Text

Issuance of Amendment Nos. 271 and 253 Revising Technical Specifications to Adopt TSTF-542, Revision 2 (CAC Nos. MG0269 and MG0270; EPID L-2017-LLA-0306)
	ML18222A203
Person / Time
Site:	Susquehanna
Issue date:	09/26/2018
From:	Tanya Hood; Plant Licensing Branch 1
To:	Cimorelli K; Susquehanna
	Hood T, NRR/DORL/LPL1-2, 301-415-1387
References
	CAC MG0269, CAC MG0270, EPID L-2017-LLA-0306
	Download: ML18222A203 (151)
	v • d • e

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, O.C. 20555-0001 September 26, 2018 Mr. Kevin Cimorelli Site Vice President Susquehanna Nuclear, LLC 769 Salem Boulevard NUCSB3 Berwick, PA 18603-0467

SUBJECT:

SUSQUEHANNA STEAM ELECTRIC STATION, UNITS 1 AND 2- ISSUANCE OF AMENDMENT NOS. 271 AND 253 REVISING TECHNICAL SPECIFICATIONS TO ADOPT TSTF-542, REVISION 2 (CAC NOS. MG0269 AND MG0270; EPID L-2017-LLA-0306)

Dear Mr. Cimorelli:

The U.S. Nuclear Regulatory Commission (NRC or the Commission) has issued the enclosed Amendment No. 271 to Renewed Facility Operating License No. NPF-14 and Amendment No. 253 to Renewed Facility Operating License No. NPF-22 for the Susquehanna Steam Electric Station, Units 1 and 2, respectively. These amendments consist of changes to the technical specifications in response to your application dated September 20, 2017, as supplemented by letters dated February 16, 2018, and May 15, 2018.

The amendments replace existing technical specification requirements related to "operations with a potential for draining the reactor vessel" with new requirements on reactor pressure vessel water inventory control to protect Safety Limit 2.1.1.3. Safety Limit 2.1.1.3 requires reactor pressure vessel water level to be greater than the top of active irradiated fuel. The changes are based on Technical Specifications Task Force (TSTF} Traveler TSTF-542, Revision 2, "Reactor Pressure Vessel Water Inventory Control."

The licensee has proposed several variations from the technical specification changes described in applicable parts of TSTF-542, or the NRG-approved TSTF-542 safety evaluation.

These are described in the enclosed safety evaluation in Section 2.2.5 and evaluated in Section 3.5 of the safety evaluation.

K. Cimorelli A copy of our related safety evaluation is also enclosed. Notice of Issuance will be included in the Commission's next Biweekly Federal Register Notice.

Sincerely,

- ~\[~ft c.~

Tany~ E. ~ ' Project Manager Plant Licensing Branch I Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket Nos. 50-387 and 50-388

Enclosures:

1. Amendment No. 271 to License No. NPF-14

2. Amendment No. 253 to License No. NPF-22

3. Safety Evaluation cc: Listserv

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 SUSQUEHANNA NUCLEAR, LLC ALLEGHENY ELECTRIC COOPERATIVE, INC.

DOCKET NO. 50-387 SUSQUEHANNA STEAM ELECTRIC STATION, UNIT 1 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 271 Renewed License No. NPF-14

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

A. The application for the amendment filed by Susquehanna Nuclear, LLC, dated September 20, 2017, as supplemented by letters dated February 16, 2018, and May 15, 2018, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's regulations set forth in 10 CFR Chapter I; B. The facility will operate in conformity with the application, the provisions of the Act, and the 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 set forth in 10 CFR Chapter I; D. The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E. The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.

Enclosure 1

2. Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Renewed Facility Operating License No. NPF-14 is hereby amended to read as follows:

(2) Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No. 271 and the Environmental Protection Plan contained in Appendix B, are hereby incorporated in the license. Susquehanna Nuclear, LLC shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

3. This license amendment is effective as of its date of issuance and shall be implemented on both units no later than initial entry into Mode 4 for Unit 2 during the Spring 2019 Unit 2 refueling outage.

FOR THE NUCLEAR REGULATORY COMMISSION CJ~~

Ja~es G. Danna, Chief Plant Licensing Branch I Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the Renewed Facility Operating License and Technical Specifications Date of Issuance: September 2 6 , 2 O1 8

ATTACHMENT TO LICENSE AMENDMENT NO. 271 SUSQUEHANNA STEAM ELECTRIC STATION, UNIT 1 RENEWED FACILITY OPERATING LICENSE NO. NPF-14 DOCKET NO. 50-387 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 a marginal line indicating the area of change.

Remove Insert Page 3 Page 3 Replace the following pages of the 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 Insert Remove Insert TS!TOC-1 TOG-1 3.5-9a TS!TOC-2 TOC-2 3.5-10 3.5-10 1.1-3 1.1-3 3.5-11 3.5-11 1.1-3a 3.5-12 3.5-12 3.3-36 3.3-36 3.6-8 3.6-8 3.3-37 3.3-37 3.6-11 3.6-11 3.3-42 3.3-42 3.6-12 3.6-12 3.3-43 3.3-43 3.6-14 3.6-14 3.3-44 3.3-44 3.6-15 3.6-15 3.3-45 3.3-45 3.6-16 3.6-16 3.3-46 3.3-46 3.6-35 3.6-35 3.3-47 3.3-47 3.6-36 3.6-36 3.3-47a 3.6-38 3.6-38 3.3-47b 3.6-40 3.6-40 3.3-47c 3.6-42 3.6-42 3.3-48 3.3-48 3.6-43 3.6-43 3.3-49 3.3-49 3.6-44 3.6-44 3.3-50 3.3-50 3.7-6 3.7-6 3.3-51 3.3-51 3.7-7 3.7-7 3.3-54 3.3-54 3.7-8 3.7-8 3.3-62 3.3-62 3.7-10 3.7-10 3.3-66 3.3-66 3.7-11 3.7-11 3.3-71 3.3-71 3.7-12 3.7-12 3.5-1 3.5-1 3.8-18 3.8-18 3.5-8 3.5-8 3.8-30 3.8-30 3.5-8a 3.8-42 3.8-42 3.5-9 3.5-9

(3) Susquehanna Nuclear, LLC, pursuant to the Act and 10 CFR Parts 30, 40, and 70, to receive, possess, and use at any time any byproduct, source and special nuclear material as sealed neutron sources for reactor startup, sealed neutron sources for reactor instrumentation and radiation monitoring equipment calibration, and as fission detectors in amounts as required; (4) Susquehanna Nuclear, LLC, pursuant to the Act and 10 CFR Parts 30, 40, and 70 to receive, possess, and use in amounts as required any byproduct, source or special nuclear material without restriction to chemical or physical form, for sample analysis or instrument calibration or associated with radioactive apparatus or components; and (5) Susquehanna Nuclear, LLC, pursuant to the Act and 10 CFR Parts 30, 40, and 70 to possess, but not separate, such byproduct and special nuclear materials as may be produced by the operation of the facility.

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

(1) Maximum Power Level Susquehanna Nuclear, LLC is authorized to operate the facility at reactor core power levels not in excess of 3952 megawatts thermal in accordance with the conditions specified herein. The preoperational tests, startup tests and other items identified in License Conditions 2.C.(36), 2.C.(37), 2.C.(38), and 2.C.(39) to this license shall be completed as specified.

(2) Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No. 271, and the Environmental Protection Plan contained in Appendix B are hereby incorporated in the license. Susquehanna Nuclear, LLC shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

For Surveillance Requirements {SRs) that are new in Amendment 178 to Facility Operating License No. NPF-14, the first performance is due at the end of the first surveillance interval that begins at implementation of Amendment 178. For SRs that existed prior to Amendment 178, including SRs with modified acceptance criteria and SRs whose frequency of performance is being extended, the first performance is due at the end of the first surveillance interval that begins on the date the Surveillance was last performed prior to implementation of Amendment 178.

Renewed Operating License No. NPF-14 Amendment No. 271

TABLE OF CONTENTS (TECHNICAL SPECIFICATIONS) 1.0 USE AND APPLICATION ............................................................................... 1.1-1 1.1 Definitions .............................................................................................. 1.1-1 1.2 Logical Connectors ................................................................................ 1.2-1 1.3 Completion Times .................................................................................. 1.3-1 1.4 Frequency .............................................................................................. 1.4-1 2.0 SAFETY LIMITS (SLs) ............................................................................. TS/2.0-1 2.1 SLs .................................................................................................. TS/2.0-1 2.2 SL Violations .................................................................................... TS/2.0-1 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY ........ TS/3.0-1 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY ...................... TS/3.0-4 3.1 REACTIVITY CONTROL SYSTEMS ........................................................ 3.1-1 3.1.1 Shutdown Margin (SOM) .................................................................... 3.1-1 3.1.2 Reactivity Anomalies .......................................................................... 3.1-5 3.1.3 Control Rod OPERABILITY ................................................................ 3.1-7 3.1.4 Control Rod Scram Times .................................................................. 3.1-12 3.1.5 Control Rod Scram Accumulators ...................................................... 3.1-15 3.1.6 Rod Pattern Control ............................................................................ 3.1-18 3.1.7 Standby Liquid Control (SLC) System ................................................ 3.1-20 3.1.8 Scram Discharge Volume (SDV) Vent and Drain Valves ............. TS/3.1-25 3.2 POWER DISTRIBUTION LIMITS ............................................................. 3.2-1 3.2.1 Average Planar Linear Heat Generation Rate (APLHGR) .................. 3.2-1 3.2.2 Minimum Critical Power Ratio (MCPR) ............................................... 3.2-3 3.2.3 Linear Heat Generation Rate (LHGR) ................................................ 3.2-5 3.3 INSTRUMENTATION ............................................................................... 3.3-1 3.3.1.1 Reactor Protection System (RPS) Instrumentation ...................... TS/3.3-1 3.3.1.2 Source Range Monitor (SRM) Instrumentation ................................... 3.3-10 3.3.2.1 Control Rod Block Instrumentation ..................................................... 3.3-16 3.3.2.2 Feedwater - Main Turbine High Water Level Trip Instrumentation ............................................................................. 3.3-21 3.3.3.1 Post Accident Monitoring (PAM) Instrumentation ......................... TS /3.3-23 3.3.3.2 Remote Shutdown System ........................................................... TS /3.3-26 3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT)

Instrumentation ............................................................................... 3.3-29 3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) Instrumentation ....................................... 3.3-33 3.3.5.1 Emergency Core Cooling System (ECCS) Instrumentation ................. 3.3-36 3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation ............................................................................... 3.3-47a 3.3.5.3 Reactor Core Isolation Cooling (RCIC) System Instrumentation ............................................................................... 3.3-48 3.3.6.1 Primary Containment Isolation Instrumentation .................................... 3.3-52 3.3.6.2 Secondary Containment Isolation Instrumentation ............................... 3.3-63 (continued)

SUSQUEHANNA - UNIT 1 TOC-1 Amendment 473, 484, 245, 24-7, 222,

~.~.~.~.271

TABLE OF CONTENTS (TECHNICAL SPECIFICATIONS) 3.3 INSTRUMENTATION (continued) 3.3.7.1 Control Room Emergency Outside Air Supply (CREOAS)

System Instrumentation .................................................................. 3.3-67 3.3.8.1 Loss of Power (LOP) lnstrumentation ................................................... 3.3-72 3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring ............................................................................................. 3.3-75 3.4 REACTOR COOLANT SYSTEM (RCS) .............................................. TS/3.4-1 3.4.1 Recirculation Loops Operating ....................................................... TS/3.4-1 3.4.2 Jet Pumps ............................................................................................. 3.4-6 3.4.3 Safety/Relief Valves (S/RVs) ................................................................ 3.4-8 3.4.4 RCS Operational LEAKAGE ................................................................. 3.4-10 3.4.5 RCS Pressure Isolation Valve (PIV) Leakage ...................................... 3.4-12 3.4.6 RCS Leakage Detection Instrumentation ....................................... TS/3.4-14 3.4.7 RCS Specific Activity ...................................................................... TS/3.4-17 3.4.8 Residual Heat Removal (RHR) Shutdown Cooling System - Hot Shutdown ........................................................... TS/3.4-19 3.4.9 Residual Heat Removal (RHR) Shutdown Cooling System - Cold Shutdown ............................................................... 3.4-22 3.4.10 RCS Pressure and Temperature (PIT) Limits ....................................... 3.4-24 3.4.11 Reactor Steam Dome Pressure ............................................................ 3.4-31 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), REACTOR PRESSURE VESSEL (RPV) WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM ..................... 3.5-1 3.5.1 ECCS - Operating ................................................................................ 3.5-1 3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control .................... 3.5-8 3.5.3 RCIC System ........................................................................................ 3.5-12 3.6 CONTAINMENT SYSTEMS ....................................................................... 3.6-1 3.6.1.1 Primary Containment ............................................................................ 3.6-1 3.6.1.2 Primary Containment Air Lock .............................................................. 3.6-4 3.6.1.3 Primary Containment Isolation Valves (PCIVs) .................................... 3.6-8 3.6.1.4 Containment Pressure .......................................................................... 3.6-17 3.6.1.5 Drywell Air Temperature ....................................................................... 3.6-18 3.6.1.6 Suppression-Chamber-to-Drywell Vacuum Breakers ........................... 3.6-19 3.6.2.1 Suppression Pool Average Temperature .............................................. 3.6-22 3.6.2.2 Suppression Pool Water Level ............................................................. 3.6-25 3.6.2.3 Residual Heat Removal (RHR) Suppression Pool Cooling ............ TS/3.6-26 3.6.2.4 Residual Heat Removal (RHR) Suppression Pool Spray ..................... 3.6-28 3.6.3.1 Not Used ........................................................................................ TS/3.6-30 3.6.3.2 Drywell Air Flow System ................................................................. TS/3.6-32 3.6.3.3 Primary Containment Oxygen Concentration ....................................... 3.6-34 3.6.4.1 Secondary Containment ....................................................................... 3.6-35 3.6.4.2 Secondary Containment Isolation Valves (SCIVs) ............................... 3.6-38 3.6.4.3 Standby Gas Treatment (SGT) System ................................................ 3.6-42 (continued)

SUSQUEHANNA - UNIT 1 TOC-2 Amendment 4+3, 424, 24+, 234, 2-70, 271

Definitions 1.1 1.1 Definitions DOSE EQUIVALENT 1-131 Concentration and Dose Conversion Factors for (continued) Inhalation, Submersion, and Ingestion," EPA, 1988, as described in Regulatory Guide 1.183. The factors in the column headed "effective" yield doses corresponding to the CEDE. The conversion factors that are used for the calculation of EDE (or DDE) from external exposure (submersion) shall be those listed in Table 111.1 of Federal Guidance Report 12, "External Exposure to Radionuclides in Air, Water, and Soil," EPA, 1993, as described in Regulatory Guide 1.183. The factors in the column headed "effective" yield doses corresponding to the EDE.

DRAIN TIME The DRAIN TIME is the time it would take for the water inventory in and above the Reactor Pressure Vessel (RPV) to drain to the top of the active fuel (TAF) seated in the RPV assuming:

a) The water inventory above the TAF is divided by the limiting drain rate; b) The limiting drain rate is the larger of the drain rate through a single penetration flow path with the highest flow rate, or the sum of the drain rates through multiple penetration flow paths susceptible to a common mode failure (e.g., seismic event, loss of normal power, single human error), for all penetration flow paths below the TAF except:

1. Penetration flow paths connected to an intact closed system, or isolated by manual or automatic valves that are locked, sealed, or otherwise secured in the closed position, blank flanges, or other devices that prevent flow of reactor coolant through the penetration flow paths;

2. Penetration flow paths capable of being isolated by valves that will close automatically without offsite power prior to the RPV water level being equal to the T AF when actuated by RPV water level isolation instrumentation; or

3. Penetration flow paths with isolation devices that can be closed prior to the RPV water level being equal to the TAF by a dedicated operator trained in the task, who in continuous communication with the control room, is stationed at the controls, and is capable of closing the penetration flow path isolation device without offsite power.

SUSQUEHANNA - UNIT 1 1.1-3 Amendment 1+3, 2-39, 271

Definitions 1.1 1.1 Definitions (continued) c) The penetration flow paths required to be evaluated per paragraph b) are assumed to open instantaneously and are not subsequently isolated, and no water is assumed to be subsequently added to the RPV water inventory; d) No additional draining events occur; and e) Realistic cross-sectional areas and drain rates are used.

A bounding DRAIN TIME may be used in lieu of a calculated value.

EMERGENCY CORE COOLING The ECCS RESPONSE TIME shall be that time interval SYSTEM(ECCS)RESPONSE from when the monitored parameter exceeds its ECCS TIME initiation setpoint at the channel sensor until the ECCS equipment is capable of performing its safety function (i.e., the valves travel to their required positions, pump discharge pressures reach their required values, etc.).

Times shall include diesel generator starting and sequence loading delays, where applicable. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

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

ISOLATION SYSTEM The ISOLATION SYSTEM RESPONSE TIME shall be that RESPONSE TIME time interval from when the monitored parameter exceeds its isolation initiation setpoint at the channel sensor until the isolation valves travel to their required positions.

Times shall include diesel generator starting and sequence loading delays, where applicable. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

SUSQUEHANNA - UNIT 1 1.1-3a Amendment .n8, 2ae, 271

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

APPLICABILITY: According to Table 3.3.5.1-1.

ACTIONS

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

Separate Condition entry is allowed for each channel.

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

B. As required by 8.1 ------NOTE------

Required Action A.1 Only applicable for Functions and referenced in 1.a, 1.b, 1.c, 2.a, 2.b, and 2.c Table 3.3.5.1-1. ---------------

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

SUSQUEHANNA - UNIT 1 3.3-36 Amendment 418, 271

ECCS Instrumentation 3.3.5.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) 8.2 ------NOTE----

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

Declare High Pressure Coolant 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery Injection (HPCI) System of loss of HPCI inoperable. initiation capability AND 8.3 Place channel in trip. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months C. As required by C.1 ----NOTE----

Required Action A.1 Only applicable for Functions and referenced in 1.d, 2.d, and 2.e Table 3.3.5.1-1. --------------

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

(continued)

SUSQUEHANNA - UNIT 1 3.3-37 Amendment 4-78, 271

ECCS Instrumentation 3.3.5.1 Table3.3.5.1-1 (page 1 of6)

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

1. Core Spray System

a. Reactor 1,2,3 4(*) B SR 3.3.5.1.1 <! -136 inches Vessel Water SR 3.3.5.1.2 Level-Low SR 3.3.5.1.4 Low Low, Level 1 SR 3.3.5.1.5

b. Drywell Pressure- 1,2,3 4(*) B SR 3.3.5.1.2 S 1.88 psig High SR 3.3.5.1.3 SR 3.3.5.1.5 C. Reactor 1,2,3 4 B SR 3.3.5.1.2 <! 407 psig (lower)

Steam Dome SR 3.3.5.1.3 s 433 psig (upper)

Pressure-Low SR 3.3.5.1.5 (initiation)

d. Reactor 1,2,3 4 C SR 3.3.5.1.2 <! 407 psig (lower)

Steam Dome SR 3.3.5.1.3 s 433 psig (upper)

Pressure-Low SR 3.3.5.1.5 (injection permissive)

e. Manual Initiation 1,2,3 2 C SR 3.3.5.1.5 NA 1 per Subsystem

2. Low Pressure Coolant Injection (LPCI)

System

a. Reactor Vessel 1,2,3 4(b) B SR 3.3.5.1.1 <! -136 inches Water Level-Low SR 3.3.5.1.2 Low Low, Level 1 SR 3.3.5.1.4 SR 3.3.5.1.5 continued (a) Also required to initiate the associated diesel generator (DG), initiate Drywell Cooling Equipment Trip, and Emergency Service Water (ESW) Pump timer reset.

(b) Also required to initiate the associated DGs, ESW Pump timer reset and Turbine Building and Reactor Building Chillers trip.

SUSQUEHANNA - UNIT 1 3.3-42 Amendment 41-3, 484, 271

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 2 of6)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REFERENCED OTHER REQUIRED FROM SPECIFIED CHANNELS PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTIONA1 REQUIREMENTS VALUE

2. LPCI System (continued)

b. Drywell Pressure- 1,2,3 B SR 3.3.5.1.2 s 1.88 psig High SR 3.3.5.1.3 SR 3.3.5.1.5

c. Reactor 1,2,3 4 B SR 3.3.5.1.2 2: 407 psig (lower)

Steam Dome SR 3.3.5.1.3 s 433 psig (upper)

Pressure-Low SR 3.3.5.1.5 (initiation)

d. Reactor Steam 1,2,3 4 C SR 3.3.5.1.2 2: 407 psig (lower)

Dome Pressure- SR 3.3.5.1.3 s 433 psig (upper)

Low (injection SR 3.3.5.1.5 permissive)

e. Reactor Steam 4 C SR 3.3.5.1.2 2: 216 psig Dome Pressure- SR 3.3.5.1.3 Low (Recirculation SR 3.3.5.1.5 Discharge Valve Permissive)

(continued)

(b) Also required to initiate the associated DGs, ESW pump timer reset and Turbine Building and Reactor Building Chiller trip.

(c) \Nith either associated recirculation pump discharge or bypass valves open.

SUSQUEHANNA - UNIT 1 3.3-43 Amendment-1-78, 484-, 271

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 3 of6)

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

2. LPCI System (continued) 1,2,3 2 C SR 3.3.5.1.5 NA

f. Manual Initiation 1 per subsystem

3. High Pressure Coolant Injection (HPCI)

System

a. Reactor Vessel 1, 4 B SR 3.3.5.1.1 ~ -45 inches Water Level-Low, id), 3(d) SR 3.3.5.1.2 Level2 SR 3.3.5.1.4 SR 3.3.5.1.5

b. Drywell Pressure- 1, 4 B SR 3.3.5.1.2 ~ 1.88 psig High id),3(d) SR 3.3.5.1.3 SR 3.3.5.1.5

c. Reactor Vessel 1, 2 C SR 3.3.5.1.2 ~ 55.5 inches Water Level- id), 3(d) SR 3.3.5.1.3 High, Level 8 SR 3.3.5.1.5

d. Condensate

1, 2 D SR 3.3.5.1.2 ~ 40.5 inches above Storage Tank id), 3(d) SR 3.3.5.1.3 tank bottom Level-Low SR 3.3.5.1.5 (continued)

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

SUSQUEHANNA - UNIT 1 3.3-44 Amendment 4-+8, 204, 2M, 271

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 4 of 6)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REFERENCED OTHER REQUIRED FROM SPECIFIED CHANNELS PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTIONA1 REQUIREMENTS VALUE

3. HPCI System (continued)

e. Manual Initiation 1, C SR 3.3.5.1.5 NA 2'dl,3(d)

4. Automatic Depressurization System (ADS) Trip System A

a. Reactor Vessel 1, 2 E SR 3.3.5.1.1 ~ -136 inches Water Level-Low 2<dl,3(d) SR 3.3.5.1.2 Low Low, Level 1 SR 3.3.5.1.4 SR 3.3.5.1.5

b. Drywell Pressure- 1, 2 E SR 3.3.5.1.2 :s 1.88 psig High id), 3<d) SR 3.3.5.1.3 SR 3.3.5.1.5 C. Automatic 1, F SR 3.3.5.1.2 :s 114 seconds Depressurization 2<d), 3(d) SR 3.3.5.1.3 System Initiation SR 3.3.5.1.5 Timer

d. Reactor Vessel 1, E SR 3.3.5.1.1 ~ 11.5 inches Water Level-Low, 2<d), 3(d) SR 3.3.5.1.2 Level3 SR 3.3.5.1.4 (Confirmatory) SR 3.3.5.1.5

e. Core Spray Pump 1, 2 F SR 3.3.5.1.2 ~ 125 psig Discharge id), 3(d) SR 3.3.5.1.3 and Pressure-High SR 3.3.5.1.5 :s 165 psig continued (d) ~h reactor steam dome pressure> 150 psig.

SUSQUEHANNA - UNIT 1 3.3-45 Amendment 478, ~ . ~ . 271

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 5 of 6)

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

4. ADS Trip System A (continued)

f. Low Pressure 1, 4 F SR 3.3.5.1.2 ~ 115 psig Coolant 2<dJ, 3(d) SR 3.3.5.1.3 and Injection Pump SR 3.3.5.1.5 s 135 psig Discharge Pressure-High

g. Automatic 1, 2 F SR 3.3.5.1.2 5450sec Depressurization id)' 3(d) SR 3.3.5.1.3 System Drywell SR 3.3.5.1.5 Pressure Bypass Actuation Timer

h. Manual Initiation 1, 2 F SR 3.3.5.1.5 NA id), 3(d)

5. ADS Trip System B

a. Reactor Vessel 1, 2 E SR 3.3.5.1.1 ~ -136 inches Water Level- id), 3(d) SR 3.3.5.1.2 LowLow Low, SR 3.3.5.1.4 Level 1 SR 3.3.5.1.5

b. Drywell 1, 2 E SR 3.3.5.1.2 :51.88 psig Pressure-High 2<dJ, 3(d) SR 3.3.5.1.3 SR 3.3.5.1.5 C. Automatic 1, F SR 3.3.5.1.2 5114sec Depressurization 2<dJ, 3(d) SR 3.3.5.1.3 System Initiation SR 3.3.5.1.5 Timer

d. Reactor Vessel 1, E SR 3.3.5.1.1 ~ 11.5 inches Water Level- id), 3(d) SR 3.3.5.1.2 Low, Level 3 SR 3.3.5.1.4 (Confirmatory) SR 3.3.5.1.5

e. Core Spray Pump 1, 2 F SR 3.3.5.1.2 ~ 125 psig Discharge id), 3(d) SR 3.3.5.1.3 and Pressure-High SR 3.3.5.1.5 ::; 165 psig continued (d) \/1/ith reactor steam dome pressure > 150 psig.

SUSQUEHANNA - UNIT 1 3.3-46 Amendment 478, G4, -22G, 271

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 6 of6)

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

5. ADS Trip System B (continued)

f. Low Pressure 4 F SR 3.3.5.1.2 ~ 115 psig Coolant Injection SR 3.3.5.1.3 and Pump Discharge SR 3.3.5.1.5 s 135 psig Pressure-High

g. Automatic 2 F SR 3.3.5.1.2 S450sec Depressurization SR 3.3.5.1.3 System Drywell SR 3.3.5.1.5 Pressure Bypass Actuation Timer

h. Manual Initiation 2 F SR 3.3.5.1.5 NA (d) With reactor steam dome pressure > 150 psig.

SUSQUEHANNA - UNIT 1 3.3-47 Amendment 418, ~ . 271

Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation 3.3.5.2 3.3 INSTRUMENTATION 3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation LCO 3.3.5.2 The RPV Water Inventory Control instrumentation for each Function in Table 3.3.5.2-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.5.2-1.

ACTIONS

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable. referenced in Table 3.3.5.2-1 for the channel.

B. As required by Required B.1 Declare associated Immediately Action A.1 and penetration flow path(s) referenced in incapable of automatic Table 3.3.5.2-1. isolation.

AND B.2 Calculate DRAIN TIME. Immediately C. As required by Required C. 1 Place channel in trip. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Action A.1 and referenced in Table 3.3.5.2-1.

D. As required by Required D*.1 Restore channel to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Action A.1 and OPERABLE status.

referenced in Table 3.3.5.2-1.

SUSQUEHANNA UNIT 1 3.3-47a Amendment 271

Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation 3.3.5.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E.1 Declare associated low Immediately associated Completion pressure ECCS Time of Condition C or D injection/spray subsystem not met. inoperable.

SURVEILLANCE REQUIREMENTS

* -----------------------------NO TE-------------------------------------------------------

Refer to Table 3.3.5.2-1 to determine which SRs apply for each ECCS Function.

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 ----------------NOTE----------------- In accordance A test of all required contacts does not have to be with the performed. Surveillance Frequency Control Program Perform CHANNEL FUNCTIONAL TEST.

SR 3.3.5.2.3 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SUSQUEHANNA UNIT 1 3.3-47b Amendment 271

Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation 3.3.5.2 Table 3.3.5.2-1 (Page 1 of 1)

RPV Water Inventory Control Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED OR OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

1. Core Spray System

a. Reactor Steam Dome 4,5 4 (a) C SR 3.3.5.2.2 :s;433 psig Pressure - Low SR 3.3.5.2.3 (upper)

(Injection Permissive)

b. Manual Initiation 4, 5 1 per D SR 3.3.5.2.3 NA subsystem (a)

2. Low Pressure Coolant Injection (LPCI)

System

a. Reactor Steam Dome Pressure - 4, 5 4 (a) C SR 3.3.5.2.2 :s; 433 psig Low (Injection SR 3.3.5.2.3 (upper)

Permissive)

b. Manual Initiation 4,5 1 per D SR 3.3.5.2.3 NA subsystem (a)

3. RHR System Isolation

a. Reactor Vessel (b) 2 in one trip B SR 3.3.5.2.1 2 11.5 inches Water Level - Low, system SR 3.3.5.2.2 Level3 SR 3.3.5.2.3

4. Reactor Water Cleanup (RWCU) System Isolation

a. Reactor Vessel (b) 2 in one trip B SR 3.3.5.2.1 2 -45 inches Water Level - Low system SR 3.3.5.2.2 Low, Level 2 SR 3.3.5.2.3 (a) Associated with an ECCS subsystem required to be OPERABLE by LCO 3.5.2, "Reactor Pressure Vessel (RPV) Water Inventory Control."

(b) When automatic isolation of the associated penetration flow path(s) is credited in calculating DRAIN TIME.

SUSQUEHANNA UNIT 1 3.3-47c Amendment 271

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

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

ACTIONS

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

Separate Condition entry is allowed for each channel.

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

B. As required by B.1 Declare RCIC System 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery Required Action A.1 inoperable. of loss of RCIC and referenced in initiation capability Table 3.3.5.3-1.

AND B.2 Place channel in trip. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months C. As required by C.1 Restore channel to OPERABLE 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Required Action A.1 status.

and referenced in Table 3.3.5.3-1.

(continued)

SUSQUEHANNA - UNIT 1 3.3-48 Amendment 4-73, 271

RCIC System Instrumentation 3.3.5.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. As required by D.1 NOTE Required Action A.1 Only applicable if RCIC pump and referenced in suction is not aligned to the Table 3.3.5.3-1. suppression pool.

Declare RCIC System 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery inoperable. of loss of RCIC initiation capability AND D.2.1 Place channel in trip. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OR D.2.2 Align RCIC pump suction to the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months suppression pool.

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

Completion Time of Condition 8, C, or D not met.

SUSQUEHANNA - UNIT 1 3.3-49 Amendment 4-78, 271

RCIC System Instrumentation 3.3.5.3 SURVEILLANCE REQUIREMENTS

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

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

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

SURVEILLANCE FREQUENCY SR 3.3.5.3.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.5.3.2 A test of all required contacts does not have to be performed.

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.5.3.3 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.5.3.4 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.5.3.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SUSQUEHANNA - UNIT 1 3.3-50 Amendment 4-+S, ~ . 271

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

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

1. Reactor Vessel 4 B SR 3.3.5.3.1 ~-45inches Water Level-Low SR 3.3.5.3.2 Low, Level2 SR 3.3.5.3.4 SR 3.3.5.3.5

2. Reactor Vessel 2 C SR 3.3.5.3.1 s 55.5 inches Water Level-High, SR 3.3.5.3.2 Levels SR 3.3.5.3.3 SR 3.3.5.3.5

3. Condensate 2 D SR 3.3.5.3.2 ~ 36.0 inches above Storage Tank SR 3.3.5.3.3 the tank bottom Level-Low SR 3.3.5.3.5

4. Manual Initiation C SR 3.3.5.3.5 NA SUSQUEHANNA - UNIT 1 3.3-51 Amendment 4-78, 271

Primary Containment Isolation Instrumentation 3.3.6.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME H. As required by Required H.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Action C.1 and referenced in Table 3.3.6.1-1. AND H.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR Required Action and associated Completion Time for Condition F or G not met.

I. As required by Required 1.1 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Action C.1 and referenced standby liquid control in Table 3.3.6.1-1 subsystem (SLC) inoperable.

OR 1.2 Isolate the Reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Water Cleanup System.

J. As required by Required J.1 Initiate action to restore Immediately Action C.1 and referenced channel to OPERABLE in Table 3.3.6.1-1. status.

SUSQUEHANNA - UNIT 1 3.3-54 Amendment 4+3, 271

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

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

6. Shutdown Cooling System Isolation

a. Reactor Steam Dome 1,2,3 F SR 3.3.6.1.2 ~ 108 psig Pressure - High SR 3.3.6.1.3 SR 3.3.6.1.5

b. Reactor Vessel Water 3 2 J SR 3.3.6.1.1 ~ 11.5 inches Level - Low, Level 3 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 C. Manual Initiation 3 G SR 3.3.6.1.5 NA

7. Traversing lncore Probe Isolation

a. Reactor Vessel Water 1,2,3 2 G SR 3.3.6.1.1

~ 11.5 inches Level - Low, Level 3 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5

b. Drywell Pressure - 1,2,3 2 G SR 3.3.6.1.2 ~ 1.88 psig High SR 3.3.6.1.4 SR 3.3.6.1.5 SUSQUEHANNA - UNIT 1 3.3-62 Amendment 4+3, ~ . ~ . 271

Secondary Containment Isolation Instrumentation 3.3.6.2 Table 3.3.6.2-1 (page 1 of 1)

Secondary Containment Isolation Instrumentation APPLICABLE MODES OR OTHER REQUIRED SPECIFIED CHANNELS PER TRIP SURVEILLANCE ALLOWABLE VALUE FUNCTION CONDITIONS SYSTEM REQUIREMENTS

1. Reactor Vessel 1,2,3 2 SR 3.3.6.2.1 <!-45 inches Water Level- SR 3.3.6.2.2 Low Low, Level 2 SR 3.3.6.2.4 SR 3.3.6.2.5

2. Drywell 1,2,3 2 SR 3.3.6.2.2 s 1.88 psig Pressure-High SR 3.3.6.2.3 SR 3.3.6.2.5

3. Unit 1 Refuel (a) SR 3.3.6.2.1 s 25 mR/hr Floor High SR 3.3.6.2.2 Exhaust Duct SR 3.3.6.2.4 Radiation-High SR 3.3.6.2.5

4. Unit 2 Refuel (a) SR 3.3.6.2.1 s 25 mR/hr Floor High SR 3.3.6.2.2 Exhaust Duct SR 3.3.6.2.4 Radiation-High SR 3.3.6.2.5

5. Unit 1 Refuel Floor (a) SR 3.3.6.2.1 s28 mR/hr Wall Exhaust Duct SR 3.3.6.2.2 Radiation-High SR 3.3.6.2.4 SR 3.3.6.2.5

6. Unit 2 Refuel Floor (a) SR 3.3.6.2.1 s 28 mR/hr Wall Exhaust Duct SR 3.3.6.2.2 Radiation-High SR 3.3.6.2.4 SR 3.3.6.2.5

7. Railroad Access (b) SR 3.3.6.2.1 s 7 mR/hr Shaft Exhaust Duct SR 3.3.6.2.2 Radiation-High SR 3.3.6.2.4 SR 3.3.6.2.5

8. Manual Initiation 1,2,3, SR 3.3.6.2.5 NA (a)

(a) During CORE ALTERATIONS and during movement of irradiated fuel assemblies in secondary containment.

(b) During movement of irradiated fuel assemblies within the Railroad Access Shaft, and above the Railroad Access Shaft with the Railroad Access Shaft Equipment Hatch open.

SUSQUEHANNA - UNIT 1 3.3-66 Amendment-+78, 271

CREOAS System Instrumentation 3.3.7.1 Table3.3.7.1-1 (page 1 of1)

Control Room Emergency Outside Air Supply System Instrumentation APPLICABLE MODES OR CONDITIONS OTHER REQUIRED REFERENCED SPECIFIED CHANNELS PER FROM REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS TRIP SYSTEM ACTIONA.1 REQUIREMENTS VALUE

1. Reactor Vessel 1,2,3 2 B SR 3.3.7.1.1 ~ -45 inches Water Level-Low SR 3.3.7.1.2 Low, Level2 SR 3.3.7.1.4 SR 3.3.7.1.5

2. Drywell Pressure- 1,2,3 2 B SR 3.3.7.1.2 s 1.88 psig High SR 3.3.7.1.3 SR 3.3.7.1.5

3. Unit 1 Refuel Floor (a) B SR 3.3.7.1.1 s 25 mR/hr Radiation-High SR 3.3.7.1.2 SR 3.3.7.1.4 SR 3.3.7.1.5

4. Unit 2 Refuel (a) B SR 3.3.7.1.1 s 25 mR/hr Floor High SR 3.3.7.1.2 Exhaust SR 3.3.7.1.4 Duct Radiation- SR 3.3.7.1.5 High

5. Unit 1 Refuel Floor (a) B SR 3.3.7.1.1 s 28 mR/hr Wall Exhaust Duct SR 3.3.7.1.2 Radiation -High SR 3.3.7.1.4 SR 3.3.7.1.5

6. Unit 2 Refuel Floor (a) B SR 3.3.7.1.1 s28 mR/hr Wall Exhaust Duct SR 3.3.7.1.2 Radiation -High SR 3.3.7.1.4 SR 3.3.7.1.5

7. Railroad Access (b) B SR 3.3.7.1.1 s 7 mR/hr Shaft Exhaust SR 3.3.7.1.2 Duct Radiation- SR 3.3.7.1.4 High SR 3.3.7.1.5

8. Main Control 1,2,3, C SR 3.3.7.1.1 s 5 mR/hr Room Outside Air (a) SR 3.3.7.1.2 Intake Radiation - SR 3.3.7.1.4 High SR 3.3.7.1.5

9. Manual Initiation 1,2,3 B SR 3.3.7.1.5 nla (a)

(a) During CORE ALTERATIONS and during movement of irradiated fuel assemblies in the secondary containment.

(b) During movement of irradiated fuel assemblies within the Railroad Access Shaft, and above the Railroad Access Shaft with the Railroad Access Shaft Equipment Hatch open.

SUSQUEHANNA - UNIT 1 3.3-71 Amendment 418, 271

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

APPLICABILITY: MODE 1, MODES 2 and 3, except high pressure coolant injection (HPCI) and ADS valves are not required to be OPERABLE with reactor steam dome pressure :s; 150 psig.

ACTIONS

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

LCO 3.0.4.b is not applicable to HPCI.

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

than Condition B.

B. One LPCI pump in one or B.1 Restore LPCI pump(s) to 7 days both LPCI subsystems OPERABLE status.

inoperable.

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

C.2 Be in MODE4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued)

SUSQUEHANNA - UNIT 1 3.5-1 Amendment++S, Q, 271

Reactor Pressure Vessel (RPV) Water Inventory Control 3.5.2 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), REACTOR PRESSURE VESSEL (RPV) WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control LCO 3.5.2 DRAIN TIME of RPV water inventory to the top of active fuel (TAF) shall be~ 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

One low pressure ECCS injection/spray subsystem shall be OPERABLE.

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

A 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.

APPLICABILITY: MODES 4 and 5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required ECCS A.1 Restore required ECCS 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months injection/spray subsystem injection/spray subsystem to inoperable. OPERABLE status.

B. Required Action and 8.1 Initiate action to establish a Immediately associated Completion Time method of water injection of Condition A not met. capable of operating without offsite electrical power.

( continued)

SUSQUEHANNA - UNIT 1 3.5-8 Amendment-t+S, 271

Reactor Pressure Vessel (RPV) Water Inventory Control 3.5.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. DRAIN TIME < 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months and C.1 Verify secondary containment 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months

.!: 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . boundary is capable of being established in less than the DRAIN TIME.

AND C.2 Verify each secondary 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months containment penetration flow path is capable of being isolated in less than the DRAIN TIME.

AND C.3 Verify one standby gas 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months treatment subsystem is capable

. of being placed in operation in less than the DRAIN TIME.

(continued)

SUSQUEHANNA - UNIT 1 3.5-Ba Amendment 271

Reactor Pressure Vessel (RPV) Water Inventory Control 3.5.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. DRAIN TIME < 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . 0.1 - - - - NOTE - - - - -

Required ECCS injection/spray subsystem or additional method of water injection shall be capable of operating without offsite electrical power.

Initiate action to establish an Immediately additional method of water injection with water sources capable of maintaining RPV water level > TAF for ~ 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

D.2 Initiate action to establish Immediately secondary containment boundary.

D.3 Initiate action to isolate each Immediately secondary containment penetration flow path or verify it can be manually isolated from the control room.

D.4 Initiate action to verify one Immediately standby gas treatment subsystem is capable of being placed in operation (continued)

SUSQUEHANNA - UNIT 1 3.5-9 Amendment 473, 271

Reactor Pressure Vessel (RPV) Water Inventory Control 3.5.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E.1 Initiate action to restore Immediately associated Completion Time DRAIN TIME to 2: 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

of Condition C or D not met.

OR DRAIN TIME < 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify DRAIN TIME 2: 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . In accordance with the Surveillance Frequency Control Program SR 3.5.2.2 Verify, for a required low pressure coolant injection In accordance with the (LPCI) subsystem, the suppression pool water Surveillance Frequency level is ~ 20 ft O inches. Control Program (continued)

SUSQUEHANNA - UNIT 1 3.5-9a Amendment 413, ~ . 271

Reactor Pressure Vessel (RPV) Water Inventory Control 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.3 Verify, for a required Core Spray (CS) subsystem, In accordance with the the: Surveillance Frequency Control Program

a. Suppression pool water level is

~ 20 ft O inches; or

b. Condensate storage tank water level is

~ 49% of capacity.

SR 3.5.2.4 Verify, for the required ECCS injection/spray In accordance with the subsystem, the piping is filled with water from the Surveillance Frequency pump discharge valve to the injection valve. Control Program SR 3.5.2.5 Verify for the required ECCS injection/spray In accordance with the subsystem, each manual, power operated, and Surveillance Frequency automatic valve in the flow path, that is not Control Program locked, sealed, or otherwise secured in position, is in the correct position.

(continued)

SUSQUEHANNA - UNIT 1 3.5-10 Amendment 4-73, 2ee, 271

Reactor Pressure Vessel (RPV) Water Inventory Control 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.6 Operate the required ECCS injection/spray In accordance with the subsystem through the recirculation line for ~ 10 Surveillance Frequency minutes. Control Program SR 3.5.2.7 Verify each valve credited for automatically In accordance with the isolating a penetration flow path actuates to the Surveillance Frequency isolation position on an actual or simulated Control Program isolation signal.

SR 3.5.2.8 ------------NOTE----------

Vessel injection/spray may be excluded.

Verify the required ECCS injection/spray In accordance with the subsystem actuates on a manual initiation signal. Surveillance Frequency Control Program SUSQUEHANNA - UNIT 1 3.5-11 Amendment-4-+S, ~ . 271

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

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

ACTIONS

NO TE-------------------------------------------------------

LCO 3.0.4.b is not applicable to RCIC.

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

AND A.2 Restore RCIC System to 14 days OPERABLE status B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met.

AND B.2 Reduce reactor steam dome 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months pressure to ~ 150 psig.

SUSQUEHANNA - UNIT 1 3.5-12 Amendment 4-73, ~ . 271

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

LCO 3.6.1.3 Each PCIV shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3 ACTIONS

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

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

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

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

4. Enter applicable Conditions and Required Actions of LCO 3.6.1.1, "Primary Containment,"

when PCIV leakage results in exceeding overall containment leakage rate acceptance criteria in MODES 1, 2, and 3.

COMPLETION CONDITION REQUIRED ACTION TIME A. ------------NOTE--------------- A.1 Isolate the affected 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months except for Only applicable to penetration flow path by main steam line penetration flow paths with use of at least one closed two PCIVs except for the and de-activated automatic AND H202 Analyzer valve, closed manual penetrations. valve, blind flange, or 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months for main

check valve with flow steam line through the valve secured.

One or more penetration flow paths with one PCIV inoperable except for purge valve leakage not within limit.

AND (continued)

SUSQUEHANNA - UNIT 1 3.6-8 Amendment~. 495, 271

PCIVs 3.6.1.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. --------~-~NOTE-------~----- D. 1 Isolate the affected 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Only applicable to penetration flow path by the H202 Analyzer the use of at least one penetrations. closed and de-activated

automatic valve, closed One or more H202 manual valve, or blind Analyzer penetrations flange.

with one or two PCIVs AND inoperable.

D.2 Verify the affected Once per 31 days penetration flow path is isolated.

E. Secondary containment E.1 Restore leakage rate to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months bypass leakage rate not within limit.

within limit.

F. One or more penetration F.1 Restore the valve leakage 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months flow paths with one or to within valve leakage more containment purge limit.

valves not within purge valve leakage limit.

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

G.2 Be in MODE4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SUSQUEHANNA - UNIT 1 3.6-11 Amendment 473, 49a, 271

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.3.1 ---------------------------NOTE---------------------------

Not required to be met when the 18 and 24 inch primary containment purge valves are open for inerting, de-inerting, pressure control, ALARA or air quality considerations for personnel entry, or Surveillances that require the valves to be open.

Verify each 18 and 24 inch primary containment purge valve is closed.

In accordance with the Surveillance Frequency Control Program SR 3.6.1.3.2 ---------------------------NOTES--------------------------

1. Valves and blind flanges in high radiation areas may be verified by use of administrative means.

2. Not required to be met for PCIVs that are open under administrative controls.

Verify each primary containment isolation manual In accordance with valve and blind flange that is located outside the Surveillance primary containment and not locked, sealed, or Frequency Control otherwise secured and is required to be closed Program during accident conditions is closed.

(continued)

SUSQUEHANNA - UNIT 1 3.6-12 Amendment 4-+S, -2ee, 271

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.1.3.6 Perform leakage rate testing for each primary In accordance with containment purge valve with resilient seals. the Surveillance Frequency Control Program SR 3.6.1.3.7 Verify the isolation time of each MSIV is In accordance with

2: 3 seconds and :::; 5 seconds. the lnservice Testing Program SR 3.6.1.3.8 Verify each automatic PCIV actuates to the In accordance with isolation position on an actual or simulated the Surveillance isolation signal. Frequency Control Program SR 3.6.1.3.9 Verify a representative sample of reactor In accordance with instrumentation line EFCVs actuate to check flow the Surveillance on a simulated instrument line break. Frequency Control Program (continued)

SUSQUEHANNA - UNIT 1 3.6-14 Amendment--4-18,-493,~.--206. 271

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.1.3.10 Remove and test the explosive squib from each In accordance with shear isolation valve of the TIP System. the Surveillance Frequency Control Program SR 3.6.1.3.11 Verify the combined leakage rate for all secondary In accordance with containment bypass leakage paths is ~ 15 scfh the Primary when pressurized to~ Pa. Containment Leakage Rate Testing Program.

SR 3.6.1.3.12 Verify leakage rate through each MSIV is In accordance with

~ 100 scfh and ~300 scfh for the combined leakage the Primary including the leakage from the MS Line Drains, Containment when the MSIVs are tested at~ 24.3 psig or Pa and Leakage Rate the MS Line Drains are tested at Pa. Testing Program.

(continued)

SUSQUEHANNA - UNIT 1 3.6-15 Amendment 418, 490, -246, ~ . -2ee, 271

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.1.3.13 Verify combined leakage rate through In accordance with hydrostatically tested lines that penetrate the the Primary primary containment is within limits. Containment Leakage Rate Testing Program.

SUSQUEHANNA - UNIT 1 3.6-16 Amendment 4-73, 271

Secondary Containment 3.6.4.1 3.6 CONTAINMENT SYSTEMS 3.6.4.1 Secondary Containment LCO 3.6.4.1 The secondary containment shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary containment, During CORE ALTERATIONS.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Secondary containment A.1 Restore secondary containment 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months inoperable in MODE 1, 2, to OPERABLE status.

or 3.

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

B.2 Be in MODE 4. 36 h.ours (continued)

SUSQUEHANNA - UNIT 1 3.6-35 Amendment-4-78.~. 271

Secondary Containment 3.6.4.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Secondary containment C.1 ------NOTE------

inoperable during movement LCO 3.0.3 is not applicable.

of irradiated fuel assemblies --------------

in the secondary containment or during CORE Suspend movement of Immediately ALTERATIONS. irradiated fuel assemblies in the secondary containment.

AND C.2 Suspend CORE Immediately ALTERATIONS.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4. 1. 1 -----------NOTE----------- In accordance with the Not required to be met for 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months if analysis Surveillance Frequency demonstrates one standby gas treatment (SGT) Control Program subsystem is capable of establishing the required secondary containment vacuum.

Verify secondary containment vacuum is

~ 0.25 inch of vacuum water gauge.

SR 3.6.4. 1.2 Verify all required secondary containment In accordance with the removable walls and equipment hatches required Surveillance Frequency to be closed are closed and sealed. Control Program (continued)

SUSQUEHANNA - UNIT 1 3.6-36 Amendment-++8, -224,-226, ~-210. 271

SCIVs 3.6.4.2 3.6 CONTAINMENT SYSTEMS 3.6.4.2 Secondary Containment Isolation Valves (SCIVs)

LCO 3.6.4.2 Each required SCIV shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary containment, During CORE ALTERATIONS.

ACTIONS

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

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

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

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

CONDITION REQUIRED ACTION COMPLETION TIME A. ------NOTE------ A.1 Isolate the affected penetration 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months Only applicable to flow path by use of at least one penetration flow paths with closed and de-activated two SCIVs. automatic valve, closed manual valve, or blind flange.

One or more penetration flow AND paths with one required SCIV inoperable.

(continued)

SUSQUEHANNA - UNIT 1 3.6-38 Amendment478, 271

SCIVs 3.6.4.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.2 -----NOTE------

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

Verify the affected penetration Once per 31 days flow path is isolated.

D. Required Action and D.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A, B or C not met in MODE 1, 2, or 3.

AND D.2 Be in MODE4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E. Required Action and E.1 -----NOTE------

associated Completion Time LCO 3.0.3 is not applicable.

of Condition A, B or C not ---------------

met during movement of irradiated fuel assemblies in Suspend movement of Immediately the secondary containment irradiated fuel assemblies in the or during CORE secondary containment.

ALTERATIONS.

AND E.2 Suspend CORE Immediately ALTERATIONS.

SUSQUEHANNA - UNIT 1 3.6-40 Amendment 4+3, 271

SGT System 3.6.4.3 3.6 CONTAINMENT SYSTEMS 3.6.4.3 Standby Gas Treatment (SGT) System LCO 3.6.4.3 Two SGT subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary containment, During CORE ALTERATIONS.

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

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A not met in MODE 1, 2, or 3. AND B.2 Be in MODE4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months C. Required Action and --------NOTE------

associated Completion Time LCO 3.0.3 is not applicable.

of Condition A not met during ------------------

movement of irradiated fuel assemblies in the secondary C.1 Place OPERABLE SGT filter Immediately containment or during CORE train in operation.

ALTERATIONS.

OR (continued)

SUSQUEHANNA - UNIT 1 3.6-42 Amendment 4-73, 271

SGT System 3.6.4.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.2.1 Suspend movement of Immediately irradiated fuel assemblies in secondary containment.

AND C.2.2 Suspend CORE Immediately ALTERATIONS.

D. Two SGT subsystems D.1 Restore one SGT subsystem 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months inoperable in MODE 1, 2, to OPERABLE status.

or 3.

E. Required Action and E.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition D not met in MODE 1, 2, or 3. AND E.2 Be in MODE4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued)

SUSQUEHANNA - UNIT 1 3.6-43 Amendment 4-78, ~ . 271

SGT System 3.6.4.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. Two SGT subsystems F.1 ----NOTE------

inoperable during movement LCO 3.0.3 is not applicable.

of irradiated fuel assemblies in the secondary containment or during CORE Suspend movement of irradiated fuel Immediately ALTERATIONS. assemblies in secondary containment.

F.2 Suspend CORE ALTERATIONS. Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.3.1 Operate each SGT filter train for ~ 15 continuous In accordance with the minutes with heaters operating. Surveillance Frequency Control Program SR 3.6.4.3.2 Perform required SGT filter testing in accordance In accordance with the VFTP with the Ventilation Filter Testing Program (VFTP).

SR 3.6.4.3.3 Verify each SGT subsystem actuates on an actual In accordance with the or simulated initiation signal. Surveillance Frequency Control Program SR 3.6.4.3.4 Verify each SGT filter cooling bypass and outside In accordance with the air damper opens and the fan starts on high Surveillance Frequency charcoal temperature. Control Program SUSQUEHANNA - UNIT 1 3.6-44 Amendment 4+3, ~.299, 263, 271

CREOAS System 3.7.3 3.7 PLANT SYSTEMS 3.7.3 Control Room Emergency Outside Air Supply (CREOAS) System LCO 3.7.3 Two CREOAS subsystems shall be OPERABLE.

-NOTE------*

The control room envelope (CRE) boundary may be opened intermittently under administrative control.

APPLICABILITY: MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary containment, During CORE AL TERATIONS.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CREOAS subsystem A.1 Restore CREOAS subsystem to 7 days inoperable for reasons other OPERABLE status.

than Condition B.

B. One or more CREOAS 8.1 Initiate action to implement Immediately subsystems inoperable due mitigating actions to inoperable CRE boundary in MODES 1, 2, and 3. AND 8.2 Verify mitigating actions ensure 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months CRE occupant exposures to radiological, chemical, and smoke hazards will not exceed limits.

AND 8.3 Restore CRE boundary to 90 days OPERABLE status.

(continued)

SUSQUEHANNA - UNIT 1 3.7-6 Amendment 473, ~ . ~ . 271

CREOAS System 3.7.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A or B not met in AND MODE 1, 2, or 3.

C.2 Be in MODE4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months D. Required Action and ----NOTE------

associated Completion Time LCO 3.0.3 is not applicable.

of Condition A not met during -------------

movement of irradiated fuel assemblies in the secondary D. 1 Place OPERABLE CREOAS Immediately containment or during CORE subsystem in pressurization/

ALTERATIONS. filtration mode.

OR D.2.1 Suspend movement of Immediately irradiated fuel assemblies in the secondary containment.

AND D.2.2 Suspend CORE Immediately ALTERATIONS.

E. Two CREOAS subsystems E.1 Enter LCO 3.0.3. Immediately inoperable in MODE 1, 2, or 3 for reasons other than Condition B.

(continued)

SUSQUEHANNA - UNIT 1 3.7-7 Amendment +73, ~ . 252-, 271

CREOAS System 3.7.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. Two CREOAS subsystems ------NOTE-----

inoperable during movement LCO 3.0.3 is not applicable.

of irradiated fuel assemblies in the secondary containment or during CORE F.1 Suspend movement of Immediately ALTERATIONS. irradiated fuel assemblies in the secondary containment.

One or more CREOAS F.2 Suspend CORE Immediately subsystems inoperable due ALTERATIONS.

to an inoperable CRE boundary during movement of irradiated fuel assemblies in the secondary containment or during CORE ALTERATIONS.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY In accordance with the SR 3. 7 .3.1 Operate each CREOAS filter train for ~ 15 Surveillance Frequency continuous minutes with the heaters operating.

Control Program SR 3.7.3.2 Perform required CREOAS filter testing in In accordance with the VFTP accordance with the Ventilation Filter Testing Program (VFTP).

SR 3.7.3.3 Verify each CREOAS subsystem actuates on an In accordance with the actual or simulated initiation signal. Surveillance Frequency Control Program (continued)

SUSQUEHANNA - UNIT 1 3.7-8 Amendment 478, ~ . ~ . ~ . -2ei, 271

Control Room Floor Cooling System 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Control Room Floor Cooling System LCO 3. 7.4 Two control room floor cooling subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary containment, During CORE ALTERATIONS.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One control room floor A.1 Restore control room floor 30 days cooling subsystem cooling subsystem to inoperable. OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A not met in AND MODE 1, 2, or 3.

B.2 Bein MODE4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued)

SUSQUEHANNA - UNIT 1 3.7-10 Amendment 413, 271

Control Room Floor Cooling System 3.7.4 ACTIONS (continued)

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

associated Completion Time LCO 3.0.3 is not applicable.

of Condition A not met during -----------------

movement of irradiated fuel C.1 Place OPERABLE control Immediately assemblies in the secondary room floor cooling subsystem containment or during CORE in operation.

ALTERATIONS.

OR C.2.1 Suspend movement of Immediately irradiated fuel assemblies in the secondary containment.

AND C.2.2 Suspend CORE Immediately ALTERATIONS.

D. Two control room floor D.1 Enter LCO 3.0.3. Immediately cooling subsystems inoperable in MODE 1, 2, or 3.

(continued)

SUSQUEHANNA - UNIT 1 3.7-11 Amendment 413, 271

Control Room Floor Cooling System 3.7.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Two control room floor -------NOTE-------

cooling subsystems LCO 3.0.3 is not applicable.

inoperable during movement - - - - - - - - - - - - - - - - -

of irradiated fuel assemblies in the secondary containment E.1 Suspend movement of Immediately or during CORE irradiated fuel assemblies in the ALTERATIONS. secondary containment.

E.2 Suspend CORE Immediately ALTERATIONS.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY In accordance with the SR 3.7.4.1 Verify each control room floor cooling subsystem Surveillance Frequency has the capability to remove the assumed heat Control Program load.

SUSQUEHANNA - UNIT 1 3.7-12 Amendment-4-7S, -268, 271

AC Sources-Shutdown 3.8.2 ACTIONS

~-------------------------NOTE------------------------------------

LCO 3.0.3 is not applicable.

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

required AC Enter applicable Condition and Required Sources Actions of LCO 3.8.8, with one required inoperable. subsystem de-energized as a result of Condition A.

A.1 Declare affected required Immediately feature(s), inoperable.

A.2.1 Suspend CORE ALTERATIONS. Immediately A.2.2 Suspend movement of irradiated Immediately fuel assemblies in the secondary containment.

A.2.3 Initiate action to restore required Immediately AC Source to OPERABLE status.

SUSQUEHANNA - UNIT 1 3.8-18 Amendment 4-73, 271

DC Sources-Shutdown 3.8.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.2 Suspend movement of Immediately irradiated fuel assemblies in the secondary containment.

AND A.2.3 Initiate action to restore Immediately required Unit 1 DC electrical power subsystems to OPERABLE status.

B. Diesel Generator E DC 8.1 Verify that all ESW valves 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months electrical power associated with Diesel

-subsystem inoperable, Generator E are closed.

while not aligned to the Class 1E distribution system.

C. Diesel Generator E DC C.1 Declare Diesel Generator E 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months electrical power inoperable.

subsystem inoperable, while aligned to the Class 1E distribution system.

SUSQUEHANNA - UNIT 1 3.8-30 Amendment 4+3, 271

Distribution Systems - Shutdown 3.8.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) -----------NOTE--------------

Enter applicable Conditions and Required Actions of LCO 3.5.2 "Reactor Pressure Vessel (RPV)

Water Inventory Control" when Condition A renders an ECCS subsystem Inoperable.

A.2.1 Suspend CORE Immediately ALTERATIONS.

A.2.2 Suspend handling of Immediately irradiated fuel assemblies in the secondary containment.

A.2.3 Initiate actions to restore Immediately required AC and DC electrical power distribution subsystems to OPERABLE status.

A.2.4 Declare associated required Immediately shutdown cooling subsystem(s) inoperable and not in operation.

(continued)

SUSQUEHANNA - UNIT 1 . 3.8-42 Amendment-4-+8, 271

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 SUSQUEHANNA NUCLEAR, LLC ALLEGHENY ELECTRIC COOPERATIVE, INC.

DOCKET NO. 50-388 SUSQUEHANNA STEAM ELECTRIC STATION, UNIT 2 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 253 Renewed License No. NPF-22

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

A. The application for the amendment filed by Susquehanna Nuclear, LLC, dated September 20, 2017, as supplemented by letters dated February 16, 2018, and May 15, 2018, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's regulations set forth in 10 CFR Chapter I; B. The facility will operate in conformity with the application, the provisions of the Act, and the 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 set forth in 10 CFR Chapter I; D. The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E. The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.

Enclosure 2

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-22 is hereby amended to read as follows:

(2) Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No. 253 and the Environmental Protection Plan contained in Appendix B, are hereby incorporated in the license. Susquehanna Nuclear, LLC shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

3. This license amendment is effective as of its date of issuance and shall be implemented on both units no later than initial entry into Mode 4 for Unit 2 during the Spring 2019 Unit 2 refueling outage.

FOR THE NUCLEAR REGULATORY COMMISSION C)-U~

James G. Danna, Chief Plant Licensing Branch I Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the Renewed Facility Operating License and Technical Specifications Date of Issuance: September 2 6, 2 o1 8

ATTACHMENT TO LICENSE AMENDMENT NO. 253 SUSQUEHANNA STEAM ELECTRIC STATION, UNIT 2 RENEWED FACILITY OPERATING LICENSE NO. NPF-22 DOCKET NO. 50-388 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 a marginal line indicating the area of change.

Remove Insert Page 3 Page 3 Replace the following pages of the 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 Insert Remove Insert TS/TOC-1 TOC-1 3.5-10 3.5-10 TS/TOC-2 TOC-2 3.5-11 3.5-11 1.1-3 1.1-3 3.5-12 3.5-12 1.1-3a 3.6-8 3.6-8 3.3-37 3.3-37 3.6-11 3.6-11 3.3-38 3.3-38 3.6-12 3.6-12 3.3-43 3.3-43 3.6-14 3.6-14 3.3-44 3.3-44 3.6-15 3.6-15 3.3-45 3.3-45 3.6-16 3.6-16 3.3-46 3.3-46 3.6-35 3.6-35 3.3-47 3.3-47 3.6-36 3.6-36 3.3-47a 3.6-38 3.6-38 3.3-47b 3.6-40 3.6-40 3.3-47c 3.6-42 3.6-42 3.3-48 3.3-48 3.6-43 3.6-43 3.3-49 3.3-49 3.6-44 3.6-44 3.3-50 3.3-50 3.7-6 3.7-6 3.3-51 3.3-51 3.7-7 3.7-7 3.3-54 3.3-54 3.7-8 3.7-8 3.3-62 3.3-62 3.7-10 3.7-10 3.3-66 3.3-66 3.7-11 3.7-11 3.3-71 3.3-71 3.7-12 3.7-12 3.5-1 3.5-1 3.8-20 3.8-20 3.5-8 3.5-8 3.8-35 3.8-35 3.5-8a 3.8-36 3.8-36 3.5-9 3.5-9 3.8-51 3.8-51 3.5-9a

3 (3) Susquehanna Nuclear, LLC, pursuant to the Act and 10 CFR Parts 30, 40, and 70, to receive, possess, and use at any time any byproduct, source and special nuclear material as sealed neutron sources for reactor startup, sealed neutron sources for reactor instrumentation and radiation monitoring equipment calibration, and as fission detectors in amounts as required; (4) Susquehanna Nuclear, LLC, pursuant to the Act and 10 CFR Parts 30, 40, and 70 to receive, possess, and use in amounts as required any byproduct, source or special nuclear material without restriction to chemical or physical form, for sample analysis or instrument calibration or associated with radioactive apparatus or components; and (5) Susquehanna Nuclear, LLC, pursuant to the Act and 10 CFR Parts 30, 40, and 70 to possess, but not separate, such byproduct and special nuclear materials as may be produced by the operation of the facility.

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

(1) Maximum Power Level Susquehanna Nuclear, LLC is authorized to operate the facility at reactor core power levels not in excess of 3952 megawatts thermal in accordance with the conditions specified herein. The preoperational tests, startup tests and other items identified in License Conditions 2.C.(20), 2.C.(21 ), 2.C.(22), and 2.C.(23) to this license shall be completed as specified.

(2) Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No. 253, and the Environmental Protection Plan contained in Appendix B are hereby incorporated in the license. Susquehanna Nuclear, LLC shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

For Surveillance Requirements (SRs) that are new in Amendment 151 to Facility Operating License No. NPF-22, the first performance is due at the end of the first surveillance interval that begins at implementation of Amendment 151. For SRs that existed prior to Amendment 151, including SRs with modified acceptance criteria and SRs whose frequency of performance is being extended, the first performance is due at the end of the first surveillance interval that begins on the date the Surveillance was last performed prior to implementation of Amendment 151.

Renewed Operating License No. NPF-22 Amendment No. 253

TABLE OF CONTENTS (TECHNICAL SPECIFICATIONS) 1.0 USE AND APPLICATION ................................................................................. 1.1-1 1.1 Definitions ................................................................................................ 1.1-1 1.2 Logical Connectors .................................................................................. 1.2-1 1.3 Completion Times .................................................................................... 1.3-1 1.4 Frequency ................................................................................................ 1.4-1 2.0 SAFETY LIMITS {SLs) ............................................................................... TS/2.0-1 2.1 SLs .................................................................................................... TS/2.0-1 2.2 SL Violations .................................................................................... TS /2.0-1 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY .......... TS/3.0-1 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY ......................... TS/3.0-4 3.1 REACTIVITY CONTROL SYSTEMS .......................................................... 3.1-1 3.1.1 Shutdown Margin (SDM) ...................................................................... 3.1-1 3.1.2 Reactivity Anomalies ............................................................................ 3.1-5 3.1.3 Control Rod OPERABILITY .................................................................. 3.1-7 3.1.4 Control Rod Scram Times .............................................................. TS/3.1-12 3.1.5 Control Rod Scram Accumulators ........................................................ 3.1-15 3.1.6 Rod Pattern Control .............................................................................. 3.1-18 3.1.7 Standby Liquid Control {SLC) System .................................................. 3.1-20 3.1.8 Scram Discharge Volume (SDV) Vent and Drain Valves ............... TS/3.1-25 3.2 POWER DISTRIBUTION LIMITS ............................................................... 3.2-1 3.2.1 Average Planar Linear Heat Generation Rate (APLHGR) .................... 3.2-1 3.2.2 Minimum Critical Power Ratio (MCPR) ................................................. 3.2-3 3.2.3 Linear Heat Generation Rate (LHGR) .................................................. 3.2-5 3.3 INSTRUMENTATION ................................................................................. 3.3-1 3.3.1.1 Reactor Protection System (RPS) Instrumentation ........................ TS/3.3-1 3.3.1.2 Source Range Monitor (SRM) lnstrumentation ..................................... 3.3-10 3.3.2.1 Control Rod Block Instrumentation ....................................................... 3.3-16 3.3.2.2 Feedwater- Main Turbine High Water Level Trip Instrumentation ............................................................................... 3.3-21 3.3.3.1 Post Accident Monitoring (PAM) Instrumentation ........................... TS/3.3-23 3.3.3.2 Remote Shutdown System ............................................................. TS/3.3-27 3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT)

Instrumentation ............................................................................... 3.3-30 3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) Instrumentation ....................................... 3.3-34 3.3.5.1 Emergency Core Cooling System (ECCS) Instrumentation ................. 3.3-37 3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation ............................................................................... 3.3-47a 3.3.5.3 Reactor Core Isolation Cooling (RCIC) System Instrumentation ............................................................................... 3.3-48 3.3.6.1 Primary Containment Isolation lnstrumentation .................................... 3.3-52 3.3.6.2 Secondary Containment Isolation Instrumentation ............................... 3.3-63 (continued)

SUSQUEHANNA - UNIT 2 TOC-1 Amendment 454, 4&8, 490, ~ . 499, 20a,244,22-G,~.~.253

TABLE OF CONTENTS (TECHNICAL SPECIFICATIONS) 3.3 INSTRUMENTATION (continued) 3.3.7.1 Control Room Emergency Outside Air Supply (CREOAS)

System Instrumentation ..................................................................... 3.3-67 3.3.8.1 Loss of Power (LOP) lnstrumentation ................................................... 3.3-72 3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring ............................................................................................. 3.3-75 3.4 REACTOR COOLANT SYSTEM (RCS) ............................................... TS/3.4-1 3.4.1 Recirculation Loops Operating ....................................................... TS/3.4-1 3.4.2 Jet Pumps ............................................................................................. 3.4-6 3.4.3 Safety/Relief Valves (S/RVs) ................................................................ 3.4-8 3.4.4 RCS Operational LEAKAGE ................................................................. 3.4-10 3.4.5 RCS Pressure Isolation Valve (PIV) Leakage ...................................... 3.4-12 3.4.6 RCS Leakage Detection Instrumentation ....................................... TS/3.4-14 3.4.7 RCS Specific Activity ...................................................................... TS/3.4-17 3.4.8 Residual Heat Removal (RHR) Shutdown Cooling System - Hot Shutdown ........................................................... TS/3.4-19 3.4.9 Residual Heat Removal (RHR) Shutdown Cooling System - Cold Shutdown ............................................................... 3.4-22 3.4.10 RCS Pressure and Temperature (PIT) Limits ....................................... 3.4-24 3.4.11 Reactor Steam Dome Pressure ............................................................ 3.4-31 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), REACTOR PRESSURE VESSEL (RPV) WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM ..................... 3.5-1 3.5.1 ECCS - Operating 3.5-1 3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control .................... 3.5-8 3.5.3 RCIC System ........................................................................................ 3.5-12 3.6 CONTAINMENT SYSTEMS ....................................................................... 3.6-1 3.6.1.1 Primary Containment ............................................................................ 3.6-1 3.6.1.2 Primary Containment Air Lock .............................................................. 3.6-4 3.6.1.3 Primary Containment Isolation Valves (PCIVs) .................................... 3.6-8 3.6.1.4 Containment Pressure .........................................................*................ 3.6-17 3.6.1.5 Drywell Air Temperature ....................................................................... 3.6-18 3.6.1.6 Suppression-Chamber-to-Drywell Vacuum Breakers ........................... 3.6-19 3.6.2.1 Suppression Pool Average Temperature .............................................. 3.6-22 3.6.2.2 Suppression Pool Water Level ............................................................. 3.6-25 3.6.2.3 Residual Heat Removal (RHR) Suppression Pool Cooling ............ TS/3.6-26 3.6.2.4 Residual Heat Removal (RHR) Suppression Pool Spray ..................... 3.6-28 3.6.3.1 Not Used ......................................................................................... TS/3.6-30 3.6.3.2 Drywell Air Flow System ................................................................. TS/3.6-32 3.6.3.3 Primary Containment Oxygen Concentration ....................................... 3.6-34 3.6.4.1 Secondary Containment ....................................................................... 3.6-35 3.6.4.2 Secondary Containment Isolation Valves (SCIVs) ............................... 3.6-38 3.6.4.3 Standby Gas Treatment (SGT) System ................................................ 3.6-42 (continued)

SUSQUEHANNA - UNIT 2 TOC-2 Amendment 4a4, 4-§8., 492-, 244, ~ . 253

Definitions 1.1 1.1 Definitions DOSE actually present. The conversion factors that are used for this EQUIVALENT 1-131 calculation of committed effective dose equivalent (CEDE) from (continued) inhalation shall be those listed in Table 2.1 of Federal Guidelines Report 11, "Limiting Values of Radionuclide Intake and Air Concentration and Dose Conversion Factors for Inhalation, Submersion, and Ingestion,"

EPA, 1988, as described in Regulatory Guide 1.183. The factors in the column headed "effective" yield doses corresponding to the CEDE. The conversion factors that are used for the calculation of EDE (or DOE) from external exposure (submersion) shall be those listed in Table 111.1 of Federal Guidance Report 12, "External Exposure to Radionuclides in Air, Water, and Soil," EPA, 1993, as described in Regulatory Guide 1.183. The factors in the column headed "effective" yield doses corresponding to the EDE.

DRAIN TIME The DRAIN TIME is the time it would take for the water inventory in and above the Reactor Pressure Vessel (RPV) to drain to the top of the active fuel (TAF) seated in the RPV assuming:

a) The water inventory above the TAF is divided by the limiting drain rate; b) The limiting drain rate is the larger of the drain rate through a single penetration flow path with the highest flow rate, or the sum of the drain rates through multiple penetration flow paths susceptible to a common mode failure (e.g., seismic event, loss of normal power, single human error), for all penetration flow paths below the TAF except:

1. Penetration flow paths connected to an intact closed system, or isolated by manual or automatic valves that are locked, sealed, or otherwise secured in the closed position, blank flanges, or other devices that prevent flow of reactor coolant through the penetration flow paths;

2. Penetration flow paths capable of being isolated by valves that will close automatically without offsite power prior to the RPV water level being equal to the TAF when actuated by RPV water level isolation instrumentation; or

3. Penetration flow paths with isolation devices that can be closed prior to the RPV water level being equal to the TAF by a dedicated operator trained in the task, who in continuous communication with the control room, is stationed at the controls, and is capable of closing the penetration flow path isolation device without offsite power.

(continued)

SUSQUEHANNA - UNIT 2 1.1-3 AmendmeRt-45~1{;. 253

Definitions 1.1 1.1 Definitions (continued) c) The penetration flow paths required to be evaluated per paragraph b) are assumed to open instantaneously and are not subsequently isolated, and no water is assumed to be subsequently added to the RPV water inventory; d) No additional draining events occur; and e) Realistic cross-sectional areas and drain rates are used.

A bounding DRAIN TIME may be used in lieu of a calculated value.

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

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

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

(continued)

SUSQUEHANNA - UNIT 2 1.1-3a Amendment 4§4, 249, 253

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

APPLICABILITY: According to Table 3.3.5.1-1.

ACTIONS

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

Separate Condition entry is allowed for each channel.

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

B. As required by B.1 ------NOTE-----

Required Action A.1 Only applicable for Functions and referenced in 1.a, 1.b, 1.c, 2.a, 2.b, and 2.c Table 3.3.5.1-1. -

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

SUSQUEHANNA - UNIT 2 3.3-37 Amendment 404, 253

ECCS Instrumentation 3.3.5.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2 -----NOTE Only applicable for Functions 3.a and 3.b.

Declare High Pressure Coolant 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Injection (HPCI) System discovery of loss of inoperable. HPCI initiation capability AND B.3 Place channel in trip. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months C. As required by Required C.1 -------NOTE-----

Action A.1 and Only applicable for Functions referenced in 1.d, 2.d, and 2.e Table 3.3.5.1-1. -------------

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

(continued)

SUSQUEHANNA - UNIT 2 3.3-38 Amendment~. 253

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

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

1. Core Spray System

a. Reactor Vessel 1,2,3 4(*) B SR 3.3.5.1.1 ~ -136 inches Water Level- SR 3.3.5.1.2 Low Low Low, SR 3.3.5.1.4 Level1 SR 3.3.5.1.5

b. Drywell Pressure- 1,2,3 4(*) B SR 3.3.5.1.2 s 1.88 psig High SR 3.3.5.1.3 SR 3.3.5.1.5 C. Reactor 1,2,3 4 B SR 3.3.5.1.2 ~ 407 psig (lower)

Steam Dome SR 3.3.5.1.3 s 433 psig (upper)

Pressure-Low SR 3.3.5.1.5 (initiation)

d. Reactor 1,2,3 4 C SR 3.3.5.1.2 ~ 407 psig (lower)

Steam Dome SR 3.3.5.1.3 s 433 psig (upper)

Pressure-Low SR 3.3.5.1.5 (injection permissive)

e. Manual Initiation 1,2,3 2 C SR 3.3.5.1.5 NA 1 per subsystem

2. Low Pressure Coolant Injection (LPCI)

System

a. Reactor Vessel 1,2,3 4(b) B SR 3.3.5.1.1 ~ -136 inches Water Level-Low SR 3.3.5.1.2 Low Low, Level 1 SR 3.3.5.1.4 SR 3.3.5.1.5 continued (a) Also required to initiate the associated diesel generator (DG), initiate Drywell Cooling Equipment Trip, and Emergency Service Water (ESW) Pump timer reset.

(b) Also required to initiate the associated DGs, ESW Pump timer reset and Turbine Building and Reactor Building Chillers trip.

SUSQUEHANNA - UNIT 2 3.3-43 Amendment 454-, 4-aa, 253

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

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

2. LPCI System (continued)

b. Drywell Pressure- 1,2,3 4(b) B SR 3.3.5.1.2 ,s 1.88 psig High SR 3.3.5.1.3 SR 3.3.5.1.5 C. Reactor 1,2,3 4 B SR 3.3.5.1.2 <! 407 psig (lower)

Steam Dome SR 3.3.5.1.3 ,s 433 psig (upper)

Pressure-Low SR 3.3.5.1.5 (initiation)

d. Reactor Steam 1,2,3 4 C SR 3.3.5.1.2 <! 407 psig (lower)

Dome Pressure- SR 3.3.5.1.3 ,s 433 psig (upper)

Low (injection SR 3.3.5.1.5 permissive)

e. Reactor Steam 1<c),2(c), 4 C SR 3.3.5.1.2 ,! 216 psig Dome Pressure- 3(c) SR 3.3.5.1.3 Low (Recirculation SR 3.3.5.1.5 Discharge Valve Permissive)

f. Manual Initiation 1,2,3 2 C SR 3.3.5.1.5 NA 1 per subsystem continued (b) Also required to initiate the associated DGs, ESW pump timer reset and Turbine Building and Reactor Building Chiller trip.

(c) With either associated recirculation pump discharge or bypass valves open.

SUSQUEHANNA - UNIT 2 3.3-44 Amendment 484, 4-aa, 253

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

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

3. High Pressure Coolant Injection (HPCI)

System

a. Reactor Vessel 1, 4 B SR 3.3.5.1.1 ~ -45 inches Water Level-Low 2(d)' 3(d) SR 3.3.5.1.2 Low, Level 2 SR 3.3.5.1.4 SR 3.3.5.1.5

b. Drywell Pressure- 1, 4 B SR 3.3.5.1.2 s 1.88 psig High 2(dl,3(d) SR 3.3.5.1.3 SR 3.3.5.1.5

c. Reactor Vessel 1 2 C SR 3.3.5.1.2 s 55.5 inches Water Level- High, 2(d)' 3(d) SR 3.3.5.1.3 Level8 SR 3.3.5.1.5

d. Condensate 1, 2 D SR 3.3.5.1.2 ~ 40.5 inches Storage Tank 2(d)' 3(d) SR 3.3.5.1.3 above tank bottom Level-Low SR 3.3.5.1.5

e. Manual Initiation 1, C SR 3.3.5.1.5 NA 2(d)' 3(d) continued (d) With reactor steam dome pressure> 150 psig.

SUSQUEHANNA - UNIT 2 3.3-45 Amendment 454, 418, ~ . 34, 253

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

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

4. Automatic Depressurization System (ADS) Trip System A

a. Reactor Vessel 1, 2 E SR 3.3.5.1.1 ;,,-136inches Water Level-Low id), 3(d) SR 3.3.5.1.2 Low Low, Level 1 SR 3.3.5.1.4 SR 3.3.5.1.5

b. Drywell Pressure- 1, 2 E SR 3.3.5.1.2 s 1.88 psig High id), 3(d) SR 3.3.5.1.3 SR 3.3.5.1.5

c. Automatic 1, F SR 3.3.5.1.2 s 114 seconds Depressurization id), 3(d) SR 3.3.5.1.3 System Initiation SR 3.3.5.1.5 nmer

d. Reactor Vessel 1, E SR 3.3.5.1.1 ;,, 11.5 inches Water Level-Low, id), 3(d) SR 3.3.5.1.2 Level3 SR 3.3.5.1.4 (Confirmatory) SR 3.3.5.1.5

e. Core Spray Pump 1, 2 F SR 3.3.5.1.2 ;,, 125 psig Discharge id), 3(d) SR 3.3.5.1.3 and Pressure-High SR 3.3.5.1.5 s 165 psig

f. Low Pressure 1, 4 F SR 3.3.5.1.2 ;,, 115 psig Coolant Injection id), 3(d) SR 3.3.5.1.3 and Pump Discharge SR 3.3.5.1.5 s 135 psig Pressure - High

g. Automatic 1, 2 F SR 3.3.5.1.2 s 450 seconds Depressurization id), 3id) SR 3.3.5.1.3 System Drywell SR 3.3.5.1.5 Pressure Bypass Actuation nrner

h. Manual Initiation 1, 2 F SR 3.3.5.1.5 NA id), 3(d) continued (d) With reactor steam dome pressure > 150 psig.

SUSQUEHANNA - UNIT 2 3.3-46 Amendment 4-M, 4-aa, 400, 253

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

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

5. ADS Trip System B

a. Reactor Vessel 1, 2 E SR 3.3.5.1.1 ;:: -136 inches Water Level - Low i"l, 3(d) SR 3.3.5.1.2 Low Low, Level 1 SR 3.3.5.1.4 SR 3.3.5.1.5

b. Drywell Pressure- 1, 2 E SR 3.3.5.1.2 s 1.88 psig High id), 3(d) SR 3.3.5.1.3 SR 3.3.5.1.5

c. Automatic 1, F SR 3.3.5.1.2 s114sec De pressurization id), 3(d) SR 3.3.5.1.3 System Initiation SR 3.3.5.1.5 Timer

d. Reactor Vessel 1, E SR 3.3.5.1.1 ;:: 11.5 inches Water Level-Low, id), 3(d) SR 3.3.5.1.2 Level3 SR 3.3.5.1.4 (Confirmatory) SR 3.3.5.1.5

e. Core Spray Pump 1, 2 F SR 3.3.5.1.2 ;:: 125 psig Discharge id), 3(d) SR 3.3.5.1.3 and Pressure-High SR 3.3.5.1.5 s 165 psig

f. Low Pressure 1, 4 F SR 3.3.5.1.2 ;:: 115 psig Coolant Injection id), 3(d) SR 3.3.5.1.3 and Pump Discharge SR 3.3.5.1.5 s 135 psig Pressure-High

g. Automatic 1, 2 F SR 3.3.5.1.2 s 450 seconds Depressurization id), 3(d) SR 3.3.5.1.3 System Drywell SR 3.3.5.1.5 Pressure Bypass Actuation Timer

h. Manual Initiation 1, 2 F SR 3.3.5.1.5 NA id), 3(d)

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

SUSQUEHANNA - UNIT 2 3.3-47 Amendment 4-a-i, 4-aa, 49&, 253

Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation 3.3.5.2 3.3 INSTRUMENTATION 3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation LCO 3.3.5.2 The RPV Water Inventory Control instrumentation for each Function in Table 3.3.5.2-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.5.2-1.

ACTIONS

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

Sepa rate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable. referenced in Table 3.3.5.2-1 for the channel.

B. As required by Required B.1 Declare associated Immediately Action A.1 and penetration flow path(s) referenced in incapable of automatic Table 3.3.5.2-1. isolation.

AND B.2 Calculate DRAIN TIME. Immediately C. As required by Required C. 1 Place channel in trip. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Action A.1 and referenced in Table 3.3.5.2-1.

D. As required by Required D.1 Restore channel to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Action A.1 and OPERABLE status.

referenced in Table 3.3.5.2-1.

SUSQUEHANNA UNIT 2 3.3-47a Amendment 253

Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation 3.3.5.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E.1 Declare associated low Immediately associated Completion pressure ECCS Time of Condition C or D injection/spray subsystem not met. inoperable.

SURVEILLANCE REQUIREMENTS

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

Refer to Table 3.3.5.2-1 to determine which SRs apply for each ECCS Function.

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 -----------------NOTE----------------- In accordance A test of all required contacts does not have to be with the performed. Surveillance Frequency Control Program Perform CHANNEL FUNCTIONAL TEST.

SR 3.3.5.2.3 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SUSQUEHANNA UNIT 2 3.3-47b Amendment 253

Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation 3.3.5.2 Table 3.3.5.2-1 (Page 1 of 1)

RPV Water Inventory Control Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED OR OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTIONA.1 REQUIREMENTS VALUE

1. Core Spray System

a. Reactor Steam Dome 4, 5 4 (a) C SR 3.3.5.2.2 s; 433 psig Pressure - Low SR 3.3.5.2.3 (upper)

(Injection Permissive)

b. Manual Initiation 4, 5 1 per D SR 3.3.5.2.3 NA subsystem (a)

2. Low Pressure Coolant Injection (LPCI)

System

a. Reactor Steam Dome Pressure - 4, 5 4 (a) C SR 3.3.5.2.2 s; 433 psig Low (Injection SR 3.3.5.2.3 (upper)

Permissive)

b. Manual Initiation 4, 5 1 per D SR 3.3.5.2.3 NA subsystem (a)

3. RHR System Isolation

a. Reactor Vessel (b) 2 in one trip B SR 3.3.5.2.1 <'. 11.5 inches Water Level - Low, system SR 3.3.5.2.2 Level3 SR 3.3.5.2.3

4. Reactor Water Cleanup (RWCU) System Isolation

a. Reactor Vessel (b) 2 in one trip B SR 3.3.5.2.1 <'. -45 inches Water Level - Low system SR 3.3.5.2.2 Low, Level 2 SR 3.3.5.2.3 (a) Associated with an ECCS subsystem required to be OPERABLE by LCO 3.5.2, "Reactor Pressure Vessel (RPV) Water Inventory Control."

(b} When automatic isolation of the associated penetration flow path(s) is credited in calculating DRAIN TIME.

SUSQUEHANNA UNIT 2 3.3-47c Amendment 253

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

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

ACTIONS

NOTE-----~--------------

Separate Condition entry is allowed for each channel.

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

B. As required by 8.1 Declare RCIC System inoperable. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Required Action A.1 discovery of loss of and referenced in RCIC initiation Table 3.3.5.3-1. capability AND 8.2 Place channel in trip. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months C. As required by C.1 Restore channel to OPERABLE 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Required Action A.1 status.

and referenced in Table 3.3.5.3-1.

(continued)

SUSQUEHANNA - UNIT 2 3.3-48 Amendment 4-54-, 253

RCIC System Instrumentation 3.3.5.3 ACTIONS (continued)

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

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

Declare RCIC System inoperable. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery of loss of RCIC initiation capability AND D.2.1 Place channel in trip. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OR D.2.2Align RCIC pump suction to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months the suppression pool.

E. Required Action and E.1 Declare RCIC System inoperable. Immediately associated Completion Time of Condition B, C, or D not met.

SUSQUEHANNA - UNIT 2 3.3-49 Amendment 454, 253

RCIC System Instrumentation 3.3.5.3 SURVEILLANCE REQUIREMENTS

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

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

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

SURVEILLANCE FREQUENCY SR 3.3.5.3.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.5.3.2 A test of all required contacts does not have to be performed.

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.5.3.3 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.5.3.4 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.5.3.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SUSQUEHANNA - UNIT 2 3.3-50 Amendment +a4, 247, 253

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

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

1. Reactor Vessel Water 4 B SR 3.3.5.3.1 2-45 inches Level-Low Low, SR 3.3.5.3.2 Level2 SR 3.3.5.3.4 SR 3.3.5.3.5

2. Reactor Vessel Water 2 C SR 3.3.5.3.1 ~ 55.5 inches Level-High, Level 8 SR 3.3.5.3.2 SR 3.3.5.3.3 SR 3.3.5.3.5

3. Condensate Storage 2 D SR 3.3.5.3.2 2 36.0 inches above the Tank Level-Low SR 3.3.5.3.3 tank bottom SR 3.3.5.3.5

4. Manual Initiation C SR 3.3.5.3.5 NA SUSQUEHANNA - UNIT 2 3.3-51 Amendment4a4, 253

Primary Containment Isolation Instrumentation 3.3.6.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME H. As required by Required H.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Action C.1 and referenced in Table 3.3.6.1-1. AND H.2 Be in MODE4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR Required Action and associated Completion Time for Condition F or G not met.

I. As required by Required 1.1 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Action C.1 and referenced standby liquid control in Table 3.3.6.1-1 subsystem (SLC) inoperable.

OR 1.2 Isolate the Reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Water Cleanup System.

J. As required by Required J.1 Initiate action to restore Immediately Action C.1 and referenced channel to OPERABLE in Table 3.3.6.1-1. status.

SUSQUEHANNA - UNIT 2 3.3-54 Amendment~. 253

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

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

6. Shutdown Cooling System Isolation

a. Reactor Steam Dome 1,2,3 F SR 3.3.6.1.2 :,; 108 psig Pressure - High SR 3.3.6.1.3 SR 3.3.6.1.5

b. Reactor Vessel Water 3 2 J SR 3.3.6.1.1 ?. 11.5 inches Level - Low, Level 3 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 C. Manual Initiation 3 G SR 3.3.6.1.5 NA

7. Traversing lncore Probe Isolation

a. Reactor Vessel Water 1,2,3 2 G SR 3.3.6.1.1 Level - Low, Level 3 SR 3.3.6.1.2 ?. 11.5 inches SR 3.3.6.1.3 SR 3.3.6.1.5

b. Drywell Pressure - 1,2,3 2 G SR 3.3.6.1.2 :,; 1.88 psig High SR 3.3.6.1.4 SR 3.3.6.1.5 SUSQUEHANNA - UNIT 2 3.3-62 Amendment 4&4, 488, ~ . 253

Secondary Containment Isolation Instrumentation 3.3.6.2 Table 3.3.6.2-1 (page 1 of 1)

Secondary Containment Isolation Instrumentation APPLICABLE MODES OR OTHER REQUIRED SPECIFIED CHANNELS PER TRIP SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM REQUIREMENTS VALUE

1. Reactor Vessel Water 1,2,3 2 SR 3.3.6.2.1 2'.-45 inches Level-Low Low, Level 2 SR 3.3.6.2.2 SR 3.3.6.2.4 SR 3.3.6.2.5

2. Drywell Pressure--High 1,2,3 2 SR 3.3.6.2.2 s 1.88 psig SR 3.3.6.2.3 SR 3.3.6.2.5

3. Unit 1 Refuel Floor High (a) SR 3.3.6.2.1 s25 mR/hr Exhaust Duct Radiation- SR 3.3.6.2.2 High SR 3.3.6.2.4 SR 3.3.6.2.5

4. Unit 2 Refuel Floor High (a) SR 3.3.6.2.1 s25 mR/hr Exhaust Duct Radiation- SR 3.3.6.2.2 High SR 3.3.6.2.4 SR 3.3.6.2.5

5. Unit 1 Refuel Floor Wall (a) SR 3.3.6.2.1 s 28 mR/hr Exhaust Duct Radiation- SR 3.3.6.2.2 High SR 3.3.6.2.4 SR 3.3.6.2.5

6. Unit 2 Refuel Floor Wall (a) SR 3.3.6.2.1 s 28 mR/hr Exhaust Duct Radiation- SR 3.3.6.2.2 High SR 3.3.6.2.4 SR 3.3.6.2.5

7. Railroad Access Shaft (b) SR 3.3.6.2.1 s 7 mR/hr Exhaust Duct Radiation- SR 3.3.6.2.2 High SR 3.3.6.2.4 SR 3.3.6.2.5

8. Manual Initiation 1,2,3, SR 3.3.6.2.5 NA (a)

(a) During CORE ALTERATIONS and during movement of irradiated fuel assemblies in secondary containment.

(b) During movement of irradiated fuel assemblies within the Railroad Access Shaft, and above the Railroad Access Shaft with the Railroad Access Shaft Equipment Hatch open.

SUSQUEHANNA - UNIT 2 3.3-66 Amendment 4-M, 253

CREOAS System Instrumentation 3.3.7.1 Table 3.3.7.1-1 (page 1 of 1)

Control Room Emergency Outside Air Supply System Instrumentation APPLICABLE CONDITIONS MODES OR REFERENCED OTHER REQUIRED FROM SPECIFIED CHANNELS PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS TRIP SYSTEM ACTIONA.1 REQUIREMENTS VALUE

1. Reactor Vessel 1,2,3 2 B SR 3.3.7.1.1 ~ -45 inches Water Level-Low SR 3.3.7.1.2 Low. Level2 SR 3.3.7.1.4 SR 3.3.7.1.5

2. Drywell Pressure- 1,2,3 2 B SR 3.3.7.1.2 S 1.88 psig High SR 3.3.7.1.3 SR 3.3.7.1.5

3. Unit 1 Refuel Floor (a) B SR 3.3.7.1.1 s 25 mR/hr High Exhaust Duct SR 3.3.7.1.2 Radiation-High SR 3.3.7.1.4 SR 3.3.7.1.5

4. Unit 2 Refuel Floor (a) B SR 3.3.7.1.1 s25 mR/hr High Exhaust Duct SR 3.3.7.1.2 Radiation-High SR 3.3.7.1.4 SR 3.3.7.1.5

5. Unit 1 Refuel Floor (a) B SR 3.3.7.1.1 s28 mR/hr Wall Exhaust Duct SR 3.3.7.1.2 Radiation -High SR 3.3.7.1.4 SR 3.3.7.1.5

6. Unit 2 Refuel Floor (a) B SR 3.3.7.1.1 s 28 mR/hr Wall Exhaust Duct SR 3.3.7.1.2 Radiation -High SR 3.3.7.1.4 SR 3.3.7.1.5

7. Railroad Access (b) B SR 3.3.7.1.1 s 7 mR/hr Shaft Exhaust Duct SR 3.3.7.1.2 Radiation-High SR 3.3.7.1.4 SR 3.3.7.1.5

8. Main Control Room 1,2,3, C SR 3.3.7.1.1 s 5 mR/hr Outside Air Intake (a) SR 3.3.7.1.2 Radiation - High SR 3.3.7.1.4 SR 3.3.7.1.5

9. Manual Initiation 1,2,3 B SR 3.3.7.1.5 nla (a)

(a) During CORE ALTERATIONS and during movement of irradiated fuel assemblies in the secondary containment.

(b) During movement of irradiated fuel assemblies within the Railroad Access Shaft, and above the Railroad Access Shaft with the Railroad Access Shaft Equipment Hatch open.

SUSQUEHANNA - UNIT 2 3.3-71 Amendment 484, 253

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

APPLICABILITY: MODE 1, MODES 2 and 3, except high pressure coolant injection (HPCI) and ADS valves are not required to be OPERABLE with reactor steam dome pressure ::; 150 psig.

ACTIONS

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

LCO 3.0.4.b is not applicable to HPCI.

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

than Condition B.

B. One LPCI pump in one or B.1 Restore LPCI pump(s) to 7 days both LPCI subsystems OPERABLE status.

inoperable.

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

C.2 Be in MODE4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued)

SUSQUEHANNA - UNIT 2 3.5-1 Amendment 4§.:1., 4-90, 253

Reactor Pressure Vessel (RPV) Water Inventory Control 3.5.2 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), REACTOR PRESSURE VESSEL (RPV) WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control LCO 3.5.2 DRAIN TIME of RPV water inventory to the top of active fuel (TAF) shall be~ 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

AND One low pressure ECCS injection/spray subsystem shall be OPERABLE.

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

A 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.

APPLICABILITY: MODES 4 and 5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required ECCS A.1 Restore required ECCS 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months injection/spray subsystem injection/spray subsystem to inoperable. OPERABLE status.

B. Required Action and B.1 Initiate action to establish a Immediately associated Completion Time method of water injection of Condition A not met. capable of operating without offsite electrical power.

SUSQUEHANNA - UNIT 2 3.5-8 Amendment 4-a4-, 253

Reactor Pressure Vessel (RPV) Water Inventory Control 3.5.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. DRAIN TIME < 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months and C.1 Verify secondary containment 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months

~ 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . boundary is capable of being established in less than the DRAIN TIME.

AND C.2 Verify each secondary 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months containment penetration flow path is capable of being isolated in less than the DRAIN TIME.

AND C.3 Verify one standby gas 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months treatment subsystem is capable of being placed in operation in less than the DRAIN TIME.

(continued)

SUSQUEHANNA - UNIT 2 3.5-8a Amendment 253

Reactor Pressure Vessel (RPV) Water Inventory Control 3.5.2 ACTIONS {continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. DRAIN TIME < 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . D.1 - - - - N O T E - - -

Required ECCS injection/spray subsystem or additional method of water injection shall be capable of operating without offsite electrical power.

Initiate action to establish an Immediately additional method of water injection with water sources capable of maintaining RPV water level > TAF for ;::; 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

D.2 Initiate action to establish Immediately secondary containment boundary.

D.3 Initiate action to isolate each Immediately secondary containment penetration flow path or verify it can be manually isolated from the control room.

D.4 Initiate action to verify one Immediately standby gas treatment subsystem is capable of being placed in operation.

SUSQUEHANNA - UNIT 2 3.5-9 Amendment 4&4, 247, 253

Reactor Pressure Vessel (RPV) Water Inventory Control 3.5.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E.1 Initiate action to restore Immediately associated Completion Time DRAIN TIME to ~ 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

of Condition C or D not met.

OR DRAIN TIME < 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify DRAIN TIME ~ 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . In accordance with the Surveillance Frequency Control Program SR 3.5.2.2 Verify, for a required low pressure coolant injection In accordance with the (LPCI) subsystem, the suppression pool water Surveillance Frequency level is ~ 20 ft O inches. Control Program (continued)

SUSQUEHANNA - UNIT 2 *3.5-9a Amendment 4a4, 247, 253

Reactor Pressure Vessel (RPV) Water Inventory Control 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.3 Verify, for a required Core Spray (CS) subsystem, In accordance with the the: Surveillance Frequency Control Program

a. Suppression pool water level is

~ 20 ft O inches; or

b. Condensate storage tank water level is ~ 49%

of capacity.

SR 3.5.2.4 Verify, for the required ECCS injection/spray In accordance with the subsystem, the piping is filled with water from the Surveillance Frequency pump discharge valve to the injection valve. Control Program SR 3.5.2.5 Verify, for the required ECCS injection/spray In accordance with the subsystem, each manual, power operated, and Surveillance Frequency automatic valve in the flow path, that is not Control Program locked, sealed, or otherwise secured in position, is in the correct position.

(continued)

SUSQUEHANNA - UNIT 2 3.5-10 Amendment 4a4, 247, 253

Reactor Pressure Vessel (RPV) Water Inventory Control 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.6 Operate the required ECCS injection/spray In accordance with the subsystem through the recirculation line for 2: 10 Surveillance Frequency minutes. Control Program SR 3.5.2. 7 Verify each valve credited for automatically In accordance with the isolating a penetration flow path actuates to the Surveillance Frequency isolation position on an actual or simulated Control Program isolation signal.

SR 3.5.2.8 ---------NOTE----------

Vessel injection/spray may be excluded.

Verify the required ECCS injection/spray In accordance with the subsystem actuates on a manual initiation signal. Surveillance Frequency Control Program SUSQUEHANNA - UNIT 2 3.5-11 Amendment 454, 247, 253

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

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

ACTIONS

---~-~----~---------~------------~-~~-----~~--NOTE---~~~-~~~-------~~~-~~----~~~-~---

LCO 3.0.4.b is not applicable to RCIC.

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

AND A.2 Restore RCIC System to 14 days OPERABLE status B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met.

AND B.2 Reduce reactor steam dome 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months pressure to ~ 150 psig.

SUSQUEHANNA - UNIT 2 3.5-12 Amendment 4M, 4-9&, 253

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

LCO 3.6.1.3 Each PCIV shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3 ACTIONS

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

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

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

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

4. Enter applicable Conditions and Required Actions of LCO 3.6.1.1, "Primary Containment,"

when PCIV leakage results in exceeding overall containment leakage rate acceptance criteria in MODES 1, 2, and 3.

CONDITION REQUIRED ACTION COMPLETION TIME A. -------------NO TE-------------- A.1 Isolate the affected 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months except for On ly applicable to penetration flow path by main steam line penetration flow paths with use of at least one closed two PCIVs except for the and de-activated H2 02 Analyzer automatic valve, closed penetrations. manual valve, blind 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months for main steam flange, or check valve with line flow through the valve One or more penetration secured.

flow paths with one PCIV inoperable except for purge valve leakage not within limit.

(continued)

SUSQUEHANNA - UNIT 2 3.6-8 Amendment 484, 4-10, 253

PCIVs 3.6.1.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. ----~-------NOTE-------------- 0.1 Isolate the affected 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Only applicable to the H202 penetration flow path by Analyzer penetrations. the use of at least one

closed and de-activated One or more H2 02 automatic valve, closed Analyzer penetrations with manual valve or blind one or two PCIVs flange.

inoperable. AND D.2 Verify the affected Once per 31 days penetration flow path is isolated.

E. Secondary containment E.1 Restore leakage rate to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months bypass leakage rate within limit.

not within limit.

F. One or more penetration F.1 Restore the valve leakage 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months flow paths with one or more to within valve leakage containment purge valves limit.

not within purge valve leakage limit.

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

G.2 Be in MODE4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SUSQUEHANNA - UNIT 2 3.6-11 Amendment~. 4+-0, 253

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.3.1 ---------------------------NOTE--------------------------

Not required to be met when the 18 and 24 inch primary containment purge valves are open for inerting, de-inerting, pressure control, ALARA or air quality considerations for personnel entry, or Surveillances that require the valves to be open.

Verify each 18 and 24 inch primary containment In accordance with purge valve is closed. the Surveillance Frequency Control Program SR 3.6.1.3.2 --------------------------NO 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 In accordance with valve and blind flange that is located outside the Surveillance primary containment and not locked, sealed, or Frequency Control otherwise secured and is required to be closed Program during accident conditions is closed.

(continued)

SUSQUEHANNA - UNIT 2 3.6-12 Amendment 4-M, 247, 253

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.1.3.6 Perform leakage rate testing for each primary In accordance with containment purge valve with resilient seals. the Surveillance Frequency Control Program SR 3.6.1.3.7 Verify the isolation time of each MSIV is In accordance with

~3 seconds and ~ 5 seconds. the lnservice Testing Program SR 3.6.1.3.8 Verify each automatic PCIV actuates to the In accordance with isolation position on an actual or simulated the Surveillance isolation signal. Frequency Control Program SR 3.6.1.3.9 Verify a representative sample of reactor In accordance with instrumentation line EFCVs actuate to check flow the Surveillance on a simulated instrument line break. Frequency Control Program SR 3.6.1.3.10 Remove and test the explosive squib from each In accordance with shear isolation valve of the TIP System. the Surveillance Frequency Control Program (continued)

SUSQUEHANNA - UNIT 2 3.6-14 Amendment $4, 468, -200, ~ . 253

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.1.3.11 Verify the combined leakage rate for all In accordance secondary containment bypass leakage with the Primary paths is::; 15 scfh when pressurized to ~ Pa. Containment Leakage Rate Testing Program.

SR 3.6.1.3.12 Verify leakage rate through each MSIV is In accordance

100 scfh and ~ 300 scfh for the combined with the Primary leakage including the leakage from the MS Line Containment Drains when the MSIVs are tested at ~ 24.3 psig Leakage Rate or Pa and the MS Line Drains are tested at Pa. Testing Program.

(continued)

SUSQUEHANNA - UNIT 2 3.6-15 Amendment 454, 4-ea, 224, ~ . 253

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.6.1.3.13 Verify combined leakage rate through In accordance hydrostatically tested lines that penetrate the with the Primary primary containment is within limits. Containment Leakage Rate Testing Program.

SUSQUEHANNA - UNIT 2 3.6-16 Amendment 4a4-, 253

Secondary Containment 3.6.4.1 3.6 CONTAINMENT SYSTEMS 3.6.4.1 Secondary Containment LCO 3.6.4.1 The secondary containment shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary containment, During CORE ALTERATIONS.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Secondary containment A.1 Restore secondary 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months inoperable in MODE 1, 2, containment to OPERABLE or 3. status.

8. Required Action and 8.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A not met.

8.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued)

SUSQUEHANNA - UNIT 2 3.6-35 Amendment 454, ~ . 253

Secondary Containment 3.6.4.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Secondary containment C.1 ------NOTE------

inoperable during movement LCO 3.0.3 is not applicable.

of irradiated fuel assemblies in the secondary containment or during CORE Suspend movement of Immediately AL TERATIONS. irradiated fuel assemblies in the secondary containment.

C.2 Suspend CORE Immediately ALTERATIONS.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1.1 -----------NOTE------------- In accordance with the Not required to be met for 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months if analysis Surveillance Frequency demonstrates one standby gas treatment (SGT) Control Program subsystem is capable of establishing the required secondary containment vacuum.

Verify secondary containment vacuum is

~ 0.25 inch of vacuum water gauge.

SR 3.6.4.1.2 Verify all required secondary containment In accordance with the removable walls and equipment hatches required Surveillance Frequency to be closed are closed and sealed. Control Program (continued)

SUSQUEHANNA - UNIT 2 3.6-36 Amendment~. 204, -20J, 247, -252, 253

SCIVs 3.6.4.2 3.6 CONTAINMENT SYSTEMS 3.6.4.2 Secondary Containment Isolation Valves (SCIVs)

LCO 3.6.4.2 Each required SCIV shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary containment, During CORE ALTERATIONS.

ACTIONS

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

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

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

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

CONDITION REQUIRED ACTION COMPLETION TIME A. ------NOTE------- A.1 Isolate the affected penetration 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months Only applicable to flow path by use of at least one penetration flow paths with closed and de-activated two SCIVs. automatic valve, closed manual valve, or blind flange.

One or more penetration flow AND paths with one required SCIV inoperable.

(continued)

SUSQUEHANNA - UNIT 2 3.6-38 Amendment 4a4, 253

SCIVs 3.6.4.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.2 -----NOTE------

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

Verify the affected penetration Once per 31 days flow path is isolated.

D. Required Action and D.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A, B or C not met in MODE 1, 2, or 3.

AND D.2 Bein MODE4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E. Required Action and E.1 ------NOTE-----

associated Completion Time LCO 3.0.3 is not applicable.

of Condition A, B or C not ---------------

met during movement of irradiated fuel assemblies in Suspend movement of Immediately the secondary containment irradiated fuel assemblies in the or during CORE secondary containment.

ALTERATIONS.

AND E.2 Suspend CORE Immediately ALTERATIONS.

SUSQUEHANNA - UNIT 2 3.6-40 Amendment +a+, 253

SGT System 3.6.4.3 3.6 CONTAINMENT SYSTEMS 3.6.4.3 Standby Gas Treatment (SGT) System LCO 3.6.4.3 Two SGT subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary containment, During CORE ALTERATIONS.

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

B. Required Action and 8.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A not met in MODE 1, 2, or 3. AND 8.2 Be in MODE4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months C. Required Action and ---------NOTE-------

associated Completion Time LCO 3.0.3 is not applicable.

of Condition A not met during -----------------

movement of irradiated fuel assemblies in the secondary C.1 Place OPERABLE SGT filter Immediately containment or during CORE train in operation.

ALTERATIONS.

OR (continued)

SUSQUEHANNA - UNIT 2 3.6-42 Amendment 4&-1-, 253

SGT System 3.6.4.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.2.1 Suspend movement of Immediately irradiated fuel assemblies in secondary containment.

AND C.2.2 Suspend CORE Immediately ALTERATIONS.

D. Two SGT subsystems D.1 Restore one SGT subsystem 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months inoperable in MODE 1, 2, to OPERABLE status.

or 3.

E. Required Action and E.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition D not met in MODE 1, 2, or 3. AND E.2 Be in MODE4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months

( continued)

SUSQUEHANNA - UNIT 2 3.6-43 Amendment 4-a-+, ~ . 253

SGT System 3.6.4.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. Two SGT subsystems F.1 ----NOTE------

inoperable during movement LCO 3.0.3 is not applicable.

of irradiated fuel assemblies in the secondary containment or during CORE Suspend movement of irradiated fuel Immediately ALTERATIONS. assemblies in secondary containment.

F.2 Suspend CORE Immediately ALTERA TIONS.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.3.1 Operate each SGT filter train for?:'. 15 continuous In accordance with the minutes with heaters operating. Surveillance Frequency Control Program SR 3.6.4.3.2 Perform required SGT filter testing in accordance In accordance with the VFTP with the Ventilation Filter Testing Program (VFTP).

SR 3.6.4.3.3 Verify each SGT subsystem actuates on an actual In accordance with the or simulated initiation signal. Surveillance Frequency Control Program SR 3.6.4.3.4 Verify each SGT filter cooling bypass and outside In accordance with the air damper opens and the fan starts on high Surveillance Frequency charcoal temperature. Control Program SUSQUEHANNA - UNIT 2 3.6-44 Amendment 4a4, ~ . ~ . 2-W, 253

CREOAS System 3.7.3 3.7 PLANT SYSTEMS 3.7.3 Control Room Emergency Outside Air Supply (CREOAS) System LCO 3.7.3 Two CREOAS subsystems shall be OPERABLE.

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

The control room envelope (CRE) boundary may be opened intermittently under administrative control.

APPLICABILITY: MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary containment, During CORE ALTERATIONS.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CREOAS subsystem A.1 Restore CREOAS subsystem to 7 days inoperable for reasons other OPERABLE status.

than Condition B.

B. One or more CREOAS 8.1 Initiate action to implement Immediately subsystems inoperable due mitigating actions to inoperable CRE boundary in MODES 1, 2, and 3. AND 8.2 Verify mitigating actions to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ensure CRE occupant exposures to radiological, chemical, and smoke hazards will not exceed limits.

AND 8.3 Restore CRE boundary to 90 days OPERABLE status.

SUSQUEHANA - UNIT 2 3.7-6 Amendment'-* 4++, ~ . 253

CREOAS System 3.7.3 ACTIONS (continued}

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A or B not met in AND MODE 1, 2, or 3.

C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months D. Required Action and -------NOTE-------

associated Completion Time LCO 3.0.3 is not applicable.

of Condition A not met during ----------------

movement of irradiated fuel assemblies in the secondary containment or during CORE D. 1 Place OPERABLE CREOAS Immediately AL TERA TIONS. subsystem in pressurization/

filtration mode.

OR D.2.1 Suspend movement of Immediately irradiated fuel assemblies in the secondary containment.

AND D.2.2 Suspend CORE Immediately ALTERATIONS.

E. Two CREOAS subsystems E.1 Enter LCO 3.0.3. Immediately inoperable in MODE 1, 2, or 3 for reasons other than Condition B.

(continued)

SUSQUEHANA - UNIT 2 3.7-7 Amendment 4a4, 47+, ~ . 253

CREOAS System 3.7.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. Two CREOAS subsystems ------NOTE------

inoperable during movement LCO 3.0.3 is not applicable.

of irradiated fuel assemblies in the secondary containment or during F.1 Suspend movement of Immediately CORE ALTERATIONS. irradiated fuel assemblies in the secondary containment.

OR One or more CREOAS F.2 Suspend CORE Immediately subsystems inoperable due ALTERATIONS.

to an inoperable CRE boundary during movement of irradiated fuel assemblies in the secondary containment or during CORE AL TERATIONS.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY In accordance with the SR 3. 7 .3.1 Operate each CREOAS tilter train for ~ 15 Surveillance Frequency continuous minutes with the heaters operating.

Control Program SR 3.7.3.2 Perform required CREOAS tilter testing in In accordance with the VFTP accordance with the Ventilation Filter Testing Program (VFTP).

In accordance with the SR 3.7.3.3 Verify each CREOAS subsystem actuates on an Surveillance Frequency actual or simulated initiation signal.

Control Program (continued)

SUSQUEHANA - UNIT 2 3.7-8 Amendment 454, 4-7-7, ~ . ~ . ~ . 253

Control Room Floor Cooling System 3.7.4

3. 7 PLANT SYSTEMS

3. 7.4 Control Room Floor Cooling System LCO 3.7.4 Two control room floor cooling subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary containment, During CORE ALTERATIONS.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One control room floor A.1 Restore control room floor 30 days cooling subsystem cooling subsystem to inoperable. OPERABLE status.

B. Required Action and B.1 Bein MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A not met in AND MODE 1, 2, or 3.

B.2 Bein M0DE4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued)

SUSQUEHANNA - UNIT 2 3.7-10 Amendment 4-a-1-, 253

Control Room Floor Cooling System 3.7.4 ACTIONS (continued}

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

associated Completion Time LCO 3.0.3 is not applicable.

of Condition A not met during ------------------

movement of irradiated fuel assemblies in the secondary containment or during CORE C.1 Place OPERABLE control Immediately AL TERATIONS. room floor cooling subsystem in operation.

OR C.2.1 Suspend movement of Immediately irradiated fuel assemblies in the secondary containment.

AND C.2.2 Suspend CORE Immediately AL TERATIONS.

D. Two control room floor D.1 Enter LCO 3.0.3. Immediately cooling subsystems inoperable in MODE 1, 2, or 3.

(continued)

SUSQUEHANNA - UNIT 2 3.7-11 Amendment 454-, 253

Control Room Floor Cooling System 3.7.4 ACTIONS (continued}

CONDITION REQUIRED ACTION COMPLETION TIME E. Two control room floor -------NOTE-------

cooling subsystems LCO 3.0.3 is not applicable.

inoperable during movement - - - - - - - - - - - - - - - - - -

of irradiated fuel assemblies in the secondary containment or during CORE E.1 Suspend movement of Immediately ALTERATIONS. irradiated fuel assemblies in the secondary containment.

AND E.2 Suspend CORE Immediately ALTERATIONS.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3. 7.4.1 Verify each control room floor cooling subsystem In accordance with the has the capability to remove the assumed heat Surveillance Frequency load. Control Program SUSQUEHANNA - UNIT 2 3.7-12 Amendment 4a4, ~ . 253

AC Sources-Shutdown 3.8.2 ACTIONS

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

LCO 3.0.3 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required AC -------NOTE-------

Sources inoperable. Enter applicable Condition and Required Actions of LCO 3.8.8, with one required subsystem de-energized as a result of Condition A.

A.1 Declare affected required Immediately feature(s), inoperable.

OR A.2.1 Suspend CORE Immediately ALTERATIONS.

A.2.2 Suspend movement of Immediately irradiated fuel assemblies in the secondary containment.

A.2.3 Initiate action to restore Immediately required AC Source to OPERABLE status.

SUSQUEHANNA - UNIT 2 3.8-20 Amendment~. 253

DC Sources-Shutdown 3.8.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.2 Suspend movement of Immediately irradiated fuel assemblies in the secondary containment.

AND A.2.3 Initiate action to restore Immediately required Unit 2 DC electrical power subsystems to OPERABLE status.

B. Diesel Generator E DC B.1 Verify that all ESW valves 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months electrical power associated with Diesel subsystem inoperable, Generator E are closed.

while not aligned to the Class 1E distribution system.

C. Diesel Generator E DC C.1 Declare Diesel Generator E 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months electrical power inoperable.

subsystem inoperable, while aligned to the Class 1E distribution system.

(continued)

SUSQUEHANNA - UNIT 2 3.8-35 Amendment 4a4-, 253

DC Sources-Shutdown 3.8.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. -----NOTE----- D.1 Declare affected required Immediately Not applicable to DG E DC feature(s) inoperable electrical power subsystem.

One or more inoperable OR required Unit 1 DC electrical power subsystem.

D.2.1 Suspend CORE Immediately ALTERATIONS.

AND D.2.2 Suspend movement of Immediately irradiated fuel assemblies in the secondary containment.

D.2.3 Initiate action to restore Immediately required DC electrical power subsystems to OPERABLE status.

(continued)

SUSQUEHANNA - UNIT 2 3.8-36 Amendment4a4, 253

Distribution Systems - Shutdown 3.8.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) --------------------NOTE-----------------

Enter applicable Conditions and Required Actions of LCO 3.5.2 "Reactor Pressure Vessel (RPV)

Water Inventory Control" when Condition A renders an ECCS subsystem Inoperable.

A.2.1 Suspend CORE Immediately ALTERATIONS.

A.2.2 Suspend handling of Immediately irradiated fuel assemblies in the secondary containment.

A.2.3 Initiate actions to restore Immediately required AC and DC electrical power distribution subsystems to OPERABLE status.

A.2.4 Declare associated required Immediately shutdown cooling subsystem(s) inoperable and not in operation.

(continued)

SUSQUEHANNA - UNIT 2 3.8-51 Amendment 4-a+, 253

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION RELATED TO AMENDMENT NO. 271 TO RENEWED FACILITY OPERATING LICENSE NO. NPF-14 AND AMENDMENT NO. 253 TO RENEWED FACILITY OPERATING LICENSE NO. NPF-22 SUSQUEHANNA NUCLEAR, LLC ALLEGHENY ELECTRIC COOPERATIVE, INC.

SUSQUEHANNA STEAM ELECTRIC STATION, UNITS 1 AND 2 DOCKET NOS. 50-387 AND 50-388

1.0 INTRODUCTION

By application dated September 20, 2017, 1 as supplemented by letters dated February 16, 2018, 2 and May 15, 2018, 3 Susquehanna Nuclear, LLC (the licensee), requested to adopt Technical Specifications Task Force (TSTF) Traveler TSTF-542, Revision 2, "Reactor Pressure Vessel Water Inventory Control," 4 which changes the Technical Specifications (TSs) for Susquehanna Steam Electric Station Units 1 and 2 (Susquehanna). Traveler TSTF-542, Revision 2, was approved by the U.S. Nuclear Regulatory Commission (NRC or the Commission) on December 20, 2016. 5 The proposed changes would replace existing TS requirements associated with "operations with a potential for draining the reactor vessel [OPDRVs]," with revised TSs providing alternative requirements for reactor pressure vessel (RPV) water inventory control (WIC). These alternative requirements would protect Safety Limit TS 2.1.1.3, which states, "Reactor vessel water level shall be greater than the top of active irradiated fuel."

Additionally, a new definition "DRAIN TIME," would be added to the Susquehanna TSs, Section 1.1, "Definitions." Drain Time would establish requirements for the licensee to make RPV water level inventory determinations and to calculate RPV water inventory drain rates for 1 Agencywide Documents Access and Management System (ADAMS) Package Accession No. ML17265A434 2 ADAMS Accession No. ML18052A579 3 ADAMS Accession No. ML18136A525 4 ADAMS Accession No. ML16074A448 5 ADAMS Accession No. ML163439008 Enclosure 3

Modes 4 and 5 outage-related activities. Adequate licensee management of secondary containment requirements or mitigation of certain emergency core cooling system (ECCS) safety injection/spray systems during Modes 4 and 5 requires a properly calculated drain time.

The licensee has proposed several variations from the TS changes described in applicable parts of TSTF-542, or the NRG-approved TSTF-542 safety evaluation. These are described in this safety evaluation (SE) in Section 2.2.5 and evaluated in Section 3.5.

The supplements dated February 16, 2018, and May 15, 2018, provided additional information that clarified the application, did not expand the scope of the application as originally noticed, and did not change the NRC staff's original proposed no significant hazards consideration determination as published in the Federal Register on November 21, 2017 (82 FR 55414).

2.0 REGULATORY EVALUATION

2.1 System Description The boiling water reactor (BWR) RPVs have a number of penetrations located below the top of active fuel (TAF). These penetrations provide entry for control rods, recirculation flow, and shutdown cooling (SDC). Since these penetrations are below the TAF, this creates a potential to drain the reactor vessel water inventory and lose effective core cooling. The loss of water inventory and effective core cooling can potentially lead to fuel cladding failure and radioactive release.

During operation in Mode 1 (Power Operation - Reactor Mode Switch in Run), Mode 2 (Startup

- Reactor Mode Switch in Refuel 6 or Startup/Hot Standby), and Mode 3 (Hot Shutdown 6 -

Reactor Mode Switch in Shutdown and average reactor coolant temperature > 200 degrees Fahrenheit (°F)), the TSs for instrumentation and emergency core cooling systems require operability of sufficient equipment to ensure large quantities of water will be injected into the vessel, should level decrease below the preselected value. These requirements are designed to mitigate the effects of a loss-of-coolant accident (LOCA) but also provide protection for other accidents and transients that involve a water inventory loss.

During BWR operation in Mode 4 (Cold Shutdown 6 - Reactor Mode Switch in Shutdown and average reactor coolant temperature s 200 °F) and Mode 5 (Refueling 7 - Reactor Mode Switch in Shutdown or Refuel), the pressures and temperatures that could cause a LOCA are not present. During certain phases of refueling (Mode 5), a large volume of water is available above the RPV (i.e., the RPV head is removed), and the water level is~ 22 feet over the top of the RPV flange with the spent fuel storage pool gates removed.

The large volume of water available in and above the RPV (during much of the time when in Mode 5) provides time for operator detection and manual operator action to stop and mitigate an RPV draining event. However, typically at other times during a refueling outage during Cold Shutdown (Mode 4) or Refueling (Mode 5), there may be a potential for significant drainage paths from certain outage activities, human error, and other events when it is more likely to have some normally available equipment, instrumentation, and systems inoperable due to maintenance and outage activities. There may not be as much time for operator action as compared to times when there are large volumes of water above the RPV.

6 All reactor vessel head closure bolts fully tensioned 7 One or more reactor vessel head closure bolts less than fully tensioned

In comparison to Modes 1, 2, and 3, with typical high temperatures and pressures (especially in Modes 1 and 2), Modes 4 and 5 generally do not have the high pressure and temperature considered necessary for a LOCA envisioned from a high energy pipe failure. Thus, while the potential sudden loss of large volumes of water from a LOCA are not expected, operators monitor for BWR RPV water level decrease from potentially significant or unexpected drainage paths. These potential drainage paths in Modes 4 and 5 generally would require less water replacement capability to maintain water above TAF.

To address the draindown potential during Modes 4 and 5, the current Susquehanna TSs contain specifications that are applicable during an OPDRV, or require suspension of OPDRVs, if certain equipment is inoperable. The term OPDRV is not specifically defined in the TSs and historically has been subject to inconsistent application by licensees. The changes discussed in this SE are intended to resolve any ambiguity by creating a new RPV WIC TS with attendant equipment operability requirements, required actions, and surveillance requirements (SRs), and delete references to OPDRVs throughout the TSs.

2.2 Changes to the TSs Section 2.2.1 describes the proposed addition of a new definition, "DRAIN TIME."

Section 2.2.2 describes the proposed revision to TS 3.3, "Instrumentation," including the proposed revision to: (1) TS 3.3.5.1, "Emergency Core Cooling System (ECCS)

Instrumentation," (2) the proposed addition of new TS 3.3.5.2, "Reactor Pressure Vessel (RPV)

Water Inventory Control Instrumentation" (including Table 3.3.5.2-1 ), (3) renumbering existing TS 3.3.5.2, "Reactor Core Isolation Cooling (RCIC) System Instrumentation," to 3.3.5.3, and (4) revisions to existing TS 3.3.6.1, "Primary Containment Isolation Instrumentation" (including Table 3.3.6.1-1 ).

Section 2.2.3 describes the proposed revision to TS 3.5, "Emergency Core Cooling System (ECCS) and Reactor Core Isolation Cooling (RCIC) System," including a proposed revision to TS 3.5.2, "ECCS - Shutdown."

Section 2.2.4 describes the proposed deletion of existing TS references to OPDRVs.

Section 2.2.5 describes Susquehanna plant-specific variations to TSTF-542, Revision 2.

The descriptions of the proposed changes are provided in this section. A summary statement of the bases or reasons for such specifications, other than those covering administrative controls, were also included in the application, but these bases will not become part of the TSs.

2.2.1 Insertion of New Definition of Drain Time The following definition of "DRAIN TIME" would be added to Section 1.1, "Definitions":

The DRAIN TIME is the time it would take for the water inventory in and above the Reactor Pressure Vessel (RPV) to drain to the top of the active fuel (TAF) seated in the RPV assuming:

a) The water inventory above the TAF is divided by the limiting drain rate;

b) The limiting drain rate is the larger of the drain rate through a single penetration flow path with the highest flow rate, or the sum of the drain rates through multiple penetration flow paths susceptible to a common mode failure (e.g., seismic event, loss of normal power, single human error), for all penetration flow paths below the T AF except:

1. Penetration flow paths connected to an intact closed system, or isolated by manual or automatic valves that are locked, sealed, or otherwise secured in the closed position, blank flanges, or other devices that prevent flow of reactor coolant through the penetration flow paths;

2. Penetration flow paths capable of being isolated by valves that will close automatically without offsite power prior to the RPV water level being equal to the TAF when actuated by RPV water level isolation instrumentation; or

3. Penetration flow paths with isolation devices that can be closed prior to the RPV water level being equal to the TAF by a dedicated operator trained in the task, who in continuous communication with the control room, is stationed at the controls, and is capable of closing the penetration flow path isolation device without offsite power.

c) The penetration flow paths required to be evaluated per paragraph b) are assumed to open instantaneously and are not subsequently isolated, and no water is assumed to be subsequently added to the RPV water inventory; d) No additional draining events occur; and e) Realistic cross-sectional areas and drain rates are used.

A bounding DRAIN TIME may be used in lieu of a calculated value.

2.2.2 Changes to TS Section 3.3, Instrumentation The following subsections describe the existing and proposed changes to the Susquehanna TSs, Section 3.3, "Instrumentation."

2.2.2.1 TS 3.3.5.1, "Emergency Core Cooling System (EGGS) Instrumentation" Proposed changes to TS 3.3.5.1 include the deletion of Note 1 in Required Actions 8.1 and C.1, which states:

Only applicable in MODES 1, 2, and 3.

As a result, the numbering for Note 2 would be removed with no change in the note.

For TS Table 3.3.5.1-1, the applicability in Modes 4 and 5 was proposed for deletion because the instrumentation requirements during shutdown would be consolidated into the new TS 3.3.5.2, "RPV Water Inventory Control Instrumentation." Modes 4 and 5 applicability and associated requirements would be deleted for the following functions:

1. Core Spray System:

(a) Reactor Vessel Water Level - Low Low Low, Level 1 (c) Reactor Steam Dome Pressure - Low (initiation)

(d) Reactor Steam Dome Pressure - Low (injection permissive)

(e) Manual Initiation

2. Low Pressure Coolant Injection (LPCI) System:

(a) Reactor Vessel Water Level - Low Low Low, Level 1 (c) Reactor Steam Dome Pressure - Low (initiation)

(d) Reactor Steam Dome Pressure - Low (injection permissive)

(f) Manual Initiation Table 3.3.5.1-1 Footnote (a), which states, "When the associated subsystem(s) are required to be OPERABLE," would be deleted. As a result, existing Footnotes (b), (c), (d), and (e) would be renumbered (a), (b), (c), and (d), respectively.

2.2.2.2 New TS 3.3.5.2, "Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation" The proposed new TS 3.3.5.2 would contain existing 'ECCS and Primary Containment Isolation' instrumentation functions that are relocated from TSs 3.3.5.1 and 3.3.6.1, as well as new requirements. The proposed new TS 3.3.5.2 is shown below.

3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation LCO 3.3.5.2 The RPV Water Inventory Control instrumentation for each Function in Table 3.3.5.2-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.5.2-1.

ACTIONS

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Enter the Condition Immediately channels referenced in Table inooerable. 3.3.5.2-1 for the channel.

B. As required by B.1 Declare associated Immediately Required Action penetration flow path( s)

A.1 and incapable of automatic referenced in isolation.

Table 3.3.5.2-1.

AND 8.2 Calculate DRAIN TIME. Immediately

C. As required by C.1 Place channel in trip. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Required Action A.1 and referenced in Table 3.3.5.2-1.

D. As required by D. 1 Restore channel to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Required Action OPERABLE status.

A.1 and referenced in Table 3.3.5.2-1.

E. Required Action E.1 Declare associated low Immediately and associated pressure ECCS Completion injection/spray Time of subsystem inoperable.

Condition C or D not met.

SURVEILLANCE REQUIREMENTS

N()TE----------------------------------------------------

Refer to Table 3.3.5.2-1 to determine which SRs apply for each ECCS Function.

SURVEILLANCE FREQUENCY SR 3.3.5.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Prooram SR 3.3.5.2.2 In accordance with

NOTE------------------------ the Surveillance A test of all required contacts does not Frequency Control have to be performed. Program Perform CHANNEL FUNCTl()NAL TEST.

SR 3.3.5.2.3 Perform L()GIC SYSTEM FUNCTIONAL In accordance with TEST. the Surveillance Frequency Control Program Table 3.3.5.2-1 (Page 1 of 1)

RPV W at er Inven tory Con t ro I Inst rumen taf10n FUNCTION APPLICABLE REQUIRED CONDITIONS SURVEILLANCE ALLOWABLE MODES CHANNELS REFERENCED REQUIREMENTS VALUE OR OTHER PER FROM SPECIFIED FUNCTION REQUIRED CONDITIONS ACTION A.1

1. Core Spray System

a. Reactor Steam Dome 4,5 4 (a) C SR 3.3.5.2.2 s 433 psig Pressure - Low SR 3.3.5.2.3 (upper)

(Injection Permissive)

b. Manual Initiation 4,5 1 per D SR 3.3.5.2.3 NA subsvstem (a)

2. Low Pressure Coolant Injection (LPCI) System

a. Reactor Steam Dome 4,5 4 (a) C SR 3.3.5.2.2 s 433 psig Pressure - Low SR 3.3.5.2.3 (upper)

(Injection Permissive)

b. Manual Initiation 4,5 1 per D SR 3.3.5.2.3 NA subsystem (a)

3. RHR System Isolation

a. Reactor Vessel Water (b) 2 in one trip B SR 3.3.5.2.1 ~ 11.5 inches Level - Low, Level 3 system SR 3.3.5.2.2 SR 3.3.5.2.3

4. Reactor Water Cleanup (RWCU) System Isolation

a. Reactor Vessel Water (b) 2 in one trip B SR 3.3.5.2.1 ~ - 45 inches Level - Low Low, system SR 3.3.5.2.2 Level2 SR 3.3.5.2.3 a) Associated with an ECCS subsystem required to be OPERABLE by LCO 3.5.2, "Reactor Pressure Vessel (RPV) Water Inventory Control."

b) When automatic isolation of the associated penetration flow path(s) is credited in calculating DRAIN TIME.

2.2.2.3 TS 3.3.5.2, "Reactor Core Isolation Cooling (RCIC) System Instrumentation" The existing TS 3.3.5.2, "Reactor Core Isolation Cooling (RCIC) System Instrumentation," and its subsection, would be renumbered to TS 3.3.5.3 in order to maintain the TS numbering conventions.

2.2.2.4 TS 3.3.6.1, "Primary Containment Isolation Instrumentation" In Limiting Conditions for Operation (LCO) 3.3.6.1, Required Action J.2 was proposed to be deleted since it was associated with the isolation of residual heat removal (RHR) SDC during Modes 4 and 5. In addition, TS Table 3.3.6.1-1, Function 6.b, Shutdown Cooling System Isolation, Reactor Vessel Water Level - Low, Level 3, and Function 6.c, Shutdown Cooling System Isolation, Manual Initiation, the applicability in Modes 4 and 5 was proposed for deletion.

Also, Table 3.3.6.1-1, Footnote (c), "Only one trip system required in MODES 4 and 5 when RHR Shutdown Cooling System integrity maintained," was proposed to be deleted, as it is applicable only to Functions 6.b and 6.c during Modes 4 and 5. Function 6.b would move to the new TS Table 3.3.5.2-1, Function 3.a, as shown in Section 2.2.2.2 of this SE. Function 6.c is further described in Section 2.2.5. 7 (Variation 7) of this SE.

2.2.3 TS Section 3.5, "Emergency Core Cooling Systems (EGGS) and Reactor Core Isolation Cooling (RCIC) System" The title of Susquehanna TS Section 3.5 would be revised from "Emergency Core Cooling Systems (ECCS) and Reactor Core Isolation Cooling (RCIC) System" to "Emergency Core Cooling Systems (ECCS), Reactor Pressure Vessel (RPV) Water Inventory Control, and Reactor Core Isolation Cooling (RCIC) System."

The title of Susquehanna TS Section 3.5.2 would be revised from "ECCS - Shutdown" to "Reactor Pressure Vessel (RPV) Water Inventory Control," and TS 3.5.2 would be revised as follows:

LCO 3.5.2 DRAIN TIME of RPV water inventory to the top of active fuel (TAF) shall be ~ 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

One low pressure ECCS injection/spray subsystem shall be OPERABLE.

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

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.

APPLICABILITY: MODES 4 and 5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required ECCS A.1 Restore required ECCS 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months injection/spray injection/spray subsystem to subsystem OPERABLE status.

8. Required Action and 8.1 Initiate action to establish a Immediately associated method of water injection Completion Time of capable of operating without Condition A not met. offsite electrical power.

C. DRAIN TIME < 36 C.1 Verify secondary 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months hours and~ 8 containment boundary is hours. capable of being established in less than the DRAIN TIME.

AND 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months C.2 Verify each secondary containment penetration flow path is capable of being isolated in less than the DRAIN TIME.

AND 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months C.3 Verify one standby gas treatment subsystem is capable of being placed in operation in less than the nRAIN TII\AI=

D. DRAIN TIME D. 1---------------N()TE---------------------

< 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . Required ECCS injection/spray subsystem or additional method of water injection shall be capable of operating without offsite electrical power.

Initiate action to establish an Immediately additional method of water injection with water sources capable of maintaining RPV water level> TAF for~ 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

AND D.2 Initiate action to establish Immediately secondary containment boundary.

AND D.3 Initiate action to isolate each Immediately secondary containment penetration flow path or verify it can be manually isolated from the control room.

AND D.4 Initiate action to verify one Immediately standby gas treatment subsystem is capable of being placed in operation.

E. Required Action and E.1 Initiate action to restore DRAIN Immediately associated TIME to ~ 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

Completion Time of Condition C or D not met.

OR DRAIN TIME< 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

The proposed SRs for TS 3.5.2 are shown below.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify DRAIN TIME ~ 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . In accordance with the Surveillance Frequency Control Program SR 3.5.2.2 Verify, for a required low pressure coolant In accordance with the injection (LPCI) subsystem, the Surveillance suppression pool water level is ~ 20 ft 0 Frequency Control inches. Program SR 3.5.2.3 Verify, for a required Core Spray (CS) In accordance with the subsystem, the: Surveillance Frequency Control

a. Suppression pool water level is ~ 20 Program ft O inches; or

b. Condensate storage tank water level is~ 49% of capacity.

SR 3.5.2.4 Verify, for the required ECCS In accordance with the injection/spray subsystem, the piping is Surveillance filled with water from the pump discharge Frequency Control valve to the injection valve. Program SR 3.5.2.5 Verify, for the required ECCS In accordance with the injection/spray subsystem, each manual, Surveillance power operated, and automatic valve in Frequency Control the flow path, that is not locked, sealed, or Program otherwise secured in position, is in the correct position.

SR 3.5.2.6 Operate the required ECCS In accordance with the injection/spray subsystem through the Surveillance recirculation line for ~ 10 minutes. Frequency Control Program SR 3.5.2.7 Verify each valve credited for In accordance with the automatically isolating a penetration flow Surveillance path actuates to the isolation position on Frequency an actual or simulated isolation signal. Control Program SR 3.5.2.8 ----------------------------N()TE--------------------

Vessel injection/spray may be excluded.

In accordance with the

Surveillance Verify the required ECCS injection/spray Frequency subsystem actuated on a manual initiation Control Program signal.

2.2.4 Deletion of References to OPDRVs and Other Miscellaneous Changes 2.2.4.1 Deletion of References to OPDRVs The licensee proposed to revise existing TS requirements related to "operations with a potential for draining the reactor vessel" or "OPDRVs," or if certain conditions are not met, the required actions direct the licensee to "initiate action to suspend operations with a potential for draining the reactor vessel (OPDRVs)" with new requirements on RPV WIC that will protect Safety Limit 2.1.1.3. To remain consistent with TSTF-542, all references to the term OPDRVs in the Susquehanna TSs would be deleted. The TS locations of these references are summarized as follows:

Susquehanna LCO Location of OPDRVs References 3.3.6.1 Primary Containment Isolation Required Action J.2 Instrumentation Table 3.3.6.1-1 Footnote (c)

(Previously described in Section 2.2.2.4 of this SE) 3.3.6.2 Secondary Containment Isolation Table 3.3.6.2-1 Footnote (a)

Instrumentation 3.3.7.1 Control Room Emergency Outside Table 3.3. 7.1-1 Footnote (a)

Air Supply System Instrumentation 3.6.1.3 Primary Containment Isolation .Applicability, Conditions G and H Valves (PC IVs) 3.6.4.1 Secondary Containment Applicability, Condition C 3.6.4.2 Secondary Containment Isolation Applicability, Condition E Valves (SCIVs) 3.6.4.3 Standby Gas Treatment (SGT) Applicability, Conditions C and F System 3.7.3 Control Room Emergency Outside Applicability, Conditions D and F Air Supply (CREOAS) System 3.7.4 Control Room Floor Cooling Applicability, Conditions C and E System 3.8.2 AC Sources - Shutdown Condition A (Required Action A.2.3 is deleted) 3.8.5 DC Sources - Shutdown Condition A (Required Action A.2.3 is deleted)

(Required Action D.2.3 is deleted for Unit 2 only) 3.8.8 Distribution Systems - Shutdown Condition A (Required Action A.2.3 is deleted) 2.2.4.2 Other Miscellaneous Changes The licensee corrected the existing TS LCO 3.8.8, Required Action 'A', note, which states:

1'\JOTE--------------------------------------------

Enter applicable Conditions and Required Actions of LCO 3.5.2 "ECCS Shutdown" when Condition A renders an ECCS subsystem Inoperable.

The proposed changes state:

1\J()TE----------------------------------------------------------

Enter applicable Conditions and Required Actions of LCO 3.5.2 "Reactor Pressure Vessel (RPV) Water Inventory Control" when Condition A renders an ECCS subsystem Inoperable.

2.2.5 Susquehanna Plant-Specific TSTF-542 TS Variations In Section 2.2 of Enclosure 1 to the license amendment request for Susquehanna, the licensee identified several plant-specific TS variations from TSTF-542, Revision 2, or the l'JRC-approved TSTF-542 SE. The licensee states these variations do not affect the applicability of TSTF-542 or the l'JRC staff's SE to the proposed license amendment.

2.2.5.1 Variation 1, TS LCO 3.5.2 Note, LPG/ Alignment The note on TS LC() 3.5.2 regarding realignment to the low pressure Injection mode is currently located in TS SR 3.5.2.4 but is proposed to be relocated to the LC(). The intent of the note was to allow LPCI subsystems to be considered operable during this condition.

2.2.5.2 Variation 2, TS Table 3.3.5.1-1, CS and LPG/ Pumps Discharge Flow Low (Bypass)

Standard TS Table 3.3.5.1-1, Function 1.d, "Core Spray Pump Discharge Flow - Low (Bypass),"

and Function 2.g, "Low Pressure Coolant Injection Pump- Discharge Flow - Low (Bypass)," are not included in the Susquehanna TSs. The minimum flow instruments are provided to protect the associated low pressure ECCS pump from overheating when the pump is operating and the associated injection valve is not fully open. The minimum flow line valve is opened when low flow is sensed, and the valve is automatically closed when the flow rate is adequate to protect the pump.

2.2.5.3 Variation 3, TS Table 3.3.5.1-1, Reactor Steam Dome Pressure- Low (Initiation)

Susquehanna TS Table 3.3.5.1-1 includes Functions 1.c and 2.c, "Reactor Steam Dome Pressure - Low (initiation)," that are not included in the standard TS. Low reactor steam dome pressure signals (Functions 1.c, 1.d, 2.c, and 2.d) are used as permissives for the low pressure ECCS subsystems. The low reactor pressure permissive is provided to prevent a high drywell pressure condition that is not accompanied by low reactor pressure (i.e., a false LOCA signal) from disabling two RHR pumps on the other unit. Functions 1.c and 2.c are not required to ensure manual initiation of CS and LPCI and are, therefore, not included in the new Table 3.3.5.2-1.

2.2.5.4 Variation 4, Standard TS SR 3.3.5.1. 7, EGGS Response Time The Susquehanna TSs do not include standard TS SR 3.3.5.1. 7 (verify the ECCS response time is within limits); however, similar requirements are included in Susquehanna SRs 3.5.1.13 and 3.5.2. 7 (verify the ECCS response time for each ECCS injection/spray subsystem is within limit). As described in the discussion in Section 3.3.3 of the TSTF-542 justification, since a draining event is not an analyzed accident, there are no accident analysis assumptions with respect to response time. In addition, response times are insignificant compared to draindown times (seconds vs. hours). ()n this basis, the existing SR 3.5.2.7 is being deleted.

2.2.5.5 Variation 5, TS SR 3.3.5.2.2 Note, Test of All Required Contacts A note was added to TS SR 3.3.5.2.2 to state, "A test of all required contacts does not have to be performed." This note is included in the existing channel functional test surveillance in TS 3.3.5.1 (SR 3.3.5.1.2) and TS 3.3.6.1 (SR 3.3.6.1.2) for the affected functions included in TS 3.3.5.2. The Bases for these SRs state that the exception is necessary because the design of instrumentation does not facilitate functional testing of all required contacts of the relay that input into the combinational logic, and that performance of such a test could result in a plant transient or place the plant in an undue risk situation. Therefore, for this SR, the channel functional test verifies acceptable response by verifying the change of state of the relay that inputs into the combinational logic. The required contacts not tested during the channel functional test are tested under the logic system functional test, SR 3.3.5.1.5 (or SR 3.3.6.1.5).

2.2.5.6 Variation 6, TS Table 3.3.5.1-1, Channel Checks The current Susquehanna TSs do not include Channel Checks for Table 3.3.5.1-1, Functions 1.d and 2.d (Reactor Steam Dome Pressure - Low (Injection Permissive)); therefore, no Channel Checks SR was added for these functions in the new Table 3.3.5.2-1 (Functions 1.a and 2.a).

2.2.5.7 Variation 7, TS Table 3.3.6.1-1, Manual Initiation, Function 6.c Susquehanna Table 3.3.6.1-1, "Primary Containment Isolation Instrumentation," includes Function 6.c, "Manual Initiation," which is not included in the standard TS. Modes 4 and 5 applicability is being removed from this function, and the footnote is correspondingly being removed from the required channels per trip system column. The SOC system can be isolated without the primary containment isolation instrumentation function; this is consistent with the basis for eliminating the applicability during OPORVs from the Manual Initiation function associated with secondary containment isolation as described in Section 3.4.1.3 of the TSTF-542 justification.

2.2.5.8 Variation 8, TS Table 3.3. 7.1-1, Manual Initiation, Function 9 Susquehanna Table 3.3. 7.1-1, "Control Room Emergency Outside Air Supply System Instrumentation," includes Function 9, "Manual Initiation," which is not included in the standard TS. Function 9 is applicable during OPORVs. The applicability during OPDRVs is eliminated.

The CREOAS system can be initiated without the associated instrumentation function; this is consistent with the basis for eliminating the applicability during OPORVs from the Manual Initiation function associated with secondary containment isolation as described in Section 3.4.1.3 of the TSTF-542 justification.

2.2.5.9 Variation 9, TS 3.6.1.3, Applicability and SRs Deletions Susquehanna TS 3.6.1.3, "Primary Containment Isolation Valves," is currently applicable in Modes 1, 2, and 3, and when associated instrumentation is required to be operable per LCO 3.3.6.1, "Primary Containment Isolation Instrumentation." However, TSTF-542 deletes from Table 3.3.6.1-1 the Mode 4 and 5 requirement for SOC system isolation. As a result, TS 3.6.1.3 will no longer require any PCIVs to be operable in Modes 4 or 5. Therefore, Susquehanna proposes to revise the applicability to Modes 1, 2, and 3 and delete Condition H, which is applicable in Modes 4 and 5. In addition, the unnecessary reference to Modes 1, 2, or 3 in Condition G and SRs 3.6.1.3.1, 3.6.1.3.6, 3.6.1.3.11, 3.6.1.3.12, and 3.6.1.3.13 is

deleted since LCO 3.6.1.3 is applicable only in Modes 1, 2, and 3. These changes are administrative in nature and are justified on the basis that TSTF-542 removed the Mode 4 and 5 applicability from LCO 3.6.1.3.

2.2.5.10 Variation 10, TS 3.6.4.1 and TS 3.6.4.3, Removal of One-Time Completion Time TS 3.6.4.1, Condition A, and TS 3.6.4.3, Condition D, for both Units 1 and 2, include a one-time completion time that expired on December 31, 2005. The note states, "48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months for a one-time outage for replacement of the Reactor Building Recirculating Fan Damper Motors, to be completed by December 31, 2005." The licensee proposes to delete these notes that no longer apply.

2.3 Applicable Regulatory Requirements The regulation at Title 10 of the Code of Federal Regulations (10 CFR) Section 50.36(a)(1 ),

requires an applicant for an operating license to include in the application proposed TSs in accordance with the requirements of 10 CFR 50.36. The applicant must also include in the application a "summary statement of the bases or reasons for such specifications, other than those covering administrative controls." However, per 10 CFR 50.36(a)(1), these TS bases "shall not become part of the technical specifications."

As required by 10 CFR 50.36(c)(1)(i)(a), TSs will include items in the following categories:

( 1) Safety limits, limiting safety system settings, and limiting control settings. (i)(A) Safety limits for nuclear reactors are limits upon important process variables that are found to be necessary to reasonably protect the integrity of certain of the physical barriers that guard against the uncontrolled release of radioactivity. If any safety limit is exceeded, the reactor must be shut down. The licensee shall notify the Commission, review the matter, and record the results of the review, including the cause of the condition and the basis for corrective action taken to preclude recurrence. Operation must not be resumed until authorized by the Commission.

As required by 10 CFR 50.36(c)(2)(i), the TSs will include LCOs, which are the lowest functional capability or performance levels of equipment required for safe operation of the facility. Per 10 CFR 50.36(c)(2)(i), when an LCO of a nuclear reactor is not met, the licensee shall shut down the reactor or follow any remedial action permitted by the TSs until the condition can be met.

As required by 10 CFR 50.36(c)(2)(ii), licensees establish TS LCOs for items meeting one or more of the listed criteria. Specifically, Criterion 4, "A structure, system, or component which operating experience or probabilistic risk assessment has shown to be significant to public health and safety," supports the establishment of LCOs for RPV WIC due to insights gained by operating experience.

As required by 10 CFR 50.36(c)(3), TSs include items in the category of SRs, which 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 LCOs will be met.

As required by 10 CFR 50.90, whenever a holder of an operating license desires to amend the license, application for an amendment must be filed with the Commission fully describing the changes desired, and following, as far as applicable, the form prescribed for original

applications. The technical information to be included in an application for an operating license is governed in particular by 10 CFR 50.34(b).

As required by 10 CFR 50.92(a), in determining whether an amendment to a license will be issued to the applicant, the Commission will be guided by the considerations that govern the issuance of initial licenses to the extent applicable and appropriate. The general considerations that guide the Commission include, as stated in 10 CFR 50.40(a), how the TSs provide reasonable assurance that the health and safety of the public will not be endangered. Also, to issue an operating license of which TSs are a part, the Commission must make the findings of 10 CFR 50.57, including the 10 CFR 50.57(a)(3)(i) finding that there is reasonable assurance that the activities authorized by the operating license can be conducted without endangering the health and safety of the public.

NUREG-1433, "Standard Technical Specifications, General Electric BWR/4 Plants," Volume 1, 8 "Specifications," and Volume 2, "Bases," 9 Revision 4, dated April 2012, contains the standard TS for BWR/4 plants and is part of the regulatory standardization effort. The NRC staff prepared standard TS for each of the light-water reactor nuclear designs.

The NRC staffs guidance for review of TSs is in Chapter 16, "Technical Specifications," of NUREG-0800, Revision 3, "Standard Review Plan for the Review of Safety Analysis Reports for Nuclear Power Plants" (Standard Review Plan), dated March 2010. 10 The regulations in Appendix A to 10 CFR Part 50, "General Design Criteria for Nuclear Power Plants" (hereinafter referred to as GDC), establish the minimum requirements for the principal design criteria for water-cooled nuclear power plants. The principal design criteria establish the necessary design, fabrication, construction, testing, and performance requirements for structures, systems, and components important to safety.

GDC 13, "Instrumentation and Control," requires that instrumentation shall be provided to monitor variables and systems over their anticipated ranges for normal operation, for anticipated operational occurrences, and for accident conditions, as appropriate, to assure adequate safety, including those variables and systems that can affect the fission process, the integrity of the reactor core, the reactor coolant pressure boundary, and the containment and its associated systems. Appropriate controls shall be provided to maintain these variables and systems within prescribed operating ranges.

GDC 14, "Reactor Coolant Pressure Boundary," requires that the reactor coolant pressure boundary shall be designed, fabricated, erected, and tested so as to have an extremely low probability of abnormal leakage, of rapidly propagating failure, and of gross rupture.

GDC 30, "Quality of Reactor Coolant Pressure Boundary," requires that components that are part of the reactor coolant pressure boundary shall be designed, fabricated, erected, and tested to the highest quality standards practical. Means shall be provided for detecting and, to the extent practical, identifying the location of the source of reactor coolant leakage.

e ADAMS Accession No. ML12104A192 9 ADAMS Accession No. ML12104A193 10 ADAMS Accession No. ML100351425

GDC 33, "Reactor Coolant Makeup," requires that a system to supply reactor coolant makeup for protection against small breaks in the reactor coolant pressure boundary shall be provided. The system safety function shall be to assure that specified acceptable fuel design limits are not exceeded as a result of reactor coolant loss due to leakage from the reactor coolant pressure boundary and rupture of small piping or other small components that are part of the boundary.

The system shall be designed to assure that for onsite electric power system operation (assuming offsite power is not available) and for offsite electric power system operation (assuming onsite power is not available), the system safety function can be accomplished using the piping, pumps, and valves used to maintain coolant inventory during normal reactor operation.

GDC 35, "Emergency Core Cooling," requires a system to provide abundant emergency core cooling. The system safety function shall be to transfer heat from the reactor core following any loss of reactor coolant at a rate such that (1) fuel and clad damage that could interfere with continued effective core cooling is prevented and (2} clad metal-water reaction is limited to negligible amounts. Suitable redundancy in components and features, and suitable interconnections, leak detection, isolation, and containment capabilities shall be provided to assure that for onsite electric power system operation (assuming offsite power is not available}

and for offsite electric power system operation (assuming onsite power is not available), the system safety function can be accomplished, assuming a single failure.

3.0 TECHNICAL EVALUATION

3.1 Staff Evaluation of Proposed "DRAIN TIME" Definition The "DRAIN TIME" is the time it would take the RPV water inventory to drain from the current level to the TAF, assuming the most limiting of the RPV penetrations flow paths with the largest flow rate, or a combination of penetration flow paths that could open due to a common mode failure, were to open, and the licensee took no mitigating action.

The NRC staff reviewed the proposed drain time definition from TSTF-542. For the purpose of NRC staff considerations, the term "break" describes a pathway for water to drain from the RPV that has not been prescribed in the "DRAIN TIME" definition in TSTF-542. Based on information furnished by the licensee, the NRC staff has determined that the licensee is appropriately adopting the principles of drain time as specified in TSTF-542.

The NRC finds there is reasonable assurance that the licensee will include all RPV penetrations below the TAF in the determination of drain time as potential pathways. As part of this evaluation, the NRC staff reviewed requests for additional information used during the development of TSTF-542, Revision 2, which provided examples of bounding drain time calculations for three examples: (1) water level at or below the reactor flange, (2) water level above the RPV flange with fuel pool gates installed, and (3) water level above the RPV flange with fuel pool gates removed. The drain time is calculated by taking the water inventory above the break and dividing by the limiting drain rate until the TAF is reached. The limiting drain rate is a variable parameter, depending on the break size and the reduction of elevation head above break location during the draindown event. The discharge point will depend on the lowest potential drain point for each RPV penetration flow path on a plant-specific basis. This calculation provides a conservative approach to determining the drain time of the RPV.

The NRC staff concluded that the licensee's calculational methods result in conservative calculations to determine RPV drain time, thereby protecting Safety Limit 2.1.1.3, which meets the requirements of 10 CFR 50.36(c)(3). Based on these considerations, the NRC staff has determined that the licensee's proposed addition of the drain time definition to the Susquehanna TSs is acceptable.

3.2 Staff Evaluation of Proposed TS 3.3.5.2, "Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation" The existing TS 3.3.5.2, "Reactor Core Isolation Cooling (RCIC) System Instrumentation," is renumbered as TS 3.3.5.3. This achieves consistency within the Susquehanna TSs and is acceptable.

The purpose of the proposed new TS 3.3.5.2 regarding RPV WIC instrumentation is to support the requirements of revised TS LCO 3.5.2 and the proposed new definition of drain time. There are instrumentation and control functions required for manual pump starts that serve as permissives, operational controls for the systems that provide water injection capability, certain start commands, pump protection, and system isolations. These instruments are required to be operable if the systems that provide water injection and isolation functions are to be considered operable as described in Section 3.3 of this SE for revised TS 3.5.2. For Susquehanna, reactor operators have a manual initiation push button start for CS and LPCI.

Specifically, the proposed new TS 3.3.5.2 supports operation of the CS and LPCI, including manual initiation when needed, as well as the system isolation of the RHR SOC system and the RWCU system. The equipment involved with each of these systems is described in the evaluation of TS 3.5.2 and the Bases for LCO 3.5.2.

3.2.1 Staff Evaluation of Proposed TS 3.3.5.2 LCO and Applicability The licensee proposed a new TS 3.3.5.2 to provide alternative instrumentation requirements to support manual initiation of the ECCS injection/spray subsystem. This subsystem is required in the revised TS 3.5.2 and automatic isolation of penetration flow paths that may be credited in the determination of drain time. The existing TSs contain instrumentation requirements related to OPDRVs in TS Tables 3.3.5.1-1, 3.3.6.1-1, 3.3.6.2-1, and 3.3.7.1-1. The requirements from Tables 3.3.5.1-1 and 3.3.6.1-1 would be consolidated into new TS 3.3.5.2. The OPDRVs requirements in Tables 3.3.6.2-1 and 3.3.7.1-1 would be deleted, as discussed in Section 3.6 of this SE.

The proposed LCO 3.3.5.2 would state:

The RPV Water Inventory Control Instrumentation for each Function in Table 3.3.5.2-1 shall be OPERABLE.

The proposed Applicability would state:

According to Table 3.3.5.2-1.

TSTF-542 selected Table 3.3.5.2-1 to contain those instrumentation functions needed to support manual initiation of the ECCS injection/spray subsystem required by LCO 3.5.2, and for automatic isolation of penetration flow paths that may be credited in a calculation of drain time.

The functions that are required in Modes 4 or 5, or during OPDRVs, are relocated to Table 3.3.5.2-1 from existing TS 3.3.5.1, "ECCS Instrumentation," and TS 3.3.6.1, "Primary Containment Isolation Instrumentation." Creation of TS 3.3.5.2 places these functions in a single location with requirements appropriate to support the safety function for TS 3.5.2.

The NRC staff concluded that the licensee's proposed alternative is acceptable for Susquehanna since either CS or LPCI (or both) subsystems would be available to perform the intended function to inject water into the RPV; this meets the intent of the NRC-approved TSTF-542.

3.2.2 Staff Evaluation of Proposed TS 3.3.5.2 Actions The NRC staff has reviewed the licensee's proposed TS 3.3.5.2 Actions to determine whether they provide effective remedial measures when one or more instrument channels are inoperable and cannot complete the required function in a normal manner. The Actions are evaluated as follows:

Action A would be applicable when one or more instrument channels are inoperable from Table 3.3.5.2-1 and directs the licensee to immediately enter the Condition referenced in Table 3.3.5.2-1 for that channel.

Action B ( concerning the RHR/SDC system isolation and RWCU system isolation functions) would be applicable when automatic isolation of the associated penetration flow path is credited as a path for potential drainage in calculating drain time. If the instrumentation is inoperable, Required Action B.1 directs an immediate declaration that the associated penetration flow path(s) are incapable of automatic isolation. Required Action 8.2 requires an immediate recalculation of drain time, but automatic isolation of the affected penetration flow paths cannot be credited.

Action C ( concerning low reactor steam dome pressure injection permissive functions necessary for ECCS subsystem manual injection valve opening) would address an event in which the permissive is inoperable. The function must be placed in the trip condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . With the permissive function instrument in the trip condition, manual injection valve opening may now be performed using the preferred control board switches. This 1-hour completion time is acceptable because despite the preferred start method being prevented, the reactor operator can take manual control of the pump and the injection valve to inject water into the RPV and achieve the safety function in that time. The time of 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months also provides reasonable time for evaluation and placing the channel in trip.

Action D (concerning manual initiation) would address actions when the manual initiation logic with the push button is inoperable. In this condition, the operator can take manual control of the pump and the injection. Similar to the justification for Action C, while this is not the preferred method, the CS and LPCI subsystem pumps can be started manually and the valves can be opened manually. The 24-hour completion time is acceptable, because the functions can be performed manually and it allows time for the operator to evaluate and have necessary repairs completed.

Action E would apply if the required actions and associated completion times of Conditions C or D were not met. If they were not met, then the associated low pressure ECCS injection/spray subsystem might be incapable of performing the intended function, and the CS/LPCI subsystem would be declared inoperable immediately.

These Actions direct the licensee to take appropriate actions and enter immediately into the Conditions referenced in Table 3.3.5.2-1. The NRC staff has determined that these Actions satisfy the requirements of 10 CFR 50.36(c}(2)(i) by providing a remedial action permitted by the TSs until the LCO can be met. Therefore, the NRC staff has concluded that there is reasonable assurance that the licensee will take appropriate actions during an unexpected drain event to either prevent or to mitigate RPV water level being lowered to the T AF and, therefore, that the proposed actions are acceptable.

3.2.3 Staff Evaluation of Proposed TS 3.3.5.2 SRs The NRC staff finds that these tests are sufficient and adequate because they will ensure the functions of TS 3.3.5.2 are operable (i.e., capable of performing the specified safety function in support of TS 3.5.2, Drain Time, and the protection from a potential draindown of the RPV in Modes 4 and 5). The NRC staff finds that the proposed SRs of LCO 3.3.5.2, as described in Section 3.3.3 of TSTF-542, are acceptable and concludes that these SRs satisfy 10 CFR 50.36(c)(3} by providing the specific SRs relating to test, calibration, or inspection to assure that the necessary quality of systems and components is maintained.

SR 3.3.5.2.1 would require a Channel Check and applies to RHR/SDC and RWCU system isolation. Performance of the Channel Check would ensure that a gross failure of instrumentation has not occurred. A Channel Check is normally a comparison of the parameter indicated on one channel to a similar parameter on other related channels. A Channel Check is significant in assuring that there is a low probability of an undetected complete channel failure and is a key safety practice to verifying the instrumentation continues to operate properly between each Channel Functional Test. The frequency is in accordance with the surveillance frequency control program (SFCP), which is consistent with the existing requirements and supports operating shift situational awareness.

SR 3.3.5.2.2 would require a Channel Functional Test and applies to all functions, except manual initiation. A Channel Functional Test is the injection of a simulated or actual signal into the channel, as close to the sensor as practicable, to verify operability of all devices in the channel required for channel operability. It would be performed on each required channel to ensure that the entire channel will perform the intended function. The frequency would be in accordance with the SFCP. This is acceptable because it is consistent with the existing requirements for these functions. In addition, if licensees so desire, this SR could be included as part of a refueling activity, since during refueling outages, periods in Modes 4 and 5 are often 30 days or less.

Variation 5, Section 2.2.5.5, of this SE, describes a note related to testing of contacts that was proposed by the licensee in SR 3.3.5.2.2. The NRC staff evaluated this note in Section 3.5.5 of this SE.

SR 3.3.5.2.3 requires a logic system functional test and applies to all functions. The logic system functional test is a test of all logic components required for operability of a logic circuit from as close to the sensor as practicable up to, but not including, the actuated device, and

demonstrates the operability of the required manual initiation logic for a specific channel. The frequency is in accordance with the SFCP. The ECCS injection/spray subsystem functional manual initiation signal testing performed in proposed SR 3.5.2.8 overlaps this surveillance to complete testing of the assumed safety function.

TSTF-542 did not include SRs to verify or adjust the instrument setpoint derived from the allowable value using a channel calibration or a surveillance to calibrate the trip unit. A draining event in Modes 4 or 5 is not an analyzed accident and, therefore, there is no accident analysis on which to base the calculation of a setpoint. The functions requiring this SR allow ECCS manual initiation or automatic isolation of a penetration flow path, but no specific RPV water level is assumed for those actions. Therefore, the allowable value for Mode 3 was chosen for use in Modes 4 and 5, as it will perform the desired function. Calibrating the functions in Modes 4 and 5 is not necessary, as TSs 3.3.5.1 and 3.3.6.1 continue to require the functions to be calibrated on an established interval. Also, a draining event in Modes 4 or 5 is not an analyzed accident and, therefore, there are no accident analysis assumptions on response time.

The NRC staff has determined that the Mode 3 allowable value and established calibration intervals are adequate to ensure that the channel will respond with the required accuracy to allow manual initiation of the pumping systems to inject water and automatic isolation of penetration flow paths.

The NRC staff concludes that the proposed SRs of LCO 3.3.5.2 satisfy 10 CFR 50.36(c)(3) by providing the specific SRs relating to test, calibration, or inspection to assure that the necessary operability of systems and components is maintained and are, therefore, acceptable.

3.2. 4 Staff Evaluation of Proposed Table 3. 3. 5. 2-1, RPV Water Inventory Control Instrumentation" In order to support the requirements of proposed TS 3.5.2, the associated instrumentation requirements would be designated in Table 3.3.5.2-1. These instruments would be required to be operable if the systems that provide water injection and isolation functions were to be considered operable as described in the NRC staff's evaluation of TS 3.5.2.

Proposed Table 3.3.5.2-1 specifies the instrumentation that shall be operable for each function in the table for Modes 4 and 5 (or other specified conditions), the required number of channels per function, conditions referenced from Required Action A.1, SR for the functions, the allowable value, and footnotes concerning items of the table.

The NRG staff finds this table acceptable because it sufficiently discusses the purpose of the functions, the applicability, the number of required channels, the references to the condition to be entered by letter (e.g., A, B, C) if the function is inoperable, the applicable SRs, the selection of the allowable value, and justification of differences between the existing and proposed TS functions. This RPV WIC instrumentation set is acceptable because it is adequate so that the instrument channels respond with the required accuracy, permitting pump systems to inject water when needed, and activating isolation equipment when commanded to support prevention or mitigation of a potential RPV draining event.

Each of the ECCS subsystems in Modes 4 and 5 can be started by manual alignment of a small number of components or by manual pushbutton. Automatic initiation of an ECCS injection/spray subsystem may be undesirable because it could lead to overflowing the RPV cavity due to injection rates of thousands of gallons per minute. Thus, there is adequate time to

take manual actions (e.g., hours vs. minutes). Considering the action statements as the drain time decreases (the proposed TS 3.5.2, Action E, prohibits plant conditions that could result in drain times less than 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ), there is sufficient time for the reactor operators to take manual action to stop the draining event and to manually start an ECCS injection/spray subsystem or additional method of water injection, as needed. Consequently, there is no need for automatic initiation of ECCS to respond to an unexpected draining event. The NRC staff finds this acceptable because a draining event is a slow evolution when compared to a design-basis LOCA assumed to occur at a significant power level.

3.2.4.1 Staff Evaluation of Proposed Table 3.3.5.2-1 Functions For Table 3.3.5.2-1, Functions 1.a (CS) and 2.a (LPCI), Reactor Steam Dome Pressure - Low (Injection Permissive), the signals would be used as permissives for the low pressure ECCS injection/spray subsystem Manual Initiation Functions. This function would ensure that the reactor pressure has fallen to a value below these subsystems' maximum design pressure before permitting the operator to open the injection valves of the low pressure ECCS subsystems. Even though the reactor steam dome pressure is expected to be below the ECCS maximum design pumping pressure during Modes 4 and 5, the reactor steam dome pressure -

low (injection permissive) signals would be required to be operable and capable of permitting initiation of the ECCS. The proposed allowable value would be s 433 pounds per square inch gauge (psig), with four required channels per function, as it is currently in Susquehanna TS Table 3.3.5.1-1.

For Table 3.3.5.2-1, Functions 1.b (CS) and 2.b (LPCI), Manual Initiation, the pushbutton channels introduce signals into the appropriate ECCS logic to provide subsystem initiation capability. There is one push button for each of the CS and LPCI subsystems (i.e., two for CS and two for LPCI). The Manual Initiation Function is not assumed in any accident or transient analyses in the Final Safety Analysis Report (FSAR). However, the Function is retained for overall redundancy and diversity of the low pressure ECCS function as required in the plant licensing basis. There is no Allowable Value for this function since the channels are mechanically actuated based solely on the position of the push buttons. Each channel of the Manual Initiation Function (one channel per subsystem) is required to be operable only when the associated ECCS is required to be operable. However, the CS/LPCI pumps can be started manually, and valves can be opened manually by the reactor operator, if required.

For Table 3.3.5.2-1, Function 3.a, RHR/SDC System Isolation, Reactor Vessel Water Level -

Low, Level 3, the function would only be required to be operable when automatic isolation of the associated penetration flow path is credited in the drain time calculation. The proposed number of required instrument channels is two in one trip system. The condition that the RHR/SDC system integrity be maintained is a concept related to OPDRVs, so it would not be carried over into TS 3.3.5.2 for RPV WIC instrumentation.

Reactor Vessel Water Level - Low, Level 3 signals are initiated from four level transmitters that sense the difference between the pressure due to a constant column of water (reference leg) and the pressure due to the actual water level (variable leg) in the vessel. While four channels (two channels per trip system) of the Reactor Vessel Water Level - Low, Level 3 function are available, only two channels (all in the same trip system) are required to be operable. The Allowable Value was chosen to be the same as the primary containment isolation instrumentation Reactor Vessel Water Level - Low, allowable value from LCO 3.3.6.1, Function 6.b (~ 11.5 inches).

For Table 3.3.5.2-1, Function 4.a, RWCU System Isolation, Reactor Vessel Water Level - Low Low Level 2, the function is only required to be operable when automatic isolation of the associated penetration flow path is credited in the drain time calculation. The proposed number of required channels is two in one trip system. The Reactor Vessel Water Level - Low Low Level 2 isolation function signals are initiated from four level transmitters that sense the difference between the pressure due to a constant column of water (reference leg) and the pressure due to the actual water level (variable leg) in the vessel. While four channels (two channels per trip system) of the Reactor Vessel Water Level - Low Low, Level 2 function are available, only two channels (all in the same trip system) are required to be operable. The allowable value was chosen to be the same as the primary containment isolation instrumentation Reactor Vessel Water Level - Low, Allowable Value from LCO 3.3.6.1, Function 5.f (~ - 45 inches).

The NRC staff finds that the proposed new LCO 3.3.5.2 correctly specifies the lowest functional capability or performance levels of equipment required for safe operation of the facility. There is reasonable assurance that the required actions to be taken when the LCO is not met are adequate to protect the health and safety of the public. This meets the requirements of 10 CFR 50.36(c)(2)(i) and, therefore, the NRC staff has determined that the licensee's proposed changes to LCO 3.3.5.2 are acceptable.

3.3 Staff Evaluation of TS 3.5.2 - Reactor Pressure Vessel (RPV) Water Inventory Control The NRC staff reviewed the water sources that would be applicable to proposed TS 3.5.2.

The proposed LCO 3.5.2 would state, in part:

One low pressure ECCS injection/spray subsystem shall be OPERABLE.

'One' low pressure ECCS injection/spray subsystem would consist of either one CS subsystem or one LPCI subsystem. A CS subsystem consists of one motor-driven pump, piping, and valves to transfer water from the suppression pool or condensate storage tank to the RPV. An LPCI subsystem consists of one motor-driven pump, piping, and valves to transfer water from the suppression pool to the RPV.

The ECCS pumps are high-capacity pumps, with flow rates of thousands of gallon per minute.

Most RPV penetration flow paths would have a drain rate on the order of tens or hundreds of gallons per minute. The manual initiation/start of an ECCS pump would provide the necessary water source to counter these expected drain rates. Decay heat removal in Modes 4 and 5 is not affected by the proposed Susquehanna TS changes, as these requirements on the number of SOC subsystems that must be operable and in operation to ensure adequate decay heat removal from the core are unchanged. These requirements can be found in Susquehanna TS 3.4.9, "Residual Heat Removal (RHR) Shutdown Cooling System - Cold Shutdown";

TS 3.9.7, "Residual Heat Removal (RHR) - High Water Level"; and TS 3.9.8, "Residual Heat Removal (RHR)- Low Water Level." These Susquehanna decay heat removal requirements are similar to the standard TS and can be found in NUREG-1433 TS 3.4.9, "Residual Heat Removal (RHR) Shutdown Cooling System - Cold Shutdown"; TS 3.9.8, "Residual Heat Removal (RHR)- High Water Level"; and TS 3.9.10, "Residual Heat Removal (RHR) - Low Water Level." Based on these considerations, the NRC staff finds that the water sources provide reasonable assurance that the lowest functional capability required for safe operation is maintained and the safety limit is protected.

The proposed TS LCO 3.5.2 contains two parts. The first part states that drain time of RPV WIC to the TAF shall be ~ 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months , and the second part states that one low pressure ECCS injection/spray subsystem shall be operable. The proposed applicability for TS 3.5.2 is Modes 4 and 5.

The NRC staff reviewed proposed TS 3.5.2 to assure that the fuel remains covered with water, and to compare the revised TS with the current TS. The proposed TS 3.5.2 contains Conditions A through E based on either required ECCS injection/spray subsystem operability or drain time.

The current TS LCO states that two low pressure ECCS injection/spray subsystems shall be operable, whereas proposed LCO 3.5.2 states that only one low pressure ECCS injection/spray subsystem shall be operable. This change is reflected in Condition A. The change from two ECCS injection/spray subsystems to one ECCS injection/spray subsystem is because this redundancy is not required. With one ECCS injection/spray subsystem and nonsafety-related injection sources, defense-in-depth will be maintained. The defense-in-depth measure is consistent with other events considered during shutdown with no additional single failure assumed. The drain time controls, in addition to the required ECCS injection/spray subsystem, provide reasonable assurance that an unexpected draining event can be prevented or mitigated before the RPV water level would be lowered to the T AF.

The proposed TS LCO 3.5.2 'note' for Modes 4 and 5 state that the RHR system may operate in the SOC mode to remove decay heat and sensible heat from the reactor, and the RHR valves that are required for LPCI subsystem operation may be aligned for decay heat removal.

This note allows a required LPCI subsystem of the RHR system to be considered operable for the ECCS function if all the required valves in the LPCI flow path can be manually realigned (remote or local) to allow injection into the RPV, and the system is not otherwise inoperable.

This will ensure adequate core cooling if an inadvertent RPV draindown should occur. This is further evaluated in Section 3.5.1 (Variation 1) of this SE.

The proposed Modes 4 and 5 applicability of TS 3.5.2 is appropriate, given that the TS requirements on ECCS in Modes 1, 2, and 3 will be unaffected.

The proposed Condition A states that if the required ECCS injection/spray subsystem is inoperable, it is to be restored to operable status within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

The proposed Condition B states that if Condition A is not met, a method of water injection capable of operating without offsite electrical power shall be established immediately. The proposed Condition B provides adequate assurance of an available water source, should Condition A not be met within the 4-hour completion time.

The proposed Condition C states that for a drain time < 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months and ~ 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , to (C.1) verify the secondary containment boundary is capable of being established in less than the drain time with a completion time of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months , and (C.2) verify each secondary containment penetration flow path is capable of being isolated less than the drain time with a completion time of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months , and (C.3) verify required one SGT subsystem is capable of being placed in operation in less than the drain time with a completion time of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . The proposed Condition C provides adequate protection, should the drain time be < 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months and ~ 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months because of the ability to establish secondary containment, isolate additional flow paths, and have the SGT subsystem capable of being placed in operation.

The proposed Condition O states that when drain time is < 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months to (0.1) immediately initiate action to establish an additional method of water injection with water sources capable of maintaining RPV water level> TAF for~ 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months , and (0.2) immediately initiate action to establish secondary containment boundary, and (0.3) immediately initiate action to isolate each secondary containment penetration flow path or verify it can be manually isolated from the control room, and (0.4) immediately initiate action to verify one SGT system is capable of being placed in operation. Additionally, there is a note stating that required ECCS injection/spray subsystem or additional method of water injection shall be capable of operating without offsite electrical power, which is similar to proposed Condition B. The existing Susquehanna TS for Condition O (Required Action C.2 and associated completion time not met) is similar to proposed Condition 0. The proposed Condition O provides adequate protection, should the drain time be < 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , because of the requirement for the ability to establish an additional method of water injection (without offsite electrical power), establish secondary containment, isolate additional flow paths, and have the SGT subsystem capable of being placed in operation.

The proposed Condition E states that when the required action and associated completion time of Condition C or O is not met, or the drain time is< 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , then immediately initiate action to restore drain time to~ 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . The proposed Condition Eis new, as it is not present in the current Susquehanna TSs. The proposed Condition E is acceptable, as it provides the necessary step to restore the drain time to~ 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months , should the other conditions not be met, or if the drain time is < 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

The NRC staff evaluated the proposed changes to TS 3.5.2 and finds them acceptable based on the actions taken to mitigate the water level reaching the TAF with the water sources available and maintaining drain time ~ 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . The LCO correctly specifies the lowest functional capability or performance levels of equipment required for safe operation of the facility. There is reasonable assurance that the required actions to be taken when the LCO is not met can be conducted without endangering the health and safety of the public and, therefore, are acceptable.

3.3.1 Staff Evaluation of Proposed TS 3.5.2 SRs The proposed TS 3.5.2 SRs includes verification of drain time, verification of water levels/volumes that support ECCS injection/spray subsystems, verification of water-filled pipes to preclude water hammer events, verification of correct valves positions for the required ECCS injection/spray subsystem, operation of the ECCS injection/spray systems through the recirculation line, verification of valves credited for automatic isolation actuated to the isolation position, and verification that the required ECCS injection/spray subsystem actuated on a manual initiation signal. Each of the eight SRs are described below.

SR 3.5.2.1: The drain time would be determined or calculated and required to be verified to be

~ 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months in accordance with the SFCP. The NRC staff has determined the option to place this frequency in the licensee's SFCP is appropriate and consistent with similar LCOs and surveillances. This surveillance would verify that the LCO for drain time is met. Numerous indications of changes in RPV level are available to the operator. The period of 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months is considered reasonable to identify and initiate action to mitigate draining of reactor coolant (normally three operator shifts). Changes in RPV level would necessitate recalculation of the drain time. As plant conditions change, the drain time must be confirmed to be ~ 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months or the LCO must be declared not met and the appropriate TS actions followed.

SR 3.5.2.2: The suppression pool water level (2:: 20 feet O inches) for a required low pressure LPCI subsystem would be required to be verified to ensure pump net positive suction head and vortex prevention is available for the ECCS injection/spray subsystem required to be operable by the LCO. Indications are available either locally or in the control room regarding suppression pool water level. This surveillance would be required to be performed in accordance with the SFCP.

SR 3.5.2.3: The suppression pool water level (2:: 20 feet O inches) or condensate storage tank level (2:: 49 percent of capacity) for a required ECCS injection/spray subsystem would be required to be verified to ensure pump net positive suction head and vortex prevention is available for the CS subsystem required to be operable by the LCO. Indications are available either locally or in the control room regarding suppression pool water level and condensate storage tank level. This surveillance would be required to be performed in accordance with the SFCP.

SR 3.5.2.4: The SR to verify the ECCS injection/spray subsystem piping is sufficiently filled with water would be retained from the existing TS 3.5.2. The proposed change would update the SR to reflect the change to LCO 3.5.2, which would require, in part, one low pressure ECCS injection/spray subsystem to be operable instead of two. SR 3.5.2.3 wording would change from "Verify, for each required ECCS ... " to "Verify, for the required ECCS ... " This change clarifies the requirement to maintain consistency with the proposed LCO. Maintaining the pump discharge lines of the required ECCS injection/spray subsystems full of water ensures that the ECCS subsystem will perform properly. This may also prevent a water hammer following an ECCS initiation signal. One acceptable method of ensuring that the lines are full is to vent at the high points. This surveillance would be required to be performed in accordance with the SFCP.

SR 3.5.2.5: The SR to verify the correct alignment for manual, power operated, and automatic valves in the required ECCS subsystem flow path would be retained from the existing TS 3.5.2.

Similar to the change discussed above for proposed SR 3.5.2.4, changes to SR 3.5.2.5 would clarify a proposed requirement for LCO 3.5.2. The proposed SR wording, "Verify, for the required ECCS injection/spray subsystem, each manual. .. " would replace "Verify each required ECCS injection/spray subsystem manual..." SR 3.5.2.5 would provide assurance that the proper flow path will be available for ECCS operation to support TS 3.5.2. This SR would not apply to valves that are locked, sealed, or otherwise secured in position, since these valves would be verified to be in the correct position prior to locking, sealing, or securing. This surveillance would be required to be performed in accordance with the SFCP.

SR 3.5.2.6: The required ECCS injection/spray subsystem would be required to be operated through its recirculation line for~ 10 minutes in accordance with the SFCP. This would demonstrate that the subsystem is capable of operation to support TS 3.5.2. Testing the ECCS injection/spray subsystem through the recirculation line is necessary to avoid overfilling the refueling cavity. The minimum operating time of 10 minutes is based on engineering judgement.

SR 3.5.2. 7: Verification that each valve credited for automatically isolating a penetration flow path actuates to the isolation position on an actual or simulated RPV water level isolation signal would be required to prevent RPV water inventory from dropping below the TAF, should an unexpected draining event occur. This surveillance would be required to be performed in accordance with the SFCP.

SR 3.5.2.8: The required ECCS injection/spray subsystem shall actuate on an initiation signal.

This surveillance verifies that a manual initiation signal will cause the required CS or LPCI subsystem to start and operate as designed, including pump startup and actuation of all automatic valves to their required positions. A note states that vessel injection/spray may be excluded. This surveillance is required to be performed in accordance with the SFCP.

The NRC staff evaluated each of these proposed SRs associated with the new LCO 3.5.2 and concluded they are appropriate for ensuring the operability of the equipment and instrumentation specified in LCO 3.5.2. The NRC staff concluded that each of the proposed SRs are acceptable since they meet the requirements of 10 CFR 50.36(c)(2){ii) regarding insights gained by operating experience and 10 CFR 50.36(c)(3} for SRs by ensuring that the necessary quality of systems and components are maintained.

3.4 Staff Evaluation of TS Table 3.3.5.1-1, "Emergency Core Cooling System Instrumentation" LCO 3.3.5.1 currently states, "The ECCS instrumentation for each Function in Table 3.3.5.1-1 shall be OPERABLE," with the applicability as stated in the table. Table 3.3.5.1-1, "Emergency Core Cooling System Instrumentation," contains requirements for function operability during Modes 4 and 5 when the associated ECCS subsystem(s) are required to be operable per LCO 3.5.2, "ECCS - Shutdown." Conforming changes were proposed for the actions table of LCO 3.3.5.1 as well.

As discussed in Section 2.2.2.1 of this SE, the licensee proposed to delete the following Modes 4 and 5, Table 3.3.5.1-1 function requirements:

1. Core Spray System (a) Reactor Vessel Water Level - Low Low Low, Level 1 (c} Reactor Steam Dome Pressure - Low (Initiation}

(d) Reactor Steam Dome Pressure - Low (Injection Permissive)

(e) Manual Initiation

2. Low Pressure Coolant Injection System (a) Reactor Vessel Water Level - Low Low Low, Level 1 (c} Reactor Steam Dome Pressure - Low (Initiation}

(d) Reactor Steam Dome Pressure - Low (Injection Permissive)

(f) Manual Initiation These functions would be deleted to support the consolidation of RPV WIC instrumentation requirements into proposed new TS 3.3.5.2. The requirements for Functions 1.d, 1.e, 2.d, and 2.f would be moved to proposed TS Table 3.3.5.2-1 as discussed in Section 3.2.4.1 of this SE.

For the other TS Table 3.3.5.1-1, Functions 1.a, 1.c, 2.a, and 2.c, the Mode 4 and 5 requirements would not be retained. The existing Susquehanna TSs require automatic initiation of ECCS pumps on low reactor vessel water level. However, in Modes 4 and 5, automatic initiation of ECCS pumps (high capacity pumps) could result in overfilling the refueling cavity or water flowing into the main steam lines, potentially damaging plant equipment.

The NRC staff has determined it is acceptable to delete TS Table 3.3.5.1-1, Functions 1.a, 1.c, 2.a, and 2.c on the bases that manual ECCS initiation is preferred over automatic initiation during Modes 4 and 5, and the operator would be able to use the most appropriately sized

pumps if needed to mitigate a draining event. Functions 1.c and 2.c are further described in Section 3.5.3 (Variation 3) of this SE.

3.5 Staff Evaluation of Proposed Technical Variations The licensee proposed the following technical variations from the TS changes described in TSTF-542 or the applicable parts of the NRC staff's SE for TSTF-542. The licensee stated in the license amendment request that these variations do not affect the applicability of TSTF-542 or the NRC staffs SE for TSTF-542 to the proposed license amendment. The NRC staff evaluated each variation below.

3.5.1 Variation 1, TS LCO 3.5.2 Note, LPG/ Alignment The note in LCO 3.5.2 regarding realignment to the Low Pressure Injection mode is currently located in SR 3.5.2.4 but is proposed to be relocated to the LCO. The intent of the note was to allow LPCI subsystems to be considered operable during this condition.

The NRC staff finds that the added footnote to LCO 3.5.2 associated with the LPCI subsystem is appropriate and is consistent with TSTF-542, which places this note within the LCO. Without the note, the associated RHR pump would be declared inoperable, which would be contrary to the intent of the existing note for SR 3.5.2.4, which allows the LPCI subsystem to be operable when aligned for decay heat removal; therefore, this variation is acceptable.

3.5.2 Variation 2, TS Table 3.3.5.1-1, CS and LPG/ Pumps Discharge Flow Low (Bypass)

Standard TS Table 3.3.5.1-1, Function 1.d, "Core Spray Pump Discharge Flow- Low (Bypass),"

and Function 2.g, "Low Pressure Coolant Injection Pump - Discharge Flow - Low (Bypass)," are not included in the Susquehanna TSs. The minimum flow instruments are provided to protect the associated low pressure ECCS pump from overheating when the pump is operating and the associated injection valve is not fully open. The minimum flow line valve is opened when low flow is sensed, and the valve is automatically closed when the flow rate is adequate to protect the pump.

Therefore, in order for the NRC staff to complete its technical review of the licensee's proposed change, the NRC staff issued a request for additional information to the licensee by e-mail dated January 22, 2018, 11 requesting technical justification for omitting ECCS pump bypass functions as presented in TSTF-542, standard TS Table 3.3.5.2-1. In its request for additional information response letter dated February 16, 2018, the licensee maintained that even with loss of flow due to a failed minimum flow valve, the ECCS pumps would still have the capability to mitigate a draindown event. Regarding operability of the minimum flow valves, the licensee stated that:

For the Residual Heat Removal (RHR) and CS systems, minimum flow valve opening is a function of the pump breaker being closed (pump running) and system flow less than the setpoint. Testing of the minimum flow function for RHR is performed separately for each pump every 24 months during RHR logic system functional testing. This test is performed using manual component by component logic. For the CS system, the minimum flow valve is verified to open on low flow during the quarterly flow verification.

11 ADAMS Accession No. ML18024A995

The NRC staff finds Variation 2 acceptable because although the "Pump Discharge Flow-Low (Bypass)" function is not a part of proposed Susquehanna TS Table 3.3.5.2-1, the existing SRs for RHR/LPCI and CS are sufficient to provide reasonable assurance that a required ECCS pump will operate as expected.

3.5.3 Variation 3, TS Table 3.3.5.1-1, Reactor Steam Dome Pressure - Low (Initiation)

Susquehanna Table 3.3.5.1-1 includes Functions 1.c and 2.c, "Reactor Steam Dome Pressure -

Low (initiation)," which are not included in the standard TS. Low reactor steam dome pressure signals (Functions 1.c, 1.d, 2.c, and 2.d) are used as permissives for the low pressure ECCS subsystems. The low reactor pressure permissive is provided to prevent a high drywell pressure condition that is not accompanied by low reactor pressure (i.e., a false LOCA signal) from disabling two RHR pumps on the other unit. Functions 1.c and 2.c are not required to ensure manual initiation of CS and LPCI and are, therefore, not included in the new Table 3.3.5.2-1.

The NRC staff finds Variation 3 acceptable because all of the permissive functions necessary for Susquehanna ECCS injection were proposed for inclusion; also, Variation 3 clarifies the Susquehanna design differences when compared to TSTF-542.

3.5.4 Variation 4, Standard TS SR 3.3.5.1. 7, EGGS Response Time The Susquehanna TSs do not include standard TS SR 3.3.5.1. 7 {verify the ECCS response time is within limits); however, similar requirements are included in Susquehanna SRs 3.5.1.13 and 3.5.2. 7 (verify the ECCS response time for each ECCS injection/spray subsystem is within limits). As described in the discussion in Section 3.3.3 of the TSTF-542 justification, since a draining event is not an analyzed accident, there are no accident analysis assumptions with respect to response time. In addition, response times are insignificant compared to draindown times (seconds vs. hours). On this basis, the existing SR 3.5.2. 7 is being deleted.

The NRC staff finds that this existing SR 3.5.2 7 related to ECCS response time is unnecessary, given the new requirements set forth in TSTF-542, drain time and WIC.

Consequently, there is no need for the Modes 4 and 5 ECCS response time SR. This is acceptable because a draining event is a slow evolution when compared to a design-basis LOCA assumed to occur at a significant power level.

3.5.5 Variation 5, TS SR 3.3.5.2.2 Note, Test of All Required Contacts A note was added to TS SR 3.3.5.2.2 to state, "A test of all required contacts does not have to be performed." This note is included in the existing channel functional test surveillance in TS 3.3.5.1 (SR 3.3.5.1.2) and TS 3.3.6.1 (SR 3.3.6.1.2) for the affected functions included in TS 3.3.5.2. The bases for these SRs state that the exception is necessary because the design of instrumentation does not facilitate functional testing of all required contacts of the relay, which input into the combinational logic, and that performance of such a test could result in a plant transient or place the plant in an undue risk situation. Therefore, for this SR, the Channel Functional Test verifies acceptable response by verifying the change of state of the relay, which inputs into the combinational logic. The required contacts that are not tested during the Channel Functional Test are tested under the Logic System Functional Test, SR 3.3.5.1.5 (or SR 3.3.6.1.5).

The NRC staff finds that variation is acceptable since this is part of Susquehanna current licensing bases and is, therefore, carried forward to the new TS SR 3.3.5.2.2. As stated above, the design of instrumentation does not facilitate functional testing of all required contacts of the relay, which input into the combinational logic, and performance of such a test could result in a plant transient or place the plant in an undue risk situation. Therefore, the NRC staff finds Variation 5 acceptable.

3.5.6 Variation 6, TS Table 3.3.5. 1-1, Channel Checks The current Susquehanna TSs do not include channel checks for Table 3.3 .5.1-1, Functions 1.d and 2.d (Reactor Steam Dome Pressure - Low (Injection Permissive)); therefore, no Channel Checks SR was added for these functions in the new Table 3.3.5.2-1 (Functions 1.a and 2.a).

Since Channel Checks for these functions have no impact on manual ECCS injection/spray capabilities for CS or LPCI, and the licensee will retain its current licensing basis for these instruments, the NRC staff has determined the proposed variation to be acceptable.

3.5.7 Variation 7, TS Table 3.3.6.1-1, Manual Initiation, Function 6.c Susquehanna Table 3.3.6.1-1, "Primary Containment Isolation Instrumentation," includes Function 6.c, "Manual Initiation," which is not included in the standard TS. Modes 4 and 5 applicability is being removed from this function, and the footnote is correspondingly being removed from the required channels per trip system column. The SOC system can be isolated without the primary containment isolation instrumentation function, and this is consistent with the basis for eliminating the applicability during OPDRVs from the Manual Initiation function associated with secondary containment isolation as described in Section 3.4.1.3 of the TSTF-542 justification.

The NRC staff finds that this existing Function 6.c manual initiation logic for SOC is unnecessary, given the new requirements set forth in TSTF-542, drain time and WIC.

Consequently, there is no need for Mode 4 and 5 manual initiation for SOC isolation, primary containment isolation instrumentation function. This is acceptable because a draining event is a slow evolution when compared to a design-basis LOCA assumed to occur at a significant power level.

3.5.8 Variation 8, TS Table 3.3. 7.1-1, Manual Initiation, Function 9 Susquehanna Table 3.3.7.1-1, "Control Room Emergency Outside Air Supply System Instrumentation," includes Function 9, "Manual Initiation," which is not included in the standard TS. Function 9 is applicable during OPDRVs. The applicability during OPDRVs is eliminated.

The CREOAS system can be initiated without the associated instrumentation function; this is consistent with the basis for eliminating the applicability during OPDRVs from the Manual Initiation function associated with secondary containment isolation as described in Section 3.4.1.3 of the TSTF-542 justification.

The NRC staff finds that this existing Function 9 manual initiation logic for CREOAS system is unnecessary, given the new requirements set forth in TSTF-542, drain time and WIC.

Consequently, there is no need for Mode 4 and 5 manual initiation for CREOAS system and Mode 4 and 5 instrumentation logic. Therefore, the NRC staff finds Variation 8 acceptable.

3.5.9 Variation 9, TS 3.6.1.3, Applicability and SR Deletions Susquehanna TS 3.6.1.3, "Primary Containment Isolation Valves (PCIVs)," is currently applicable in Modes 1, 2, and 3, and when associated instrumentation is required to be operable per LCO 3.3.6.1, "Primary Containment Isolation Instrumentation." However, TSTF-542 deletes from Table 3.3.6.1-1 the Modes 4 and 5 requirement for SDC system isolation. As a result, TS 3.6.1.3 will no longer require any PCIVs to be operable in Modes 4 or 5. Therefore, the licensee proposes to revise the applicability to Modes 1, 2, and 3, and delete Condition H, which is applicable in Modes 4 and 5. In addition, the unnecessary reference to Modes 1, 2, or 3 in Condition G and SRs 3.6.1.3.1, 3.6.1.3.6, 3.6.1.3.11, 3.6.1.3.12, and 3.6.1.3.13 is deleted since LCO 3.6.1.3 is applicable only in Modes 1, 2, and 3. These changes are justified on the basis that TSTF-542 removed the Mode 4 and 5 applicability from LCO 3.6.1.3.

This variation is consistent with the treatment of other primary containment isolation instruments as discussed in Section 3.4.1.2, "TS 3.3.6.1A and 3.3.6.1b, Primary Containment Isolation Instrumentation," and in Section 3.4.2, "Other Proposed Changes - Containment, Containment Isolation Valves, and Standby Gas Treatment Requirements," of the justification for TSTF-542, Revision 2. The applicability for TS 3.6.1.3 is revised with the deletion of the statement, "When associated instrumentation is required to be OPERABLE per LCO 3.3.6.1, 'Primary Containment Isolation Instrumentation.'" Therefore, the NRC staff finds Variation 9 acceptable.

3.5.10 Variation 10, TS 3.6.4.1 and TS 3.6.4.3, Removal of One-Time Completion Time TS 3.6.4.1, Condition A, and TS 3.6.4.3, Condition D, for both Units 1 and 2, include a one-time completion time that expired on December 31, 2005. The note states, "48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months for a one-time outage for replacement of the Reactor Building Recirculating Fan Damper Motors, to be completed by December 31, 2005." The licensee proposes to delete these notes that no longer apply.

The NRC staff finds Variation 10 acceptable because, the condition is expired and its removal is administrative in nature.

3.6 Staff Evaluation of Proposed Deletion of Reference to OPDRVs Term Section 2.2.4 of this SE lists the numerous OPDRVs references proposed for deletion. The proposed changes would replace the existing specifications related to OPDRVs with revised specifications for the RPV WIC. For example, the proposed changes would remove:

During operations with a potential for draining the reactor vessel

Only one trip system required in MODES 4 and 5 with RHR Shutdown Cooling System Integrity maintained

OPDVRs

Initiation action to suspend OPDRVs

During OPDRV The term OPDRVs is not specifically defined in the TSs and historically has been subject to inconsistent application by licensees. The changes discussed in this SE are intended to resolve any ambiguity by creating a new RPV WIC TS with attendant equipment operability requirements, required actions and SRs, and deleting references to OPDRVs throughout the TSs.

The existing Susquehanna TSs contain instrumentation requirements related to OPDRVs in four separate TSs. Proposed TS 3.3.5.2 consolidates the instrumentation requirements into a single location to simplify the presentation and provide requirements consistent with TS 3.5.2. The remaining TSs with OPDRVs requirements are for primary/secondary containment, primary/secondary containment isolation valves, SGT system, control room habitability, control room floor temperature control, and electrical sources. Each of these system's requirements during OPDRVs were proposed for consolidation into new TS 3.5.2 for RPV WIC, based on the appropriate plant conditions and calculated drain time.

The NRC staff determined that the deletion of OPDRVs references, along with the corresponding editorial changes, are appropriate because the proposed TSs governing RPV WIC and the associated instrumentation, TSs 3.5.2 and 3.3.5.2, respectively, are a simplified alternative set of controls for ensuring water level is maintained above the TAF and, therefore, these changes are acceptable.

3.7 Staff Evaluation of TS 3.10, Special Operations, and TSTF-484 The current Susquehanna TS LCO 3.10.1, "lnservice Leak and Hydrostatic Testing Operations,"

allows performance of an inservice leak or hydrostatic test with the average reactor coolant temperature greater than 212 degrees Fahrenheit (°F(. while considering operational conditions to still be in Mode 4, provided certain secondary containment LCOs are met.

TSTF-484, "Use of TS 3.10.1 for Scram Time Testing Activities," Revision 0, 12 revised LCO 3.10.1 to expand its scope to include operations where temperature exceeds 200 °F:

(1) as a consequence of maintaining adequate reactor pressure for an inservice leak or hydrostatic test or (2) as a consequence of maintaining adequate reactor pressure for control rod scram time testing initiated in conjunction with an inservice leak or hydrostatic test.

By Amendment Nos. 245 and 223 (Units 1 and 2, respectively), dated December 20, 2007, 13 the NRC approved changes to Susquehanna TS LCO 3.10.1 in accordance with TSTF-484. The NRC staff's SE for these amendments stated, in part, that, "Two low-pressure emergency core cooling systems (ECCS) injected/spray subsystems are required to be operable in Mode 4 by TS 3.5.2, ECCS-Shutdown." However, per the proposed new LCO 3.5.2, only one low pressure ECCS injection/spray subsystem would be required to be operable in Mode 4.

The NRC staff has determined that changing from two ECCS injection/spray subsystems to one ECCS injection/spray subsystem is acceptable because, as stated previously in Section 3.3 of this SE, this level of redundancy is not required, even during application of LCO 3.10.1. When the licensee applies LCO 3.10.1 at the end of a refueling outage, an exceptionally large volume of water is present in the reactor vessel since the vessel is nearly water solid. There is much more water in the reactor vessel than is present during power operation and more than is present during most of an outage. Small leaks from the reactor coolant system would be detected by inspections before a significant loss of inventory occurred. In the event of a large reactor coolant system leak, the RPV would rapidly depressurize and allow operation of the low pressure ECCS. At low decay heat values, and near Mode 4 conditions, the stored energy in the reactor core will be very low. Therefore, the reasoning that operators would have time to respond with manual actions to start any ECCS pumps and properly align valves for injection from the control room remains valid.

2 ADAMS Accession No. ML052930102 1 ADAMS Accession No. ML073330471

As stated previously in Section 3.3 of this SE, with one ECCS injection/spray subsystem and nonsafety-related injection sources, defense-in-depth will be maintained. The defense-in-depth measure is consistent with other events considered during shutdown with no additional single failure assumed. The drain time controls, in addition to the required ECCS injection/spray subsystem, provide reasonable assurance that an unexpected draining event can be prevented or mitigated before the RPV water level would be lowered to the T AF.

After considering the reasoning presented in this SE and reviewing the letter dated December 20, 2007, issuing Amendment Nos. 245 and 223, the NRC staff determined that LCOs 3.3.5.2 and 3.5.2 adopted as part of TSTF-542 are satisfactory and will be acceptable even application of LCO 3.10.1.

3.8 Technical Conclusion Susquehanna Safety Limit 2.1.1.3 requires that reactor vessel water level shall be greater than the top of active irradiated fuel. Maintaining water level above the TAF ensures that the fuel cladding fission product barrier is protected during shutdown conditions. The proposed TS changes evaluated within this SE establish new LCO requirements that address the preventive and mitigative equipment and associated instrumentation that provide an alternative means to support Safety Limit 2.1.1.3 during Mode 4 and 5 operations.

The reactor coolant system is at a low operating temperature(< 200 °F) and is depressurized during Mode 4 and 5 conditions. An event involving a loss of inventory while in the shutdown condition does not exceed the capacity of one ECCS subsystem. The accidents that are postulated to occur during shutdown conditions, the fuel and equipment handling accident (FSAR 15.7.4) and gaseous radwaste system leak or failure (FSAR 15.7.1 ), do not involve a loss of inventory. Therefore, the equipment and instrumentation associated with the reactor vessel WIC TSs do not provide detection or mitigation related to these design-basis accidents.

Proposed TS LCO 3.5.2 contains requirements for operability of one ECCS subsystem along with requirements to maintain a sufficiently long drain time so that plant operators would have time to diagnose and mitigate an unplanned draining event. The NRC staff has determined that LCOs 3.5.2 and 3.3.5.2 provide for the lowest functional capability or performance levels of equipment required for safe operation of the facility and, therefore, meet the LCO requirements of 10 CFR 50.36(c)(2}(i}.

Additionally, the revised TS LCOs 3.5.2 and 3.3.5.2 provide remedial actions to be taken in the event the LCO is not satisfied and, therefore, meet the requirements of 10 CFR 50.36(c)(2)(i).

The NRC staff finds that the proposed action statements provide reasonable assurance that an unexpected draining event can be prevented or mitigated before the RPV water level would be lowered to the TAF.

The NRC staff evaluated the proposed drain time definition, TS 3.5.2, which contains the requirements for RPV WIC, and TS 3.3.5.2, which contains the requirements for instrumentation necessary to support TS 3.5.2. Based on the considerations discussed above, the NRC staff concludes that the proposed revisions are acceptable because they consolidate and clarify the RPV WIC requirements, which meet 10 CFR 50.36(c)(2)(ii), Criterion 4, to establish LCOs for structures, systems, or components significant to public health and safety as evidenced by operating experience.

The licensee proposed to delete OPDRV references from the TS Applicability description, Condition, Required Actions, and Footnotes. The NRC staff has reviewed the proposed changes and determined that the deletion of OPDRVs references, along with the corresponding editorial changes, are appropriate because the proposed TSs governing RPV WIC and the associated instrumentation, TSs 3.5.2 and 3.3.5.2, respectively, are a clarified and simplified alternative set of controls for ensuring that water level is maintained above the TAF.

The NRC staff reviewed the SRs associated with the new LCOs 3.5.2 and 3.3.5.2. The NRC staff finds that the proposed TS SRs in TS 3.5.2 are acceptable since they support TS 3.5.2 drain time requirements, assure that water inventory is available for ECCS injection/spray subsystem RPV injection and pump performance, ECCS injection/spray subsystems are adequately filled (mitigates effects of gas accumulation or voiding}, the subsystems have verified valve positions to support RPV injection, verified pumps provide adequate flow to support drain time and RPV injection, verification of automatic isolation, and ECCS injection/spray subsystems can be manually operated to inject by main control room push buttons. The NRC staff finds that the three SRs proposed for TS 3.3.5.2 are sufficient and adequate, because they ensure that the Functions are capable of performing their specified safety functions in support of TS 3.5.2, Drain Time, and the protection from a potential draindown of the RPV in Modes 4 and 5. Therefore, the NRC staff concludes that the proposed SRs satisfy 10 CFR 50.36(c)(3).

The NRC staff evaluated the licensee's proposed changes against each of the unit applicable design requirements listed in Section 2.3 of this SE. The NRC staff finds that the proposed changes for Mode 4 and 5 operations, as they relate to the proposed TS changes for the new drain time definition and the removal of OPDRV references remain consistent with the GDCs in that the Susquehanna design requirements for instrumentation, reactor coolant leakage detection, reactor coolant pressure boundary, and reactor coolant makeup are unaffected.

The regulation at 10 CFR 50.36(a)(1) states that a summary statement of the bases or reasons for such specifications, other than those covering administrative controls, shall also be included in the application, but shall not become part of the TSs. In accordance with this requirement, the licensee provided TS Bases changes in the proposed license amendment request. The NRC staff concludes that the TS Bases changes provided describe the basis for the affected TSs and follow the Final Policy Statement on TSs Improvements for Nuclear Power Reactors (58 FR 39132).

Additionally, the proposed TS changes were reviewed for technical clarity and consistency with the existing Susquehanna requirements for customary terminology and formatting. The NRC staff found that the proposed changes were consistent with TSTF-542 and Standard Review 0 1an Chapter 16.

.0 STATE CONSULTATION accordance with the Commission's regulations, the Pennsylvania State official was notified of

\ proposed issuance of the amendments on June 12, 2018. The State official had no nments.

ENVIRONMENTAL CONSIDERATION 1mendments change a requirement with respect to installation or use of a facility onent located within the restricted area as defined in 10 CFR Part 20 and change* SRs.

The NRC staff has determined that the amendments involve no significant increase in the amounts, and no significant change in the types, of any effluents that may be released offsite, and that there is no significant increase in individual or cumulative occupational radiation exposure. The Commission has previously issued a proposed finding that the amendments involve no significant hazards consideration, and there has been no public comment on such finding published in the Federal Register on November 21, 2017 (82 FR 55414). Accordingly, the amendments meet the eligibility criteria for categorical exclusion set forth in 10 CFR 51.22(c)(9). Pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the issuance of the amendments.

6.0 CONCLUSION

The Commission 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: M. Razzaque K. West L. Wheeler Date: September 26, 2018

K. Cimorelli

SUBJECT:

SUSQUEHANNA STEAM ELECTRIC STATION, UNITS 1 AND 2 - ISSUANCE OF AMENDMENT NOS. 271 AND 253 REVISING TECHNICAL SPECIFICATIONS TO ADOPT TSTF-542, REVISION 2 (CAC NOS. MG0269 AND MG0270; EPID L-2017-LLA-0306) DATED SEPTEMBER 26, 2018 DISTRIBUTION:

PUBLIC RidsRgn 1MailCenter Resource RidsACRS_MailCTR Resource RidsNrrDeEicb Resource RidsNrrDorlLpl1 Resource RidsNrrDssSrxb Resource RidsNrrDssStsb Resource RidsNrrLAJBurkhardt Resource RidsNrrLALRonewicz Resource RidsNrrPMSusquehanna Resource RHaskell, NRR MRazzaque, NRR PSnyder, NRR DWarner, NRR KWest, NRR LWheeler, NRR ADAMS Access1on No.: ML18222A203

b>V e-ma1*1 **b y memorandum OFFICE DORL/LPL 1/PM DORL/LPL 1/LA DSS/STSB/BC** DE/El CB/BC NAME THood LRonewicz VCusumano MWaters DATE 08/24/2018 09/04/2018 05/21/2018 05/15/2018 OFFICE DSS/SRXB/BC OGC-NLO DORL/LPL 1/BC DORL/LPL 1/PM NAME JWhitman STurk (w/comment) JDanna THood DATE 05/15/2018 09/18/2018 09/25/2018 09/26/2018 OFFICIAL RECORD COPY

v t e Letter Sequence Approval
CAC:MG0269, (Approved, Closed) CAC:MG0270, (Approved, Closed) EPID:L-2017-LLA-0306, (Approved, Closed)
Initiation Request Acceptance Supplement Administration Questions Answers Results Approval Other: PLA-7709, Proposed Amendment to Licenses: Change to Requested Implementation Date Associated with TSTF-542, Reactor Pressure Vessel Water Inventory Control
MONTHYEAR2018-02-16 [Table View]

ML18222A203

Text

SUBJECT:

Dear Mr. Cimorelli:

Enclosures:

Attachment:

Attachment:

1.0 INTRODUCTION

2.0 REGULATORY EVALUATION

3.0 TECHNICAL EVALUATION

6.0 CONCLUSION

SUBJECT:

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