveillance frequency is implemented. The NEI 04-10 process also requires consideration of qualitative sources of information with regards to potential impacts of test frequency on SSC performance, including industry and plant-specific operating experience, vendor recommendations, industry standards, and code-specified test

-12 -intervals. Thus the process is not reliant upon risk analyses as the sole basis for the proposed changes. The potential benefits of a reduced surveillance frequency, including reduced downtime and reduced potential for restoration errors, test-caused transients, and test-caused wear of equipment, are identified qualitatively, but not quantitatively assessed. Thus, the NRC staff concludes that through the application of NEI 04-10, Revision 1, the licensee has employed reasonable assumptions with regard to extensions of surveillance test intervals, and is consistent with Regulatory Position 2.3.4 of RG 1.177, Revision 1. 3.1.4.5 Sensitivity and Uncertainty Analyses By having the TSs require that changes to the frequencies listed in the SFCP be made in accordance with NEI 04-10, Revision 1, the licensee will be required to have sensitivity studies to assess the impact of uncertainties from key assumptions of the PRA, uncertainty in the failure probabilities of the affected SSCs, impact on the frequency of initiating events, and any identified deviations from Capability Category II of the PRA standard. Where the sensitivity analyses identify a potential impact on the proposed change, revised surveillance frequencies are considered, along with any qualitative considerations that may bear on the results of such sensitivity studies. The licensee will also be required to perform monitoring and feedback of SSC performance once the revised surveillance frequencies are implemented. Thus, the NRC staff concludes that through the application of NEI 04-10, Revision 1, the licensee has appropriately considered the possible impact of PRA model uncertainty and sensitivity to key assumptions and model limitations and is consistent with Regulatory Position 2.3.5 of RG 1.177, Revision 1. 3.1.4.6 Acceptance Guidelines The licensee will be required to quantitatively evaluate the change in total risk (including internal and external events contributions) in terms of CDF and LERF for both the individual risk impact of a proposed change in surveillance frequency and the cumulative impact from all individual changes to surveillance frequencies using the guidance contained in NEI 04-10, Revision 1, in accordance with the TS SFCP. Each individual change to surveillance frequency must show a risk impact below 1 E-6 per year for change to CDF, and below 1 E-7 per year for change to LERF. These changes to CDF and LERF are consistent with the acceptance criteria of RG 1.17 4, Revision 2, for very small changes in risk. Where the RG 1.17 4, Revision 2, acceptance criteria are not met, the process either considers revised surveillance frequencies which are consistent with RG 1.17 4, Revision 2, or the process terminates without permitting the proposed changes. Where quantitative results are unavailable for comparison with the acceptance guidelines, appropriate qualitative analyses are required to demonstrate that the associated risk impact of a proposed change to surveillance frequency is negligible or zero. Otherwise, bounding quantitative analyses are required which demonstrate the risk impact is at least one order of magnitude lower than the RG 1.17 4, Revision 2, acceptance guidelines for very small changes in risk. In addition to assessing each individual SSC surveillance frequency change, the cumulative impact of all changes must result in a risk impact less than 1 E-5 per year for change to CDF, and less than 1 E-6 per year for change to LERF, and the total CDF and total LERF must be reasonably shown to be less than 1 E-4 per year and 1 E-5 per year,

-13 -respectively. These values are consistent with the acceptance criteria of RG 1.17 4, Revision 2, as referenced by RG 1.177, Revision 1, for changes to surveillance frequencies. Consistent with the NRC's SE dated September 19, 2007, for NEI 04-10, Revision 1, the licensee is required to calculate the total change in risk (i.e., the cumulative risk) by comparing a baseline model that uses failure probabilities based on surveillance frequencies prior to being changed per the SFCP to a revised model that uses failure probabilities based on the changed surveillance frequencies. The NRC staff further notes that the licensee includes a provision to exclude the contribution to cumulative risk from individual changes to surveillance frequencies associated with insignificant risk increases (i.e., less than 5E-8 CDF and 5E-9 LERF) once the baseline PRA models are updated to include the effects of the revised surveillance frequencies. The quantitative acceptance guidance of RG 1.174, Revision 2, is supplemented by qualitative information to evaluate the proposed changes to surveillance frequencies, including industry and plant-specific operating experience, vendor recommendations, industry standards, the results of sensitivity studies, and SSC performance data and test history. The final acceptability of the proposed change is based on all of these considerations and not solely on the PRA results. Post implementation performance monitoring and feedback are also required to assure continued reliability of the components. The licensee's application of NEI 04-10, Revision 1, provides acceptable methods for evaluating the risk increase associated with proposed changes to surveillance frequencies, consistent with Regulatory Position 2.4 of RG 1.177, Revision 1. Therefore, the NRC staff concludes that the proposed methodology satisfies the fourth key safety principle of RG 1.177, Revision 1, by assuring any increase in risk is small consistent with the intent of the Commission's Safety Goal Policy Statement. 3.1.5 The Impact of the Proposed Change Should Be Monitored Using Performance Measurement Strategies The licensee's adoption of TSTF-425, Revision 3, requires application of NEI 04-10, Revision 1, in the SFCP. NEI 04-10, Revision 1, requires performance monitoring of SSCs whose surveillance frequencies have been revised as part of a feedback process to assure that the change in test frequency has not resulted in degradation of equipment performance and operational safety. The monitoring and feedback includes consideration of Maintenance Rule monitoring of equipment performance. In the event of SSC performance degradation, the surveillance frequency will be reassessed in accordance with the methodology, in addition to any corrective actions which may be required by the Maintenance Rule. The performance monitoring and feedback specified in NEI 04-10, Revision 1, is sufficient to reasonably assure acceptable SSC performance and is consistent with Regulatory Position 3.2 of RG 1.177, Revision 1. Thus, the NRC staff concludes that the fifth key safety principle of RG 1.177, Revision 1, is satisfied. 3.2 Addition of Surveillance Frequency Control Program to Administrative Controls The licensee proposed including the SFCP and specific requirements into the NMP2, TSs, Section 5.5.14, as follows:

-14 -Surveillance Frequency Control Program This program provides controls for Surveillance Frequencies. The program shall ensure that Surveillance Requirements specified in the Technical Specifications are performed at intervals sufficient to assure that the associated Limiting Conditions for Operation are met. a. The Surveillance Frequency Control Program shall contain a list of Frequencies of those Surveillance Requirements for which the Frequency is controlled by the program. b. Changes to the Frequency listed in the Surveillance Frequency Controlled Program shall be made in accordance with NEI 04-10, "Risk-Informed Method for Control of Surveillance Frequencies," Revision 1. c. The provisions of Surveillance Requirements 3.0.2 and 3.0.3 are applicable to the frequencies established in the Surveillance Frequency Control Program. The proposed program is consistent with the model application of TSTF-425, and therefore, the NRC staff concludes that it is acceptable. 3.3 Deviations from TSTF-425 and Other Changes 3.3.1 Revised Clean TS Pages In its submittal dated November 19, 2014, the licensee only provided marked-up TS pages, but did not provide bases pages which provide reasons for such TS to assist in our review. Only providing mark-ups of the proposed TS changes satisfies the requirements of 10 CFR 50.90 "Application for amendment of license, construction permit, or early site permit," because the mark-ups fully describe the changes desired. The NRC staff finds that this is an administrative deviation from the NRC staff's model application for TSTF-425 implementation dated July 6, 2009 (74 FR 31996), but has no impact on the NRC staff's safety evaluation. 3.3.2 Definition of STAGGERED TEST BASIS In its submittal dated November 19, 2014, the licensee proposed to retain the definition of STAGGERED TEST BASIS in the TS Definition Section 1.1. This phrase is used in Administrative TS Section 5.5.13, "Control Room Habitability," which is not changed in this amendment. The NRC staff finds that this is an administrative deviation from the NRC staff's model application dated July 6, 2009 (74 FR 31996), but has no impact on the NRC staff's safety evaluation. 3.3.3 Differences between NMP2 TSs and NUREG-1433 In its submittal dated November 19, 2014, the licensee stated that the NMP2 TS SR numbers, and associated TS Bases numbers, differ from those in NUREG-1433, Revision 4, "Standard Technical Specifications -General Electric BWR/4 Plants," Volumes 1 and 2, and TSTF-425,

-15 -Revision 3. There are also surveillances contained in NUREG-1433 that are not contained in the NMP2 TSs. These surveillances identified in TSTF-425 for NUREG-1433 are not applicable to NMP2. These differences are administrative deviations from TSTF-425 that have no impact on the NRC staff's safety evaluation. In its submittal dated November 19, 2014, the licensee requested that plant specific surveillance frequencies be relocated to the SFCP. The relocation of the plant-specific surveillance frequencies is consistent with TSTF-425 and with the NRC staff's model SE dated July 6, 2009 (74 FR 31996), including the scope exclusions identified in Section 1.0, "Introduction," of the model SE because the plant-specific surveillance frequencies involved fixed period frequencies. Changes to the frequencies for these plant-specific surveillances would be controlled under the SFCP. Therefore, the NRC staff finds this acceptable. 3.3.4 TS Bases Variations In its submittal dated November 19, 2014, the licensee noted that the TSTF-425 TS Bases insert, "The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program," should be revised to state, "The Surveillance Frequency is controlled under the Surveillance Frequency Control Program." The licensee noted that this change is necessary because surveillance frequencies that were relocated, but not changed, under the SFCP may not have been based on operating experience, equipment reliability, or plant risk. The NRC agreed with the TSTF in a letter dated April 14, 2010 (ADAMS Accession No. ML 100990099), that the wording of the TSTF-425 TS Bases does not apply to SFs relocated to the SFCP but not changed. This is an administrative deviation from TSTF-425 that has no impact on the NRC staff's safety evaluation because the NRC staff does not approve TS Bases changes. 3.4 Summary and Conclusions The NRC staff has reviewed the licensee's proposed relocation of some surveillance frequencies to a licensee-controlled document, and controlling changes to surveillance frequencies in accordance with a new program, the SFCP, identified in the Administrative Controls of TSs. The NRC staff confirmed that this amendment does not relocate surveillance frequencies that reference other approved programs for the specific interval, are purely event-driven, are event-driven but have a time component for performing the surveillance on a one-time basis once the event occurs, or are related to specific conditions. The SFCP and TS Section 5.5.14 references NEI 04-10, Revision 1, which provides a risk-informed methodology using plant-specific risk insights and performance data to revise surveillance frequencies within the SFCP. This methodology supports relocating surveillance frequencies from TSs to a licensee-controlled document, provided those frequencies are changed in accordance with NEI 04-10, Revision 1, which is specified in the administrative controls of the TSs. The licensee's proposed adoption of TSTF-425, Revision 3, and risk-informed methodology of NEI 04-10, Revision 1, as referenced in the Administrative Controls of TSs, satisfies the key principles of risk-informed decision making applied to changes to TSs as delineated in RG 1.177, Revision 1, and RG 1.17 4, Revision 2, in that:

-16 -* The proposed change meets current regulations;

  • The proposed change is consistent with defense-in-depth philosophy;
  • The proposed change maintains sufficient safety margins;
  • Increases in risk resulting from the proposed change are small and consistent with the Commission's Safety Goal Policy Statement; and
  • The impact of the proposed change is monitored with performance measurement strategies. Section 50.36(c) of 10 CFR discusses the categories that will be included in TSs. Section 50.36(c)(3) of 10 CFR discusses the specific category of Surveillance Requirements and states, "Surveillance requirements are requirements relating to test, calibration, or inspection to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met." The NRC staff finds that with the proposed relocation of surveillance frequencies to a licensee-controlled document and administratively controlled in accordance with the TS SFCP, the licensee continues to meet 10 CFR 50.36(c)(3). 4.0 STATE CONSULTATION In accordance with the Commission's regulations, the New York State official was notified of the proposed issuance of the amendment. The State official had no comments. 5.0 ENVIRONMENTAL CONSIDERATION This amendment changes inspection or surveillance requirements or requirements with respect to installation or use of facility components located within the restricted area as defined in 10 CFR Part 20. The NRC staff determined that the amendment involves no significant change in the types or significant increase in the amounts of any effluents that may be released offsite, and that there is no significant increase in individual or cumulative occupational radiation exposure. By FR notice dated March 17, 2015 (80 FR 13906), the NRC issued a proposed finding that the amendment involves no significant hazards consideration, and there has been no public comment on these findings. Accordingly, the amendment meets the eligibility criteria for categorical exclusion set forth in 10 CFR 51.22(c)(9). Pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the issuance of the amendment.

-17 -6.0 CONCLUSION The staff has concluded, based on the considerations discussed above, that: (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner, (2) there is reasonable assurance that such activities will be conducted in compliance with the Commission's regulations, and (3) the issuance of the amendment will not be inimical to the common defense and security or to the health and safety of the public. Principal Contributors: Jonathan Evans, NRR/DRA Alice Erickson, NRR/DRA Mihaela Biro, NRR/DRA Date:November 30, 2015 A copy of the related Safety Evaluation is enclosed. A Notice of Issuance will be included in the Commission's next regular biweekly Federal Register notice. Docket No. 50-410

Enclosures:

1. Amendment No. 152 to NPF-69 2. Safety Evaluation cc w/encls: Distribution via Listserv DISTRIBUTION: PUBLIC LPLl-1 R/F RidsNrrDorlLPL 1-1 RidsNrrLAKGoldstein RidsNrrPMNineMilePoint J. Evans, NRR M. Biro, NRR

Sincerely,IRA! Brenda L. Mozafari, Sr. Project Manager Plant Licensing Branch 1-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation RidsNrrDraApla RidsNrrDssStsb RidsRgn1 MailCenter RidsACRS_MailCTR TDimitriadis, Region 1 P. Snyder, NRR A Erickson, NRR ADAMS A ccess1on N ML 15317A307 o.: *SE t "tt db ransm1 e ,y memo ML 15251A325 OFFICE NRR/DORL/LPLl-1 /PM NRR/DORL/LPLl-1 /LA NRR/DRA/APLA/BC NRR/DSS/STSB/BC NAME BMozafari KGoldstein SRosenberg* RElliott DATE 11/19/2015 11/17/2015 10/30/2015 11/19/2015 OFFICE OGC /NLO NRR/DORL/LPLl-1 /BC NRR/DORL/LPLl-1 /PM NAME Jlindell TTate BMozafari DATE 11/30/2015 11/30/2015 11/30/2015 OFFICIAL RECORD COPY

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