Text

Issuance of Amendment Nos. 227 and 190 Revising Technical Specifications to Adopt TSTF-542, Revision 2, Reactor Pressure Vessel Water Inventory Control (CAC Nos. MF9967 and MF9968; EPID L-2017-LLA-0260)
	ML18017A201
Person / Time
Site:	Limerick
Issue date:	02/27/2018
From:	V Sreenivas; Plant Licensing Branch 1
To:	Bryan Hanson; Exelon Generation Co, Exelon Nuclear
	Sreenivas V, NRR/DORL/LPLI, 415-2597
References
	CAC MF9967, CAC MF9968, EPID L-2017-LLA-0260
	Download: ML18017A201 (118)
	v • d • e

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 February 27, 2018 Mr. Bryan C. Hanson Senior Vice President Exelon Generation Company, LLC President and Chief Nuclear Officer Exelon Nuclear 4300 Winfield Road Warrenville, IL 60555

SUBJECT:

LIMERICK GENERATING STATION, UNITS 1 AND 2 - ISSUANCE OF AMENDMENT NOS. 227 AND 190 REVISING TECHNICAL SPECIFICATIONS TO ADOPT TSTF-542, REVISION 2, "REACTOR PRESSURE VESSEL WATER INVENTORY CONTROL" (CAC NOS. MF9967 AND MF9968; EPID L-2017-LLA-0260)

Dear Mr. Hanson:

The U.S. Nuclear Regulatory Commission (the Commission) has issued the enclosed Amendment Nos. 227 and 190 to Renewed Facility Operating License Nos. NPF-39 and NPF-85 for the Limerick Generating Station, Units 1 and 2, respectively. These amendments consist of changes to the technical specifications in response to your application dated July 19, 2017, as supplemented by letters dated December 6, 2017; February 19, 2018; and February 27, 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 2.1.4. Safety Limit 2.1.4 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."

A copy of our related Safety Evaluation is also enclosed. Notice of Issuance will be included in the Commission's biweekly Federal Register notice.

Sincerely,

. Sreenivas, Project Manager Plant Licensing Branch I Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket Nos. 50-352 and 50-353

Enclosures:

1. Amendment No. 227 to Renewed NPF-39

2. Amendment No. 190 to Renewed NPF-85

3. Safety Evaluation cc w/

Enclosures:

Distribution via Listserv

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, O.C. 20555-0001 EXELON GENERATION COMPANY, LLC DOCKET NO. 50-352 LIMERICK GENERATING STATION, UNIT 1 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 227 Renewed License No. NPF-39

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

A. The application for amendment by Exelon Generation Company, LLC (Exelon Generation Company), dated July 19, 2017, as supplemented by letters dated December 6, 2017; February 19, 2018; and February 27, 2018, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations set forth in 10 CFR Chapter I; B. The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C. There is reasonable assurance (i) that the activities authorized by this amendment can be conducted v.nthout endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance v.nth the Commission's regulations; D. The issuance of this amendment v.nll 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 paagraph 2.C.(2) of Renewed Facility Operating License No. NPF-39 is hereby amended to read as follows:

(2) Technical Specifications The Technical Specifications contained in Appendix A and the Environmental Protection Plan contained in Appendix B, as revised through Amendment No. 227, are hereby incorporated into this renewed license. Exelon Generation Company 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 no later than May 31, 2019.

FOR THE NUCLEAR REGULATORY COMMISSION JS:~-

Plant Licensing Branch I Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the Facility Operating License and Technical Specifications Date of Issuance: February 27, 2018

ATTACHMENT TO LICENSE AMENDMENT NO. 227 LIMERICK GENERATING STATION, UNIT 1 RENEWED FACILITY OPERATING LICENSE NO. NPF-39 DOCKET NO. 50-352 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 3 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 3/4 5-6a vii vii 3/4 5-7 3/4 5-7 xii xii 3/4 5-8 3/4 5-8 xviii xviii 3/4 5-9 3/4 5-9 xx xx 3/4 6-47 3/4 6-47 1-2 1-2 3/4 6-50 3/4 6-50 1-2a 3/4 6-52 3/4 6-52 3/4 3-16 3/4 3-16 3/4 7-6 3/4 7-6 3/4 3-31 3/4 3-31 3/4 7-7 3/4 7-7 3/4 3-33 3/4 3-33 3/4 8-9 3/4 8-9 3/4 3-35 3/4 3-35 3/4 8-14a 3/4 8-14a 3/4 3-36 3/4 3-36 3/4 8-20 3/4 8-20 3/4 3-40 3/4 3-40 3/4 3-41 3/4 3-41 3/4 3-41a 3/4 3-41b 3/4 3-41c 3/4 3-41d 3/4 3-41e 3/4 3-65 3/4 3-65 3/4 3-67 3/4 3-67 3/4 5-6 3/4 5-6

(2) Pursuant to the Act and 10 CFR Part 70, to receive, possess and to use at any time special nuclear material as reactor fuel, in accordance with the limitations for storage and amounts required for reactor operation, as described in the Final Safety Analysis Report, as supplemented and amended; (3) Pursuant to the Act and 10 CFR Parts 30, 40 and 70, to receive, possess and use at any time any byproduct, source and special nuclear material as sealed neutron sources for reactor startup, sealed sources for reactor instrumentation and radiation monitoring equipment calibration, and as fission detectors in amounts as required; (4) Pursuant to the Act and 10 CFR Parts 30, 40, 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) 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, and to receive and possess, but not separate, such source, byproduct, and special nuclear materials as contained in the fuel assemblies and fuel channels from the Shoreham Nuclear Power Station.

C. This renewed license shall be deemed to contain and is subject to the conditions specified in the Commission's regulations set forth in 10 CFR Chapter I (except as exempted from compliance in Section 2.0. below) 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 Exelon Generation Company is authorized to operate the facility at reactor core power levels not in excess of 3515 megawatts thermal

( 100% rated power) in accordance with the conditions specified herein and in Attachment 1 to this license. The items identified in Attachment 1 to this renewed license shall be completed as specified. Attachment 1 is hereby incorporated into this renewed license.

(2) Technical Specifications The Technical Specifications contained in Appendix A and the Environmental Protection Plan contained in Appendix B, as revised through Amendment No. 227, are hereby incorporated into this renewed license. Exelon Generation Company shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

Renewed License No. NPF-39 Amendment No. 227

DEFIN TION SECTION

1. 0 DEF IN IT IONS

1. 1 ACT I ON ....................................................... 1-1 1.2 AVERAGE PLANAR EXPOSURE ...................................... 1-1 1.3 AVERAGE PLANAR LINEAR HEAT GENERATION RATE ................... 1-1 1.4 CHANNEL CALIBRATION .......................................... 1-1 1.5 CHANNEL CHECK ................................................ 1-1 1.6 CHANNEL FUNCTIONAL TEST ...................................... 1-1

1. 7 CORE ALTERATION .............................................. 1-2 1.7A CORE OPERATING LIMITS REPORT ................................. 1-2 1.8 CRITICAL POWER RATIO ......................................... 1-2 1.9 DOSE EQUIVALENT I-131. ....................................... 1-2 1.9a DOWNSCALE TRIP SETPOINT (DTSP) ............................... 1-2 1 . 9b DRAIN TIME . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1- 2 1.10 (DELETED) .................................................... l-2a 1.11 EMERGENCY CORE COOLING SYSTEM (ECCS) RESPONSE TIME ........... l-2a 1.12 END-OF-CYCLE RECIRCULATION PUMP TRIP SYSTEM RESPONSE TIME .... 1-3 1.13 (DELETED) .................................................... 1-3 1.14 (DELETED) .................................................... 1-3 1.15 FREQUENCY NOTATION ........................................... 1-3 1.15a HIGH (POWER) TRIP SETPOINT (HTSP) ............................ 1-3 1.16 IDEN TI FI ED LEAKAGE ........................................... 1-3 1.16a INTERMEDIATE (POWER) TRIP SETPOINT (ITSP) .................... 1-3 1.17 ISOLATION SYSTEM RESPONSE TIME ............................... 1-3 1.18 LIMITING CONTROL ROD PATTERN ................................. 1-3 1.19 LINEAR HEAT GENERATION RATE .................................. 1-3 1.20 LOGIC SYSTEM FUNCTIONAL TEST ................................. 1-4 LIMERICK - UNIT 1 Amendment No. JJ, J-7., ~. +74, 227

INDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS SECTION INSTRUMENTATION (Continued) 3/4.3.2 ISOLATION ACTUATION INSTRUMENTATION .......................... 3/4 3-9 Table 3.3.2-1 Isolation Actuation Instrumentation .......................... 3/4 3-11 Table 3.3.2-2 Isolation Actuation Instrumentation Setpoints ................ 3/4 3-18 Table 3.3.2-3 Isolation System Instrumen-tation Response Time ..................... 3/4 3-23 Table 4.3.2.1-1 Isolation Actuation Instrumen-tation Surveillance Requirements ........................... 3/4 3-27 3/4.3.3 EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION .............................................. 3/4 3-32 Table 3.3.3-1 Emergency Core Cooling System Actuation Instrumentation ................ 3/4 3-33 Table 3.3.3-2 Emergency Core Cooling System Actuation Instrumentation Setpoints ................................ 3/4 3-37 Table 3.3.3-3 Emergency Core Cooling System Response Times ........................... 3/4 3-39 Table 4.3.3.1-1 Emergency Core Cooling System Actuation Instrumentation Surveillance Requirements .............. 3/4 3-40 3/4.3.3.A REACTOR PRESSURE VESSEL (RPV) WATER INVENTORY CONTROL (WIC)

INSTRUMENTATION .............................................. 3/4 3-4la Table 3.3.3.A-l RPV Water Inventory Control (WIC)

Instrumentation ......................... 3/4 3-4lb Table 3.3.3.A-2 RPV Water Inventory Control (WIC)

Instrumentation Set points ............... 3/4 3-4ld Table 4.3.3.A-l RPV Water Inventory Control (WIC)

Instrumentation Surveillance Requirements3/4 3-4le 3/4.3.4 RECIRCULATION PUMP TRIP ACTUATION INSTRUMENTATION ATWS Recirculation Pump Trip System Instrumentation .......... 3/4 3-42 Table 3.3.4.1-1 ATWS Recirculation Pump Trip System Instrumentation ................. 3/4 3-43 Table 3.3.4.1-2 ATWS Recirculation Pump Trip System Instrumentation Setpoints .............................. 3/4 3-44 Table 4.3.4.1-1 (Deleted) .............................. 3/4 3-45 End-of-Cycle Recirculation Pump Trip System Instrumentation .............................................. 3/4 3-46 LIMERICK - UNIT 1 Vii Amendment No. JJ, ~ . 227

LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS SECTION REACTOR COOLANT SYSTEM (Continued) 3/4.4.9 RESIDUAL HEAT REMOVAL Hot Shutdown ............................................... 3/4 4-25 Cold Shutdown .............................................. 3/4 4-26 3/4.5 EMERGENCY CORE COOLING SYSTEMS 3/4.5.1 ECCS - OPERATING ........................................... 3/4 5-1 3/4.5.2 REACTOR PRESSURE VESSEL (RPV)

WATER INVENTORY CONTROL (WIC) .............................. 3/4 5-6 3/4.5.3 SUPPRESSION CHAMBER ........................................ 3/4 5-8 3/4.6 CONTAINMENT SYSTEMS 3/4.6.1 PRIMARY CONTAINMENT Primary Containment Integrity .............................. 3/4 6-1 Primary Containment Leakage ................................ 3/4 6-2 Primary Containment Air Lock ............................... 3/4 6-5 MSIV Leakage Alternate Drain Pathway ....................... 3/4 6-7 Primary Containment Structural Integrity ................... 3/4 6-8 Drywel l and Suppression Chamber Internal Pressure .......... 3/4 6-9 Drywell Average Air Temperature ............................ 3/4 6-10 Drywell and Suppression Chamber Purge System ............... 3/4 6-11 3/4.6.2 DEPRESSURIZATION SYSTEMS Suppression Chamber ........................................ 3/4 6-12 Suppression Pool Spray ..................................... 3/4 6-15 Suppression Pool Cooling ................................... 3/4 6-16 3/4.6.3 PRIMARY CONTAINMENT ISOLATION VALVES ....................... 3/4 6-17 LIMERICK - UNIT 1 xii Amendment No. J.J, +G+, J..4e, 227

BASES SECTION 3/4.0 APPLICABILITY .................................................... B 3/4 0-1 3/4.1 REACTIVITY CONTROL SYSTEMS 3/4.1.1 SHUTDOWN MARGIN ............................................. B 3/4 1-1 3/4.1.2 REACTIVITY ANOMALIES ........................................ B 3/4 1-1 3/4.1.3 CONTROL RODS ................................................ B 3/4 1-2 3/4.1.4 CONTROL ROD PROGRAM CONTROLS ................................ B 3/4 1-3 3/4.1.5 STANDBY LIQUID CONTROL SYSTEM ............................... B 3/4 1-4 3/4.2 POWER DISTRIBUTION LIMITS 3/4.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 3/ 4 2-1 3/4.2.2 (DELETED) ................................................... B 3/4 2-2 LEFT INTENTIONALLY BLANK ............................................... B 3/4 2-3 3/4.2.3 MINIMUM CRITICAL POWER RATIO ................................ B 3/4 2-4 3/4.2.4 LINEAR HEAT GENERATION RATE ................................. B 3/4 2-5 3/4.3 INSTRUMENTATION 3/4.3.1 REACTOR PROTECTION SYSTEM INSTRUMENTATION ................... B 3/4 3-1 3/4.3.2 ISOLATION ACTUATION INSTRUMENTATION ......................... B 3/4 3-2 3/4.3.3 EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION ............................................. B 3/4 3-2 3/4.3.3.A REACTOR PRESSURE VESSEL (RPV) WATER INVENTORY CONTROL (WIC) INSTRUMENTATION ............................... B 3/4 3-2a 3/4.3.4 RECIRCULATION PUMP TRIP ACTUATION INSTRUMENTATION ........... B 3/4 3-3 3/4.3.5 REACTOR CORE ISOLATION COOLING SYSTEM ACTUATION INSTRUMENTATION ............................................. B 3/4 3-4 3/4.3.6 CONTROL ROD BLOCK INSTRUMENTATION ........................... B 3/4 3-4 3/4.3.7 MONITORING INSTRUMENTATION Radiation Monitoring Instrumentation ..................... B 3/4 3-5 LIMERICK - UNIT 1 xviii Amendment No.+, JJ, ~. ~. 227

BAE SECTION REACTOR COOLANT SYSTEM (Continued) 3/4.4.5 SPECIFIC ACTIVITY ............................................ B 3/4 4-4 3/4.4.6 PRESSURE/TEMPERATURE LIMITS .................................. B 3/4 4-4 Bases Table B 3/4.4.6-1 Reactor Vessel Toughness ..................... B 3/4 4-7 Bases Figure B 3/4.4.6-1 Fast Neutron Fluence (E>l MeV) At 1/4 T As A Function of Service Life .......................... B 3/4 4-8 3/4.4.7 MAIN STEAM LINE ISOLATION VALVES ............................. B 3/4 4-6 3/4.4.8 (DELETED) .................................................... B 3/4 4-6 3/4.4.9 RESIDUAL HEAT REMOVAL ........................................ B 3/4 4-6 3/4.5 EMERGENCY CORE COOLING SYSTEMS 3/ 4 . 5 . 1 EC CS - 0PERA TI NG . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 3/ 4 5 -1 3/4 5.2 REACTOR PRESSURE VESSEL (RPV) WATER INVENTORY CONTROL (WIC) ........................................... B 3/4 5-3a 3/4.5.3 SUPPRESSION CHAMBER ..................................... B 3/4 5-4 3/4.6 CONTAINMENT SYSTEMS 3/4.6.1 PRIMARY CONTAINMENT Primary Containment Integrity ........................... B 3/4 6-1 Primary Containment Leakage ............................. B 3/4 6-1 Primary Containment Air Lock ............................ B 3/4 6-1 MSIV Leakage Control System ............................. B 3/4 6-1 Primary Containment Structural Integrity ................ B 3/4 6-2 Drywell and Suppression Chamber Internal Pressure .............................................. B 3/4 6-2 Drywel l Average Air Temperature ......................... B 3/4 6-2 Drywel l and Suppression Chamber Purge System ............ B 3/4 6-2 3/4.6.2 DEPRESSURIZATION SYSTEMS ................................ B 3/4 6-3 LIMERICK - UNIT 1 xx Amendment No. ;n, 9-9-,

Associated with Amendment 216 227

DEFI IT CORE ALTERATION 1.7 CORE ALTERATION shall be the movement of any fuel, sources, or reactivity control components within the reactor vessel with the vessel head removed and fuel in the vessel. The following exceptions are not considered to be CORE ALTERATIONS:

a) Movement of source range monitors, local power range monitors, intermediate range monitors, traversing incore probes, or special moveable detectors (including undervessel replacement); and b) Control rod movement, provided there are no fuel assemblies in the associated core cell.

Suspension of CORE ALTERATIONS shall not preclude completion of movement of a component to a safe position.

CORE OPERATING LIMITS REPORT 1.7a The CORE OPERATING LIMITS REPORT (COLR) is the unit-specific document that provides the core operating limits for the current operating reload cycle. These cycle-specific core operating limits shall be determined for each reload cycle in accordance with Specifications 6.9.1.9 thru 6.9.1.12. Plant operation within these limits is addressed in individual specifications.

CRITICAL POWER RATIO 1.8 The CRITICAL POWER RATIO (CPR) shall be the ratio of that power in the assembly which is calculated by application of the (GEXL) correlation to cause some point in the assembly to experience boiling transition, divided by the actual assembly operating power.

DOSE EQUIVALENT I-131 1.9 DOSE EQUIVALENT I-131 shall be that concentration of I-131, microcuries per gram, which alone would produce the same inhalation committed effective dose equivalent (CEDE) as the quantity and isotopic mixture of I-131, I-132, I-133, I-134, and I-135 actually present. The inhalation committed effective dose equivalent (CEDE) conversion factors used for this calculation 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," ORNL, 1989, as described in Regulatory Guide 1.183. The factors in the column headed "effective" yield doses corresponding to the CEDE.

DOWNSCALE TRIP SETPOINT (DTSPl 1.9a The downscale trip setpoint associated with the Rod Block Monitor (RBM) rod block trip setting.

DRAIN TIME 1.9b 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; bl 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 LIMERICK - UNIT 1 1-2 Amendment No. J+, -i-&, &-7-, +74, +&§., 227

DEFI IT DRAIN TIME (Continued) 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 is 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.

1.10 (Deleted)

EMERGENCY CORE COOLING SYSTEM (ECCS) RESPONSE TIME 1.11 The EMERGENCY CORE COOLING SYSTEM (ECCS) RESPONSE TIME shall be that time interval from when the monitored parameter exceeds its ECCS actuation set-point 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 any series of sequential, overlapping or total steps such that the entire response time is measured.

LIMERICK - UNIT 1 l-2a Amendment No. :J+, ~. &+, +/-+4, ~ . 227

TABLE 3.3.2-1 (Continued)

ISOLATION ACTUATION INSTRUMENTATION ACTION STATEMENTS ACTION 20 - Be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the next 24-hours.

ACTION 21 - Be in at least STARTUP with the associated isolation valves closed within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 22 - Be in at least STARTUP within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

ACTION 23 - In OPERATIONAL CONDITION 1 or 2, verify the affected system isolation valves are closed within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and declare the affected system inoperable. In OPERATIONAL CONDITION 3, be in at least COLD SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

ACTION 24 - Restore the manual initiation function to OPERABLE status within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or close the affected system isolation valves within the next hour and declare the affected system inoperable or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 25 - Establish SECONDARY CONTAINMENT INTEGRITY with the standby gas treatment system operating within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

ACTION 26 - Close the affected system isolation valves within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

TABLE NOTATIONS

Required when handling RECENTLY IRRADIATED FUEL in the secondary containment.

- May be bypassed under administrative control, with all turbine stop valves closed.

During operation of the associated Unit 1 or Unit 2 ventilation exhaust system.

(a) DELETED (b) A channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance without placing the trip system in the tripped condition provided at least one OPERABLE channel in the same trip system is monitoring that parameter. Trip functions common to RPS Actuation Instrumentation are shown in Table 4.3.2.1-1. In addition, for the HPCI system and RCIC system isolation, provided that the redundant isolation valve, inboard or outboard, as applicable, in each line is OPERABLE and all required actuation instrumentation for that valve is OPERABLE, one channel may be placed in an inoperable status for up to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months for required surveillance without placing the channel or trip system in the tripped condition.

LIMERICK - UNIT 1 3/4 3-16 Amendment No. ~.4G,-9-d,-e-9,-14i, ~.227

TABLE 4.3.2.1-1 (Continued)

ISO_LAIJON ACTUATION INSTRUMrnTA_llON SURVEILLANCE REQUIREMENTS CHANNEL OPERATIONAL CHANNEL FUNCTIONAL CHANNEL CONDITIONS FOR WHICH TRIP FUNCTION CHECK (a) TEST (a) CALIBRATION(a) SURVEILLANCE REQUIRED

7. SECONDARY CONTAINMENT ISOLATION

a. Reactor Vessel Water Level Low, Low - Level 2 1, 2, 3

b. Drywel l Pressure## - High 1, 2, 3 c.1. Refueling Area Unit 1 Ventilation Exhaust Duct Radiation - High *#

2. Refueling Area Unit 2 Ventilation Exhaust Duct Radiation - High *#

d. Reactor Enclosure Ventilation Exhaust Duct Radiation - High 1, 2, 3

e. Deleted

f. Deleted

g. Reactor Enclosure Manual Initiation N.A. N.A. 1, 2, 3

h. Refueling Area Manual Initiation N.A. N.A. *

(a) Frequencies are specified in the Surveillance Frequency Control Program unless otherwise noted in the table.

Required when handling RECENTLY IRRADIATED FUEL in the secondary containment.

- When not administratively bypassed and/or when any turbine stop valve is open.

During operation of the associated Unit 1 or Unit 2 ventilation exhaust system.

1. These trip functions (2a, 6b, and 7b) are common to the RPS actuation trip function.

LIMERICK - UNIT 1 3/4 3-31 Amendment No . .iJ, 4G, w, @, g.g., ~ . ~ . ~ . 227

TABLE 3.3.3-1 EMER_G_ENCY_CORE COOLING SYSTEM ACTUATION INSTRUMENTATION MINIMUM OPERABLE CHANNELS PER APPLICABLE TRIP OPERATIONAL TRIP FUN CTI ON FUNCTION(al CONDITIONS ACTION

1. CORE SPRAY SYSTEM***

(b)

a. Reactor Vessel Water Level - Low Low Low, Level 1 2/pump(bl 1, 2, 3 30

b. Drywel l Pressure - High 2/pump 1, 2, 3 30 6(b)

C. Reactor Vessel Pressure - Low (Permissive) 1, 2, 3 31 z(e) 1, 2, 3

d. Manual Initiation 33

2. LOW PRESSURE COOLANT INJECTION MODE OF RHR SYSTEM***

a. Reactor Vessel Water Level - Low Low Low, Level 1 2 1, 2, 3 30

b. Drywel l Pressure - High 2 1, 2, 3 30 C. Reactor Vessel Pressure - Low (Permissive) 2 1, 2, 3 31

d. Injection Valve Differential Pressure-Low 1/valve 1, 2, 3 31 (Permissive)

e. Manual Initiation 1 1, 2, 3 33

3. HIGH PRESSURE COOLANT INJECTION SYSTEM##

a. Reactor Vessel Water LeltBJ - Low Low Level 2 4 1, 2, 3 34

b. Drywel l Pressure - High 4 1, 2, 3 34 z(c)

C. Condensate Storage Tank Level - Low 1, 2, 3 35

d. Suppression Pool Water Level - High 2(d) 1, 2, 3 35

e. Reactor Vessel WaMJ Level - High, Level 8 4 1, 2, 3 31

f. Manual Initiation 1/system 1, 2, 3 33 LIMERICK - UNIT 1 3/4 3-33 Amendment No. -bM-, 227

TABLE 3.3.3-1 (Continued)

EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION TABLE NOTATIONS (a) A channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance without placing the trip system in the tripped condition provided at least one OPERABLE channel in the same trip system is monitoring that parameter.

(b) Also provides input to actuation logic for the associated emergency diesel generators.

(c) One trip system. Provides signal to HPCI pump suction valves only.

(d) On 1 out of 2 taken twice logic, provides a signal to trip the HPCI pump turbine only.

(e) The manual initiation push buttons start the respective core spray pump and diesel generator. The "A" and "B" logic manual push buttons also actuate an initiation permissive in the injection valve opening logic.

(f) A channel as used here is defined as the 127 bus relay for Item 1 and the 127, 127Y, and 127Z feeder relays with their associated time delay relays taken together for Item 2.

DELETED

Not required to be OPERABLE when reactor steam dome pressure is less than or equal to 100 psig.

- Required when ESF equipment is required to be OPERABLE.

1. Not required to be OPERABLE when reactor steam dome pressure is 1ess than or equal to 200 psig.

1. 1. The injection functions of Drywell Pressure - High and Manual Initiation are not required to be OPERABLE with reactor steam dome pressure less than 550 psig.

LIMERICK - UNIT 1 3/4 3-35 Amendment No. -eJ,-l24, 227

TABLE 3.3.3-1 (Continued)

EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION ACTION STATEMENTS ACTION 30 - With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement:

a. With one channel inoperable, place the inoperable channel in the tripped condition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or declare the associated system inoperable.

b. With more than one channel inoperable, declare the associated system inoperable.

ACTION 31 - With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement, declare the associated ECCS inoperable within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 32 - DELETED ACTION 33 - With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement, restore the inoperable channel to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or declare the associated ECCS inoperable.

ACTION 34 - With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement:

a. For one channel inoperable, place the inoperable channel in the tripped condition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or declare the HPCI system inoperable.

b. With more than one channel inoperable, declare the HPCI system inoperable.

ACTION 35 - With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement, place at least one inoperable channel in the tripped condition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or declare the HPCI system inoperable.

ACTION 36 - With the number of OPERABLE channels less than the Total Number of Channels, declare the associated emergency diesel generator and the associated offsite source breaker that is not supplying the bus inoperable and take the ACTION required by Specification 3.8.1.1 or 3.8.1.2, as appropriate.

LIMERICK - UNIT 1 3/4 3-36 Amendment No. ii, ~. -+/--e&, 227

TABLE 4.3.3.1-1 EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS CHANNEL OPERATIONAL CHANNEL FUNCTIONAL CHANNEL CONDITIONS FOR WHICH TRIP FUNCTION CHECK(a) TEST(a) CALIBRATION(a) SURVEILLANCE REQUIRED

1. CORE SPRAY SYSTEM

a. Reactor Vessel Water Level -

Low Low Low, Level 1 1, 2, 3

b. Drywel l Pressure - High 1, 2, 3 C. Reactor Vessel Pressure - Low 1, 2, 3

d. Manual Initiation N.A. N.A. 1, 2, 3

2. LOW PRESSURE COOLANT INJECTION MODE OF RHR SYSTEM

a. Reactor Vessel Water Level -

Low Low Low, Level 1 1, 2, 3

b. Drywell Pressure - High 1, 2, 3 C. Reactor Vessel Pressure - Low 1, 2, 3

d. Injection Valve Differential Pressure - Low (Permissive) 1, 2, 3

e. Manual Initiation N.A. N.A. 1, 2, 3

3. HIGH PRESSURE COOLANT INJECTION SYSTEM***

a. Reactor Vessel Water Level -

Low Low, Level 2 1, 2, 3

b. Drywell Pressure - High 1, 2, 3 C. Condensate Storage Tank Level -

Low 1, 2, 3

d. Suppression Pool Water Level -

High 1, 2, 3

e. Reactor Vessel Water Level -

High, Level 8 1, 2, 3

f. Manual Initiation N.A. N.A. 1, 2, 3 LIMERICK - UNIT 1 3/4 3-40 Amendment No. BJ, -7+, ~ . 227

TABLE 4.3.3.1-1 (Continued)

EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS CHANNEL OPERATIONAL CHANNEL FUNCTIONAL CHANNEL CONDITIONS FOR WHICH TRIP FUNCTION CHE..G.KW TEST( a) CALIBRATION(a) SURVEILLANCE REQUIRED

4. AUTOMATIC DEPRESSURIZATION SYSTEM#

a. Reactor Vessel Water Level -

Low Low Low, Level 1 1, 2, 3

b. Drywel l Pressure - High 1, 2, 3 C. ADS Timer N.A. 1, 2, 3

d. Core Spray Pump Discharge Pressure - High 1, 2, 3

e. RHR LPCI Mode Pump Discharge Pressure - High 1, 2, 3

f. Reactor Vessel Water Level - Low, Level 3 1, 2, 3

g. Manual Initiation N.A. N.A. 1, 2, 3

h. ADS Drywell Pressure Bypass Timer N. A. 1, 2, 3

5. LOSS OF POWER

a. 4.16 kV Emergency Bus Under-voltage (Loss of Voltage)~ N.A. N.A. 1, 2, 3, 4**, 5**

b. 4.16 kV Emergency Bus Under -

voltage (Degraded Voltage) 1, 2, 3, 4**, 5**

(a) Frequencies are specified in the Surveillance Frequency Control Program unless otherwise noted in the table.

DELETED

- Required OPERABLE when ESF equipment is required to be OPERABLE.

- - Not required to be OPERABLE when reactor steam dome pressure is less than or equal to 200 psig.

Not required to be OPERABLE when reactor steam dome pressure is less than or equal to 100 psig.

1. Loss of Voltage Relay 127-llX is not field setable.

LIMERICK - UN IT 1 3/4 3-41 Amendment No. -&J, ~ . 227

INSTRUMENTATION 3/4.3.3.A REACTOR PRESSURE VESSEL (RPV) WATER INVENTORY CONTROL (WIC) INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.A The RPV Water Inventory Control (WIC) instrumentation channels shown in Table 3.3.3.A-l shall be OPERABLE.

APPLICABILITY: As shown in Table 3.3.3.A-l ACTION:

a. With one or more channels inoperable in a trip system, take the ACTION referenced in Table 3.3.3.A-l for the trip system.

SURVEILLANCE REQUIREMENTS 4.3.3.1.A Each RPV Water Inventory Control (WIC) instrumentation channel shall be demonstrated OPERABLE by performance of the CHANNEL CHECK, CHANNEL FUNCTIONAL TEST and LOGIC SYSTEM FUNCTIONAL TEST as shown in Table 4.3.3.A-l and at the frequencies specified in the Surveillance Frequency Control Program unless otherwise noted in Table 4.3.3.A-l.

LIMERICK - UNIT 1 3/4 3-4la Amendment No. 227

TABLE 3.3.3.A-l RPV WATER INVENTORY CONTROL (WIC) INSTRUMENTATION MINIMUM OPERABLE CHANNELS PER APPLICABLE TRIP OPERATIONAL TRIP FUNCTION FUNCTION CONDITIONS ACTION

1. CORE SPRAY SYSTEM

a. Reactor Vessel Pressure - Low (Permissive) 5(a) 4, 5 39

b. Manual Initiation 2(a)(c) 4, 5 40

2. LOW PRESSURE COOLANT INJECTION MODE OF RHR SYSTEM

a. Injection Valve Differential Pressure - Low (Permissive) 1/val ve(a) 4, 5 39

b. Manual Initiation 1(a) 4, 5 40

3. RHR SYSTEM SHUTDQ_WN COOLING MODE ISOLATION

a. Reactor Vessel Water Level -

Low - Level 3 2 in one ( b) 38 trip system

4. REACTOR WATER CLEANUP SYSTEM ISOLATION

a. Reactor Vessel Water Level -

Low, Low - Level 2 2 in one ( b) 38 trip system (a) Associated with an ECCS subsystem required to be OPERABLE by LCD 3.5.2, "REACTOR PRESSURE VESSEL (RPV) WATER INVENTORY CONTROL (WIC)."

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

(c) The manual initiation push buttons start the respective core spray pump and diesel generator. The "A" and "B" logic manual push buttons also actuate an initiation permissive in the injection valve opening logic.

LIMERICK - UNIT 1 3/4 3-4lb Amendment No. 227

TABLE 3.3.3.A-1 (Continued)

RPV WATER INVENTORY CONTROL (WIC) INSTRUMENTATION ACTION STATEMENTS ACTION 38 - Declare the associated trip system for the penetration flow path(s) incapable of automatic isolation and calculate DRAIN TIME.

ACTION 39 - Within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , place channel in trip. Otherwise, declare associated low pressure ECCS injection/spray subsystem inoperable.

ACTION 40 - Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , restore channel to OPERABLE status. Otherwise, declare associated low pressure ECCS injection/spray subsystem inoperable.

LIMERICK - UNIT 1 3/4 3-41c Amendment No. 227

TABLE 3.3.3.A-2 RPV WATER INVENTORY CONTROL (WIC) INSTRUMENTATION SETPOINTS ALLOWABLE TRIP FUNCTION VALUE

1. CORE SPRAY SYSTEM

a. Reactor Vessel Pressure - Low (Permissive) ~ 435 psig (decreasing)

b. Manual Initiation N.A.

2. LOW PRESSURE COOLANT INJECTION MODE OF RHR SYSTEM

a. Injection Valve Differential Pressure - Low (Permissive) ::s 84 psid

b. Manual Initiation N.A.

3. RHR SYSTEM SHUTDOWN COOLING MODE ISOLATION

a. Reactor Vessel Water Level -

Low - Level 3 ~ 11.0 inches

4. REACTOR WATER CLEANUP SYSTEM ISOLATION

a. Reactor Vessel Water Level -

Low, Low - Level 2 ~ -45 inches LIMERICK - UNIT 1 3/4 3-4ld Amendment No. 227

TABLE 4.3.3.A-1 RPV WATER INVENTORY CONTROL (WIC) INSTRUMENTATION SURVEILLANCE REQUIREMENTS CHANNEL LOGIC SYSTEM OPERATIONAL CHANNEL FUNCTIONAL FUNCTIONAL CONDITIONS FOR WHICH TRIP FUNCTION CHECK( a) TEST( a) TEST(a) SURVEILLANCE REQUIRED

1. CORE SPRAY SYSTEM

a. Reactor Vessel Pressure - Low (Permissive) N.A. 4, 5

b. Manual Initiation N.A. N.A. 4, 5

2. LOW PRESSURE COOLANT INJECTION MODE OF RHR SYSTEM

a. Injection Valve Differential Pressure - Low (Permissive) N.A. 4, 5

b. Manual Initiation N.A. N.A. 4, 5

3. RHR SYSTEM SHUTDOWN COOLING MODE ISOLATION

a. Reactor Vessel Water Level -

Low - Level 3 N.A. ( b)

4. REACTOR WATER CLEANUP SYSTEM ISOLATION

a. Reactor Vessel Water Level -

Low, Low - Level 2 N.A. ( b)

(a) Frequencies are specified in the Surveillance Frequency Control Program unless otherwise noted in the table.

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

LIMERICK - UNIT 1 3/4 3-41e Amendment No. 227

TABLE 3.3.7.1-1 (Continued)

RADIATION MONITORING INSTRUMENTATION TABLE NOTATIONS

When RECENTLY IRRADIATED FUEL is being handled in the secondary containment with the vessel head removed and fuel in the vessel.

(a) With fuel in the spent fuel storage pool.

(b) Alarm only.

ACTION STATEMENTS ACTION 70 With one monitor inoperable, restore the inoperable monitor to the OPERABLE status within 7 days or, within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , initiate and maintain operation of the control room emergency filtration system in the radiation isolation mode of operation.

With two or more of the monitors inoperable, within one hour, initiate and maintain operation of the control room emergency filtration system in the radiation mode of operation.

ACTION 71 With one of the required monitor inoperable, assure a portable continuous monitor with the same alarm setpoint is OPERABLE in the vicinity of the installed monitor during any fuel movement.

If no fuel movement is being made, perform area surveys of the monitored area with portable monitoring instrumentation at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 72 With the required monitor inoperable, obtain and analyze at least one grab sample of the monitored parameter at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 73 With the required monitor inoperable, assure a portable alarming monitor is OPERABLE in the vicinity of the installed monitor or perform area surveys of the monitored area with portable monitor-ing instrumentation at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

LIMERICK - UNIT 1 3/4 3-65 Amendment No. ~ . 227

TABLE 4.3.7.1-1 (Continued)

RADIATION MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS TABLE NOTATIONS

When RECENTLY IRRADIATED FUEL is being handled in the secondary containment with the vessel head removed and fuel in the vessel.

(al With fuel in the spent fuel storage pool.

(bl The initial CHANNEL CALIBRATION shall be performed using one or more of the reference standards certified by the National Bureau of Standards (NBS) or using standards that have been obtained from suppliers that participate in measurement assurance activities with NBS. These standards shall permit calibrating the system over its intended range of energy and measurement range. For subsequent CHANNEL CALIBRATION, sources that have been related to the initial calibration shall be used.

(cl Frequencies are specified in the Surveillance Frequency Control Program unless otherwise noted in the table.

LIMERICK - UNIT 1 3/4 3-67 Amendment No. ~ . ~ . 227

EMERGENCY CORE COOLING SYSTEMS 3/4.5.2 REACTOR PRESSURE VESSEL (RPV) WATER INVENTORY CONTROL (WIC)

LIMITING CONDITION FOR OPERATION 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 At least one of the following shall be OPERABLE:

a. Core spray system (CSS) subsystem comprised of:

1. Two OPERABLE CSS pumps, and

2. An OPERABLE flow path capable of taking suction from at least one of the following water sources and transferring the water through the spray sparger to the reactor vessel:

a) From the suppression chamber, or b) When the suppression chamber water level is less than the limit or is drained, from the condensate storage tank containing at least 135,000 available gallons of water, equivalent to a level of 29 feet.

b. Low pressure coolant injection (LPCI) system subsystem comprised of:

1. One OPERABLE LPCI pump, and

2. An OPERABLE flow path capable of taking suction from the suppression chamber and transferring the water to the reactor vessel.**

APPLICABILITY: OPERATIONAL CONDITIONS 4 and 5.

ACTION:

a. With none of the above required subsystems OPERABLE, immediately suspend CORE ALTERATIONS. Restore at least one subsystem to OPERABLE status within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . Otherwise, initiate action to establish a method of water injection capable of operating without offsite electrical power.

b. DELETED

- One LPCI subsystem may be considered OPERABLE during alignment and operation for decay heat removal if capable of being manually realigned and not otherwise inoperable.

LIMERICK - UNIT 1 3/4 5-6 Amendment No. ~.227

EMERGENCY CORE COOLING SYSTEMS LIMITING CONDITION FOR OPERATION (Continued)

ACTION:

c. With DRAIN TIME less than 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months and greater than or equal to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , within 4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months s:

1. Verify SECONDARY CONTAINMENT INTEGRITY is capable of being established in less than the DRAIN TIME,

2. Verify each secondary containment penetration flow path is capable of being isolated in less than the DRAIN TIME, and

3. Verify one standby gas treatment subsystem is capable of being placed in operation in less than the DRAIN TIME.

d. With DRAIN TIME less than 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , immediately:

1. Initiate action to establish an additional method of water injection with water sources capable of maintaining RPV water level greater than TAF for greater than or equal to 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months ,***

2. Initiate action to establish SECONDARY CONTAINMENT INTEGRITY,

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

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

e. With required ACTION and associated allowed outage time for ACTIONs c. or d. not met, or DRAIN TIME less than 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , immediately initiate action to restore DRAIN TIME to greater than or equal to 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

- - The required injection/spray subsystem or an additional method of water injection shall be capable of operating without offsite electrical power.

LIMERICK - UNIT 1 3/4 5-6a Amendment No. 227 .

EMERGENCY CORE COOLING SYSTEMS SURVEILLANCE REQUIREMENTS 4.5.2.1 Verify DRAIN TIME is greater than or equal to 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months in accordance with the Surveillance Frequency Control Program.

4.5.2.2 Verify, for a required LPCI subsystem, the suppression chamber water level is greater than or equal to 16 feet O inches in accordance with the Surveillance Frequency Control Program.

4.5.2.3 Verify, for a required CSS subsystem, that the suppression chamber water level is greater than or equal to 16 feet O inches or the condensate storage tank water level is greater than or equal to 29 feet O inches in accordance with the Surveillance Frequency Control Program.

4.5.2.4 Verify, for the required ECCS injection/spray subsystem, locations susceptible to gas accumulation are sufficiently filled with water.

4.5.2.5 Verify, for the required ECCS injection/spray subsystem, each manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position in accordance with the Surveillance Frequency Control Program.#A 4.5.2.6 Operate the required ECCS injection/spray subsystem through the recirculation line for greater than or equal to 10 minutes in accordance with the Surveillance Frequency Control Program.

4.5.2.7 Verify each valve credited for automatically isolating a penetration flow path actuates to the isolation position on an actual or simulated isolation signal in accordance with the Surveillance Frequency Control Program.

4.5.2.8 Verify the required ECCS injection/spray subsystem actuates on a manual initiation signal in accordance with the Surveillance Frequency Control Program.##

DELETED.

Not required to be met for system vent flow paths open under administrative control.

AExcept that an automatic valve capable of automatic return to its ECCS position when an ECCS signal is present may be in position for another mode of operation.

1. Vessel injection/spray may be excluded.

LIMERICK - UNIT 1 3/4 5-7 Amendment No.~.~. 227

EMERGENCY CORE COOLING SYSTEMS 3/4.5.3 SUPPRESSION CHAMBER LIMITING CONDITION FOR OPERATION 3.5.3 The suppression chamber shall be OPERABLE:

a. In OPERATIONAL CONDITIONS 1, 2, and 3 with a contained water volume of at least 122,120 ft 3 , equivalent to a level of 22'0".

b. DELETED APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, and 3.

ACTION:

a. In OPERATIONAL CONDITION 1, 2 or 3 with the suppression chamber water level less than the above limit, restore the water level to within the limit within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

b. DELETED LIMERICK - UNIT 1 3/4 5-8 Amendment No. 227

EMERGENCY CORE COOLING SYSTEMS SURVEILLANCE REQUIREMENTS 4.5.3.1 The suppression chamber shall be determined OPERABLE by verifying the water level to be greater than or equal to, as applicable:

a. 22'0" in accordance with the Surveillance Frequency Control Program.

b. DELETED 4.5.3.2 DELETED LIMERICK - UNIT 1 3/4 5-9 Amendment No.~. 227

CONTAINMENT SYSTEMS 3/4.6.5 SECONDARY CONTAINMENT REFUELING AREA SECONDARY CONTAINMENT INTEGRITY LIMITING CONDITION FOR OPERATION 3.6.5.1.2 REFUELING AREA SECONDARY CONTAINMENT INTEGRITY shall be maintained.

APPLICABILITY: When RECENTLY IRRADIATED FUEL is being handled in the secondary containment.

ACTION:

Without REFUELING AREA SECONDARY CONTAINMENT INTEGRITY, suspend handling of RECENTLY IRRADIATED FUEL in the secondary containment. The provisions of Specification 3.0.3 are not applicable.

SURVEILLANCE REQUIREMENTS 4.6.5.1.2 REFUELING AREA SECONDARY CONTAINMENT INTEGRITY shall be demonstrated by:

a. Verifying in accordance with the Surveillance Frequency Control Program that the pressure within the refueling area secondary containment is greater than or equal to 0.25 inch of vacuum water gauge.

b. Verifying in accordance with the Surveillance Frequency Control Program that:

1. All refueling area secondary containment equipment hatches and blowout panels are closed and sealed.

2. At least one door in each access to the refueling area secondary containment is closed, except when the access opening is being used for entry and exit.

3. All refueling area secondary containment penetrations not capable of being closed by OPERABLE secondary containment automatic iso-lation dampers/valves and required to be closed during accident conditions are closed by valves, blind flanges, slide gate dampers or deactivated automatic dampers/valves secured in position.

c. In accordance with the Surveillance Frequency Control Program:

Operating one standby gas treatment subsystem for one hour and main-taining greater than or equal to 0.25 inch of vacuum water gauge in the refueling area secondary containment at a flow rate not exceeding 764 cfm.

LIMERICK - UNIT 1 3/4 6-47 Amendment No. i-9-,+i,-!.g..§.,~, ~ , 227

CONTAINMENT SYSTEMS REFUELING AREA SECONDARY CONTAINMENT AUTOMATIC ISOLATION VALVES LIMITING CONDITION FOR OPERATION 3.6.5.2.2 The refueling area secondary containment ventilation system automatic isolation valves shall be OPERABLE.

APPLICABILITY: When RECENTLY IRRADIATED FUEL is being handled in the secondary containment.

ACTION:

With one or more of the refueling area secondary containment ventilation system automatic isolation valves inoperable, maintain at least one isolation valve OPERABLE in each affected penetration that is open and within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months either:

a. Restore the inoperable valves to OPERABLE status, or

b. Isolate each affected penetration by use of at least one deactivated valve secured in the isolation position, or

c. Isolate each affected penetration by use of at least one closed manual valve, blind flange or slide gate damper.

Otherwise, suspend handling of RECENTLY IRRADIATED FUEL in the refueling area secondary containment. The provisions of Specification 3.0.3 are not applicable.

SURVEILLANCE REQUIREMENTS 4.6.5.2.2 Each refueling area secondary containment ventilation system auto-matic isolation valve shall be demonstrated OPERABLE:

a. Prior to returning the valve to service after maintenance, repair or replacement work is performed on the valve or its associated actuator, control or power circuit by cycling the valve through at least one complete cycle of full travel and verifying the specified isolation time.

b. In accordance with the Surveillance Frequency Control Program by verifying that on a containment isolation test signal each isolation valve actuates to its isolation position.

c. By verifying the isolation time to be within its limit in accordance with the Surveillance Frequency Control Program.

LIMERICK - UNIT 1 3/4 6-50 Amendment No. B,40,+l-,-l-Q..e.,+/-&5-, ~ . 227

CONTAINMENT SYSTEMS STANDBY GAS TREATMENT SYSTEM - COMMON SYSTEM LIMITING CONDITION FOR OPERATION 3.6.5.3 Two independent standby gas treatment subsystems shall be OPERABLE.

APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, 3, and when (1) irradiated fuel is being handled in the refueling area secondary containment, or (2) during CORE ALTE RA TI ON S .

ACTION:

a. In OPERATIONAL CONDITION 1, 2, or 3:

1. With one standby gas treatment subsystem inoperable, restore the inoperable subsystem to OPERABLE status within 7 days, or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

b. When (1) irradiated fuel is being handled in the refueling area secondary containment, or (2) during CORE ALTERATIONS:

1. With one standby gas treatment subsystem inoperable, restore the inoperable subsystem to OPERABLE status within 7 days, or suspend handling of irradiated fuel in the secondary containment and CORE ALTERATIONS. The provisions of Specification 3.0.3 are not applicable.

2. With both standby gas treatment subsystems inoperable, if in progress, suspend handling of irradiated fuel in the secondary containment and CORE ALTERATIONS. The provisions of Specification 3.0.3. are not applicable.

SURVEILLANCE REOlJIREMENTS 4.6.5.3 Each standby gas treatment subsystem shall be demonstrated OPERABLE:

a. In accordance with the Surveillance Frequency Control Program by initiating, from the control room, flow through the HEPA filters and charcoal adsorbers and verifying that the subsystem operates with the heaters OPERABLE.

LIMERICK - UNIT 1 3/4 6-52 Amendment No. ~.4-G,~.~. -&G-G, 227

PLANT SYSTEMS 3/4.7.2 CONTROL ROOM EMERGENCY FRESH AIR SUPPLY SYSTEM - COMMON SYSTEM LIMITING CONDITION FOR OPERATION 3.7.2 Two independent control room emergency fresh air supply system subsystems shall be OPERABLE.

NOTE: The main control room envelope (CRE) boundary may be opened intermittently under administrative control APPLICABILITY: All OPERATIONAL CONDITIONS and when RECENTLY IRRADIATED FUEL is being handled in the secondary containment.

ACTION:

a. In OPERATIONAL CONDITION 1, 2, or 3:

1. With one control room emergency fresh air supply subsystem inoperable for reasons other than Condition a.2, restore the inoperable subsystem to OPERABLE status within 7 days or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

2. With one or more control room emergency fresh air supply subsystems inoperable due to an inoperable CRE boundary,

a. Initiate action to implement mitigating actions immediately or be in HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ; and

b. Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , verify mitigating actions ensure CRE occupant exposures to radiological and chemical hazards will not exceed limits and actions to mitigate exposure to smoke hazards are taken or be in HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ; and

c. Restore CRE boundary to operable status within 90 days or be in HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

b. In OPERATIONAL CONDITION 4, 5, or when RECENTLY IRRADIATED FUEL is being handled in the secondary containment:

1. With one control room emergency fresh air supply subsystems inoperable for reasons other than Condition b.3, restore the inoperable subsystem to OPERABLE status within 7 days or initiate and maintain operation of the OPERABLE subsystem in the radiation isolation mode of operation.

2. With both control room emergency fresh air supply subsystems inoperable for reasons other than Condition b.3, immediately suspend handling of RECENTLY IRRADIATED FUEL in the secondary containment. The provisions of Specification 3.0.3 are not applicable.

LIMERICK - UNIT 1 3/4 7-6 Amendment No. 4-G,+--+/--,~.~. ~ . 227

PLANT SYSTEMS LIMITING CONDITION FOR OPERATION (Continued)

ACTION: (Continued)

3. With one or more control room emergency fresh air subsystems inoperable due to an inoperable CRE boundary, immediately suspend handling of RECENTLY IRRADIATED FUEL in the secondary containment.

The provisions of Specification 3.0.3 are not applicable.

SURVEILLANCE REQUIREMENTS 4.7.2.1 Each control room emergency fresh air supply subsystem shall be demonstrated OPERABLE:

a. In accordance with the Surveillance Frequency Control Program by verifying the control room air temperature to be less than or equal to 85°F effective temperature.

b. In accordance with the Surveillance Frequency Control Program on a STAGGERED TEST BASIS by initiating, from the control room, flow through the HEPA filters and charcoal adsorbers and verifying that the subsystem operates with the heaters OPERABLE.

c. In accordance with the Surveillance Frequency Control Program or (1) after any structural maintenance on the HEPA filter or charcoal adsorber housings, or (2) following painting, fire, or chemical release in any ventilation zone communicating with the subsystem by:

1. Verifying that the subsystem satisfies the in-place penetration and bypass leakage testing acceptance criteria of less than 0.05% and uses the test procedure guidance in Regulatory Positions C.5.a, C.5.c, and C.5.d of Regulatory Guide 1.52, Revision 2, March 1978, and the system flow rate is 3000 cfm +/- 10%.

2. Verifying within 31 days after removal that a laboratory analysis of a representative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, shows the methyl iodide penetration of less than 2.5%

when tested in accordance with ASTM D3803-1989 at a temperature of 30°C (86°F) and a relative humidity of 70%.

3. Verifying a subsystem flow rate of 3000 cfm +/- 10% during subsystem operation when tested in accordance with ANSI N510-1980.

d. After every 720 hours0.00833 days 0.2 hours 0.00119 weeks 2.7396e-4 months of charcoal adsorber operation by verifying within 31 days after removal that a laboratory analysis of a repre-sentative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, shows the methyl iodide penetration of less than 2.5%

when tested in accordance with ASTM D3803-1989 at a temperature of 30°C (86°F) and a relative humidity of 70%.

LIMERICK - UNIT 1 3/4 7-7 Amendment No. ~.4-G,+l-,-+/--44,~.

-+/--&&, J..gg, 227

ELECTRICAL POWER SYSTEMS A.C. SOURCES - SHUTDOWN LIMITING CONDITION FOR OPERATION 3.8.1.2 As a minimum, the following A.C. electrical power sources shall be OPERABLE:

a. One circuit between the offsite transmission network and the onsite Class lE distribution system, and

b. Two diesel generators each with:

1. A day fuel tank containing a minimum of 250 gallons of fuel.

2. A fuel storage system containing a minimum of 33,500 gallons of fuel.

3. A fuel transfer pump.

APPLICABILITY: OPERATIONAL CONDITIONS 4, 5, and*

ACTION:

a. With less than the above required A.C. electrical power sources OPERABLE, suspend CORE ALTERATIONS, handling of irradiated fuel in the secondary containment, and crane operations over the spent fuel storage pool when fuel assemblies are stored therein. In addition, when in OPERATIONAL CONDITION 5 with the water level less than 22 feet above the reactor pressure vessel flange, immediately initiate corrective action to restore the required power sources to OPERABLE status as soon as practical.

b. The provisions of Specification 3.0.3 are not applicable.

SURVEILLANCE REQUIREMENTS 4.8.1.2 At least the above required A.C. electrical power sources shall be demonstrated OPERABLE per Surveillance Requirements 4.8.1.1.1 and 4.8.1.1.2.

When handling irradiated fuel in the secondary containment.

LIMERICK - UNIT 1 3/4 8-9 Amendment No. Ji, -+/---9--i, -+/---9-J, 227

ELECTRICAL POWER SYSTEMS LIMITING CONDITION FOR OPERATION (Continued)

ACTION: (Continued)

2. Division 1 or 2 with float current> 2 amps, or with Division 3 or 4 with float current> 1 amp, perform 4.8.2.1.a.2 within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for affected battery(s) and restore battery float current to within limits within 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months .

3. One or two batteries on one division with one or more cells electrolyte level less than minimum established design limits, if electrolyte level was below the top of the plates restore electrolyte level to above top of plates within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months and verify no evidence of leakage(*) within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . In all cases, restore electrolyte level to greater than or equal to minimum established design limits within 31 days.

4. One or two batteries on one division with pilot cell electrolyte temperature less than minimum established design limits, restore battery pilot cell temperature to greater than or equal to minimum established design limits within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

5. Batteries in more than one division affected, restore battery parameters for all batteries in one division to within limits within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

6. (i) Any battery having both (Action b.l) one or more battery cells float voltage< 2.07 volts and (Action b.2) float current not within limits, and/or (ii) Any battery not meeting any Action b.l through b.5, Restore the battery parameters to within limits within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

c. 1. With the requirements of Action a. and/or Action b. not met, or

2. With less than two divisions of the above required D.C. electrical power sources OPERABLE for reasons other than Actions a. and/orb.,

Suspend CORE ALTERATIONS and handling of irradiated fuel in the secondary containment.

d. The provisions of Specification 3.0.3 are not applicable.

SURVEILLANCE REQUIREMENTS 4.8.2.2 At least the above required battery and charger shall be demonstrated OPERABLE per Surveillance Requirement 4.8.2.1.

(*) Contrary to the prov1s1ons of Specification 3.0.2, if electrolyte level was below the top of the plates, the verification that there is no evidence of leakage is required to be completed regardless of when electrolyte level is restored.

LIMERICK - UNIT 1 3/4 8-14a Amendment No. +/--e-4-, 227

ELECTRICAL POWER SYSTEMS LIMITING CONDITION FOR OPERATION (Continued)

APPLICABILITY: OPERATIONAL CONDITIONS 4, 5, and*

ACTION:

a. With less than two divisions of the above required Unit 1 A.C. dis-tribution systems energized, suspend CORE ALTERATIONS and handling of irradiated fuel in the secondary containment.

b. With less than two divisions of the above required Unit 1 D.C. dis-tribution systems energized, suspend CORE ALTERATIONS and handling of irradiated fuel in the secondary containment.

c. With any of the above required Unit 2 and common AC and/or DC distribution system divisions not energized, declare the associated common equipment inoperable, and take the appropriate ACTION for that system.

d. The provisions of Specification 3.0.3 are not applicable.

SURVEILLANCE REQUIREMENTS 4.8.3.2 At least the above required power distribution system divisions shall be determined energized in accordance with the Surveillance Frequency Control Program by verifying correct breaker alignment and voltage on the busses/MCCs/panels.

When handling irradiated fuel in the secondary containment.

LIMERICK - UNIT 1 3/4 8-20 Amendment No . .;?4- l&e-,

227

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 EXELON GENERATION COMPANY, LLC DOCKET NO. 50-353 LIMERICK GENERATING STATION. UNIT 2 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 190 Renewed License No. NPF-85

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

A. The application for amendment by Exelon Generation Company, LLC (Exelon Generation Company), dated July 19, 2017, as supplemented by letters dated December 6, 2017; February 19, 2018; and February 27, 2018, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations set forth in 10 CFR Chapter I; B. The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C. There is reasonable assurance (i) that the activities authorized by this amendment can be conducted \Mthout endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance \Mth the Commission's regulations; D. The issuance of this amendment will not be inimical to the common dei:mse 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 paagraph 2.C.(2) of Renewed Facility Operating License No. NPF-85 is hereby amended to read as follows:

(2) Technical Specifications The Technical Specifications contained in Appendix A and the Environmental Protection Plan contained in Appendix B, as revised through Amendment No. 190, are hereby incorporated into this renewed license. Exelon Generation Company 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 no later than May 31, 2019.

FOR THE NUCLEAR REGULATORY COMMISSION

,,-~

C)ewuvU~

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

Attachment:

Changes to the Facility Operating License and Technical Specifications Date of Issuance: February 27, 2018

ATTACHMENT TO LICENSE AMENDMENT NO. 190 LIMERICK GENERATING STATION, UNIT 2 RENEWED FACILITY OPERATING LICENSE NO. NPF-85 DOCKET NO. 50-353 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 3 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 Remove Insert 3/4 5-6a vii vii 3/4 5-7 3/4 5-7 xii xii 3/4 5-8 3/4 5-8 xviii xviii 3/4 5-9 3/4 5-9 xx xx 3/4 6-47 3/4 6-47 1-2 1-2 3/4 6-50 3/4 6-50 1-2a 3/4 6-52 3/4 6-52 3/4 3-16 3/4 3-16 3/4 7-6 3/4 7-6 3/4 3-31 3/4 3-31 3/4 7-6a 3/4 7-6a 3/4 3-33 3/4 3-33 3/4 8-9 3/4 8-9 3/4 3-35 3/4 3-35 3/4 8-14a 3/4 8-14a 3/4 3-36 3/4 3-36 3/4 8-19 3/4 8-19 3/4 3-40 3/4 3-40 3/4 8-20 3/4 8-20 3/4 3-41 3/4 3-41 3/4 3-41a 3/4 3-41b 3/4 3-41c 3/4 3-41d 3/4 3-41e 3/4 3-65 3/4 3-65 3/4 3-67 3/4 3-67 3/4 5-6 3/4 5-6

(2) Pursuant to the Act and 10 CFR Part 70, to receive, possess and to use at any time special nuclear material as reactor fuel, in accordance with the limitations for storage and amounts required for reactor operation, as described in the Final Safety Analysis Report, as supplemented and amended; (3) Pursuant to the Act and 10 CFR Parts 30, 40 and 70, to receive, possess and use at any time any byproduct, source and special nuclear material as sealed neutron sources for reactor startup, sealed sources for reactor instrumentation and radiation monitoring equipment calibration, and as fission detectors in amounts as required;

( 4) Pursuant to the Act and 10 CFR Parts 30, 40, 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) 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, and to receive and possess, but not separate, such source, byproduct, and special nuclear materials as contained in the fuel assemblies and fuel channels from the Shoreham Nuclear Power Station.

C. This renewed license shall be deemed to contain and is subject to the conditions specified in the Commission's regulations set forth in 10 CFR Chapter I (except as exempted from compliance in Section 2.D. below) 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 Exelon Generation Company is authorized to operate the facility at reactor core power levels of 3515 megawatts thermal ( 100 percent rated power) in accordance with the conditions specified herein.

(2) Technical Specifications The Technical Specifications contained in Appendix A and the Environmental Protection Plan contained in Appendix B, as revised through Amendment No. 190, are hereby incorporated into this renewed license. Exelon Generation Company shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

Renewed License No. NPF-85 Amendment No. 190

DEFINITIONS SECTION 1.0 DEFINITIONS 1.1 ACTION ........................................................ 1-1

1. 2 AVERAGE PLANAR EXPOSURE ....................................... 1-1 1.3 AVERAGE PLANAR LINEAR HEAT GENERATION RATE .................... 1-1 1.4 CHANNEL CALIBRATION ........................................... 1-1 1.5 CHANNEL CHECK ................................................. 1-1 1.6 CHANNEL FUNCTIONAL TEST ....................................... 1-1 1.7 CORE ALTERATION ............................................... 1-2 1.7a CORE OPERATING LIMITS REPORT .................................. 1-2 1.8 CRITICAL POWER RATIO .......................................... 1-2 1.9 DOSE EQUIVALENT I-131. ........................................ 1-2 1.9a DOWNSCALE TRIP SETPOINT (DTSP) ................................ 1-2 1 . 9b DRA I N T I ME . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 - 2 1.10 (DELETED) ..................................................... l-2a 1.11 EMERGENCY CORE COOLING SYSTEM (ECCS) RESPONSE TIME ............ l-2a 1.12 END-OF-CYCLE RECIRCULATION PUMP TRIP SYSTEM RESPONSE TIME ..... 1-3 1.13 (DELETED) ..................................................... 1-3 1.14 (DELETED) ..................................................... 1-3 1.15 FREQUENCY NOTATION ............................................ 1-3 1.15a HIGH (POWER) TRIP SETPOINT (HTSP) ............................. 1-3 1.16 IDENTIFIED LEAKAGE ............................................ 1-3 1.16a INTERMEDIATE (POWER) TRIP SETPOINT (ITSP) ..................... 1-3 1.17 ISOLATION SYSTEM RESPONSE TIME ................................ 1-3 1.18 LIMITING CONTROL ROD PATTERN .................................. 1-3 1.19 LINEAR HEAT GENERATION RATE ................................... 1-3 1.20 LOGIC SYSTEM FUNCTIONAL TEST .................................. 1-4 LIMERICK - UNIT 2 Amendment No. 4, ~. -+/---J.6,190

LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS SECTION INSTRUMENTATION (Continued) 3/4.3.2 ISOLATION ACTUATION INSTRUMENTATION ........................... 3/4 3-9 Table 3.3.2-1 Isolation Actuation Instrumentation ...... 3/4 3-11 Table 3.3.2-2 Isolation Actuation Instrumentation Setpoints ................ 3/4 3-18 Table 3.3.2-3 Isolation System Instrumentation Response Time ............................ 3/4 3-23 Table 4.3.2.1-1 Isolation Actuation Instrumentation Survei 11 ance Requirements .............. 3/4 3-27 3/4.3.3 EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION ............................................... 3/4 3-32 Table 3.3.3-1 Emergency Core Cooling System Actuation Instrumentation ................ 3/4 3-33 Table 3.3.3-2 Emergency Core Cooling System Actuation Instrumentation Setpoints ...... 3/4 3-37 Table 3.3.3-3 Emergency Core Cooling System Response Times ........................... 3/4 3-39 Table 4.3.3.1-1 Emergency Core Cooling System Actuation Instrumentation Survei 11 ance Requirements .............. 3/4 3-40 3/4.3.3.A REACTOR PRESSURE VESSEL (RPV) WATER INVENTORY CONTROL (WIC)

INSTRUMENTATION .............................................. 3/4 3-4la Table 3.3.3.A-l RPV Water Inventory Control (WIC)

Instrumentation .......................... 3/4 3-4lb Table 3.3.3.A-2 RPV Water Inventory Control (WIC)

Instrumentation Set points ................ 3/4 3-4ld Table 4.3.3.A-l RPV Water Inventory Control (WIC)

Instrumentation Surveillance Requirements 3/4 3-4le 3/4.3.4 RECIRCULATION PUMP TRIP ACTUATION INSTRUMENTATION ATWS Recirculation Pump Trip System Instrumentation ........... 3/4 3-42 Table 3.3.4.1-1 ATWS Recirculation Pump Trip System Instrumentation ................. 3/4 3-43 Table 3.3.4.1-2 ATWS Recirculation Pump Trip System Instrumentation Setpoints .............................. 3/4 3-44 Table 4.3.4.1-1 (Deleted) .............................. 3/4 3-45 End-of-Cycle Recirculation Pump Trip System Instrumentation ............................................... 3/4 3-46 LIMERICK - UNIT 2 Vii Amendment No. -+/-4-7-,190

INDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS SECTION REACTOR COOLANT SYSTEM (Continued) 3/4.4.9 RESIDUAL HEAT REMOVAL Hot Shutdown ............................................... 3/4 4-25 Cold Shutdown .............................................. 3/4 4-26 3/4.5 EMERGENCY CORE COOLING SYSTEMS 3/4.5.1 ECCS - OPERATING ........................................... 3/4 5-1 3/4.5.2 REACTOR PRESSURE VESSEL (RPV)

WATER INVENTORY CONTROL (WIC) .............................. 3/4 5-6 3/4.5.3 SUPPRESSION CHAMBER ........................................ 3/4 5-8 3/4.6 CONTAINMENT SYSTEMS 3/4.6.1 PRIMARY CONTAINMENT Primary Containment Integrity .............................. 3/4 6-1 Primary Containment Leakage ................................ 3/4 6-2 Primary Containment Air Lock ............................... 3/4 6-5 MSIV Leakage Alternate Drain Pathway ....................... 3/4 6-7 Primary Containment Structural Integrity ................... 3/4 6-8 Drywel l and Suppression Chamber Internal Pressure .......... 3/4 6-9 Drywell Average Air Temperature ............................ 3/4 6-10 Drywell and Suppression Chamber Purge System ............... 3/4 6-11 3/4.6.2 DEPRESSURIZATION SYSTEMS Suppression Chamber ........................................ 3/4 6-12 Suppression Pool Spray ..................................... 3/4 6-15 Suppression Pool Cooling ................................... 3/4 6-16 3/4.6.3 PRIMARY CONTAINMENT ISOLATION VALVES ....................... 3/4 6-17 LIMERICK - UNIT 2 Xii Amendment No. J, J.G-7.,190

BASES SECTION 3/4.0 APPLICABILITY ..................................................... B 3/4 0-1 3/4.1 REACTIVITY CONTROL SYSTEMS 3/4.1.1 SHUTDOWN MARGIN .............................................. B 3/4 1-1 3/4.1.2 REACTIVITY ANOMALIES ......................................... B 3/4 1-1 3/4.1.3 CONTROL RODS ................................................. B 3/4 1-2 3/4.1.4 CONTROL ROD PROGRAM CONTROLS ................................. B 3/4 1-3 3/4.1.5 STANDBY LIQUID CONTROL SYSTEM ................................ B 3/4 1-4 3/4.2 POWER DISTRIBUTION LIMITS 3/4.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE ......................................................... B 3/4 2-1 3/4.2.2 (DELETED) .................................................... B 3/4 2-2 LEFT INTENTIONALLY BLANK ................................................ B 3/4 2-3 3/4.2.3 MINIMUM CRITICAL POWER RATIO ................................. B 3/4 2-4 3/4.2.4 LINEAR HEAT GENERATION RATE .................................. B 3/4 2-5 3/4.3 INSTRUMENTATION 3/4.3.1 REACTOR PROTECTION SYSTEM INSTRUMENTATION .................... B 3/4 3-1 3/4.3.2 ISOLATION ACTUATION INSTRUMENTATION .......................... B 3/4 3-2 3/4.3.3 EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION .............................................. B 3/4 3-2 3/4.3.3.A REACTOR PRESSURE VESSEL (RPV) WATER INVENTORY CONTROL (WIC) INSTRUMENTATION ................................ B 3/4 3-2a 3/4.3.4 RECIRCULATION PUMP TRIP ACTUATION INSTRUMENTATION ............ B 3/4 3-3 3/4.3.5 REACTOR CORE ISOLATION COOLING SYSTEM ACTUATION INSTRUMENTATION .............................................. B 3/4 3-4 3/4.3.6 CONTROL ROD BLOCK INSTRUMENTATION ............................ B 3/4 3-4 3/4.3.7 MONITORING INSTRUMENTATION Radiation Monitoring Instrumentation ......................... B 3/4 3-5 LIMERICK - UNIT 2 xviii Amendment No. 4, ~. ~.190

BA ES SECTION REACTOR COOLANT SYSTEM (Continued) 3/4.4.5 SPECIFIC ACTIVHY ............................................. B 3/4 4-4 3/4.4.6 PRESSURE/TEMPERATURE LIMITS ................................... B 3/4 4-4 Bases Table B 3/4.4.6-1 Reactor Vessel Toughness ...................... B 3/4 4- 7 Bases Figure B 3/4.4.6-1 Fast Neutron Fluence (E>l MeV) At 1/4 T As A Function of Service Life ........................... B 3/4 4-8 3/4.4.7 MAIN STEAM LINE ISOLATION VALVES .............................. B 3/4 4-6 3/4.4.8 (DELETED) ..................................................... B 3/4 4-6 3/4.4.9 RESIDUAL HEAT REMOVAL ......................................... B 3/4 4-6 3/4.5 EMERGENCY CORE COOLING SYSTEMS 3I 4 . 5 . 1 EC CS - 0PERA TING . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 3/ 4 5 -1 3/4.5.2 REACTOR PRESSURE VESSEL (RPV) WATER INVENTORY CONTROL (WIC) ............................................ B 3/4 5-3a 3/4.5.3 SUPPRESSION CHAMBER ..................................... B 3/4 5-4 3/4.6 CONTAINMENT SYSTEMS 3/4.6.1 PRIMARY CONTAINMENT Primary Containment Integrity ........................... B 3/4 6-1 Primary Containment Leakage ............................. B 3/4 6-1 Primary Containment Air Lock ............................ B 3/4 6-1 MSIV Leakage Control System ............................. B 3/4 6-1 Primary Containment Structural Integrity ................ B 3/4 6-2 Drywell and Suppression Chamber Internal Pressure .............................................. B 3/4 6-2 Drywel l Average Air Temperature ......................... B 3/4 6-2 Drywel l and Suppression Chamber Purge System ............ B 3/4 6-2 3/4.6.2 DEPRESSURIZATION SYSTEMS ................................ B 3/4 6-3 LIMERICK - UNIT 2 xx Amendment No. -e-G, Associated with Amendment 178 190

DEFINITIONS CORE ALTERATION

1. 7 CORE AL TE RATION shall be the movement of any fuel, sources, or reactivity control components within the reactor vessel with the vessel head removed and fuel in the vessel. The following exceptions are not considered to be CORE ALTERATIONS:

a) Movement of source range monitors, local power range monitors, intermediate range monitors, traversing incore probes, or special moveable detectors (including undervessel replacement); and b) Control rod movement, provided there are no fuel assemblies in the associated core eel l.

Suspension of CORE ALTERATIONS shall not preclude completion of movement of a component to a safe position.

CORE OPERATING LIMITS REPORT 1.7a The CORE OPERATING LIMITS REPORT (COLR) is the unit-specific document that provides the core operating limits for the current operating reload cycle. These cycle-specific core operating limits shall be determined for each reload cycle in accordance with Specifications 6.9.1.9 thru 6.9.12. Plant operation within these limits is addressed in individual specifications.

CRITICAL POWER RATIO 1.8 The CRITICAL POWER RATIO (CPR) shall be the ratio of that p'ower in the assembly which is calculated by application of the (GEXL) correlation to cause some point in the assembly to experience boiling transition, divided by the actual assembly operating power.

DOSE EQUIVALENT I-131 1.9 DOSE EQUIVALENT I-131 shall be that concentration of I-131, microcuries per gram, which alone would produce the same inhalation committed effective dose equivalent (CEDE) as the quantity and isotopic mixture of I-131, I-132, I-133, I-134, and I-135 actually present. The inhalation committed effective dose equivalent (CEDE) conversion factors used for this calculation 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," ORNL, 1989, as descri be'd in Regulatory Gui de 1.183. The factors in the column headed "effective" yield doses corresponding to the CEDE.

DOWNSCALE TRIP SETPOINT (DTSP) 1.9a The downscale trip setpoint associated with the Rod Block Monitor (RBM) rod block trip setting.

DRAIN TIME 1.9b 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 LIMERICK - UNIT 2 1-2 Amendment No. 4, -4.g, 9, -+/--JB, -+/---46,190

DEFINITIONS DRAIN TIME (Continued) 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 is 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.

1.10 (Deleted)

EMERGENCY CORE COOLING SYSTEM (ECCS) RESPONSE TIME 1.11 The EMERGENCY CORE COOLING SYSTEM (ECCS) RESPONSE TIME shall be that time interval from when the monitored parameter exceeds its ECCS actuation set-point 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 any series of sequential, overlapping or total steps such that the entire response time is measured.

LIMERICK - UNIT 2 l-2a Amendment No. 4, -4.g, 4-9, -+/--Je, -l-4&,190

TABLE 3.3.2-1 (Continued)

ISOLATION ACTUATION INSTRUMENTATION ACTION STATEMENTS ACTION 20 Be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 21 Be in at least STARTUP with the associated isolation valves closed within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 22 - Be in at least STARTUP within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

ACTION 23 In OPERATIONAL CONDITION 1 or 2, verify the affected system isolation valves are closed within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and declare the affected system inoperable. In OPERATIONAL CONDITION 3, be in at least COLD SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

ACTION 24 Restore the manual initiation function to OPERABLE status within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or close the affected system isolation valves within the next hour and declare the affected system inoperable or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 25 Establish SECONDARY CONTAINMENT INTEGRITY with the standby gas treatment system operating within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

ACTION 26 Close the affected system isolation valves within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

TABLE NOTATIONS

Required when handling RECENTLY IRRADIATED FUEL in the secondary containment.

- May be bypassed under administrative control, with all turbine stop valves closed.

During operation of the associated Unit 1 or Unit 2 ventilation exhaust system.

(al DELETED

( bl A channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance without pla~ing the trip system in the tripped condition provided at least one OPERABLE channel in the same trip system is monitoring that parameter. Trip functions common to RPS Actuation Instrumentation are shown in Table 4.3.2.1-1. In addition, for the HPCI system and RCIC system isolation, provided that the redundant isolation valve, inboard or outboard, as applicable, in each line is OPERABLE and all required actuation instrumentation for that valve is OPERABLE, one channel may be placed in an inoperable status for up to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months for required surveillance without placing the channel or trip system in the tripped condition.

LIMERICK - UNIT 2 3/4 3-16 Amendment No. -+/-+, *, -+/--G+, -l-4-e-, 190

TABLE 4.3.2.1-1 (Continued)

ISOLATION ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS CHANNEL OPERATIONAL CHANNEL FUNCTIONAL CHANNEL CONDITIONS FOR WHICH TRIP FUNCTION CHECK(a) TEST(a) CALIBRATION(a) SURVEILLANCE REQUIRED

7. SECONDARY CONTAINMENT ISOLATION

a. Reactor Vessel Water Level Low, Low - Level 2 1, 2, 3

b. Drywel l Pressure## - High 1, 2, 3 c.1. Refueling Area Unit 1 Ventilation Exhaust Duct Radiation - High *#

2. Refueling Area Unit 2 Ventilation Exhaust Duct Radiation - High *#

d. Reactor Enclosure Ventilation Exhaust Duct Radiation - High 1, 2, 3

e. Deleted

f. Deleted

g. Reactor Enclosure Manual Initiation N.A. N.A. 1, 2, 3

h. Refueling Area Manual Initiation N.A. N.A. *

(a) Frequencies are specified in the Surveillance Frequency Control Program unless otherwise noted in the table.

Required when handling RECENTLY IRRADIATED FUEL in the secondary containment.

- When not administratively bypassed and/or when any turbine stop valve is open.

During operation of the associated Unit 1 or Unit 2 ventilation exhaust system.

1. These trip functions (2a, 6b, and 7b) are common to the RPS actuation trip function.

LIMERICK - UNIT 2 3/4 3-31 Amendment No.++, J..6-, .§.Z, +4-, -+/---4-9, J.4+,190

TABLE 3.3.3-1 EMERGENCY CORE _COOLING SYSTEM ACTUATION INSTRUMENTATION MINIMUM OPERABLE CHANNELS PER APPLICABLE TRIP OPERATIONAL TRIP FUNCTION FUNCTIONCal CONDITIONS ACTION

1. CORE SPRAY SYSTEM***

a. Reactor Vessel Water Level - Low Low Low, Level 1 (bl 1, 2, 3 30 2/pumpCbl

b. Drywel l Pressure - High 2/pump 1, 2, 3, 30 C. Reactor Vessel Pressure - Low (Permissive) 6(b) 1, 2, 3 31

d. Manual Initiation 2cel 1, 2, 3 33

2. LO~ PRESSURE COOLANT INJECTION MODE OF RHR SYSTEM***

a. Reactor Vessel Water Level - Low Low Low, Level 1 2 1, 2, 3 30

b. Drywel l Pressure - High 2 1, 2, 3 30 C. Reactor Vessel Pressure - Low (Permissive) 2 1, 2, 3 31

d. Injection Valve Differential Pressure-Low 1/valve 1, 2, 3 31 (Permissive)

e. Manual Initiation 1 1, 2, 3 33

3. HIGH PRESSURE COOLANT INJECTION SYSTEM##

a. Reactor Vessel Water Lew - Low Low, Level 2 4 1, 2, 3 34

b. Drywel l Pressure - High 4 cc) 1, 2, 3 34 C. Condensate Storage Tank Level - Low 2 1, 2, 3 35

d. Suppression Pool Water Level - High 2(d) 1, 2, 3 35

e. Reactor Vessel WaJi£r Level - High, Level 8 4 1, 2, 3 31

f. Manual Initiation 1/system 1, 2, 3 33 LIMERICK - UNIT 2 3/4 3-33 Amendment No. -+/--&f,,190

TABLE 3.3.3-1 (Continued)

EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION TABLE NOTATIONS (a) A channel may be pl aced in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance without placing the trip system in the tripped condition provided at least one OPERABLE channel in the same trip system is monitoring that parameter.

(b) Also provides input to actuation logic for the associated emergency diesel generators.

(c) One trip system. Provides signal to HPCI pump suction valves only.

(d) On 1 out of 2 taken twice logic, provides a signal to trip the HPCI pump turbine only.

(e) The manual initiation push buttons start the respective core spray pump and diesel generator. The "A" and "B" logic manual push buttons al so actuate an initiation permissive in the injection valve opening logic.

(f) A channel as used here is defined as the 127 bus relay for Item 1 and the 127, 127Y, and 127Z feeder relays with their associated time delay relays taken together for Item 2.

DELETED

Not required to be OPERABLE when reactor steam dome pressure is less than or equal to 100 psig.

- Required when ESF equipment is required to be OPERABLE.

1. Not required to be OPERABLE when reactor steam dome pressure is less than or equal to 200 psig.

1. 1. The injection functions of Drywell Pressure - High and Manual Initiation are not required to be OPERABLE with reactor steam dome pressure less than 550 psig.

LIMERICK - UNIT 2 3/4 3-35 Amendment No. J+, ~ . 190

TABLE 3.3.3-1 (Continued)

EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION ACTION STATEMENTS ACTION 30 - With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement:

a. With one channel inoperable, place the inoperable channel in the tripped condition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or declare the associated system inoperable.

b. With more than one channel inoperable, declare the associated system inoperable.

ACTION 31 - With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement, declare the associated ECCS inoperable within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 32 - DELETED ACTION 33 - With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement, restore the inoperable channel to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or declare the associated ECCS inoperable.

ACTION 34 - With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement:

a. For one channel inoperable, place the inoperable channel in the tripped condition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or declare the HPCI system inoperable.

b. With more than one channel inoperable, declare the HPCI system inoperable.

ACTION 35 - With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement, place at least one inoperable channel in the tripped condition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or declare the HPCI system inoperable.

ACTION 36 - With the number of OPERABLE channels less than the Total Number of Channels, declare the associated emergency diesel generator and the associated offsite source breaker that is not supplying the bus inoperable and take the ACTION required by Specification 3.8.1.l or 3.8.1.2, as appropriate.

LIMERICK - UNIT 2 3/4 3-36 Amendment No.+/-+, +Z-G,190

TABLE 4.3.3.1-1 EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS CHANNEL OP ERA TI ONAL CHANNEL FUNCTIONAL CHANNEL CONDITIONS FOR WHICH TRIP FUNCTION CHECK(a) TEST (a) CALIBRATION(a) SURVEILLANCE REQUIRED

1. CORE SPRAY SYSTEM

a. Reactor Vessel Water Level -

Low Low Low, Level 1 1, 2, 3

b. Drywell Pressure - High 1, 2, 3 C. Reactor Vessel Pressure - Low 1, 2, 3 ct. Manual Initiation N.A. N.A. 1, 2, 3

2. LOW PRESSURE COOLANT INJECTION MODE OF RHR SYSTEM

a. Reactor Vessel Water Level -

Low Low Low, Level 1 1, 2, 3

b. Drywell Pressure - High 1, 2, 3 C. Reactor Vessel Pressure - Low 1, 2, 3 ct. Injection Valve Differential Pressure - Low (Permissive) 1, 2, 3

e. Manual Initiation N.A. N.A. 1, 2, 3

3. HIGH PRESSURE COOLANT INJECTION SYSTEM***

a. Reactor Vessel Water Level -

Low Low, Level 2 1, 2, 3

b. Drywell Pressure - High 1, 2, 3 C. Condensate Storage Tank Level -

Low 1, 2, 3 ct. Suppression Pool Water Level -

High 1, 2, 3

e. Reactor Vessel Water Level -

High, Level 8 1, 2, 3

f. Manual Initiation N.A. N.A. 1, 2, 3 LIMERICK - UNIT 2 3/4 3-40 Amendment No. -l+, J4, -+/---4.;l.,190

TABLE 4.3.3.1-1 (Continued)

EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS CHANNEL OPERATIONAL CHANNEL FUNCTIONAL CHANNEL CONDITIONS FOR WHICH TRIP FUNCTION CHECK (a) TEST (a) CALIBRATION(a) SURVEILLANCE REQUIRED

4. AUTOMATIC DEPRESSURIZATION SYSTEM#

a. Reactor Vessel Water Level -

Low Low Low, Level 1 1, 2, 3

b. Drywel l Pressure - High 1, 2, 3 C. ADS Timer N.A. 1, 2, 3

d. Core Spray Pump Discharge Pressure - High 1, 2, 3

e. RHR LPCI Mode Pump Discharge Pressure - High 1, 2, 3

f. Reactor Vessel Water Level - Low, Level 3 1, 2, 3

g. Manual Initiation N.A. N.A. 1, 2, 3

h. ADS Drywel l Pressure Bypass Timer N.A. 1, 2, 3

5. LOSS OF POWER

a. 4.16 kV Emergency Bus Under voltage (Loss of Voltage)## N.A. N.A. 1, 2, 3, 4**, 5**

b. 4.16 kV Emergency Bus Under-voltage (Degraded Voltage) 1, 2, 3, 4**, 5**

(a) Frequencies are specified in the Surveillance Frequency Control Program unless otherwise noted in the table.

DELETED

- Required OPERABLE when ESF equipment is required to be OPERABLE.

- - Not required to be OPERABLE when reactor steam dome pressure is less than or equal to 200 psig.

Not required to be OPERABLE when reactor steam dome pressure is less than or equal to 100 psig.

1. Loss of Voltage Relay 127-llX is not field setable.

LIMERICK - UNIT 2 3/4 3-41 Amendment No . .W:., +4+, 190

INSTRUMENTATION 3/4.3.3.A REACTOR PRESSURE VESSEL (RPV) WATER INVENTORY CONTROL (WIC) INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.A The RPV Water Inventory Control (WIC) instrumentation channels shown in Table 3.3.3.A-l shall be OPERABLE.

APPLICABILITY: As shown in Table 3.3.3.A-l ACTION:

a. With one or more channels inoperable in a trip system, take the ACTION referenced in Table 3.3.3.A-l for the trip system.

SURVEILLANCE REQUIREMENTS 4.3.3.1.A Each RPV Water Inventory Control (WIC) instrumentation channel shall be demonstrated OPERABLE by performance of the CHANNEL CHECK, CHANNEL FUNCTIONAL TEST and LOGIC SYSTEM FUNCTIONAL TEST as shown in Table 4.3.3.A-l and at the frequencies specified in the Surveillance Frequency Control Program unless otherwise noted in Table 4.3.3.A-l.

LIMERICK - UNIT 2 3/4 3-4la Amendment No.190

TABLE 3.3.3.A-l RPV WATER INVENTORY CONTROL (WIC) INSTRUMENTATION MINIMUM OPERABLE CHANNELS PER APPLICABLE TRIP OPERATIONAL TRIP FUNCTION FUNCTION CONDITIONS ACTION

1. CORE SPRAY SYSTEM

a. Reactor Vessel Pressure - Low (Permissive) 51aJ 4, 5 39

b. Manual Initiation 2(a)(c) 4, 5 40

2. LOW _PRESSURE COOLANT INJECTION MODE OF RHR SYSTEM

a. Injection Valve Differential Pressure - Low (Permissive) 1/val vela) 4, 5 39

b. Manual Initiation 1la) 4, 5 40

3. RHR SYSTEM SHUTDOWN COOLING MODE ISOLATION

a. Reactor Vessel Water Level Low - Level 3 Z in one ( b) 38 trip system

4. REACTOR WATER CLEANUP SYSTEM ISOLATION

a. Reactor Vessel Water Level -

Low, Low - Level 2 2 in one ( b) 38 trip system (a) Associated with an ECCS subsystem required to be OPERABLE by LCO 3. 5. 2, "REACTOR PRESSURE VESSEL ( RPV) WATER INVENTORY CONTROL (WIC)."

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

(c) The manual initiation push buttons start the respective core spray pump and diesel generator. The "A" and "B" logic manual push buttons also actuate an initiation permissive in the injection valve opening logic.

LIMERICK - UNIT 2 3/4 3-4lb Amendment No. 190

TABLE 3.3.3.A-1 (Continued)

RPV WATER INVENTORY CONTROL (WIC) INSTRUMENTATION ACTION STATEMENTS ACTION 38 - Declare the associated trip system for the penetration flow path(s) incapable of automatic isolation and calculate DRAIN TIME.

ACTION 39 - Within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , place channel in trip. Otherwise, declare associated low pressure ECCS injection/spray subsystem inoperable.

ACTION 40 - Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , restore channel to OPERABLE status. Otherwise, declare associated low pressure ECCS injection/spray subsystem inoperable.

LIMERICK - UNIT 2 3/4 3-41c Amendment No. 190

TABLE 3.3.3.A-2 RPV WATER INVENTORY CONTROL (WIC) INSTRUMENTATION SETPOINTS ALLOWABLE TRIP FUNCTION VALUE

1. CORE SPRAY SYSTEM

a. Reactor Vessel Pressure - Low (Permissive) 2 435 psig (decreasing)

b. Manual Initiation N.A.

2. LOW PRESSURE COOLANT INJECTION MODE OF RHR SYSTEM

a. Injection Valve Differential Pressure - Low (Permissive) ~ 84 psid

b. Manual Initiation N.A.

3. RHR SYSTEM SHUTDOWN COOLING MODE ISOLATION

a. Reactor Vessel Water Level -

Low - Level 3 ;::: 11.0 inches

4. REACTOR WATER CLEANUP SYSTEM ISOLATION

a. Reactor Vessel Water Level -

Low, Low - Level 2 ;::: -45 inches LIMERICK - UNIT 2 3/4 3-41d Amendment No. 190

TABLE 4.3.3.A-l RPV WATER INVENTORY CONTROL (WIC) INSTRUMENTATION SURVEILLANCE REQUIREMENTS CHANNEL LOGIC SYSTEM OPERATIONAL CHANNEL FUNCTIONAL FUNCTIONAL CONDITIONS FOR WHICH TRIP FUNCTION CHECK(a) TEST(a) TEST(a) SURVEILLANCE REQUIRED

1. CORE SPRAY SYSTEM

a. Reactor Vessel Pressure - Low (Permissive) N.A. 4, 5

b. Manual Initiation N.A. N.A. 4, 5

2. LOW PRESSURE COOLANT INJECTION MODE OF RHR SYSTEM

a. Injection Valve Differential Pressure Low (Permissive) N.A. 4, 5

b. Manual Initiation N.A. N.A. 4, 5

3. RHR SYSTEM SHUTDOWN COOLING MODE ISOLATION

a. Reactor Vessel Water Level Low - Level 3 N.A. ( b)

4. REACTOR WATER CLEANUP SYSTEM ISOLATION

a. Reactor Vessel Water Level -

Low, Low - Level 2 N.A. ( b)

(a) Frequencies are specified in the Surveillance Frequency Control Program unless otherwise noted in the table.

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

LIMERICK - UNIT 2 3/4 3-4le Amendment No. 190

TABLE 3.3.7.1-1 (Continued)

RADIATION MONITORING INSTRUMENTATION TABLE NOTATIONS

When RECENTLY IRRADIATED FUEL is being handled in the secondary containment with the vessel head removed and fuel in the vessel.

(a) With fuel in the spent fuel storage pool.

(b) Alarm only.

ACTION STATEMENTS ACTION 70 With one monitor inoperable, restore the inoperable monitor to the OPERABLE status within 7 days or, within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , initiate and maintain operation of the control room emergency filtration system in the radiation isolation mode of operation.

With two or more of the monitors inoperable, within one hour, initiate and maintain operation of the control room emergency filtration system in the radiation mode of operation.

ACTION 71 With one of the required monitor inoperable, assure a portable continuous monitor with the same alarm setpoint is OPERABLE in the vicinity of the installed monitor during any fuel movement.

If no fuel movement is being made, perform area surveys of the monitored area with portable monitoring instrumentation at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 72 With the required monitor inoperable, obtain and analyze at least one grab sample of the monitored parameter at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 73 With the required monitor inoperable, assure a portable alarming monitor is OPERABLE in the vicinity of the installed monitor or perform area surveys of the monitored area with portable monitor-ing instrumentation at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

LIMERICK - UNIT 2 3/4 3-65 Amendment No. -+/--4--9, 190

TABLE 4.3.7.1-1 (Continued)

RADIATION MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS TABLE NOTATIONS

When RECENTLY IRRADIATED FUEL is being handled in the secondary containment with the vessel head removed and fuel in the vessel.

(a) With fuel in the spent fuel storage pool.

(b) The initial CHANNEL CALIBRATION shall be performed using one or more of the reference standards certified by the National Bureau of Standards (NBS) or using standards that have been obtained from suppliers that participate in measurement assurance activities with NBS. These standards shall permit calibrating the system over its intended range of energy and measurement range. For subsequent CHANNEL CALIBRATION, sources that have been related to the initial calibration shall be used.

(c) Frequencies are specified in the Surveillance Frequency Control Program unless otherwise noted in the table.

LIMERICK - UNIT 2 3/4 3-67 Amendment No. -+/-4-e, -+/--4-7-, 190

EMERGENCY CORE COOLING SYSTEMS 3/4.5.2 REACTOR PRESSURE VESSEL (RPV) WATER INVENTORY CONTROL (WIC)

LIMITING CONDITION FOR OPERATION 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 At least one of the following shall be OPERABLE:

a. Core spray system (CSS) subsystem comprised of:

1. Two OPERABLE CSS pumps, and

2. An OPERABLE flow path capable of taking suction from at least one of the following water sources and transferring the water through the spray sparger to the reactor vessel:

a) From the suppression chamber, or b) When the suppression chamber water level is less than the limit or is drained, from the condensate storage tank containing at least 135,000 available gallons of water, equivalent to a level of 29 feet.

b. Low pressure coolant injection (LPCI) system subsystem comprised of:

1. One OPERABLE LPCI pump, and

2. An OPERABLE flow path capable of taking suction from the suppression chamber and transferring the water to the reactor vessel.**

APPLICABILITY: OPERATIONAL CONDITIONS 4 and 5.

ACTION:

a. With none of the above required subsystems OPERABLE, immediately suspend CORE ALTERATIONS. Restore at least one subsystem to OPERABLE status within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . Otherwise, initiate action to establish a method of water injection capable of operating without offsite electrical power.

b. DELETED.

- One LPCI subsystem may be considered OPERABLE during alignment and operation for decay heat removal if capable of being manually realigned and not otherwise inoperable.

LIMERICK - UNIT 2 3/4 5-6 Amendment No. -9-, 190

EMERGENCY CORE COOLING SYSTEMS LIMITING CONDITION FOR OPERATION (Continued)

ACTION:

c. With DRAIN TIME less than 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months and greater than or equal to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , within 4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months s:

1. Verify SECONDARY CONTAINMENT INTEGRITY is capable of being established in less than the DRAIN TIME,

2. Verify each secondary containment penetration flow path is capable of being isolated in less than the DRAIN TIME, and

3. Verify one standby gas treatment subsystem is capable of being placed in operation in less than the DRAIN TIME.

d. With DRAIN TIME less than 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , immediately:

1. Initiate action to establish an additional method of water injection with water sources capable of maintaining RPV water level greater than TAF for greater than or equal to 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months ,***

2. Initiate action to establish SECONDARY CONTAINMENT INTEGRITY,

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

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

e. With required ACTION and associated allowed outage time for ACTIONs c. or d. not met, or DRAIN TIME less than 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , immediately initiate action to restore DRAIN TIME to greater than or equal to 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

- - The required injection/spray subsystem or an additional method of water injection shall be capable of operating without offsite electrical power.

LIMERICK - UNIT 2 3/4 5-6a Amendment No. 190

EMERGENCY CORE COOLING SYSTEMS SURVEILLANCE REQUIREMENTS 4.5.2.1 Verify DRAIN TIME is greater than or equal to 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months in accordance with the Surveillance Frequency Control Program.

4.5.2.2 Verify, for a required LPCI subsystem, the suppression chamber water level is greater than or equal to 16 feet O inches in accordance with the Surveillance Frequency Control Program.

4.5.2.3 Verify, for a required CSS subsystem, that the suppression chamber water level is greater than or equal to 16 feet O inches or the condensate storage tank water level is greater than or equal to 29 feet O inches in accordance with the Surveillance Frequency Control Program.

4.5.2.4 Verify, for the required ECCS injection/spray subsystem, locations susceptible to gas accumulation are sufficiently filled with water.

4.5.2.5 Verify, for the required ECCS injection/spray subsystem, each manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position in accordance with the Surveillance Frequency Control Program.#A 4.5.2.6 Operate the required ECCS injection/spray subsystem through the recirculation line for greater than or equal to 10 minutes in accordance with the Surveillance Frequency Control Program.

4.5.2.7 Verify each valve credited for automatically isolating a penetration flow path actuates to the isolation position on an actual or simulated isolation signal in accordance with the Surveillance Frequency Control Program.

4.5.2.8 Verify the required ECCS injection/spray subsystem actuates on a manual initiation signal in accordance with the Surveillance Frequency Control Program.##

DELETED.

Not required to be met for system vent flow paths open under administrative control.

AExcept that an automatic valve capable of automatic return to its ECCS position when an ECCS signal is present may be in position for another mode of operation.

1. Vessel injection/spray may be excluded.

LIMERICK - UNIT 2 3/4 5-7 Amendment No. ~. J-4+, 190

EMERGENCY CORE COOLING SYSTEMS 3/4.5.3 SUPPRESSION CHAMBER LIMITING CONDITION FOR OPERATION 3.5.3 The suppression chamber shall be OPERABLE:

a. In OPERATIONAL CONDITIONS 1, 2, and 3 with a contained water volume of at least 122,120 ft 3 , equivalent to a level of 22'0".

b. DELETED APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, and 3.

ACTION:

a. In OPERATIONAL CONDITION 1, 2 or 3 with the suppression chamber water level less than the above limit, restore the water level to within the limit within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

b. DELETED LIMERICK - UNIT 2 3/4 5-8 Amendment No. 190

EMERGENCY CORE COOLING SYSTEMS SURVEILLANCE REQUIREMENTS 4.5.3.1 The suppression chamber shall be determined OPERABLE by verifying the water level to be greater than or equal to, as applicable:

a. 22' O" in accordance with the Survei 11 ance Frequency Control Program.

b. DELETED 4.5.3.2 DELETED LIMERICK - UNIT 2 3/4 5-9 Amendment No. -14+, 190

CONTAINMENT SYSTEMS 3/4.6.5 SECONDARY CONTAINMENT REFUELING AREA SECONDARY CONTAINMENT INTEGRITY LIMITING CONDITION FOR OPERATION 3.6.5.1.2 REFUELING AREA SECONDARY CONTAINMENT INTEGRITY shall be maintained.

APPLICABILITY: When RECENTLY IRRADIATED FUEL is being handled in the secondary containment.

ACTION:

Without REFUELING AREA SECONDARY CONTAINMENT INTEGRITY, suspend handling of RECENTLY IRRADIATED FUEL in the secondary containment. The provisions of Specification 3.0.3 are not applicable.

SURVEILLANCE REQUIREMENTS 4.6.5.1.2 REFUELING AREA SECONDARY CONTAINMENT INTEGRITY shall be demonstrated by:

a. Verifying in accordance with the Surveillance Frequency Control Program that the pressure within the refueling area secondary containment is greater than or equal to 0.25 inch of vacuum water gauge.

b. Verifying in accordance with the Surveillance Frequency Control Program that:

1. All refueling area secondary containment equipment hatches and blowout panels are closed and sealed.

2. At least one door in each access to the refueling area secondary containment is closed, except when the access opening is being used for entry and exit.

3. All refueling area secondary containment penetrations not capable of being closed by OPERABLE secondary containment automatic iso-lation dampers/valves and required to be closed during accident conditions are closed by valves, blind flanges, slide gate dampers or deactivated automatic dampers/valves secured in position.

c. In accordance with the Surveillance Frequency Control Program:

Operating one standby gas treatment subsystem for one hour and main-taining greater than or equal to 0.25 inch of vacuum water gauge in the refueling area secondary containment at a flow rate not exceeding 764 cfm.

LIMERICK - UNIT 2 3/4 6-47 Amendment No. J4,.:J:.4.e.,-l-4+, ~ . 190

CONTAINMENT SYSTEMS REFUELING AREA SECONDARY CONTAINMENT AUTOMATIC ISOLATION VALVES LIMITING CONDITION FOR OPERATION 3.6.5.2.2 The refueling area secondary containment ventilation system automatic isolation valves shall be OPERABLE.

APPLICABILITY: When RECENTLY IRRADIATED FUEL is being handled in the secondary containment.

ACTION:

With one or more of the refueling area secondary containment ventilation system automatic isolation valves inoperable, maintain at least one isolation valve OPERABLE in each affected penetration that is open and within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months either:

a. Restore the inoperable valves to OPERABLE status, or

b. Isolate each affected penetration by use of at least one deactivated valve secured in the isolation position, or

c. Isolate each affected penetration by use of at least one closed manual valve, blind flange or slide gate damper.

Otherwise, suspend handling of RECENTLY IRRADIATED FUEL in the refueling area secondary containment. The provisions of Specification 3.0.3 are not applicable.

SURVEILLANCE REQUIREMENTS 4.6.5.2.2 Each refueling area secondary containment ventilation system auto-matic isolation valve shall be demonstrated OPERABLE:

a. Prior to returning the valve to service after maintenance, repair or replacement work is performed on the valve or its associated actuator, control or power circuit by cycling the valve through at least one complete cycle of full travel and verifying the specified isolation time.

b. In accordance with the Surveillance Frequency Control Program by verifying that on a containment isolation test signal each isolation valve actuates to its isolation position.

c. By verifying the isolation time to be within its limit in accordance with the Surveillance Frequency Control Program.

LIMERICK - UNIT 2 3/4 6-50 Amendment No. J4, 9-, J..49, +/-4+, 190

CONTAINMENT SYSTEMS STANDBY GAS TREATMENT SYSTEM - COMMON SYSTEM LIMITING CONDITION FOR OPERATION 3.6.5.3 Two independent standby gas treatment subsystems shall be OPERABLE.

APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, 3, and when (1) irradiated fuel is being handled in the refueling area secondary containment, or (2) during CORE ALTERATIONS.

ACTION:

a. In OPERATIONAL CONDITION 1, 2, or 3:

1. With the Unit 1 diesel generator for one standby gas treatment subsystem inoperable for more than 30 days, be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

2. With one standby gas treatment subsystem inoperable, restore the inoperable subsystem to OPERABLE status within 7 days, or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

3. With one standby gas treatment subsystem inoperable and the other standby gas treatment subsystem with an inoperable Unit 1 diesel generator, restore the inoperable subsystem to OPERABLE status or restore the inoperable Unit 1 diesel generator to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

4. With the Unit 1 diesel generators for both standby gas treatment system subsystems inoperable for more than 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

b. When (1) irradiated fuel is being handled in the refueling area secondary containment, or (2) during CORE ALTERATIONS:

1. With one standby gas treatment subsystem inoperable, restore the inoperable subsystem to OPERABLE status within 7 days, or suspend handling of irradiated fuel in the secondary containment and CORE ALTERATIONS. The provisions of Specification 3.0.3 are not applicable.

2. With both standby gas treatment subsystems inoperable, if in progress, suspend handling of irradiated fuel in the secondary containment and CORE ALTERATIONS. The provisions of Specification 3.0.3 are not applicable.

LIMERICK - UNIT 2 3/4 6-52 Amendment No. ~ . -+/--4-9, 190

PLANT SYSTEMS 3/4.7.2 CONTROL ROOM EMERGENCY FRESH AIR SUPPLY SYSTEM - COMMON SYSTEM LIMITING CONDITION FOR OPERATION 3.7.2 Two independent control room emergency fresh air supply system subsystems shall be OPERABLE.

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

APPLICABILITY: All OPERATIONAL CONDITIONS and when RECENTLY IRRADIATED FUEL is being handled in the secondary containment.

ACTION:

a. In OPERATIONAL CONDITION 1, 2, or 3:

1. With the Unit 1 diesel generator for one control room emergency fresh air supply subsystem inoperable for more than 30 days, be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

2. With one control room emergency fresh air supply subsystem inoperable for reasons other than Condition a.5, restore the inoperable subsystem to OPERABLE status within 7 days, or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

3. With one control room emergency fresh air supply subsystem inoperable for reasons other than Condition a.5, and the other control room emergency fresh air supply subsystem with an inoperable Unit 1 diesel generator, restore the inoperable subsystem to OPERABLE status or restore the Unit 1 diesel generator to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

4. With the Unit 1 diesel generators for both control room emergency fresh air supply subsystems inoperable for more than 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

5. With one or more control room emergency fresh air supply subsystems inoperable due to an inoperable CRE boundary,

a. Initiate action to implement mitigating actions immediately or be in HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ; and

b. Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , verify mitigating actions ensure CRE occupant exposures to radiological and chemical hazards will not exceed limits and actions to mitigate exposure to smoke hazards are taken or be in HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ; and LIMERICK - UNIT 2 3/4 7-6 Amendment No. ~ . -+/---4-e-, ~ . 190

PLANT SYSTEMS LIMITING CONDITION FOR OPERATION_(Continuedl.~~~~*~~~~=~~~~~~~

ACTION: (Continued)

c. Restore CRE boundary to operable status within 90 days or be in HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

b. In OPERATIONAL CONDITION 4, 5 or when RECENTLY IRRADIATED FUEL is being handled in the secondary containment:

1. With one control room emergency fresh air supply subsystem inoperable for reasons other than Condition b.3, restore the inoperable subsystem to OPERABLE status within 7 days, or initiate and maintain operation of the OPERABLE subsystem in the radiation isolation mode of operation.

2. With both control room emergency fresh air supply subsystem inoperable for reasons other than Condition b.3, immediately suspend handling of RECENTLY IRRADIATED FUEL in the secondary containment. The provisions of Specification 3.0.3 are not applicable.

3. With one or more control room emergency fresh air subsystems inoperable due to an inoperable CRE boundary, immediately suspend handling of RECENTLY IRRADIATED FUEL in the secondary containment. The provisions of Specification 3.0.3 are not applicable.

SURVEILLANCE REQUIREMENTS 4.7.2.1 Each control room emergency fresh air supply subsystem shall be demonstrated OPERABLE:

a. In accordance with the Surveillance Frequency Control Program by verifying the control room air temperature to be less than or equal to 85°F effective temperature.

b. In accordance with the Surveillance Frequency Control Program on a STAGGERED TEST BASIS by initiating, from the control room, flow through the HEPA filters and charcoal adsorbers and verifying that the subsystem operates with the heaters OPERABLE.

c. In accordance with the Surveillance Frequency Control Program or (1) after any structural maintenance on the HEPA filter or charcoal adsorber housings, or (2) following painting, fire, or chemical release in any ventilation zone communicating with the subsystem by:

1. Verifying that the subsystem satisfies the in-place penetration and bypass leakage testing acceptance criteria of less than 0.05% and uses the test procedure guidance in Regulatory Positions C.5.a, C.5.c, and C.5.d of Regulatory Guide 1.52, Revision 2, March 1978, and the system flow rate is 3000 cfm +/- 10%.

LIMERICK - UNIT 2 3/4 7-6a Amendment No. M, M+, -+/-4-9-, ~ . 190

ELECTRICAL POWER SYSTEMS A.C. SOURCES - SHUTDOWN LIMITING CONDITION FOR OPERATION 3.8.1.2 As a minimum, the following A.C. electrical power sources shall be OPERABLE:

a. One circuit between the offsite transmission network and the onsite Class lE distribution system, and

b. Two diesel generators each with:

1. A day fuel tank containing a minimum of 250 gallons of fuel.

2. A fuel storage system containing a minimum of 33,500 gallons of fuel.

3. A fuel transfer pump.

APPLICABILITY: OPERATIONAL CONDITIONS 4, 5, and*

ACTION:

a. With less than the above required A.C. electrical power sources OPERABLE, suspend CORE ALTERATIONS, handling of irradiated fuel in the secondary containment, and crane operations over the spent fuel storage pool when fuel assemblies are stored therein. In addition, when in OPERATIONAL CONDITION 5 with the water level less than 22 feet above the reactor pressure vessel flange, immediately initiate corrective action to restore the required power sources to OPERABLE status as soon as practical.

b. The provisions of Specification 3.0.3 are not applicable.

SURVEILLANCE REQUIREMENTS 4.8.1.2 At least the above required A.C. electrical power sources shall be demonstrated OPERABLE per Surveillance Requirements 4.8.1.1.1 and 4.8.1.1.2.

When handling irradiated fuel in the secondary containment.

LIMERICK - UNIT 2 3/4 8-9 Amendment No. +hl, +/-M, 190

ELECTRICAL POWER SYSTEMS LIMITING CONDITION FOR OPERATION ACTION: (Continued)