Text

Edwin I. Hatch Nuclear Plant, Units 1 and 2 - Issuance of Amendments to Adopt TSTF-542, RPV Water Inventory Control (CAC Nos. MF9662 and MF9663; EPID L-2017-LLA-0215)
	ML18123A368
Person / Time
Site:	Hatch
Issue date:	05/31/2018
From:	Hall J R; Plant Licensing Branch II
To:	Gayheart C A; Southern Nuclear Operating Co
	Hall J R
References
	CAC MF9662, CAC MF9663, EPID L-2017-LLA-0215
	Download: ML18123A368 (200)
	v • d • e

UNITED STATES NUCLEAR REGULATORY COMMISSION Ms. Cheryl A. Gayheart Regulatory Affairs Director WASHINGTON, D.C. 20555-0001 May 31, 2018 Southern Nuclear Operating

Company, Inc. P. 0. Box 1295, Bin 038 Birmingham, AL 35201-1295

SUBJECT:

EDWIN I. HATCH NUCLEAR PLANT, UNIT NOS. 1 AND 2 -ISSUANCE OF AMENDMENTS TO ADOPT TSTF-542, REVISION 2, "REACTOR PRESSURE VESSEL WATER INVENTORY CONTROL" (CAC NOS. MF9662 AND MF9663; EPID L-2017-LLA-0215)

Dear Ms. Gayheart:

The U.S. Nuclear Regulatory Commission (NRC, the Commission) has issued the enclosed Amendment No. 290 to Renewed Facility Operating License No. DPR-57 and Amendment No. 235 to Renewed Facility Operating License No. NPF-5 for the Edwin I. Hatch Nuclear Plant, Unit Nos. 1 and 2 (HNP), respectively.

The amendments consist of changes to the Technical Specifications (TSs) in response to your application dated April 20, 2017, as supplemented by letters dated September 14, 2017, and February 19 and May 1, 2018. The amendments replace the existing requirements in several TSs related to operations with a potential for draining the reactor vessel with revised TSs providing alternative requirements in new TS 3.5.2, "Reactor Pressure Vessel (RPV) Water Inventory Control,"

and associated changes.

These alternative requirements ensure that Safety Limit 2.1.1.3, which requires RPV water level to be greater than the top of active fuel, will continue to be met.

C. A copy of the related Safety Evaluation is also enclosed.

A Notice of Issuance will be included in the Commission's biweekly Federal Register notice. Docket Nos. 50-321 and 50-366

Enclosures:

1. Amendment No. 290 to DPR-57 2. Amendment No. 235 to NPF-5 3. Safety Evaluation cc: Listserv Sincerely, Jl:~~~~ct Manager Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 SOUTHERN NUCLEAR OPERA TING COMPANY, INC. GEORGIA POWER COMPANY OGLETHORPE POWER CORPORATION MUNICIPAL ELECTRIC AUTHORITY OF GEORGIA CITY OF DAL TON, GEORGIA DOCKET NO. 50-321 EDWIN I. HATCH NUCLEAR PLANT, UNIT NO. 1 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 290 Renewed License No. DPR-57 1. The Nuclear Regulatory Commission (the Commission) has found that: A. The application for amendment to the Edwin I. Hatch Nuclear Plant, Unit No. 1 (the facility)

Renewed Facility Operating License No. DPR-57 filed by Southern Nuclear Operating

Company, Inc. (the licensee),

acting for itself, Georgia Power Company, Oglethorpe Power Corporation, Municipal Electric Authority of Georgia, and City of Dalton, Georgia (the owners),

dated April 20, 2017, as supplemented by letters dated September 14, 2017, and February 19 and May 1, 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 as set forth in 10 CFR Chapter I; B. The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C. There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations; D. The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E. The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.

Enclosure 1 2. Accordingly, the license is hereby amended by page changes as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Renewed Facility Operating License No. DPR-57 is hereby amended to read as follows:

(2) Technical Specifications The Technical Specifications (Appendix A) and the Environmental Protection Plan (Appendix B), as revised through Amendment No. 290, are hereby incorporated in the renewed license.

Southern Nuclear 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 prior to the commencement of the Unit No. 2 refueling outage (U2R25) in February 2019.

Attachment:

Changes to Renewed Facility Operating License No. DPR-57 and Technical Specifications Date of Issuance:

May 31 , 2 o 1 8 FOR THE NUCLEAR REGULATORY COMMISSION Michael T. Markley, Chief Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation ATTACHMENT TO LICENSE AMENDMENT NO. 290 EDWIN I. HATCH NUCLEAR PLANT, UNIT NO. 1 RENEWED FACILITY OPERATING LICENSE NO. DPR-57 DOCKET NO. 50-321 Replace the following pages of the license and the Appendix A Technical Specifications (TSs) with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change. Remove Pages License 4 ii (TOC) 1.1-2 1.1-3 1.1-4 1.1-5 1.1-6 3.3-34 3.3-35 3.3-36 3.3-39 3.3-40 3.3-41 3.3-42 3.3-43 3.3-44 3.3-45 3.3-46 3.3-47 3.3-48 3.3-49 3.3-50 3.3-51 3.3-52 3.3-53 3.3-54 3.3-55a 3.3-55b Insert Pages License 4 ii (TOC) 1.1-2 1.1-3 1.1-4 1.1-5 1.1-6 1.1-7 3.3-34 3.3-35 3.3-36 3.3-39 3.3-40 3.3-41 3.3-42 3.3-43 3.3-44 3.3-45 3.3-46 3.3-47 3.3-48 3.3-49 3.3-50 3.3-51 3.3-52 3.3-53 3.3-54 3.3-55 3.3-56 3.3-57 3.3-58 3.3-59 Amendment No. 290 Remove Pages TSs 3.3-56 3.3-57 3.3-58 3.3-59 3.3-60 3.3-61 3.3-62 3.3-63 3.3-64 3.3-65 3.3-66 3.3-67 3.3-68 3.3-69 3.3-70 3.3-71 3.5-1 3;5-6 3.5-7 3.5-8 3.5-9 3.5-10 3.6-7 3.6-9 3.6-10 3.6-11 3.6-12 3.6-34 3.6-35 3.6-37 3.6-38 3.6-39 3.6-40 3.6-41 3.6-42 3.7-8 3.7-9 3.7-10 3.7-12 3.7-13 3.7-14 3.8-21 3.8-22 3.8-33 3.8-44 Insert Pages TSs 3.3-60 3.3-61 3.3-62 3.3-63 3.3-64 3.3-65 3.3-66 3.3-67 3.3-68 3.3-69 3.3-70 3.3-71 3.3-72 3.3-73 3.3-74 3.3-75 3.5-1 3.5-6 3.5-7 3.5-8 3.5-9 3.5-10 3.5-11 3.6-7 3.6-9 3.6-10 3.6-11 3.6-12 3.6-34 3.6-35 3.6-37 3.6-38 3.6-39 3.6-40 3.6-41 3.6-42 3.7-8 3.7-9 3.7-10 3.7-12 3.7-13 3.7-14 3.8-21 3.8-22 3.8-33 3.8-44 Amendment No. 290 for sample analysis or instrumentation calibration, or associated with radioactive apparatus or components; (6) Southern

Nuclear, pursuant to the Act and 10 CFR Parts 30 and 70, to possess, but not separate, such byproduct and special nuclear materials as may be produced by the operation of the facility.

C. This renewed license shall be deemed to contain and is subject to the conditions specified in the following Commission regulations in 10 CFR Chapter I: Part 20, Section 30.34 of Part 30, Section 40.41 of Part 40, Section 50.54 of Part 50, and Section 70.32 of Part 70; all applicable provisions of the Act and the rules, regulations, and orders of the Commission now or hereafter in effect; and the additional conditions specified or incorporated below: ( 1) (2) (3) Maximum Power Level Southern Nuclear is authorized to operate the facility at steady state reactor core power levels not in excess of 2804 megawatts thermal.

Technical Specifications The Technical Specifications (Appendix A) and the Environmental Protection Plan (Appendix B), as revised through Amendment No. 290, are hereby incorporated in the renewed license.

Southern Nuclear shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan. The Surveillance Requirement (SR) contained in the Technical Specifications and listed below, is not required to be performed immediately upon implementation of Amendment No. 195. The SR listed below shall be successfully demonstrated before the time and condition specified:

SR 3.8.1.18 shall be successfully demonstrated at its next regularly scheduled performance.

Fire Protection Southern Nuclear shall implement and maintain in effect all provisions of the fire protection

program, which is referenced in the Updated Final Safety Analysis Report for the facility, as contained in the updated Fire Hazards Analysis and Fire Protection Program for the Edwin I. Hatch Nuclear Plant, Units 1 and 2, which was originally submitted by letter dated July 22, 1986. Southern Nuclear may make changes to the fire protection program without prior Commission approval only if the changes Renewed License No. DPR-57 Amendment No. 290 TABLE OF CONTENTS (continued) 3.3 3.3.4.1 3.3.4.2 3.3.5.1 3.3.5.2 3.3.5.3 3.3.6.1 3.3.6.2 3.3.6.3 3.3.7.1 3.3.8.1 3.3.8.2 3.4 3.4.1 3.4.2 3.4.3 3.4.4 3.4.5 3.4.6 3.4.7 3.4.8 3.4.9 3.4.10 3.5.1 3.5.2 3.5.3 3.6.1.1 3.6.1.2 3.6.1.3 3.6.1.4 3.6.1.5 INSTRUMENTATION (continued)

End of Cycle Recirculation Pump Trip (EOC-RPn Instrumentation

.............

3.3-28 Anticipated Transient Without Scram Recirculation Pump Trip (A TWS-RPn Instrumentation

................................................

3.3-31 Emergency Core Cooling System (ECCS) Instrumentation

..........................

3.3-34 Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation

... 3.3-44 Reactor Core Isolation Cooling (RCIC) System Instrumentation

..................

3.3-47 Primary Containment Isolation Instrumentation

............................................

3.3-51 Secondary Containment Isolation Instrumentation

........................................

3.3-60 Low-Low Set (LLS) Instrumentation

..............................................................

3.3-64 Main Control Room Environmental Control (MCREC) System Instrumentation

........................................................................................

3.3-68 Loss of Power (LOP) Instrumentation

...........................................................

3.3-70 Reactor Protection System (RPS) Electric Power Monitoring

.......................

3.3-73 REACTOR COOLANT SYSTEM (RCS} .......................................................

3.4-1 Recirculation Loops Operating

......................................................................

3.4-1 Jet Pumps .....................................................................................................

3.4-3 Safety/Relief Valves (S/RVs) .........................................................................

3.4-5 RCS Operational LEAKAGE .........................................................................

3.4-7 RCS Leakage Detection Instrumentation

......................................................

3.4-9 RCS Specific Activity

.....................................................................................

3.4-11 Residual Heat Removal (RHR) Shutdown Cooling System -Hot Shutdown

..........................................................................................

3.4-13 Residual Heat Removal (RHR) Shutdown Cooling System -Cold Shutdown

........................................................................................

3.4-16 RCS Pressure and Temperature (PIT) Limits ...............................................

3.4-18 Reactor Steam Dome Pressure

....................................................................

3.4-25 EMERGENCY CORE COOLING SYSTEMS (ECCSl, RPV WATER INVENTORY

CONTROL, ANO REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM ........................................................................................................

3.5-1 ECCS -Operating

.........................................................................................

3.5-1 RPV Water Inventory Control ........................................................................

3.5-6 RCIC System .................................................................................................

3.5-10 CONTAINMENT SYSTEMS ..........................................................................

3.6-1 Primary Containment.

....................................................................................

3.6-1 Primary Containment Air Lock .......................................................................

3.6-3 Primary Containment Isolation Valves (PCIVs) .............................................

3.6-7 Drywell Pressure

...........................................................................................

3.6-13 Drywell Air Temperature

................................................................................

3.6-14 (continued)

HATCH UNIT 1 ii Amendment No. 2 9 0 Definitions 1.1 1.1 Definitions (continued)

CHANNEL FUNCTIONAL TEST CORE ALTERATION CORE OPERATING LIMITS REPORT (COLR) DOSE EQUIVALENT 1-131 DRAIN TIME HATCH UNIT 1 A CHANNEL FUNCTIONAL TEST shall be the injection of a simulated or actual signal into the channel as close to the sensor as practicable to verify OPERABILITY, including required alarm, interlock,

display, and trip functions, and channel failure trips. The CHANNEL FUNCTIONAL TEST may be performed by means of any series of sequential, overlapping, or total channel steps so that the entire channel is tested. CORE AL TERA TION 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 AL TERA TIONS: a. Movement of source range monitors, local power range monitors, intermediate range monitors, traversing incore probes, or special movable detectors (including undervessel replacement);

and b. Control rod movement, provided there are no fuel assemblies in the associated core cell. Suspension of CORE AL TERA TIONS shall not preclude completion of movement of a component to a safe position.

The COLR is the unit specific document that provides cycle specific parameter limits for the current reload cycle. These cycle specific limits shall be determined for each reload cycle in accordance with Specification 5.6.5. Plant operation within these limits is addressed in individual Specifications.

DOSE EQUIVALENT 1-131 shall be that concentration of 1-131 (microcuries/gram) that alone would produce the same Committed Effective Dose Equivalent as the quantity and isotopic mixture of 1-131, 1-132, 1-133, 1-134, and 1-135 actually present.

The dose conversion factors used for this calculation shall be those listed in Federal Guidance Report (FGR) 11, "Limiting Values of Radionuclide Intake and Air Concentration and Dose Conversion Factors for Inhalation, Submersion, and Ingestion,"

1988. 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 T AF is divided by the limiting drain rate; b. The limiting drain rate is the larger of the drain rate through a single penetration flow path with the highest flow rate, or the sum of the drain rates through multiple penetration flow paths susceptible to a common mode failure (e.g., seismic event, loss of normal power, single human error), for all penetration flow paths below the TAF except: 1.1-2 (continued)

Amendment No. 290 Definitions 1.1 1.1 Definitions (continued)

DRAIN TIME (continued)

HATCH UNIT 1 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 T AF by a dedicated operator trained in the task, who in continuous communication with the control room, is stationed at the controls, and is capable of closing the penetration flow path isolation device without offsite power. c. The penetration flow paths required to be evaluated per paragraph b) are assumed to open instantaneously and are not subsequently

isolated, and no water is assumed to be subsequently added to the RPV water inventory;

d. No additional draining events occur; and e. Realistic cross-sectional areas and drain rates are used. A bounding DRAIN TIME may be used in lieu of a calculated value. 1.1-3 (continued)

Amendment No. 290 Definitions 1.1 1.1 Definitions (continued)

END OF CYCLE RECIRCULATION PUMP TRIP (EOC-RPT)

SYSTEM RESPONSE TIME INSERVICE TESTING PROGRAM LEAKAGE LINEAR HEAT GENERATION RATE LOGIC SYSTEM FUNCTIONAL TEST HATCH UNIT 1 The EOC-RPT SYSTEM RESPONSE TIME shall be that time interval from initial signal generation by the associated turbine stop valve limit switch or from when the turbine control valve hydraulic control oil pressure drops below the pressure switch setpoint to complete suppression of the electric arc between the fully open contacts of the recirculation pump circuit breaker.

The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

The INSERVICE TESTING PROGRAM is the licensee program that fulfills the requirements of 10 CFR 50.55a(f).

LEAKAGE shall be: a. Identified LEAKAGE 1. LEAKAGE into the drywell, such as that from pump seals or valve packing, that is captured and conducted to a sump or collecting tank; or 2. LEAKAGE into the drywell atmosphere from sources that are both specifically located and known either not to interfere with the operation of leakage detection systems or not to be pressure boundary LEAKAGE;

b. Unidentified LEAKAGE All LEAKAGE into the drywell that is not identified LEAKAGE;

c. Total LEAKAGE d. Sum of the identified and unidentified LEAKAGE; Pressure Boundary LEAKAGE LEAKAGE through a nonisolable fault in a Reactor Coolant System (RCS) component body, pipe wall, or vessel wall. LINEAR HEAT GENERATION RATE (LHGR) shall be the power generation in an arbitrary length of fuel rod, usually six inches. It is the integral of the heat flux over the heat transfer area associated with the unit length. A LOGIC SYSTEM FUNCTIONAL TEST shall be a test of all required logic components (i.e., all required relays and contacts, trip units, solid state logic elements, etc.) of a logic circuit, from as close to the sensor as practicable up to, but not including, the actuated device, to verify OPERABILITY.

The LOGIC SYSTEM FUNCTIONAL TEST may be performed by means of any series of sequential, overlapping, or total system steps so that the entire logic system is tested. 1.1-4 (continued)

Amendment No. 290

*--* --Definitions 1.1 1.1 Definitions (continued)

MINIMUM CRITICAL POWER RATIO (MCPR) MODE OPERABILITY PHYSICS TESTS PRESSURE AND TEMPERATURE LIMITS REPORT (PTLR) RATED THERMAL POWER (RTP) REACTOR PROTECTION SYSTEM (RPS) RESPONSE TIME HATCH UNIT 1 The MCPR shall be the smallest critical power ratio (CPR) that exists in the core for each class of fuel. The CPR is that power in the assembly that is calculated by application of the appropriate correlation(s) to cause some point in the assembly to experience boiling transition, divided by the actual assembly operating power. A MODE shall correspond to any one inclusive combination of mode switch position, average reactor coolant temperature, and reactor vessel head closure bolt tensioning specified in Table 1.1-1 with fuel in the reactor vessel. A system, subsystem,

division, component, or device shall be OPERABLE or have OPERABILITY when it is capable of performing its specified safety function(s) and when all necessary attendant instrumentation,

controls, normal or emergency electrical power, cooling and seal water, lubrication, and other auxiliary equipment that are required for the system, subsystem,

division, component, or device to perform its specified safety function(s) are also capable of performing their related support function(s).

PHYSICS TESTS shall be those tests performed to measure the fundamental nuclear characteristics of the reactor core and related instrumentation.

These tests are: a. Described in Section 13.6, Startup and Power Test Program, of the FSAR; b. Authorized under the provisions of 10 CFR 50.59; or c. Otherwise approved by the Nuclear Regulatory Commission.

The PTLR is the unit specific document that provides the reactor vessel pressure and temperature limits, including heatup and cooldown rates, for the current reactor vessel fluence period. These pressure and temperature limits shall be determined for each fluence period in accordance with Specification 5.6.7. RTP shall be a total reactor core heat transfer rate to the reactor coolant of 2804 MWt. The RPS RESPONSE TIME shall be that time interval from when the monitored parameter exceeds its RPS trip setpoint at the channel sensor until de-energization of the scram pilot valve solenoids.

The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

1.1-5 (continued)

Amendment No. 2 _9 o Definitions 1.1 1.1 Definitions (continued)

SHUTDOWN MARGIN (SOM) STAGGERED TEST BASIS SOM shall be the amount of reactivity by which the reactor is subcritical or would be subcritical throughout the operating cycle assuming that: a. The reactor is xenon free; b. The moderator temperature is 68°F, corresponding to the most reactive state; and c. All control rods are fully inserted except for the single control rod of highest reactivity worth, which is assumed to be fully withdrawn.

With control rods not capable of being fully inserted, the reactivity worth of these control rods must be accounted for in the determination of SOM. A STAGGERED TEST BASIS shall consist of the testing of one of the systems, subsystems,

channels, or other designated components during the interval specified by the Surveillance Frequency, so that all systems, subsystems,

channels, or other designated components are tested during n Surveillance Frequency intervals, where n is the total number of systems, subsystems,

channels, or other designated components in the associated function.

THERMAL POWER THERMAL POWER shall be the total reactor core heat transfer rate to the reactor coolant.

TURBINE BYPASS SYSTEM RESPONSE TIME HATCH UNIT 1 The TURBINE BYPASS SYSTEM RESPONSE TIME consists of two components:

a. The time from initial movement of the main turbine stop valve or control valve until 80% of the turbine bypass capacity is established; and b. The time from initial movement of the main turbine stop valve or control valve until initial movement of the turbine bypass valve. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

1.1-6 Amendment No. 2 9 O MODE TITLE 1 Power Operation 2 Startup 3 Hot Shutdown<*>

4 Cold Shutdown<a>

5 Refueling<bl Table 1. 1-1 (page 1 of 1 ) MODES REACTOR MODE SWITCH POSITION Run Refue1<*>

or Startup/Hot Standby Shutdown Shutdown Shutdown or Refuel (a) All reactor vessel head closure bolts fully tensioned.

Definitions 1.1 AVERAGE REACTOR COOLANT TEMPERATURE

(°F) NA NA > 212 :S 212 NA (b) One or more reactor vessel head closure bolts less than fully tensioned.

HATCH UNIT 1 1.1-7 Amendment No.290 3.3 INSTRUMENTATION 3.3.5.1 Emergency Core Cooling System (ECCS) Instrumentation ECCS Instrumentation 3.3.5.1 LCO 3.3.5.1 The ECCS instrumentation for each Function in Table*3.3.5.1-1 shall be OPERABLE.

APPLICABILITY:

According to Table 3.3.5.1-1.

ACTIONS -------------------------------------NOTE

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the Con.dition Immediately inoperable.

referenced in Table 3.3.5.1-1 for the channel.

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

Action A.1 and referenced Only applicable for in Table 3.3.5.1-1.

Functions 1.a, 1.b, 2.a, and 2.b. -----------------------

Declare supported 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery feature(s) inoperable.

of loss of initiation capability for feature(s) in both divisions AND (continued)

HATCH UNIT 1 3.3-34 Amendment No. 2 9 0 ACTIONS CONDITION B. (continued) 8.2 AND 8.3 C. As required by Required C.1 Action A.1 and referenced in Table 3.3.5.1-1.

AND C.2 HATCH UNIT 1 REQUIRED ACTION ------NOTE------

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

Declare High Pressure Coolant Injection (HPCI) System inoperable.

Place channel in trip. --------NOTE--:------

Only applicable for Functions 1.c, 2.c, 2.d, and 2.f. ---------------

Declare supported feature(s) inoperable.

Restore channel to OPERABLE status. 3.3-35 ECCS Instrumentation 3.3.5.1 COMPLETION TIME 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery of loss of HPCI initiation capability 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 1 hour from discovery of loss of initiation capability for feature(s) in both divisions 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (continued)

Amendment No. 290 ACTIONS (continued)

CONDITION REQUIRED ACTION D. As required by Required D.1 ----NOTE----

Action A.1 and referenced Only applicable if HPCI in Table 3.3.5.1-1.

pump suction is not aligned to the suppression pool. -------------------

Declare HPCI System inoperable.

AND D.2.1 Place channel in trip. OR D.2.2 Align the HPCI pump suction to the suppression pool. E. As required by Required E.1 ------NOTE--------

Action A.1 and referenced Only applicable for in Table 3.3.5.1-1.

Functions 1.d and 2.g. ------------------------

Declare supported feature(s) inoperable.

AND E.2 Restore channel to OPERABLE status. HATCH UNIT 1 3.3-36 ECCS Instrumentation 3.3.5.1 COMPLETION TIME 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery of loss of HPCI initiation capability 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 24 hours 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery of loss of initiation capability for subsystems in both divisions 7 days (continued)

Amendment No. 2 9 0 ECCS Instrumentation 3.3.5.1 Table3.3.5.1-1 (page 1 of5) Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED CROTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTIONA.1 REQUIREMENTS VALUE 1. Core Spray System a. Reactor Vessel 1, 2, 3 4(a) B SR 3.3.5.1.1

-113 Inches I Water Level -Low SR 3.3.5.1.2 Low Low, Level 1 SR 3.3.5.1.4 SR 3.3.5.1.5

b. Drywell Pressure

-1,2,3 4(a) B SR 3.3.5.1.1

s; 1.92 psig High SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.5 C. Reactor Steam 1, 2, 3 4 C SR 3.3.5.1.1

390 pslg Dome Pressure

-SR 3.3.5.1.2 and Low (Injection SR 3.3.5.1.4 S476 psig Permissive)

SR 3.3.5.1.5

d. Core Spray Pump 1,2,3 1 per E SR 3.3.5.1.1

610 gpm Discharge Flow -subsystem SR 3.3.5. 1.2 and Low (Bypass)

SR 3.3.5.1.4 s825gpm SR 3.3.5.1.5

2. Low Pressure Coolant Injection (LPCI) System a. Reactor Vessel 1, 2, 3 4(a) B SR 3.3.5.1.1

-113 inches I Water Level -Low SR 3.3.5.1.2 Low Low, Level 1 SR 3.3.5.1.4 SR 3.3.5.1.5

b. Drywall 1, 2, 3 4(a) B SR 3.3.5.1.1

s; 1.92 psig Pressure

-High SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.5 continued (a) Also required to initiate the associated diesel generator (DG) and isolate the associated plant service water (PSW) turbine building (TIB) isolation valves. HATCH UNIT 1 3.3-39 Amendment No. 290 ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 2 of 5) Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED OR OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTIONA.1 REQUIREMENTS VALUE 2. LPCI System (continued)

C. Reactor Steam Dome 1, 2, 3 4 C SR 3.3.5.1.1 i!: 390 psig Pressure

-Low SR 3.3.5.1.2 and (Injection Permissive)

SR 3.3.5.1.4 S476 psig SR 3.3.5.1.5

d. Reactor Steam Dome 1 (b), 2(b), 4 C SR 3.3.5.1.1 i!: 335 psig Pressure

-Low 3(b) SR 3.3.5.1.2 (Recirculation SR 3.3.5.1.4 Discharge Valve SR 3.3.5.1.5 Permissive)

e. Reactor Vessel Shroud 1,2,3 2 B SR 3.3.5.1.1 i!: -202 Inches Level -Level O SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.5

f. Low Pressure Coolant 1,2,3 1 per C SR 3.3.5.1.4 Injection Pump Start -pump SR 3.3.5.1.5 Time Delay Relay Pumps A, 8, D i!: 9 seconds and s 15 seconds PumpC s 1 second g. Low Pressure Coolant 1,2,3 1 per E SR 3.3.5.1.1 c?. 1670 gpm Injection Pump subsystem SR 3.3.5.1.2 and Discharge Flow -SR 3.3.5.1.4 S2205gpm Low (Bypass)

SR 3.3.5.1.5 (continued)

(b) With associated recirculation pump discharge valve open. HATCH UNIT 1 3.3-40 Amendmerit No. 290 --------------

Table 3.3.5.1-1 (page 3 of5) Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED OR OTHER CHANNELS FROM SPECIFIED PER REQUIRED FUNCTION CONDITIONS FUNCTION ACTIONA.1

3. High Pressure Coolant Injection (HPCI) System a. Reactor Vessel Water 1, 4 B Level -Low Low, 2(c), 3(c) Level2 b. Drywall Pressure

-High 1, 4 B 2(c), 3(c) C. Reactor Vessel Water 1, 2 C Level -High, Level 8 2(c), 3(c) d. Condensate Storage 1, 2 D Tank Level

Low 2(c), 3(c) e. Suppression Pool 1, 2 D Water Level -High 2(C), 3(c) f. High Pressure Coolant 1, E Injection Pump 2(c), 3(c) Discharge Flow -Low (Bypass)

(c) With reactor steam dome pressure>

150 psig. HATCH UNIT 1 3.3-41 ECCS Instrumentation 3.3.5.1 SURVEILLANCE ALLOWABLE REQUIREMENTS VALUE SR 3.3.5.1.1 -47 inches SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.5 SR 3.3.5.1.1 s 1.92 psig SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.5 SR 3.3.5.1.1 s 56.5 inches SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.5 SR 3.3.5.1.3 2.58 ft SR 3.3.5.1.5 SR 3.3.5.1.1 s 154 inches SR 3.3.5.1.2 SR 3°.3.5.1.4 SR 3.3.5.1.5 SR 3.3.5.1.1

~605 gpm SR 3.3.5.1.2 and SR 3.3.5. 1.4 s 865 gpm SR 3.3.5.1.5 (continued)

Amendment No. 2 9 O

-* ---------------------------------

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 4 of 5) Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED OR OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTIONA.1 REQUIREMENTS VALUE 4. Automatic Depressurization System (ADS) Trip System A a. Reactor Vessel Water 1, 2 F SR 3.3.5.1.1 -113 inches Level -Low Low Low, 2(c), 3(c) SR 3.3.5.1.2 Level 1 SR 3.3.5.1.4 SR 3.3.5.1.5

b. Drywell 1, 2 F SR 3.3.5.1.1 s 1.92 psig Pressure

-High 2(c), 3(c) SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.5 C. Automatic 1, 1 G SR 3.3.5.1.4 s 114 seconds Depressurization 2cc), 3(c) SR 3.3.5.1.5 System Initiation Timer d. Reactor Vessel Water 1, 1 F SR 3.3.5.1.1 0 inches Level -Low, Level 3 2cc), 3(c) SR 3.3.5.1.2 (Confirmatory)

SR 3.3.5.1.4 SR 3.3.5.1.5

e. Core Spray Pump 1, 2 G SR 3.3.5.1.1 137 psig Discharge Pressure

-2cc), 3(c) SR 3.3.5.1.2 and High SR 3.3.5.1.4 SR 3.3.5.1.5 s 180 psig f. Low Pressure Coolant 1, 4 G SR 3.3.5.1.1 112 psig Injection Pump 2cc), 3(c) SR 3.3.5.1.2 and Discharge Pressure

-SR 3.3.5.1.4 s 180 psig High SR 3.3.5.1.5

g. Automatic 1, 2 G SR 3.3.5.1.4

,;; 12 minutes Depressurization 2(c), 3(c) SR 3.3.5.1.5 18 seconds System Low Water Level Actuation 11mer (continued)

(c) With reactor steam dome pressure

> 150 psig. HATCH UNIT 1 3.3-42 Amendment No. 2 9 0 ECCS Instrumentation 3.3.5.1 Table3.3.5.1-1 (page5of5)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED OR OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTIONA.1 REQUIREMENTS VALUE 5. ADS Trip System 8 a. Reactor Vessel Water 1, 2 F SR 3.3.5.1.1 -113 inches Level -Low Low Low, 2(c), 3(c) SR 3.3.5.1.2 Level 1 SR 3.3.5.1.4 SR 3.3.5.1.5

b. Drywell Pressure

-High 1, 2 F SR 3.3.5.1.1 s; 1.92 psig 2(c), 3(c) SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.5 C. Automatic 1, G SR 3.3.5.1.4 s; 114 seconds Depressurization 2(c), 3(c) SR 3.3.5.1.5 System Initiation Timer d. Reactor Vessel Water 1, F SR 3.3.5.1.1

1!: 0 inches Level -Low, Level 3 2(c), 3(c) SR 3.3.5.1.2 (Confirmatory)

SR 3.3.5.1.4 SR 3.3.5.1.5

e. Core Spray Pump 1, 2 G SR 3.3.5.1.1

137 psig Discharge Pressure

-2(c), 3(c) SR 3.3.5.1.2 and High SR 3.3.5.1.4 SR 3.3.5.1.5 s; 180 pslg f. Low Pressure Coolant 1, 4 G SR 3.3.5.1.1

112 psig Injection Pump 2(c), 3(c) SR 3.3.5.1.2 and Discharge Pressure

-SR 3.3.5.1.4 s; 180 psig High SR 3.3.5.1.5

g. Automatic 1, 2 G SR 3.3.5.1.4 s; 12 minutes Depressurization 2(c), 3(c) SR 3.3.5.1.5 18 seconds System Low Water Level Actuation Tlmer (c) With reactor steam dome pressure>

150 pslg. HATCH UNIT 1 3.3-43 Amendment No. 2 9 o 3.3 INSTRUMENTATION RPV Water Inventory Control Instrumentation 3.3.5.2 3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation LCO 3.3.5.2 The RPV Water Inventory Control instrumentation for each Function in Table 3.3.5.2-1 shall be OPERABLE.

APPLICABILITY:

According to Table 3.3.5.2-1.

ACTIONS -------------------------------------NOTE--------------------------------------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable.

referenced in Table 3.3.5.2-1 for the channel.

B. As required by Required 8.1 Declare associated Immediately Action A. 1 and referenced penetration flow path(s) in Table 3.3.5.2-1.

incapable of automatic isolation.

AND 8.2 Calculate DRAIN TIME. Immediately C. As required by Required C.1 Place channel in trip. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Action A.1 and referenced in Table 3.3.5.2-1.

D. As required by Required D. 1 Restore channel to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Action A.1 and referenced OPERABLE status. in Table 3.3.5.2-1.

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

HATCH UNIT 1 3.3-44 Amendment No. 2 9 o RPV Water Inventory Control Instrumentation 3.3.5.2 SURVEILLANCE REQUIREMENTS

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

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

'

SR 3.3.5.2.1 SR 3.3.5.2.2 HATCH UNIT 1 SURVEILLANCE Perform CHANNEL CHECK. Perform CHANNEL FUNCTIONAL TEST. 3.3-45 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 290 -~-~------------

RPV Water Inventory Control Instrumentation 3.3.5.2 Table 3.3.5.2-1 (page 1 of1) RPV Water Inventory Control Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED OR OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOV\IABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE 1. Core Spray System a. Reactor Steam 4,5 4<*1 C SR 3.3.5.2.1 s 476 psig Dome Pressure

-SR 3.3.5.2.2 Low (Injection Permissive)

b. Core Spray Pump 4,5 1 per D SR 3.3.5.2.1 l! 610 gpm Discharge Flow -subsystem<*>

SR 3.3.5.2.2 and Low (Bypass)

s 825 gpm 2. Low Pressure Coolant Injection (LPCI) System a. Reactor Vessel 4,5 41*1 C SR 3.3.5. 2.1 S476 psig Dome Pressure

-SR 3.3.5.2.2 Low (Injection Permissive)

b. Low Pressure 4,5 1 per D SR 3.3.5.2.1 1670 gpm Coolant Injection subsysteml*>

,,, SR 3.3.5.2.2 and Pump Discharge s 2205gpm Flow -Low (Bypass)

3. RHR System lsolatior,

a. Reactor Vessel (b) 2 in one trip B SR 3.3.5.2.1 l! Oinches Water Level -Low, system SR 3.3.5.2.2 Level3 4. Reactor Water Clean~ (RWCU) System Isolation (b) 2 in one trip B SR 3.3.5.2.1 l! -47 inches a Reactor Vessel system SR 3.3.5-2.2 Water Level -Low Low, Level2 (a) Associated with an ECCS subsystem required to be OPERABLE by LCO 3.5.2, "Reactor Pressure Vessel Water Inventory Control*.

(b) Wien automatic isolation of the associated penetration flow path(s) is credited in calculating DRAIN TIME. (cl Function not required to be OPERABLE while associated pump is operating in decay heat removal when minimum flow valve is closed and deactivated HATCH UNIT 1 3.3-46 Amendment No. 290 3.3 INSTRUMENTATION RCIC System Instrumentation 3.3.5.3 3.3.5.3 Reactor Core Isolation Cooling (RCIC) System Instrumentation LCO 3.3.5.3 The RCIC System instrumentation for each Function in Table 3.3.5.3-1 shall be OPERABLE.

APPLICABILITY:

MODE 1, MODES 2 and 3 with reactor steam dome pressure

> 150 psig. ACTIONS -------------------------NOTE--------------------------------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable.

referenced in Table 3.3.5.3-1 for the channel.

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

of loss of RCIC in Table 3.3.5.3-1.

initiation capability AND B.2 Place channel in trip. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months C. As required by Required C.1 Restore channel to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Action A.1 and referenced OPERABLE status. in Table 3.3.5.3-1.

(continued)

HATCH UNIT 1 3.3-47 AmendmentNo.290 I

ACTIONS (continued)

CONDITION D. As required by Required Action A.1 and referenced in Table 3.3.5.3-1.

E. Required Action and associated Completion Time of Condition B, C, or D not met. HATCH UNIT 1 RCIC System Instrumentation 3.3.5.3 REQUIRED ACTION COMPLETION TIME D.1 ----NOTE------

Only applicable if RCIC pump suction is not aligned to the suppression pool. ----------------

Declare RCIC System 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery inoperable.

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

3.3-48 Amendment No. 2 9 O SURVEILLANCE REQUIREMENTS

RCIC System Instrumentation 3.3.5.3 ----------------------------------NOTES-------------------------------------

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

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed as follows:

(a) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Function 2; and (b) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Functions 1, 3, and 4 provided the associated Function maintains RCIC initiation capability.

SURVEILLANCE SR 3.3.5.3.1 Perform CHANNEL CHECK. SR 3.3.5.3.2 Perform CHANNEL FUNCTIONAL TEST. SR 3.3.5.3.3 Perform CHANNEL FUNCTIONAL TEST. SR 3.3.5.3.4 Perform CHANNEL CALIBRATION.

SR 3.3.5.3.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. HATCH UNIT 1 3.3-49 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 2 9 o Table3.3.5.3-1 (page 1 of 1) RCIC System Instrumentation 3.3.5.3 Reactor Core Isolation Cooling System Instrumentation REQUIRED CHANNELS PER FUNCTION FUNCTION

1. Reactor Vessel water Level -4 Low Low, Level 2 2. Reactor Vessel Water Level -2 High, Level 8 3. Condensate Storage Tank 2 Level-Low 4. Suppression Pool Water 2 Level-High HATCH UNIT 1 CONDITIONS REFERENCED FROM REQUIRED ACTION.A.1 B C D D 3.3-50 SURVEILLANCE REQUIREMENTS SR 3.3.5.3.1 SR 3.3.5.3.2 SR 3.3.5.3.4 SR 3.3.5.3.5 SR 3.3.5.3.1 SR 3.3.5.3.2 SR 3.3.5.3.4 SR 3.3.5.3.5 SR 3.3.5.3.3 SR 3.3.5.3.5 SR 3.3.5.3.3 SR 3.3.5.3.5 ALLOWABLE VALUE t!:.-47 inches s 56.5 inches t!:. 0.87 ft s 151 inches Amendment No. 2 9 O 3.3 INSTRUMENTATION Primary Containment Isolation Instrumentation 3.3.6.1 3.3.6.1 Primary Containment Isolation Instrumentation LCO 3.3.6.1 The primary containment isolation instrumentation for each Func:tion in Table 3.3.6.1-1 shall be OPERABLE.

APPLICABILITY:

According to Table 3.3.6.1-1.

ACTIONS ------------------NOTES-------------------------------

1. Penetration flow paths except for 18 inch purge valve penetration flow paths may be unisolated intermittently under administrative controls.

2. Separate Condition entry is allowed for each channel.

, _______________________

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

Functions 2.a, 2.b, 6.b, 7.a, and ?.b AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for Functions other than Functions 2.a, 2.b, 6.b, 7.a, and 7.b B. --------NOTE--------

8.1 Restore isolation 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Not applicable for capability.

Function 5.c. ----------------------

One or more automatic Functions with isolation capability not maintained.

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

(c1>ntrnued)

HATCH UNIT 1 3.3-51 Amendment No. 2*9 o ACTIONS (continued)

CONDITION D. As required by Required Action C.1 and referenced in Table 3.3.6.1-1.

E. As required by Required Action C. 1 and referenced in Table 3.3.6.1-1.

F. As required by Required Action C.1 and referenced in Table 3.3.6.1-1.

G. As required by Required Action C.1 and referenced in Table 3.3.6.1-1.

H. As required by Required Action C.1 and referenced in Table 3.3.6.1-1.

QR Required Action and associated Completion Time of Condition F or G not met. HATCH UNIT 1 0.1 OR D.2.1 Primary Containment Isolation Instrumentation 3.3.6.1 REQUIRED ACTION COMPLETION TIME. Isolate associated main 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months steam line (MSL). Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND 0.2.2 Be in MODE4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months F.1 Isolate the affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months penetration flow path(s).

G.1 Isolate the affected 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months penetration flow path(s).

H.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND H.2 Be in M0DE4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued) 3.3-52 Amendment No. 290

-----------------

Primary Containment Isolation Instrumentation 3.3.6.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME I. As required by Required 1.1 Declare Standby Liquid 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Action C.1 and referenced Con.trot (SLC) System in Table 3.3.6.1-1.

inoperable.

OR 1.2 Isolate the Reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Water Cleanup (RWCU) System. -J. As required by Required J.1 Initiate action to restore Immediately Action C.1 and referenced channel to OPERABLE in Table 3.3.6.1-1.

status. SURVEILLANCE REQUIREMENTS

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

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

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

isolation capability.

SURVEILLANCE SR 3.3.6.1.1 Perform CHANNEL CHECK. HATCH UNIT 1 3.3-53 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued)

Amendment No. 290

-----------------

*-------*-----

Primary Containment Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE SR 3.3.6.1.2 Perform CHANNEL FUNCTIONAL TEST. SR 3.3.6.1.3 Perform CHANNEL CALIBRATION.

SR 3.3.6.1.4 Perform CHANNEL CALIBRATION.

SR 3.3.6.1.5 Perform CHANNEL CALIBRATION.

SR 3.3.6.1.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. HATCH UNIT 1 3.3-54 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No.290 Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 1 of 5) Primar:y Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE 1. Main Steam Line Isolation

a. Reactor Vessel Water Level -1,2,3 2 D SR 3.3.6.1.1 t? -113 inches Low Low Low, Level 1 SR 3.3.6.1.2 SR 3.3:6.1 .5 SR 3.3.6.1.6

b. Main Steam Line Pressure

-2 E SR 3.3.6.1.3 t? 825 psig Low SR 3.3.6.1.6

c. Main Steam Line 1,2,3 2per D SR 3.3.6.1.1 s 138% rated Flow-High MSL SR 3.3.6.1.2 steam flow SR 3.3.6.1.5 SR 3.3.6.1.6

d. Condenser Vacuum -Low 1, 2 D SR 3.3.6.1.3 t? 7 inches Hg 2(a), 3(a) SR 3.3.6.1.6 vacuum e. Main Steam Tunnel 1,2,3 6 D SR 3.3;6.1.1 s 194°F Temperature

-High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

f. Turbine Building Area 1,2,3 16(b) D SR 3.3.6.1.2 s 200°F Temperature

-High SR 3.3.6.1.5 SR 3.3.6.1.6

2. Primary Containment Isolation

a. Reactor Vessel water Level 1,2,3 2 H SR 3.3.6.1.1 t? O inches -Low, Level 3 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

b. Drywell Pressure

-High 1,2,3 2 H SR 3.3.6.1.1 s 1.92 psig SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 continued (a) With any turbine stop valve not closed. (b) With 8 channels per trip string. Each trip string shall have 2 channels per main steam line, with no more than 40 ft separating any two OPERABLE channels.

HATCH UNIT 1 3.3-55 Amendment No. 2 9 o Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 2 of 5) Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE 2. Primary Containment Isolation (contin'ued)

C. Drywall Radiation

-1,2,3 F SR 3.3.6.1.1 s 138 R/hr High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

d. Reactor Building Exhaust 1,2,3 2 H SR 3.3.6.1.1 s 60 mR/hr Radiation

-High SR 3.3.6.1.3 SR 3.3.6.1.6

e. Refueling Floor Exhaust 1,2,3 2 H SR 3.3.6.1.1 s 80 mR/hr Radiation

-High SR 3.3.6.1.3 SR 3.3.6.1.6

3. High Pressure Coolant injection (HPCI) System Isolation

a. HPCI Steam Line Flow -1,2,3 1 F SR 3.3.6.1.1

s 303% rated High SR 3.3.6.1.2 steam flow SR 3.3.6.1.5 SR 3.3.6.1.6

b. HPCI Steam Supply Line 1,2,3 2 F SR 3.3.6.1.1 i!: 100 psig Pressure

-Low SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 C. HPCI Turbine Exhaust 1,2,3 2 F SR 3.3.6.1.1 s 20 psig Diaphragm Pressure

-High SR 3.3.6.1 .2 SR 3.3.6.1.5 SR 3.3.6.1.6

d. Drywell Pressure

-High 1,2,3 F SR 3.3.6.1.1

s 1.92 psig SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

e. HPCI Pipe Penetration Roon 1,2,3 F SR 3.3.6.1.1 s 169°F Temperature

-High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

f. Suppression Pool Area 1,2,3 F SR 3.3.6.1.1

s 169°F Ambient Temperature

-High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 continued HATCH UNIT 1 3.3-56 Amendment No. 2 9 o Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 3 of5) Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE 3. HPCI System Isolation (continued)

g. Suppression Pool Area 1,2,3 F SR 3.3.6.1.4 s 16 minutes Temperature

-Time Delay SR 3.3.6.1.6 15 seconds Relays h. Suppression Pool Area 1,2,3 F SR 3.3.6.1.1 S42°F Differential Temperature

-SR 3.3.6.1.2 High SR 3.3.6.1.5 SR 3.3.6.1.6

i. Emergency Area Cooler 1,2,3 F SR 3.3.6.1.1 s 16s°F Temperature

-High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

4. Reactor Core Isolation Cooling (RCIC) System Isolation

a. RCIC Steam Line Flow -1,2,3 F SR 3.3.6.1.1 s 306% rated High SR 3.3.6.1.2 steam flow SR 3.3.6.1.5 SR 3.3.6.1.6

b. RCIC Steam Supply Line 1,2,3 2 F SR 3.3.6.1.1.

~60 psig Pressure

-Low SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 C. RCIC Turbine Exhaust 1,2,3 2 F SR 3.3.6.1.1 s 20 psig Diaphragm Pressure

-SR 3.3.6.1.2 High SR 3.3.6.1.5 SR 3.3.6.1.6

d. Drywall Pressure

-High 1,2,3 F SR 3.3.6.1.1 s 1.92 psig SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

e. RCIC Suppression Pool 1,2,3 F SR 3.3.6.1.1 s 16s°F Ambient Area SR 3.3.6.1.2 Temperature

-High SR 3.3.6.1.5 SR 3.3.6.1.6

f. Suppression Pool Area 1,2,3 F SR 3.3.6.1.4 S31 minutes Temperature

-Time Delay SR 3.3.6.1.6 15 seconds Relays continued HATCH UNIT 1 3.3-57 Amendment No. 290 I Primary Containment Isolation Instrumentation 3.3.6.1 Table3.3.6.1-1 (page4of5)

Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE 4. RCIC System Isolation (continued)

g. RCIC Suppression Pool 1,2,3 1 F SR 3.3.6.1.1 S42°F Area Differential SR 3.3.6.1.2 Temperature

-High SR 3.3.6.1.5 SR 3.3.6.1.6

h. Emergency Area Cooler 1,2,3 F SR 3.3.6.1.1 s 169°F Temperature

-High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

5. RWCU System Isolation

a. Area Temperature

-High 1,2,3 1 per area F SR 3.3.6.1.1 s 150°F SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

b. Area Ventilation 1,2,3 1 per area F SR 3.3.6.1.1 S67°F Differential Temperature

-SR 3.3.6.1.2 High SR 3.3.6.1.5 SR 3.3.6.1.6 C. SLC System Initiation 1,2 1(c) SR 3.3.6.1.6 NA d. Reactor Vessel Water 1,2,3 2 F SR 3.3.6.1.1 l!: -47 inches Level -Low Low, Level 2 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

6. RHR Shutdown Cooling System Isolation

a. Reactor Steam Dome 1,2,3 F SR 3.3.6.1.1 s 145 psig Pressure

-High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

b. Reactor Vessel Water 3 2 J SR 3.3.6.1.1 l!: O Inches Level -Low, Level 3 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 (continued)

I (c) SLC System Initiation only inputs into one of the two trip systems.

HATCH UNIT 1 3.3-58 Amendment No. 290 I FUNCTION

7. Traversing lncore Probe System Isolation

a. Reactor Vessel Water Level -Low, Level 3 b. Drywell Pressure

-High HATCH UNIT 1 Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 5 of5) Primary Containment Isolation Instrumentation APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS 1,2,3 1,2,3 REQUIRED CHANNELS PER TRIP SYSTEM 2 2 3.3-59 CONDITIONS REFERENCED FROM REQUIRED ACTION C.1 G G SURVEILLANCE REQUIREMENTS SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6. 1.1 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 ALLOWABLE VALUE o inches s 1.92 psig Amendment No. 2' 9 0 I Secondary Containment Isolation Instrumentation 3.3.6.2 3.3 INSTRUMENTATION 3.3.6.2 Secondary Containment Isolation Instrumentation LCO 3.3.6.2 The secondary containment isolation instrumentation for each Function in Table 3.3.6.2-1 shall be OPERABLE.

APPLICABILITY:

According to Table 3.3.6.2-1.

ACTIONS -----------------------NOTE----------------------------

Separate Condition entry is allowed for each channel.

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

Function 2 AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for Functions other than Function 2 B. One or more automatic 8.1 Restore isolation 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Functions with isolation capability.

capability not maintained.

C. Required Action and C.1.1 Isolate the associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated Completion penetration flow Time of Condition A or B path{s).

not met. OR C.1.2 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months secondary containment isolation valves inoperable.

AND (continued)

HATCH UNIT 1 3.3-60 Amendment No. 2 9 o ACTIONS Secondary Containment Isolation Instrumentation 3.3.6.2 CONDITION REQUIRED ACTION COMPLETION TIME C. (continued)

C.2.1 Place the associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months standby gas treatment (SGT) subsystem(s) in operation.

OR C.2.2 Declare associated SGT subsystem(s) inoperable.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SURVEILLANCE REQUIREMENTS

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

1. Refer to Table 3.3.6.2-1 to determine which SRs apply for each Secondary Containment Isolation Function.

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

SURVEILLANCE SR 3.3.6.2.1 Perform CHANNEL CHECK. SR 3.3.6.2.2 Perform CHANNEL FUNCTIONAL TEST. SR 3.3.6.2.3 Perform CHANNEL CALIBRATION.

HATCH UNIT 1 3.3-61 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued)

Amendment No. 2 9 O Secondary Containment Isolation Instrumentation 3.3.6.2 SURVEILLANCE REQUIREMENTS (continued}

SURVEILLANCE SR 3.3.6.2.4 Perform CHANNEL CALIBRATION.

SR 3.3.6.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. HATCH UNIT 1 3.3-62 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 2 9 o FUNCTION

1. Reactor Vessel Water Level Low -Low, Level 2 2. Drywell Pressure

-High 3. Reactor Building Exhaust Radiation

-High 4. Refueling Floor Exhaust Radiation

-High Secondary Containment Isolation Instrumentation 3.3.6.2 Table 3.3.6.2-1 (page 1 of 1) Secondary Containment Isolation Instrumentation APPLICABLE MODES OR REQUIRED OTHER CHANNELS SPECIFIED PER CONDITIONS TRIP SYSTEM 1 ,2, 3 2 1, 2, 3 2 1,2,3 2 1, 2, 3, 2 5,(a) SURVEILLANCE REQUIREMENTS SR 3.3.6.2.1 SR 3.3.6.2.2 SR 3.3.6.2.4 SR 3.3.6.2.5 SR 3.3.6.2.1 SR 3.3.6.2.2 SR 3.3.6.2.4 SR 3.3.6.2.5 SR 3.3.6.2.1 SR 3.3.6.2.3 SR 3.3.6.2.5 SR 3.3.6.2.1 SR 3.3.6.2.3 SR 3.3.6.2.5 ALLOWABLE VALUE ;i:-47 inches s 1.92 psig s 80 mR/hr s 80 mR/hr (a) During CORE AL TERA TIONS and during movement of irradiated fuel assemblies in secondary containment.

HATCH UNIT 1 3.3-63 Amendment No. 2 9 o

~---

3.3 INSTRUMENTATION 3.3.6.3 Low-Low Set (LLS) Instrumentation LLS Instrumentation 3.3.6.3 LCO 3.3.6.3 The LLS valve instrumentation for each Function in Table 3.3.6.3-1 shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One LLS valve with A.1 Restore LLS valve 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months initiation capability not initiation capability.

maintained.

B. One or more safety/relief 8.1 Restore tailpipe Prior to entering valves ($/RVs) with one pressure switches to MODE 2 or 3 from Function 3 channel OPERABLE status. MODE4 inoperable.

C. -------NOTE----------

C.1 Restore one tailpipe 14 days Separate Condition entry is pressure switch to allowed for each S/RV. OPERABLE status. ---------------

One or more S/RVs with two Function 3 channels inoperable.

(continued)

HATCH UNIT 1 3.3-64 Amendment No. 2 go ACTIONS (continued)

CONDITION REQUIRED ACTION LLS Instrumentation 3.3.6.3 COMPLETION TIME D. Required Action and associated Completion Time of Condition A, 8, or C not met. D.1 Declare the associated Immediately LLS valve(s)

OR Two or more LLS valves with initiation capability not maintained.

SURVEILLANCE REQUIREMENTS inoperable.

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

1. Refer to Table 3.3.6.3-1 to determine which SRs apply for each Function.

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

SR 3.3.6.3.1 SR 3.3.6.3.2 HATCH UNIT 1 SURVEILLANCE Perform CHANNEL CHECK. Perform CHANNEL FUNCTIONAL TEST for portion of the channel outside primary containment.

3.3-65 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued)

Amendment No. 2go

SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.6.3.3 SR 3.3.6.3.4 SR 3.3.6.3.5 SR 3.3.6.3.6 HATCH UNIT 1 SURVEILLANCE

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

Only required to be performed prior to entering MODE 2 during each scheduled outage > 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months when entry is made into primary containment.

Perform CHANNEL FUNCTIONAL TEST for portions of the channel inside primary containment.

Perform CHANNEL FUNCTIONAL TEST. Perform CHANNEL CALIBRATION.

Perform LOGIC SYSTEM FUNCTIONAL TEST. 3.3-66 ------*-----

-LLS Instrumentation

. 3.3.6.3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 290 \

FUNCTION

1. Reactor Steam Dome Pressure

-High 2. Low-Low Set Pressure Setpolnts

3. Tailpipe Pressure Switch HATCH UNIT 1 Table 3.3.6.3-1 (page 1 of 1) Low-Low Set Instrumentation REQUIRED CHANNELS PER SURVEILLANCE FUNCTION REQUIREMENTS 1 per LLS valve SR 3.3.6.3.1 SR 3.3.6.3.4 SR 3.3.6.3.5 SR 3.3.6.3.6 2 per LLS valve SR 3.3.6.3.1 SR 3.3.6.3.4 SR 3.3.6.3.5 SR 3.3.6.3.6 2 perS/RV 3.3-67 SR 3.3.6.3.2 SR 3.3.6.3.3 SR 3.3.6.3.5 SR 3.3.6.3.6 LLS Instrumentation 3.3.6.3 ALLOWABLE VALUE s 1085 psig Low: Open s 1005 psig Close s 857 psig Medium-Low:

Open s 1020 pslg Close s 872 pslg Medium-High:

Open s 1035 psig Close s 887 psig High: Open s 1045 psig Close s 897 pslg 80 psig and s 100 psig Amendment No.290 MCREC System Instrumentation 3.3.7.1 3.3 INSTRUMENTATION 3.3.7.1 Main Control Room Environmental Control (MCREC) System Instrumentation LCO 3.3.7.1 Two channels of the Control Room Air Inlet Radiation

-High Function shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary containment, During CORE AL TERA TIONS. ACTIONS -------------------------------NOTE----------------------------------

Separate Condition entry is allowed for each channel.

*---

CONDITION REQUIRED ACTION COMPLETION TIME A. One or both channels A.1 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery inoperable.

MCREC subsystem(s) of loss of MCREC inoperable.

initiation capability in both trip systems AND A.2 Place channel in trip. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months B. Required Action and 8.1 Place the associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated Completion MCREC subsystem(s)

Time not met. in the pressurization mode of operation.

OR 8.2 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months MCREC subsystem(s) inoperable.

HATCH UNIT 1 3.3-68 Amendment No. 290 MCREC System Instrumentation 3.3.7.1 SURVEILLANCE REQUIREMENTS

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

When a Control Room Air Inlet Radiation

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

SR 3.3.7.1.1 SR 3.3.7.1.2 SR 3.3.7.1.3 SR 3.3.7.1.4 HATCH UNIT 1 SURVEILLANCE Perform CHANNEL CHECK. Perform CHANNEL FUNCTIONAL TEST. Perform CHANNEL CALIBRATION.

The Allowable Value shall be 1 mr/hour.

Perfonn LOGIC SYSTEM FUNCTIONAL TEST. 3.3-69 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 2 9 o

,-------------

3.3 INSTRUMENTATION 3.3-.8.1 Loss of Power (LOP) Instrumentation LOP Instrumentation 3.3.8.1 LCO 3.3.8.1 The LOP instrumentation for each Function in Table 3.3.8.1-1 shall be OPERABLE.

APPLICABILITY:

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

ACTIONS -----------------------NOTE-------------

'*' ---------------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Restore channel to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable for Functions 1 OPERABLE status. and 2. 8. One or more channels B.1 Verify voltage on Once per hour inoperable for Function

3. associated 4.16 kV bus is c:: 3825 V. C. Required Action and C.1 Declare associated DG Immediately associated Completion inoperable.

Time not met. HATCH UNIT 1 3.3-70 Amendment No. 2 9 o SURVEILLANCE REQUIREMENTS LOP Instrumentation 3.3.8.1 -----------------------NOTES----------------

1. Refer to Table 3.3.8.1-1 to determine which SRs apply for each LOP Function.

2. When a 4.16 kV Emergency Bus Undervoltage channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains initiation capability (for Functions 1 and 2) and annunciation capability (for Function 3). SURVEILLANCE SR 3.3.8.1.1 Perform CHANNEL CHECK. SR 3.3.8.1.2 Perform CHANNEL FUNCTIONAL TEST. SR 3.3.8.1.3 Perform CHANNEL CALIBRATION.

SR 3.3.8.1.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. HATCH UNIT 1 3.3-71 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 2 9 o FUNCTION

1. 4.16 kV Emergency Bus Undervoltage (Loss of Voltage)

a. Bus Undervoltage

b. Time Delay 2. 4.16 kV Emergency Bus Undervoltage (Degraded Voltage)

a. Bus Undervoltage

b. Time Delay 3. 4.16 kV Emergency Bus Undervoltage (Annunciation)

a. Bus Undervoltage

b. Time Delay HATCH UNIT 1 Table 3.3.8.1-1 (page 1 of1) Loss of Power Instrumentation REQUIRED CHANNELS PER FUNCTION SURVEILLANCE REQUIREMENTS 2 2 2 2 2 2 3.3-72 SR 3.3.8.1.2 SR 3.3.8.1.3 SR 3.3.8.1.4 SR 3.3.8.1.2 SR 3.3.8.1.3 SR 3.3.8.1.4 SR 3.3.8.1.2 SR 3.3.8.1.3 SR 3.3.8.1.4 SR 3.3.8.1.2 SR 3.3.8.1.3 SR 3.3.8.1.4 SR 3.3.8.1.1 SR 3.3.8.1.2 SR 3.3.8.1.3 SR 3.3.8.1.4 SR 3.3.8.1.2 SR 3.3.8. 1.3 SR 3.3.8.1.4 LOP Instrumentation 3.3.8.1 ALLOWABLE VALUE 2800V s 6.5 seconds 3280V s 21.5 seconds 3825V s 65 seconds Amendment No. 290 3.3 INSTRUMENTATION RPS Electric Power Monitoring 3.3.8.2 3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring LCO 3.3.8.2 Two RPS electric power monitoring assemblies shall be OPERABLE for each inservice RPS motor generator set or alternate power supply. APPLICABILITY:

MODES 1, 2, and 3, MODES 4 and 5 with any control rod withdrawn from a core cell containing one or more fuel assemblies or with both residual heat removal (RHR) shutdown cooling (SDC) isolation valves open. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or both inservice A.1 Remove associated 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months power supplies with one inservice power electric power monitoring supply(s) from service.

assembly inoperable.

B. One or both inservice 8.1 Remove associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months power supplies with both inservice power electric power monitoring supply(s) from service.

assemblies inoperable.

C. Required Action and C. 1 ------NOTE---'"

associated Completion LCO 3.0.4.a is not Time of Condition A or B applicable when not met in MODE 1, 2, or 3. entering MODE 3. ----------Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

HATCH UNIT 1 3.3-73 Amendment No. 2go ACTIONS (continued)

CONDITION D. Required Action and associated Completion Time of Condition A or B not met in MODE 4 or 5 with any control rod withdrawn from a core cell containing one or more fuel assemblies or with both RHR SOC isolation valves open. HATCH UNIT 1 . RPS Electric Power Monitoring 3.3.8.2 REQUIRED ACTION COMPLETION TIME D.1 Initiate action to fully Immediately insert all insertable control rods in core cells containing one or more fuel assemblies.

AND D.2.1 Initiate action to restore Immediately one electric power monitoring assembly to OPERABLE status for inservice power supply(s) supplying required instrumentation.

OR D.2.2 Initiate action to isolate Immediately the RHR SOC. 3.3-74 Amendment No. 290 RPS Electric Power Monitoring 3.3.8.2 SURVEILLANCE REQUIREMENTS

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

When an RPS electric power monitoring assembly is placed in an inoperable status solely for performance of required Surveillances, entry into the associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the other RPS electric power monitoring assembly for the associated power supply maintains trip capability.

SR 3.3.8.2.1 SR 3.3.8.2.2 SR 3.3.8.2;3 HATCH UNIT 1 SURVEILLANCE

---,*------NOTE------------

Only required to be performed prior to entering MODE 2 or 3 from MODE 4, when in MODE 4 for r?: 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . Perform CHANNEL FUNCTIONAL TEST. Perform CHANNEL CALIBRATION.

The Allowable Values shall be: a. Overvoltage s 132 V, with time delay set to s 4 seconds.

b. Undervoltage r?: 108 V, with time delay set to s 4 seconds.

c. Underfrequency

57 Hz, with time delay set to s 4 seconds.

Perform a system functional test. 3.3-75 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 290 ----------* ----*** ------------

ECCS -Operating 3.5.1 3.5 EMERGENCY

.CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY

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

APPLICABILITY:

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

---*-------

LCO 3.0.4.b is not applicable to HPCI. ----------------

---------

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

subsystem(s) to OPERABLE status . .QB One LPCI pump in both LPCI subsystems inoperable.

B. Required Action and 8.1 -----NOTE----

associated Completion LCO 3.0.4.a is not Time of Condition A not applicable when met. entering MOD~ 3. ---------------

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

HATCH UNIT 1 3.5-1 Amendment No. 2 9 o RPV Water Inventory Control 3.5.2 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY

CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control LCO 3.5.2 DRAIN TIME of RPV water inventory to the top of active fuel (TAF) shall be~ 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . One low pressure ECCS injection/spray subsystem shall be OPERABLE.

APPLICABILITY:

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

subsystem to OPERABLE status. 8. Required Action and 8.1 Initiate action to Immediately associated Completion establish a method of Time of Condition A not water injection capable met. of operating without offsite electrical power. C. DRAIN TIME< 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months C.1 Verify secondary 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . containment boundary is capable of being established in less than the DRAIN TIME. AND C.2 Verify each secondary 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months containment penetration flow path is capable of being isolated in less than the DRAIN TIME. AND (continued)

HATCH UNIT 1 3.5-6 Amendment No. 290 ACTIONS CONDITION C. (continued)

C.3 D. DRAIN TIME< 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . 0.1 AND D.2 AND D.3 AND D.4 HATCH UNIT 1 RPV Water Inventory Control 3.5.2 REQUIRED ACTION Verify required standby gas treatment subsystem(s) are capable of being placed in operation in less than the DRAIN TIME. ---NOTE-----

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

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

Initiate action to isolate each secondary containment penetration flow path or verify it can be manually isolated from the control room. Initiate action to verify required standby gas treatment subsystem(s) are capable of being placed in operation.

3.5-7 COMPLETION TIME 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Immediately Immediately Immediately Immediately (continued)

Amendment No. 2 9 o RPV Water Inventory Control 3.5.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and associated Completion Time of Condition C or D not met. E.1 Initiate action to restore Immediately DRAIN TIME to 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . DRAIN TIME< 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . SURVEILLANCE REQUIREMENTS SR 3.5.2.1 SR 3.5.2.2 SR 3.5.2.3 HATCH UNIT 1 SURVEILLANCE Verify DRAIN TIME~ 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . Verify, for a required low pressure coolant injection (LPCI) subsystem, the suppression pool water level is~ 146 inches. Verify, for a required Core Spray (CS) subsystem, the: a. Suppression pool water level is .:: 146 inches; or b. Condensate storage tank water level is 13 ft. 3.5-8 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued)

Amendment No. 2 9 o RPV Water Inventory Control 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SR 3.5.2.4 SR 3.5.2.5 SR 3.5.2.6 SR 3.5.2.7 SR 3.5.2.8 HATCH UNIT 1 SURVEILLANCE Verify, for the required ECCS injection/

spray subsystem, locations susceptible to gas accumulation are sufficiently filled with water. ----------

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

1. A Low Pressure Coolant Injection (LPCI) subsystem may be considered OPERABLE during alignment and operation for decay heat removal if capable of being manually realigned and not otherwise inoperable.

2. Not required to be met for system vent flowpaths opened under administrative control.

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.

Operate the required ECCS injection/spray subsystem through the recirculation line for .:: 10 minutes.

Verify each valve credited for automatically isolating a penetration flow path actuates to the isolation position on an actual or simulated isolation signal. ---------------------NOTE--------------------

Vessel injection/spray may be excluded.

______________________________

, _________________

_ Verify the required ECCS injection/spray subsystem can be manually operated.

3.5-9 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 290 ----. -* ----------

, RCIC System 3.5.3 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY

CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.3 RCIC System LCO 3.5.3 The RCIC System shall be OPERABLE.

APPLICABILITY:

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

150 psig. ACTIONS ---------------------NOTE

LCO 3.0.4.b is not applicable to RCIC. CONDITION REQUIRED ACTION COMPLETION TIME A. RCIC System inoperable.

A.1 Verify by administrative 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months means high pressure coolant injection (HPCI) System is OPERABLE.

AND A.2 Restore RCIC System 14 days to OPERABLE status. B. Required Action and 8.1 ---NOTE---

associated Completion LCO 3.0.4.a is not Time not met. applicable when entering MODE 3. ----------------

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months HATCH UNIT 1 3.5-10 Amendment No.290 SURVEILLANCE REQUIREMENTS SR 3.5.3.1 SR 3.5.3.2 SR 3.5.3.3 SR 3.5.3.4 SR 3.5.3.5 HATCH UNIT 1 SURVEILLANCE Verify the RCIC System locations susceptible to gas accumulation are sufficiently filled with water. ---------------NOTE------------

Not required to be met for system vent flowpaths opened under administrative control.

Verify each RCIC System manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

NOTE

Not required to be peliormed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure and flow are adequate to perform the test. Verify, with reactor pressures 1058 psig and .!: 920 psig, the RCIC pump can develop a flow rate .!: 400 gpm against a system head corresponding to reactor pressure.

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

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure and flow are adequate to perform the test. Verify, with reactor pressure

s; 165 psig, the RCIC pump can develop a flow rate 400 gpm against a system head corresponding to reactor pressure.

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

Vessel injection may be excluded.

Verify the RCIC System actuates on an actual or simulated automatic initiation signal. 3.5-11 RCICSystem 3.5.3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No.2 o 3.6 CONTAINMENT SYSTEMS 3.6.1.3 Primary Containment Isolation Valves (PCIVs) PCIVs 3.6.1.3 LCO 3.6.1.3 Each PCIV, except reactor building-to-suppression chamber vacuum breakers, shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3. ACTIONS --------~~~~~~~-~------~--~-~~~~----~--NOTES-~~~-~~-~~~-~-~-~--~~~-~~-~-----

1. Penetration flow paths except for 18 inch purge valve penetration flow paths may be unisolated intermittently under administrative controls.

2. Separate Condition entry is allowed for each penetration flow path. 3. Enter applicable Conditions and Required Actions for systems made inoperable by PCIVs. 4. Enter applicable Conditions and Required Actions of LCO 3.6.1.1, "Primary Containment,"

when PCIV leakage results in exceeding overall containment leakage rate acceptance criteria.

CONDITION REQUIRED ACTION COMPLETION TIME A. --~---~---NOTE------~-------

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

automatic valve, closed manual valve, blind 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months for main One or more penetration flange, or check valve steam line flow paths with one PCIV with flow through the inoperable except due to valve secured.

leakage not within limit. AND (continued)

HATCH UNIT 1 3.6-7 Amendment No. 2 9 o ACTIONS (continued)

CONDITION C. -------NOTE--------

C. 1 Only applicable to penetration flow paths with only one PCIV. -------------------------------------

One or more penetration flow paths with one PCIV inoperable except due to leakage not within limits. AND C.2 D. One or more penetration 0.1 flow paths with leakage not within limit. E. Required Action and E.1 associated Completion Time of Condition A, B, C, AND or D not met in MODE 1, 2, or 3. E.2 HATCH UNIT 1 REQUIRED ACTION Isolate the affected penetration flow path by use of at least one closed and de-activated automatic valve, closed manual valve, or blind flange. --------NOTES---

1. Valves and blind flanges in high radiation areas may be verified by use of administrative means. 2. Isolation devices that are locked, sealed, or otherwise secured may be verified by administrative means. --------------------------~----

Verify the affected penetration flow path is isolated.

Restore leakage to within limit. Be in MODE 3. Be in M0DE4. 3.6-9 PCIVs 3.6.1.3 COMPLETION TIME 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months except for excess flow check valve (EFCV) line and penetrations with a closed system AND 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for EFCV line and penetrations with a closed system Once per 31 days 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months 12 hours 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Amendment No. 290 I SURVEILLANCE REQUIREMENTS SR 3.6.1.3.1 SR 3.6.1.3.2 SR 3.6.1.3.3 HATCH UNIT 1 SURVEILLANCE

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

Not required to be met when the 18 inch primary containment purge valves are open for inerting, de-inerting, pressure

control, ALARA, or air quality considerations for personnel entry, or Surveillances that require the valves to be open.

Verify each 18 inch primary containment purge valve is closed. ---------------------NOTES---------------

1. Valves and blind flanges in high radiation areas may be verified by use of administrative means. 2. Not required to be met for PCIVs that are open under administrative controls.

Verify each primary containment isolation manual valve and blind flange that is located outside primary containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. -------------------------NOTES------------------------

1. Valves and blind flanges in high radiation areas may be verified by use of administrative means. 2. Not required to be met for PCIVs that are open under administrative controls.

Verify each primary containment manual isolation valve and blind flange that is located inside primary containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. 3.6-10 PCIVs 3.6.1.3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Prior to entering MODE 2 or 3 from MODE 4 if primary containment was de-inerted while in MODE 4, if not performed within the previous 92 days (continued)

Amendment No. 2 9 0 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE SR 3.6.1.3.4 Verify continuity of the traversing incore probe (TIP) shear isolation valve explosive charge. SR 3.6.1.3.5 Verify the isolation time of each power operated, automatic PCIV, except for MSIVs, is within limits. SR 3.6.1.3.6 Verify the isolation time of each MSIV is i!: 3 seconds ands 5 seconds.

SR 3.6.1.3.

7 Verify each automatic PCIV, excluding EFCVs, actuates to the isolation position on an actual or simulated isolation signal. SR 3.6.1.3.8 Verify each reactor instrumentation line EFCV (of a representative sample) actuates to restrict flow to within limits. SR 3.6.1.3.9 Remove and test the explosive squib from each shear isolation valve of the TIP system. SR 3.6.1.3.10 Verify combined MSIV leakage rate for all four main steam lines is s 100 scfh when tested at i!: 28.0 psig and < 50.8 psig. OR Verify combined MSIV leakage rate for all four main steam lines is s 144 scfh when tested at i!: 50.8 psig. SR 3.6.1.3.11 Deleted HATCH UNIT 1 3.6-11 PCIVs 3.6.1.3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the INSERVICE TESTING PROGRAM In accordance with the INSERVICE TESTING PROGRAM In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Primary Containment Leakage Rate Testing Program ( continued)

Amendment No. 290 I SURVEILLANCE REQUIREMENTS (continued)

SR 3.6.1.3.12 SR 3.6.1.3.13 HATCH UNIT 1 SURVEILLANCE Cycle each 18 inch excess flow isolation damper to the fully closed and fully open position.

Verify the combined leakage rate for all secondary containment bypass leakage paths is s 0.02 La when pressurized to .?: Pa. 3.6-12 PCIVs 3.6.1.3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Primary Containment Leakage Rate Testing Program Amendment No2 9 o 3.6 CONTAINMENT SYSTEMS 3.6.4.1 Secondary Containment LCO 3.6.4.1 The secondary containment shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3, Secondary Containment 3.6.4.1 During movement of irradiated fuel assemblies in the secondary containment, During CORE AL TERA TIONS. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Secondary containment A.1 Restore secondary 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months inoperable in MODE 1, 2, containment to* or 3. OPERABLE status. B. Required Action and 8.1 ------NOTE----

associated Completion LCO 3.0.4.a is not Time of Condition A not applicable when met. entering MODE 3. ------------------

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months C. Secondary containment C.1 ---------NOTE---------

inoperable during LCO 3.0.3 is not movement of irradiated fuel applicable.

assemblies in the --------------------------

secondary containment or during CORE Suspend movement of Immediately ALTERATIONS.

irradiated fuel assemblies in the secondary containment.

AND (continued)

HATCH UNIT 1 3.6-34 Amendment No. 2 9 O ACTIONS CONDITION REQUIRED ACTION C. (continued)

C.2 Suspend CORE AL TERA TIONS. SURVEILLANCE REQUIREMENTS SR 3.6.4.1.1 SR 3.6.4.1.2 SURVEILLANCE Verify all secondary containment equipment hatches are closed and sealed. Verify one secondary containment access door in each access opening is closed, except when the access opening is being used for entry and exit. Secondary Containment 3.6.4.1 COMPLETION TIME Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program SR 3.6.4.1.3

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

HATCH UNIT 1 The number of standby gas treatment (SGT) subsystem(s) required for this Surveillance is dependent on the secondary containment configuration, and shall be one less than the number required to meet LCO 3.6.4.3, "Standby Gas Treatment (SGT) System,"

for the given configuration.

Verify secondary containment can be drawn down to 0.20 inch of vacuum water gauge in s 1 O minutes using required standby gas treatment (SGT) subsystem(s).

3.6-35 In accordance with the Surveillance Frequency Control Program (continued)

Amendment No. 290 3.6 CONTAINMENT SYSTEMS 3.6.4.2 Secondary Containment Isolation Valves (SCIVs) LCO 3.6.4.2 Each SCIV shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3, SCIVs 3.6.4.2 During movement of irradiated fuel assemblies in the secondary containment, During CORE ALTERATIONS.

ACTIONS ------------------------------NOTES-

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

2. Separate Condition entry is allowed for each penetration flow path. 3. Enter applicable Conditions and Required Actions for systems made inoperable by SCIVs. CONDITION A. One or more penetration flow paths with one SCIV inoperable.

HATCH UNIT 1 REQUIRED ACTION COMPLETION TIME A.1 Isolate the affected 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months penetration flow path by use of at least one closed and deactivated automatic valve, closed manual valve, or blind flange. AND A.2 -----NOTES----

1. Isolation devices in high radiation areas may be verified by use of administrative means. 3.6-37 (continued)

Amendment No. 2 9 o ACTIONS CONDITION A. ( continued)

B. One or more penetration B.1 flow paths with two SCIVs inoperable.

C. Required Action and C.1 associated Completion Time of Condition A or B AND not met in MODE 1, 2, or 3. C.2 D. Required Action and D.1 associated Completion Time of Condition A or B not met during movement of irradiated fuel assemblies in the secondary containment or during CORE AL TERA TIONS. HATCH UNIT 1 REQUIRED ACTION 2. Isolation devices that are locked, sealed, or otherwise secured may be verified by administrative means. -----------

Verify the affected penetration flow path is isolated.

Isolate the affected penetration flow path by use of at least one closed and deactivated automatic valve, closed manual valve, or blind flange. Be in MODE 3. Be in M0DE4. ----NOTE------

LCO 3.0.3 is not applicable.

Suspend movement of irradiated fuel assemblies in the ...,secondary containment.

3.6-38 SCIVs 3.6.4.2 COMPLETION TIME Once per 31 days 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months 12 hours 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Immediately (continued)

Amendment No. 2 9 0 ACTIONS CONDITION D. (continued)

REQUIRED ACTION SCIVs 3.6.4.2 COMPLETION TIME AND D.2 Suspend CORE AL TERA TIONS. Immediately SURVEILLANCE REQUIREMENTS SR 3.6.4.2.1 SR 3.6.4.2.2 SR 3.6.4.2.3 HATCH UNIT 1 SURVEILLANCE

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

1. Valves and blind flanges in high radiation areas may be verified by use of administrative means. 2. Not required to be met for SCIVs that are open under administrative controls.

Verify each secondary containment isolation manual valve and blind flange that is not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. Verify the isolation time of each power operated, automatic SCIV is within limits. Verify each automatic SCIV actuates to the isolation position on an actual or simulated actuation signal. 3.6-39 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 2 9 o 3.6 CONTAINMENT SYSTEMS 3.6.4.3 Standby Gas Treatment (SGn System SGT System 3.6.4.3 LCO 3.6.4.3 The Unit 1 and Unit 2 SGT subsystems required to support LCO 3.6.4.1, "Secondary Containment,"

shall be OPERABLE.

APPLICABILITY:

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required Unit 1 SGT A.1 Restore required Unit 1 30 days from subsystem inoperable SGT subsystem to discovery of failure to while: OPERABLE status. meet the LCO 1. Four SGT subsystems required

OPERABLE, and 2. Unit 1 reactor building-to-refueling floor plug not installed.

B. One required Unit 2 SGT 8.1 Restore required SGT 7days subsystem inoperable.

subsystem to OPERABLE status. OR One required Unit 1 SGT subsystem inoperable for reasons other than Condition A. (continued)

HATCH UNIT 1 3.6-40 Amendment No. 2 9 o ACTIONS (continued)

CONDITION C. Required Action and associated Completion Time of Condition A or B not met in MODE 1, 2, or 3. D. Required Action and associated Completion Time of Condition A or B not met during movement of irradiated fuel assemblies in the secondary containment or during CORE ALTERATIONS.

E. Two or more required SGT subsystems inoperable in MODE 1, 2, or 3. HATCH UNIT 1 REQUIRED ACTION C.1 ----NOTE---

LCO 3.0.4.a is not applicable when entering MODE 3. ---------------

Be in MODE 3. --------NOTE---------

LCO 3.0.3 is not applicable.

D.1 Place remaining OPERABLE SGT subsystem(s) in operation.

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

AND D.2.2 Suspend CORE AL TERA TIONS. E.1 ------NOTE--------

LCO 3.0.4.a is not applicable when entering MODE 3. -----------------

Be in MODE 3. 3.6-41 SGT System 3.6.4.3 COMPLETION TIME 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Immediately Immediately Immediately 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

Amendment No.2 9 0 ACTIONS (continued)

CONDITION F. Two or more required SGT F .1 subsystems inoperable during movement of irradiated fuel assemblies in the secondary containment REQUIRED ACTION LCO 3.0.3 is not applicable.

_____ , _____ _ SGT System 3.6.4.3 COMPLETION TIME or during CORE Suspend movement of Immediately ALTERATIONS.

AND F.2 irradiated fuel assemblies in secondary containment.

Suspend CORE ALTERATIONS.

Immediately SURVEILLANCE REQUIREMENTS SR 3.6.4.3.1 SR 3.6.4.3.2 SR 3.6.4.3.3 HATCH UNIT 1 SURVEILLANCE Operate each required SGT subsystem for ::!: 15 continuous minutes.

FREQUENCY In accordance with the Surveillance Frequency Control Program Perform required SGT filter testing in accordance In accordance with with the Ventilation Filter Testing Program (VFTP). the VFTP Verify each required SGT subsystem actuates on an actual or simulated initiation signal. 3.6-42 In accordance with the Surveillance Frequency Control Program Amendment No. 2 go

3. 7 PLANT SYSTEMS 3. 7.4 Main Control Room Environmental Control (MCREC) System LCO 3.7.4 Two MCREC subsystems shall be OPERABLE.

MCREC System 3.7.4 ----------------------NOTE------------------.

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

APPLICABILITY:

MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary containment, During CORE AL TERA TIONS. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One MCREC subsystem A.1 Restore MCREC 7days inoperable for reasons subsystem to other than Condition B. OPERABLE status. B. One or more MCREC 8.1 Initiate action to Immediately subsystems inoperable due implement mitigating to inoperable CRE actions.

boundary in MODE 1, 2, or 3. AND B.2 Verify mitigating actions 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ensure CRE occupant exposures to radiological,

chemical, and smoke hazards will not exceed limits. AND 8.3 Restore CRE boundary 90 days to OPERABLE status. (continued)

HATCH UNIT 1 3.7-8 Amendment No. 290 ACTIONS (continued)

CONDITION C. Required Action and associated Completion Time of Condition A or B not met in MODE 1, 2, or 3. D. Required Action and associated Completion Time of Condition A not met during movement of irradiated fuel assemblies in the secondary containment or during CORE ALTERATIONS.

E. Two MCREC subsystems inoperable in MODE 1, 2, or 3 for reasons other than Condition

8. HATCH UNIT 1 REQUIRED ACTION C.1 -----NOTE------

LCO 3.0.4.a is not applicable when entering MODE 3. ---------------

Be in MODE 3. -------------NOTE------------

LCO 3.0.3 is not applicable.

D.1 Place OPERABLE MCREC subsystem in pressurization mode. OR D.2.1 Suspend movement of irradiated fuel assemblies in the secondary containment.

AND D.2.2 Suspend CORE ALTERATIONS.

E.1 ------NOTE-------

LCO 3.0.4.a is not applicable when entering MODE 3. --------------------

Be in MODE 3. 3.7-9 MCREC System 3.7.4 COMPLETION TIME 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Immediately Immediately Immediately 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

Amendment No. 2 9 0 ACTIONS (continued)

F. OR CONDITION Two MCREC subsystems inoperable during movement of irradiated fuel assemblies in the secondary containment or during CORE ALTERATIONS.

One or more MCREC subsystems inoperable due REQUIRED ACTION LCO 3.0.3 is not applicable.

F .1 Suspend movement of irradiated fuel assemblies in the secondary containment.

to an inoperable CRE F .2 Suspend CORE ALTERATIONS.

boundary during movement of irradiated fuel assemblies in the secondary containment or during CORE AL TERA TIONS. SURVEILLANCE REQUIREMENTS SR 3.7.4.1 SR 3.7.4.2 SR 3.7.4.3 HATCH UNIT 1 SURVEILLANCE Operate each MCREC subsystem 15 minutes.

Perform required MCREC filter testing in accordance with the Ventilation Filter Testing Program (VFTP). Verify each MCREC subsystem actuates on an actual or simulated initiation signal. 3.7-10 MCREC System 3.7.4 COMPLETION TIME Immediately Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the VFTP In accordance with the Surveillance Frequency Control Program (continued)

Amendment No. 290 3.7 PLANT SYSTEMS 3.7.5 Control Room Air Conditioning (AC) System Control Room AC System 3.7.5 LCO 3.7.5 Three control room AC subsystems shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary containment, During CORE AL TERA TIONS. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One control room AC A.1 Restore control room 30 days subsystem inoperable.

AC subsystem to OPERABLE status. B. Two control room AC B.1 Verify control room area Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months subsystems inoperable.

temperature<

90°F. AND 8.2 Restore one control 7 days room AC subsystem to OPERABLE status. C. Three control room AC C.1 Verify control room area Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months subsystems inoperable.

temperature<

90°F. AND C.2 Restore one control 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months room AC subsystem to OPERABLE status. (continued)

HATCH UNIT 1 3.7-12 Amendment No. 2 9 o ACTIONS (continued)

CONDITION D. Required Action and associated Completion Time of Condition A, B, or C not met in MODE 1, 2, or 3. E. Required Action and associated Completion Time of Condition A not met during movement of irradiated fuel assemblies in the secondary containment or during CORE ALTERATIONS.

HATCH UNIT 1 REQUIRED ACTION D.1 ----NOTE----

LCO 3.0.4.a is not applicable when entering MODE 3. ---------------

Be in MODE 3. ---------NOTE---------

LCO 3.0.3 is not applicable.

E.1 Place OPERABLE control room AC subsystems in operation.

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

AND E.2.2 Suspend CORE ALTERATIONS.

3.7-13 Control Room AC System 3.7.5 COMPLETION TIME 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Immediately Immediately Immediately (continued)

Amendment No. 290 ACTIONS (continued)

CONDITION F. Required Action and associated Completion Time of Condition B or C not met during movement of irradiated fuel assemblies in the secondary containment or during CORE AL TERA TIONS. REQUIRED ACTION LCO 3.0.3 is not applicable.

Control Room AC System 3.7.5 COMPLETION TIME F.1 Suspend movement of Immediately irradiated fuel assemblies in the secondary containment.

F.2 Suspend CORE AL TERA TIONS. Immediately HATCH UNIT 1 3.7-14 Amendment No. 2 9 0 ACTIONS CONDITION A. One or more required offsite circuit(s) inoperable.

HATCH UNIT 1 REQUIRED ACTION Enter applicable Condition and Required Actions of LCO 3.8.8, with one required 4160 V ESF bus de-energized as a result of Condition A. AC Sources -Shutdown 3.8.2 COMPLETION TIME A.1 Declare affected Immediately required feature(s),

with no offsite power available, inoperable.

OR A.2.1 Suspend CORE ALTERATIONS.

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

A.2.3 Initiate action to restore Immediately required offsite power circuit(s) to OPERABLE status. (continued) 3.8-21 Amendment No. 290 ACTIONS (continued)

CONDITION B. One or more required DG(s) inoperable.

SURVEILLANCE REQUIREMENTS 8.1 AND 8.2 AND 8.3 REQUIRED ACTION Suspend CORE AL TERA TIONS. Suspend movement of irradiated fuel assemblies in secondary containment.

Initiate action to restore required DG(s) to OPERABLE status. SURVEILLANCE AC Sources -Shutdown 3.8.2 COMPLETION TIME Immediately Immediately Immediately FREQUENCY SR 3.8.2.1 ----------NOTE------------

SR 3.8.2.2 HATCH UNIT 1 The following SRs are not required to be performed:

SR 3.8.1.2.b, SR 3.8.1. 7 through SR 3.8.1.9, SR 3.8.1.11 through SR 3.8.1.14, SR 3.8.1.16, and SR 3.8.1.17.

For required Unit 1 AC sources, the SRs of LCO 3.8.1, except SR 3.8.1.6, SR 3.8.1.15, and SR 3.8.1.18, are applicable.

For required Unit 2 AC sources, SR 3.8.2.1 of Unit 2 Specification 3.8.2 is applicable.

3.8-22 In accordance with applicable SRs In accordance with

Unit 2 SR 3.8.2.1 Amendment No. 290 f ACTIONS (continued)

CONDITION C. ( continued)

D. One or more required station service DC electrical power subsystems inoperable for reasons other than Condition

8. OR Required Actions and associated Completion Times of Condition B not met. HATCH UNIT 1 REQUIRED ACTION C.2.3 Initiate action to restore required DG DC electrical power subsystems to OPERABLE status. 0.1 Declare affected required feature(s) inoperable.

QB D.2.1 Suspend CORE AL TERA TIONS. AND D.2.2 Suspend movement of irradiated fuel assemblies in the secondary containment.

AND D.2.3 Initiate action to restore required station service DC electrical power subsystems to OPERABLE status. 3.8-33 DC Sources -Shutdown 3.8.5 COMPLETION TIME Immediately Immediately Immediately Immediately Immediately Amendment No. 2 9 o ACTIONS Distribution Systems -Shutdown 3.8.8 CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)

A.2.3 Initiate actions to Immediately restore required AC and DC electrical power distribution subsystem(s) to OPERABLE status. A.2.4 Declare associated required shutdown cooling subsystem(s) inoperable and not in operation.

Immediately SURVEILLANCE REQUIREMENTS SR 3.8.8.1 HATCH UNIT 1 SURVEILLANCE Verify correct breaker alignments and voltage to required AC and DC electrical power distribution subsystems.

3.8-44 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment No. 2 9 0 UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 SOUTHERN NUCLEAR OPERATING

COMPANY, INC. GEORGIA POWER COMPANY OGLETHORPE POWER CORPORATION MUNICIPAL ELECTRIC AUTHORITY OF GEORGIA CITY OF DAL TON, GEORGIA DOCKET NO. 50-366 EDWIN I. HATCH NUCLEAR PLANT, UNIT NO. 2 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 235 Renewed License No. NPF-5 1. The Nuclear Regulatory Commission (the Commission) has found that: A. The application for amendment to the Edwin I. Hatch Nuclear Plant, Unit No. 2 (the facility)

Renewed Facility Operating License No. NPF-5 filed by Southern Nuclear Operating

Company, Inc. (the licensee),

acting for itself, Georgia Power Company, Oglethorpe Power Corporation, Municipal Electric Authority of Georgia, and City of Dalton, Georgia (the owners),

dated April 20, 2017, as supplemented by letters dated September 14, 2017, and February 19 and May 1, 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 as set forth in 10 CFR Chapter I; B. The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C. There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations; D. The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E. The issuance of this amendment is in accordance with 1 O CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.

Enclosure 2 2. Accordingly, the license is hereby amended by page changes as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Renewed Facility Operating License No. NPF-5 is hereby amended to read as follows:

(2) Technical Specifications The Technical Specifications (Appendix A) and the Environmental Protection Plan (Appendix B), as revised through Amendment No. 235, are hereby incorporated in the renewed license.

Southern Nuclear 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 prior to the commencement of the Unit No. 2 refueling outage (U2R25) in February 2019.

Attachment:

Changes to Renewed Facility Operating License No. NPF-5 and Technical Specifications Date of Issuance:

May 31 , 2 o 1 8 FOR THE NUCLEAR REGULATORY COMMISSION Michael T. Markley, Chief Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation ATTACHMENT TO LICENSE AMENDMENT NO. 235 EDWIN I. HATCH NUCLEAR PLANT, UNIT NO. 2 RENEWED FACILITY OPERATING LICENSE NO. NPF-5 DOCKET NO. 50-366 Replace the following pages of the license and the Appendix A Technical Specifications (TSs) with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change. Remove Pages License 4 TSs ii (TOC) 1.1-2 1.1-3 1.1-4 1.1-5 1.1-6 1.1-7 3.3-34 3.3-35 3.3-36 3.3-39 3.3-40 3.3-41 3.3-42 3.3-43 3.3-44 3.3-45 3.3-46 3.3-47 3.3-48 3.3-49 3.3-50 3.3-51 3.3-52 3.3-53 3.3-54 3.3-55a 3.3-55b Insert Pages License 4 TSs ii (TOC) 1.1-2 1.1-3 1.1-4 1.1-5 1.1-6 1.1-7 1.1-8 3.3-34 3.3-35 3.3-36 3.3-39 3.3-40 3.3-41 3.3-42 3.3-43 3.3-44 3.3-45 3.3-46 3.3-47 3.3-48 3.3-49 3.3-50 3.3-51 3.3-52 3.3-53 3.3-54 3.3-55 3.3-56 3.3-57 3.3-58 3.3-59 Amendment No. 235 Remove Pages TSs 3.3-56 3.3-57 3.3-58 3.3-59 3.3-60 3.3-61 3.3-62 3.3-63 3.3-64 3.3-65 3.3-66 3.3-67 3.3-68 3.3-69 3.3-70 3.3-71 3.5-1 3.5-7 3.5-8 3.5-9 3.5-10 3.5-11 3.6-7 3.6-9 3.6-10 3.6-11 3.6-12 3.6-33 3.6-34 3.6-36 3.6-37 3.6-38 3.6-39 3.6-40 3.6-41 3.7-8 3.7-9 3.7-10 3.7-12 3.7-13 3.7-14 3.8-21 3.8-22 3.8-33 3.8-44 Insert Pages TSs 3.3-60 3.3-61 3.3-62 3.3-63 3.3-64 3.3-65 3.3-66 3.3-67 3.3-68 3.3-69 3.3-70 3.3-71 3.3-72 3.3-73 3.3-74 3.3-75 3.5-1 3.5-7 3.5-8 3.5-9 3.5-10 3.5-11 3.5-12 3.5-13 3.6-7 3.6-9 3.6-10 3.6-11 3.6-12 3.6-33 3.6-34 3.6-36 3.6-37 3.6-38 3.6-39 3.6-40 3.6-41 3.7-8 3.7-9 3.7-10 3.7-12 3.7-13 3.7-14 3.8-21 3.8-22 3.8-33 3.8-44 Amendment No. 235 (6) Southern

Nuclear, pursuant to the Act and 10 CFR Parts 30 and 70, to possess, but not separate, such byproduct and special nuclear materials as may be produced by the operation of the facility.

C. This renewed license shall be deemed to contain, and is subject to, the conditions specified in the following Commission regulations in 10 CFR Chapter I: Part 20, Section 30.34 of Part 30, Section 40.41 of Part 40, Section 50.54 of Part 50, and Section 70.32 of Part 70; all applicable provisions of the Act and the rules, regulations, and orders of the Commission now or hereafter in effect; and the additional conditions 2 specified or incorporated below: (1) Maximum Power Level Southern Nuclear is authorized to operate the facility at steady state reactor core power levels not in excess of 2,804 megawatts

thermal, in accordance with the conditions specified herein. (2) Technical Specifications The Technical Specifications (Appendix A) and the Environmental Protection Plan (Appendix B), as revised through Amendment No. 235, are hereby incorporated in the renewed license.

Southern Nuclear shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan. (3) Additional Conditions The matters specified in the following conditions shall be completed to the satisfaction of the Commission within the stated time periods following the issuance of the renewed license or within the operational restrictions indicated.

The removal of these conditions shall be made by an amendment to the license supported by a favorable evaluation by the Commission.

(a) Fire Protection Southern Nuclear shall implement and maintain in effect all provisions of the fire protection

program, which is referenced in the Updated Final Safety Analysis Report for the facility, as contained 2 The original licensee authorized to possess, use, and operate the facility with Georgia Power Company (GPC). Consequently, certain historical references to GPC remain in certain license conditions.

Renewed License No. NPF-5 Amendment No. 235 TABLE OF CONTENTS 3.3 3.3.4.1 3.3.4.2 3.3.5.1 3.3.5.2 3.3.5.3 3.3.6.1 3.3.6.2

3.3.6.3 3.3.7.1 3.3.8.1 3.3.8.2 M 3.4.1 3.4.2 3.4.3 3.4.4 3.4.5 3.4.6 3.4.7 3.4.8 3.4.9 3.4.10 3.5.1 3.5.2 3.5.3 INSTRUMENTATION (continued)

End of Cycle Recirculation Pump Trip (EOC-RPl)

Instrumentation

........................................................................................

3.3-28 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT)

Instrumentation

................................................

3.3-31 Emergency Core Cooling System (ECCS) Instrumentation

................................

........................................................

3.3-34 RPV Water Inventory Control Instrumentation

..............................................

3.3-44 Reactor Core Isolation Cooling (RCIC) System Instrumentation

..................

3.3-47 Primary Containment Isolation Instrumentation

............................................

3.3-51 Secondary Containment Isolation Instrumentation

........................................

3.3-60 Low-Low Set (LLS) Instrumentation

..............................................................

3.3-64 Main Control Room Environmental Control (MCREC) System Instrumentation

........................................................................................

3.3-68 Loss of Power (LOP) Instrumentation

...........................................................

3.3-70 Reactor Protection System (RPS) Electric Power Monitoring

................................................................................................

3.3-73 REACTOR COOLANT SYSTEM (RCS) .......................................................

3.4-1 Recirculation Loops Operating

......................................................................

3.4-1 Jet Pumps .............................

.......................................................................

3.4-3 Safety/Relief Valves (S/RVs) .........................................................................

3.4-5 RCS Operational LEAKAGE .........................................................................

3.4-7 RCS Leakage Detection Instrumentation

......................................................

3.4-9 RCS Specific Activity

.....................................................................................

3.4-11 Residual Heat Removal (RHR) Shutdown Cooling System -Hot Shutdown

...........................................................................

3.4-13 Residual Heat Removal (RHR) Shutdown Cooling System -Cold Shutdown

.........................................................................

3.4-16 RCS Pressure and Temperature (PIT) Limits ...............................................

3.4-18 Reactor Steam Dome Pressure

....................................................................

3.4-25 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY

CONTROL, AND REACTOR CORE ISOLATION COOLING {RCIC) SYSTEM ........................................................................................................

3.5-1 ECCS -Operating

.........................................................................................

3.5-1 RPV Water Inventory Control ........................................................................

3.5-7 RCIC System .................................................................................................

3.5-11 (continued)

HATCH UNIT2 ii Amendment No. 2 3 5 Definitions 1.1 1.1 Definitions (continued)

CHANNEL FUNCTIONAL TEST CORE ALTERATION CORE OPERATING LIM ITS REPORT (COLR) DOSE EQUIVALENT 1-131 DRAIN TIME HATCH UNIT2 A CHANNEL FUNCTIONAL TEST shall be the injection of a simulated or actual signal into the channel as close to the sensor as practicable to verify OPERABILITY, including required alarm, interlock,

display, and trip functions, and channel failure trips. The CHANNEL FUNCTIONAL TEST may be performed by means of any series of sequential, overlapping, or total channel steps so that the entire channel is tested. 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 ra~ge monitors, intermediate range monitors, traversing incore probes, or special movable detectors (including undervessel replacement);

and b. Control rod movement, provided there are no fuel assemblies in the associated core cell. Suspension of CORE AL TERA TIONS shall not preclude completion of movement of a component to a safe position.

The COLR is the unit specific document that provides cycle specific parameter limits for the current reload cycle. These cycle specific limits shall be determined for each reload cycle in accordance with Specification 5.6.5. Plant operation within these limits is addressed in individual Specifications.

DOSE EQUIVALENT 1-131 shall be that concentration of 1-131 (microcuries/gram) that alone would produce the same Committed Effective Dose Equivalent as the quantity and isotopic mixture of 1-131, 1-132, 1-133, 1-134, and 1-135 actually present.

The dose conversion factors used for this calculation shall be those listed in Federal Guidance Report (FGR) 11, "Limiting Values of Radionuclide Intake and Air Concentration and Dose Conversion Factors for Inhalation.

Submersion.

and Ingestion,"

1988. The DRAIN TIME is the time it would take for the water inventory in and above the Reactor Pressure Vessel (RPV) to drain to the top of the active fuel (TAF) seated in the RPV assuming:

a. The water inventory above the TAF is divided by the limiting drain rate; b. The limiting drain rate is the larger of the drain rate through a single penetration flow path with the highest flow rate, or the sum of the drain rates through multiple penetration flow paths susceptible to a common mode failure (e.g., seismic event, loss of normal power, single human error), for all penetration flow paths below the TAF except: 1.1-2 (continued)

Amendment No235 1.1 Definitions DRAIN TIME (continued)

HATCH UNIT2 Definitions 1.1 1. Penetration flow paths connected to an intact closed system, or isolated by manual or automatic valves that are locked, sealed, or otherwise secured in the closed position, blank flanges, or other devices that prevent flow of reactor coolant through the penetration flow paths; 2. Penetration flow paths capable of being isolated by valves that will close automatically without offsite power prior to the RPV water level being equal to the TAF when actuated by RPV water level isolation instrumentation; or 3. Penetration flow paths with isolation devices that can be closed prior to the RPV water level being equal to the TAF by a dedicated operator trained in the task, who in continuous communication with the control room, is stationed at the controls, and is capable of closing the penetration flow path isolation device without offsite power. c. The penetration flow paths required to be evaluated per paragraph b) are assumed to open instantaneously and are not subsequently

isolated, and no water is assumed to be subsequently added to the RPV water inventory;

d. No additional draining events occur; and e. Realistic cross-sectional areas and drain rates are used. A bounding DRAIN TIME may be used in lieu of a calculated value. 1.1-3 (continued)

Amendment No.23s Definitions 1.1 1.1 Definitions (continued)

EMERGENCY CORE COOLING SYSTEM (ECCS) RESPONSE TIME END OF CYCLE RECIRCULATION PUMP TRIP (EOC-RPT)

SYSTEM RESPONSE TIME INSERVICE TESTING PROGRAM ISOLATION SYSTEM RESPONSE TIME LEAKAGE HATCH UNIT2 The ECCS RESPONSE TIME shall be that time interval from when the monitored parameter exceeds its ECCS initiation setpoint at the channel sensor until the ECCS equipment is capable of performing its safety function (i.e., the valves travel to their required positions, pump discharge pressures reach their required values, etc.). Times shall include diesel generator starting and sequence loading delays, where applicable.

The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

The EOC-RPT SYSTEM RESPONSE TIME shall be that time interval from initial signal generation by the associated turbine stop valve limit switch or from when the turbine control valve hydraulic control oil pressure drops below the pressure switch setpoint to complete suppression of the electric arc between the fully open contacts of the recirculation pump circuit breaker.

The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

The INSERVICE TESTING PROGRAM is the licensee program that fulfills the requirements of 1 O CFR 50.55a(f).

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

Times shall include diesel generator starting and sequence loading delays, where applicable.

The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

LEAKAGE shall be: a. Identified LEAKAGE b. 1. LEAKAGE into the drywell, such as that from pump seals or valve packing, that is captured and conducted to a sump or collecting tank; or 2. LEAKAGE into the drywell atmosphere from sources that are both specifically located and known either not to interfere with the operation of leakage detection systems or not to be pressure boundary LEAKAGE; Unidentified LEAKAGE All LEAKAGE into the drywell that is not identified LEAKAGE; (continued) 1.1-4 Amendment No. 2 3 s 1.1 . Definitions LEAKAGE (continued)

LINEAR HEAT GENERATION RATE LOGIC SYSTEM FUNCTIONAL TEST MINIMUM CRITICAL POWER RATIO (MCPR) MODE OPERABILITY HATCH UNIT2 C. d. Total LEAKAGE Sum of the identified and unidentified LEAKAGE; Pressure Boundary LEAKAGE Definitions 1.1 LEAKAGE through a nonisolable fault in a Reactor Coolant System (RCS) component body, pipe wall, or vessel wall. LINEAR HEAT GENERATION RATE (LHGR) shall be the power generation in an arbitrary length of fuel rod, usually six inches. It is the integral of the heat flux over the heat transfer area associated with the unit length. A LOGIC SYSTEM FUNCTIONAL TEST shall be a test of all required logic components (i.e., all required relays and contacts, trip units, solid state logic elements, etc.} of a logic circuit, from as close to the sensor as practicable up to, but not including, the actuated device, to verify OPERABILITY.

The LOGIC SYSTEM FUNCTIONAL TEST may be performed by means of any series of sequential, overlapping, or total system steps so that the entire logic system is tested. The MCPR shall be the smallest critical power ratio (CPR) that exists in the core for each class of fuel. The CPR is that power in the assembly that is calculated by application of the appropriate correlation(s) to cause some point in the assembly to experience boiling transition, divided by the actual assembly operating power. A MODE shall correspond to any one inclusive combination of mode switch position, average reactor coolant temperature, and reactor vessel head closure bolt tensioning specified in Table 1 .1-1 with fuel in the reactor vessel. A system, subsystem,

division, component, or device shall be OPERABLE or have OPERABILITY when it is capable of performing its specified safety function(s) and when all necessary attendant instrumentation,

controls, normal or emergency electrical power, cooling and seal water, lubrication, and other auxiliary equipment that are required for the system, subsystem,

division, component, or device to perform its specified safety function(s) are also capable of performing their related support function(s).

(continued) 1.1-5 Amendment No. 2.3 5 Definitions 1.1 1.1 Definitions (continued)

PHYSICS TESTS PHYSICS TESTS shall be those tests performed to measure the fundamental nuclear characteristics of the reactor core and related instrumentation.

These tests are: PRESSURE AND TEMPERATURE LIMITS REPORT (PTLR) RA TED THERMAL POWER (RTP) REACTOR PROTECTION SYSTEM (RPS) RESPONSE TIME SHUTDOWN MARGIN (SOM) STAGGERED TEST BASIS a. Described in Chapter 14, Initial Tests and Operation, of the FSAR; b. Authorized under the provisions of 10 CFR 50.59; or c. Otherwise approved by the Nuclear Regulatory Commission.

The PTLR is the unit specific document that provides the reactor vessel pressure and temperature limits, including heatup and cooldown rates, for the current reactor vessel fluence period. These pressure and temperature limits shall be determined for each fluence period in accordance with Specification 5.6.7. RTP shall be a total reactor core heat transfer rate to the reactor coolant of 2804 MWt. The RPS RESPONSE TIME shall be that time interval from when the monitored parameter exceeds its RPS trip setpoint at the channel sensor until de-energization of the scram pilot valve solenoids.

The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

SDM shall be the amount of reactivity by which the reactor is subcritical or would be subcritical assuming that: a. The reactor is xenon free; b. The moderator temperature is 68°F; and c. Alf control rods are fully inserted except for the single control rod of highest reactivity worth, which is assumed to be fully withdrawn.

With control rods not capable of being fully inserted, the reactivity worth of these control rods must be accounted for in the determination of SDM. A STAGGERED TEST BASIS shall consist of the testing of one of the systems, subsystems,

channels, or other designated components during the interval specified by the Surveillance Frequency, so that all systems, subsystems,

channels, or other designated components are tested during n Surveillance Frequency intervals, where n is the total number of systems, subsystems,

channels, or other designated components in the associated function.

THERMAL POWER THERMAL POWER shall be the total reactor core heat transfer rate to the reactor coolant.

{continued)*

HATCH UNIT2 1.1-6 Amendment No. 2 3 5 Definitions 1.1 1.1 Definitions (continued)

TURBINE BYPASS SYSTEM RESPONSE TIME HATCH UNIT2 The TURBINE BYPASS SYSTEM RESPONSE TIME consists of two components:

a. The time from initial movement of the main turbine stop valve or control valve until 80% of the turbine bypass capacity is established; and b. The time from initial movement of the main turbine stop valve or control valve until initial movement of the turbine bypass valve. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

1.1-7 Amendment No. 2 3 5 MODE TITLE 1 Power Operation 2 Startup 3 Hot Shutdown<*>

4 Cold Shutdown<*>

5 Refueling!b>

Table 1.1-1 (page 1 of 1) MODES REACTOR MODE SWITCH POSITION Run Refue~*>

or Startup/Hot Standby Shutdown Shutdown Shutdown or Refuel (a) All reactor vessel head closure bolts fully tensioned.

Definitions 1.1 AVERAGE REACTOR COOLANT TEMPERATURE (OF) NA NA > 212 S212 NA (b) One or more reactor vessel head closure bolts less than fully tensioned.

HATCH UNIT2 1.1-8 Amendment No. 23S 3.3 INSTRUMENTATION 3.3.5.1 Emergency Core Cooling System (ECCS) Instrumentation ECCS Instrumentation 3.3.5.1 LCO 3.3.5.1 The ECCS instrumentation for each Function in Table 3.3.5.1-1 shall be OPERABLE.

APPLICABILITY:

According to Table 3.3.5.1-1.

ACTIONS -----------------------NOTE------------------*

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable.

referenced in Table 3.3.5.1-1 for the channel.

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

Action A.1 and referenced Only applicable for in Table 3.3.5.1-1.

Functions 1.a, 1.b, 2.a, and 2.b. ' ----------------

Declare supported 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery feature(s) inoperable.

of loss of initiation capability for feature(s) in both divisions AND (continued)

HATCH UNIT2 3.3-34 Amendment No.2 3 5 ACTIONS CONDITION B. ( continued)

B.2 AND 8.3 C. As required by Required C.1 Action A.1 and referenced in Table 3.3.5.1-1.

AND C.2 HATCH UNIT 2 REQUIRED ACTION --NOTE------

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

Declare High Pressure Coolant Injection (HPCI) System inoperable.

Place channel in trip. ---NOTE-------

Only applicable for Functions 1.c, 2.c, 2.d, and 2.f. --------------------

Declare supported feature(s) inoperable.

Restore channel to OPERABLE status. 3.3-35 ECCS Instrumentation 3.3.5.1 COMPLETION TIME 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery of loss of HPCI initiation capability 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 1 hour from discovery of loss of initiation capability for feature(s) in both divisions 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (continued)

Amendment No. 235 ACTIONS (continued)

CONDITION REQUIRED ACTION D. As required by Required D.1 ----NOTE---

Action A.1 and referenced Only applicable if in Table 3.3.5.1-1.

HPCI pump suction is not aligned to the suppression pool. -----------

Declare HPCI System inoperable.

AND D.2.1 Place channel in trip. OR D.2.2 Align the HPCI pump suction to the suppression pool. E. As required by Required E.1 ------NOTES----*--

Action A.1 and referenced Only applicable for in Table 3.3.5.1-1.

Functions 1.d and 2.g. --------------

Declare supported feature(s) inoperable.

AND E.2 Restore channel to OPERABLE status. HATCH UNIT2 3.3-36 ECCS Instrumentation 3.3.5.1 COMPLETION TIME 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery of loss of HPCI initiation capability 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 24 hours 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery of loss of initiation capability for subsystems in both divisions 7days (continued)

Amendment No. 2 3 5 I ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 1 of5) Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED OR OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEIUANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTIONA.1 REQUIREMENTS VALUE 1. Core Spray System a. Reactor Vessel 1,2,3 4(a) B SR 3.3.5.1.1

.!: -113 inches I Water Level -Low SR 3.3.5.1.2 Low Low, Level 1 SR 3.3.5.1.4 SR 3.3.5.1.5

b. Drywell Pressure

-1,2,3 4(a) B SR 3.3.5.1.1 s 1.92 pslg High SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.5 C. Reactor Steam 1,2,3 4 C SR 3.3.5.1.1

.!:390 psig Dome Pressure

-SR 3.3.5.1.2 and Low (Injection SR 3.3.5.1.4 S476 pslg Permissive)

SR 3.3.5.1.5

d. Core Spray Pump 1,2,3 1 per E SR 3.3.5.1.1

.!: 570gpm Discharge Flow -subsystem SR 3.3.5.1.2 and Low (Bypass)

SR 3.3.5.1.4 S745 gpm SR 3.3.5.1.5

2. Low Pressure Coolant Injection (LPCI) System a. Reactor Vessel 1,2,3 4(a) B SR 3.3.5.1.1 -113 inches I Water Level -Low SR 3.3.5.1.2 Low Low, Level 1 SR 3.3.5.1 .4 SR 3.3.5.1.5

b. Drywall 1,2,3 4(a) B SR 3.3.5.1.1 s 1.92 psig Pressure

-High SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.5 continued (a) Also required to Initiate the associated diesel generator (DG) and isolate the associated plant service water (PSW) turbine building (T/8) isolation valves. HATCH UNIT2 3.3-39 Amendment No.235 ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 2 of 5) Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED OR OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTIONA.1 REQUIREMENTS VALUE 2. LPCI System (continued)

C. Reactor Steam Dome 1,2,3 4 C SR 3.3.5.1.1

.: 390 psig Pressure

-Low SR 3.3.5.1.2 and (Injection Permissive)

SR 3.3.5.1.4 s 476 psig SR 3.3.5.1.5

d. Reactor Steam Dome 1(b), 2(b), 4 C SR 3.3.5.1.1

.: 335 psig Pressure

-Low 3(b) SR 3.3.5.1.2 (Recirculation SR 3.3.5.1.4 Discharge Valve SR 3.3.5.1.5 Permissive)

e. Reactor Vessel Shroud 1,2,3 2 B SR 3.3.5.1.1

.: -202 inches Level-LevelO SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.5

f. Low Pressure Coolant 1,2,3 1 per C SR 3.3.5.1.4 Injection Pump Start -pump SR 3.3.5.1.5 Time Delay Relay Pumps A, B, D .: 9 seconds and s 15 seconds PumpC s 1 second g. Low Pressure Coolant 1,2,3 1 per E SR 3.3.5.1.1

.: 1675 gpm Injection Pump subsystem SR 3.3.5.1.2 and Discharge Flow -SR 3.3.5.1.4 S2215 gpm Low (Bypass)

SR 3.3.5.1.5 (continued)

(b) With associated recirculation pump discharge valve open. HATCH UNIT2 3.3-40 Amendment No. 2 3 5 ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 3 of 5) Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED OR OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTIONA.1 REQUIREMENTS VALUE 3. High Pressure Coolant Injection (HPCI) System a .. Reactor Vessel Water 1, 4 B SR 3.3.5.1.1 l!:-47 inches Level -Low Low, 2(c), 3(c) SR 3.3.5.1.2 Level2 SR 3.3.5. 1.4 SR 3.3.5.1.5

b. Drywall Pressure

-High 1, 4 B SR 3.3.5.1.1 s 1.92 psig 2cc), 3(c) SR 3.3.5.1.2 I SR 3.3.5.1.4 SR 3.3.5.1.5 C. Reactor Vessel Water 1, 2 C SR 3.3.5.1.1 s 56.5 inches Level -High, Level 8 2(c), 3(c) SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.5

d. Condensate Storage 1, 2 D SR 3.3.5.1.3 l!: 2.61 ft Tank Level -Low 2(C), 3(c) SR 3.3.5.1.5

e. Suppression Pool 1, 2 D SR 3.3.5.1.1 s 154 inches Water Level -High 2(c), 3(c) SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.5

f. High Pressure Coolant 1, E SR 3.3.5.1.1 l!:590gpm Injection Pump 2(c), 3(c) SR 3.3.5.1.2 and Discharge Flow -Low SR 3.3.5.1.4 S845gpm (Bypass)

SR 3.3.5.1.5 (continued)

(c) With reactor steam dome pressure>

150 pslg. HATCH UNIT 2 3.3-41 Amendment No. 2 3 5 ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 4 of 5) Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED OR OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTIONA1 REQUIREMENTS VALUE 4. Automatic Depressurization System (ADS) Trip System A a. Reactor Vessel Water 1, 2 F SR 3.3.5.1.1 -113 inches Level -Low Low Low, 2cc), 3(c) SR 3.3.5.1.2 Level 1 SR 3.3.5.1.4 SR 3.3.5.1.5

b. Drywall 1, 2 F SR 3.3.5.1.1

s 1.92 psig Pressure

-High 2(c), 3(c) SR 3.3.5.1.2 I SR 3.3.5.1 .4 SR 3.3.5.1.5 C. Automatic 1, G SR 3.3.5.1.4 s 114 seconds Depressurization 2(c), 3(c) SR 3.3.5.1.5 I System Initiation Timer d. Reactor Vessel Water 1, F SR 3.3.5.1.1 0 inches Level-Low,Level3 2(C), 3(C) SR 3.3.5.1.2 (Confirmatory)

SR 3.3.5.1.4 SR 3.3.5.1.5

e. Core Spray Pump 1, 2 G SR 3.3.5.1.1 137 pslg Discharge Pressure

-2(c), 3(c) SR 3.3.5.1.2 and High SR 3.3.5.1.4

s 180 pslg SR 3.3.5.1.5

f. Low Pressure Coolant 1, 4 G SR 3.3.5.1.1 112 psig Injection Pump 2cc), 3(c) SR 3.3.5.1.2 and Discharge Pressure

-SR 3.3.5.1.4 s 180 psig High SR 3.3.5.1.5

g. Automatic 1, 2 G SR 3.3.5.1.4

s 12 minutes De pressurization 2(c), 3(c) SR 3.3.5.1.5 18 seconds System Low Water Level Actuation Timer (continued)

(c) With reactor steam dome pressure>

150 psig. HATCH UNIT2 3.3-42 Amendment No. 2 3 5 ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 5 of 5) Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED OR OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE 5. ADS Trip System B a. Reactor Vessel Water 1, 2 F SR 3.3.5.1.1 r? -113 inches Level-Low Low Low, 2(c), 3(c) SR 3.3.5.1.2 Level 1 SR 3.3.5.1.4 SR 3.3.5.1.5

b. Drywell Pressure

-High 1, 2 F SR 3.3.5.1.1 s 1.92 psig 2(c), 3(c) SR 3.3.5.1.2 I SR 3.3.5.1.4 SR 3.3.5.1.5 C. Automatic 1, 1 G SR 3.3.5.1.4 s 114 seconds Depressurization 2(c), 3(c) SR 3.3.5.1.5 I System Initiation Timer d. Reactor Vessel Water 1, 1 F SR 3.3.5.1.1 r? O inches Level-Low, Level 3 2(c), 3(c) SR 3.3.5.1.2 (Confirmatory)

SR 3.3.5.1.4 SR 3.3.5.1.5

e. Core Spray 1, 2 G SR 3.3.5.1.1 i? 137 psig Pump Discharge 2(c), 3(c) SR 3.3.5.1.2 and Pressure

-High SR 3.3.5.1.4 s 180 psig SR 3.3.5.1.5

f. Low Pressure Coolant 1, 4 G SR 3.3.5.1.1 r? 112 psig Injection Pump 2(c), 3(c) SR 3.3.5.1.2 and Discharge Pressure

-SR 3.3.5.1.4 S180psig High SR 3.3.5.1.5

g. Automatic 1, 2 G SR 3.3.5.1.4 s 12 minutes Depressurization 2<c), 3(c) SR 3.3.5.1.5 18 seconds System Low Water Level Actuation Timer (c) With reactor steam dome pressure>

150 psig. HATCH UNIT2 3.3-43 Amendment No. 2 3 5 3.3 INSTRUMENTATION RPV Water Inventory Control Instrumentation 3.3.5.2 3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation LCO 3.3.5.2 The RPV Water Inventory Control instrumentation for each Function in Table 3.3.5.2-1 shall be OPERABLE.

APPLICABILITY:

According to Table 3.3.5.2-1.

ACTIONS --------------------------------------NOTE--------------------------------------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable.

referenced in Table 3.3.5.2-1 for the channel.

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

incapable of automatic isolation.

AND 8.2 Calculate DRAIN TIME. Immediately C. As required by Required C.1 Place channel in trip. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Action A.1 and referenced in Table 3.3.5.2-1.

D. As required by Required 0.1 Restore channel to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Action A.1 and referenced OPERABLE status. in Table 3.3.5.2-1.

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

HATCH UNIT 2 3.3-44 Amendment No.2 3 5 RPV Water Inventory Control Instrumentation 3.3.5.2 SURVEILLANCE REQUIREMENTS

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

SURVEILLANCE SR 3.3.5.2.1 Perform CHANNEL CHECK. SR 3.3.5.2.2 Perform CHANNEL FUNCTIONAL TEST. HATCH UNIT2 3.3-45 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 2 3 5 RPV Water Inventory Control Instrumentation 3.3.5.2 Table 3.3.5.2-1 (page 1 of 1) RPV Water Inventory Control Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILlANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A 1 REQUIREMENTS VALUE 1. Core Spray System a. Reactor Steam Dome 4,5 4e1; C SR 3.3.5.2.1 s 476 psig Pressure

-Low SR 3.3.5.2.2 (Injection Pecmissive)

b. Core Spray Pump 4.5 1 per D SR 3.3.5.2.1

,! 570 gpm Discharge Flow -Lem subsystem 1*> SR 3.3.5.2.2 and (Bypass)

S745 gpm 2. Low Pressure Coolant Injection (LPCI) System a. Reaclor Steam Dome 4. 5 41t) C SR 3.3.5.2.1 s 476 psig Pressure

-Low SR 3.3.5.2.2 (Injection Permissive)

b. Lem Pressure Coolant 4,5 1 per D SR 3.3.5.2.1

,! 1675 gpm Injection Pump subsystem'*!

tel SR 3.3.5.2.2 and Discharge Flow -Low s2215 gpm (Bypass)

3. RHR System Isolation

a. Reactor Vessel Water (b) 2 in one trip B SR 3352.1 2 0 inches Level -Low Level 3 system SR 3.3.5.2.2

4. Reacta Water Cleanup (RWCU) System Isolation

a. Reactor Vessel (b) 2 in one trip B SR 3 3 5 2.1 2-47inches Water Level

Low system SR 3.3.5.22 Low. Level 2 (a) Associated with an ECCS subsystem required lo be OPERABLE by LCO 3 5 2, "Reactor Pressure Vessel Water Inventory Control".

(b) When autcmatic isolation of the associated penetration flow path(s) is credited in calculating DRAIN TIME. (C) Function not required to be OPERABLE while associated pump is operating in decay heat removal when minimum flow valve is closed and deactivated.

HATCH UNIT 2 3.3-46 Amendment No. 235 3.3 INSTRUMENTATION RCIC System Instrumentation 3.3.5.3 3.3.5.3 Reactor Core Isolation Cooling (RCIC) System Instrumentation LCO 3.3.5.3 The RCIC System instrumentation for each Function in Table 3.3.5.3-1 shall be OPERABLE.

APPLICABILITY:

MODE 1, MODES 2 and 3 with reactor steam dome pressure

> 150 psig. ACTIONS ----------------------------------------NOTE-------------------------------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A One or more channels A.1 Enter the Condition Immediately inoperable.

referenced in Table 3.3.5.3-1 for the channel.

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

of loss of RCIC in Table 3.3.5.3-1.

initiation capability AND 8.2 Place channel in trip. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months C. As required by Required C.1 Restore channel to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Action A.1 and referenced OPERABLE status. in Table 3.3.5.3-1.

(continued)

HATCH UNIT2 3.3-47 Amendment No. 2 3 5 ACTIONS (continued)

CONDITION D. As required by Required Action A.1 and referenced in Table 3.3.5.3-1.

E. Required Action and associated Completion Time of Condition B, C, or D not met. HATCH UNIT2 D.1 AND D.2.1 RCIC System Instrumentation 3.3.5.3 REQUIRED ACTION COMPLETION TIME ------NOTE----

Only applicable if RCIC pump suction is not aligned to the suppression pool. ------Declare RCIC System 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery inoperable.

of loss of RCIC initiation capability Place channel in trip. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OR D.2.2 Align RCIC pump 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months suction to the suppression pool. E.1 Declare RCIC System Immediately inoperable.

3.3-48 Amendment No. 2 3 5 I RCIC System Instrumentation

. 3.3.5.3 SURVEILLANCE REQUIREMENTS

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

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

I 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed as follows:

(a) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Function 2; and (b) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Functions 1, 3, and 4 provided the associated Function maintains RCIC initiation capability.

SURVEILLANCE SR 3.3.5.3.1 Perform CHANNEL CHECK. SR 3.3.5.3.2 Perform CHANNEL FUNCTIONAL TEST. SR 3.3.5.3.3 Perform CHANNEL FUNCTIONAL TEST. SR 3.3.5.3.4 Perform CHANNEL CALIBRATION.

SR 3.3.5.3.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. HATCH UNIT2 3.3-49 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 2 3 s Table 3.3.5.3-1 (page 1 of 1) RCIC System Instrumentation 3.3.5.3 Reactor Core Isolation Cooling System Instrumentation CONDITIONS REQUIRED REFERENCED CHANNELS FROM PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION FUNCTION ACTIONA.1 REQUIREMENTS VALUE 1. Reactor Vessel Water Level -4 B SR 3.3.5.3.1

.: -47 inches Low Low, Level 2 SR 3.3.5.3.2 SR 3.3.5.3.4 SR 3.3.5.3.5

2. Reactor Vessel water Level -2 C SR 3.3.5.3.1 s 56.5 inches High, Level 8 SR 3.3.5.3.2 SR 3.3.5.3.4 SR 3.3.5.3.5

3. Condensate Storage Tank 2 D SR 3.3.5.3.3 i!: 1.0 ft Level-Low SR 3.3.5.3.5

4. Suppression Pool water 2 D SR 3.3.5.3.3 s 151 inches Level-High SR 3.3.5.3.5 HATCH UNIT2 3.3-50 Amendment No. 2 3 s Primary Containment Isolation Instrumentation 3.3.6.1 3.3 INSTRUMENTATION 3.3.6.1 Primary Containment Isolation Instrumentation LCO 3.3.6.1 The primary containment isolation instrumentation for each Function in Table 3.3.6.1-1 shall be OPERABLE.

APPLICABILITY:

According to Table 3.3.6.1-1.

ACTIONS ------------------NOTES--------------------

1. Penetration flow paths except for 18 inch purge valve penetration flow paths may be unisolated intermittently under administrative controls.

2. Separate Condition entry is allowed for each channel.

,-----------------*---

CONDITION REQUIRED ACTION A. One or more required A.1 Place channel in trip. channels inoperable.

B. -----NOTE-------*

B.1 Restore isolation Not applicable for capability.

Function 5.c. -------------------------

One or more automatic Functions with isolation capability not maintained.

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

HATCH UNIT2 3.3-51 COMPLETION TIME 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for Functions 2.a, 2.b, 6.b, 7.a, and 7.b AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for Functions other than Functions 2.a, 2.b, 6.b, 7.a, and 7.b 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Immediately (continued)

Amendment No. 2 3 s ACTIONS (continued)

CONDITION D. As required by Required Action C.1 and referenced in Table 3.3.6.1-1.

E. As required by Required Action C.1 and referenced in Table 3.3.6.1-1.

F. As required by Required Action C.1 and referenced in Table 3.3.6.1-1.

G. As required by Required Action C.1 and referenced in Table 3.3.6.1-1.

H. As required by Required Action C.1 and referenced in Table 3.3.6.1-1.

OR Required Action and associated Completion Time of Condition F or G not met. HATCH UNIT2 D.1 OR 0.2.1 Primary Containment Isolation Instrumentation 3.3.6.1 REQUIRED ACTION COMPLETION TIME Isolate associated main 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months steam line (MSL). Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND D.2.2 Bein MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months F.1 Isolate the affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months penetration flow path(s).

G.1 Isolate the affected 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months penetration flow path(s).

H.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND H.2 Be in M0DE4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued) 3.3-52 Amendment No. 2 3 5 \

ACTIONS (continued)

CONDITION I. As required by Required 1.1 Action C.1 and referenced in Table 3.3.6.1-1.

OR 1.2 J. As required by Required J.1 Action C.1 and referenced in Table 3.3.6.1-1.

SURVEILLANCE REQUIREMENJS Primary Containment Isolation Instrumentation 3.3.6.1 REQUIRED ACTION COMPLETION TIME Declare Standby Liquid 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Control (SLC) System inoperable.

Isolate the Reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Water Cleanup (RWCU) System. Initiate action to restore Immediately channel to OPERABLE status. ----------------------------NOTES-------------------------------

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

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

SURVEILLANCE SR 3.3.6.1.1 Perform CHANNEL CHECK. HATCH UNIT2 3.3-53 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued)

Amendment No. 2 3 5 Primary Containment Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.6.1.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.3 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.4 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.5 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.7

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

Channel sensors are excluded.

Verify the ISOLATION SYSTEM RESPONSE In accordance with TIME is within limits. the Surveillance Frequency Control Program HATCH UNIT2 3.3-54 Amendment No. 2 3 5 Primary Containment Isolation Instrumentation 3.3.6.1 Table3.3.6.1-1 (page 1 of5) Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE 1. Main Steam Line Isolation

a. Reactor Vessel Water 1,2,3 2 D SR 3.3.6.1.1 -113 inches Level -Low Low Low, SR 3.3.6.1.2 Level 1 SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7

b. Main Steam Line 2 E SR 3.3.6.1.3 825 psig Pressure

-Low SR 3.3.6.1.6 C. Main Steam Line 1,2,3 2 per D SR 3.3.6.1.1 s 138% rated Flow-High MSL SR 3.3.6.1.2 steam flow SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7

d. Condenser Vacuum -Low 1, 2 D SR 3.3.6.1.3

.: 7 Inches Hg 2(a), 3(a) SR 3.3.6.1.6 vacuum e. Main Steam Tunnel 1,2,3 6 D SR 3.3.6.1.1 s 194°F Temperature

-High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

f. Turbine Building Area 1,2,3 16(b) D SR 3.3.6.1.2 S200°F Temperature

-High SR 3.3.6.1.5 SR 3.3.6.1.6

2. Primary Containment Isolation

a. Reactor Vessel Water 1,2,3 2 H SR 3.3.6.1.1 D inches Level-Low, Level 3 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

b. Drywell Pressure

-High 1,2,3 2 H SR 3.3.6.1.1 s 1.92 pslg SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 continued (a) With any turbine stop valve not closed. (b) With B channels per trip string. Each trip string shall have 2 channels per main steam line, with no more than 40 ft separating any two OPERABLE channels.

HATCH UNIT2 3.3-55 Amendment No. 2 3 s

2. 3. Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 2 of 5) Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE Primary Containment Isolation (continued)

C. Drywell Radiation

-High 1,2,3 F SR 3.3.6.1.1

S 138 R/hr SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

d. Reactor Building Exhaust 1,2,3 2 H SR 3.3.6.1.1

S 80 mR/hr Radiation

-High SR 3.3.6.1.3 SR 3.3.6.1.6

e. Refueling Floor Exhaust 1,2,3 2 H SR 3.3.6.1.1

S80 mR/hr Radiation

-High SR 3.3.6.1.3 SR 3.3.6.1.6 High Pressure Coolant Injection (HPCI) System Isolation

a. HPCJ Steam Line Flow-1,2,3 F SR 3.3.6.1.1

S 303% rated High SR 3.3.6.1.2 steam flow SR 3.3.6.1.5 SR 3.3.6.1.6

b. HPCI Steam Supply Line 1,2,3 2 F SR 3.3.6.1.1 100 psig Pressure

-Low SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 C. HPCI Turbine Exhaust 1,2,3 2 F SR 3.3.6.1.1

S 20 psig Diaphragm Pressure

-High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

d. Drywell Pressure

-High 1,2,3 F SR 3.3.6.1.1

S 1.92 psJg SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

e. HPCI Pipe Penetration Room 1,2,3 F SR 3.3.6.1.1

S 169"F Temperature

-High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

f. Suppression Pool Area Ambient 1,2,3 F SR 3.3.6.1.1

S 169"F Temperature

-High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 continued HATCH UNIT2 3.3-56 Amendment No. 2 3 s Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 3 of 5) Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE 3. HPCI System Isolation (continued)

g. Suppression Pool Area 1,2,3 F SR 3.3.6.1.4 s 16 minutes Temperature

-Time Delay SR 3.3.6.1.6 15 seconds Relays h. Suppression Pool Area 1,2,3 1 F SR 3.3.6.1.1 S42'F Differential Temperature

-SR 3.3.6.1.2 High SR 3.3.6.1.5 SR 3.3.6.1.6 I. Emergency Area Cooler 1,2,3 1 F SR 3.3.6.1.1 s 169'F Temperature

-High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

4. Reactor Core Isolation Cooling (RCIC) System Isolation

a. RCIC Steam Line Flow -1,2,3 F SR 3.3.6.1.1 S307% rated High SR 3.3.6.1.2 steam flow SR 3.3.6.1.5 SR 3.3.6.1.6

b. RCIC Steam Supply Line 1,2,3 2 F SR 3.3.6.1.1 60 psig Pressure

-Low SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 C. RCIC Turbine Exhaust 1,2,3 2 F SR 3.3.6.1.1 S20 psig Diaphragm Pressure

-SR 3.3.6.1.2 High SR 3.3.6.1.5 SR 3.3.6.1.6

d. Drywell Pressure

-High 1,2,3 F SR 3.3.6.1.1 s 1.92 psig SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

e. RCIC Suppression Pool 1,2,3 F SR 3.3.6.1.1 s 169'F Ambient Area SR 3.3.6.1.2 Temperature

-High SR 3.3.6.1.5 SR 3.3.6.1.6

f. Suppression Pool Area 1,2,3 F SR 3.3.6.1.4 s 31 minutes Temperature

-Time Delay SR 3.3.6.1.6 15 seconds Relays {continued)

HATCH UNIT2 3.3-57 Amendment No. 2 3 5 Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 4 of 5) Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE 4. RCIC System Isolation (continued)

g. RCIC Suppression Pool 1,2,3 1 F SR 3.3.6.1.1 S42°F Area Differential SR 3.3.6.1.2 Temperature

-High SR 3.3.6.1.5 SR 3.3.6.1.6

h. Emergency Area Cooler 1,2,3 1 F SR 3.3.6.1.1 s 169°F Temperature

-High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

5. R\NCU System Isolation

a. Area Temperature

-High 1,2,3 1 per area F SR 3.3.6.1.1 s 1so°F SR 3.3.6.1 .2 SR 3.3.6.1.5 SR 3.3.6.1.6

b. Area Ventilation 1,2,3 1 per area F SR 3.3.6.1.1 S67°F Differential Temperature

-SR 3.3.6.1.2 High SR 3.3.6.1.5 SR 3.3.6.1.6 C. SLC System Initiation 1,2 1(c) SR 3.3.6.1.6 NA d. Reactor Vessel Water 1,2,3 2 F SR 3.3.6.1.1

.!:-47 inches Level -Low Low, Level 2 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

6. RHR Shutdown Cooling System Isolation

a. Reactor Steam Dome 1,2,3 F SR 3.3.6.1.1 s 145 psig Pressure

-High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

b. Reactor Vessel Water 3 2 J SR 3.3.6.1.1

.!: o Inches I Level -Low, Level 3 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 con nue (c) SLC System Initiation only inputs into one of the two trip systems.

HATCH UNIT2 3.3-58 Amendment No. 2 3 5 Primary Containment Isolation Instrumentation

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

7. Traversing lncore Probe System Isolation

a. Reactor Vessel Water Level -Low, Level 3 b. Drywall Pressure

-High HATCH UNIT 2 APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS 1,2,3 1,2,3 REQUIRED CHANNELS PER TRIP SYSTEM 2 2 3.3-59 CONDITIONS REFERENCED FROM REQUIRED ACTION C.1 G G SURVEILLANCE ALLOWABLE REQUIREMENTS VALUE SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 o inches s 1.92 psig Amendment No. 2 3 5 Secondary Containment Isolation Instrumentation 3.3.6.2 3.3 INSTRUMENTATION 3.3.6.2 Secondary Containment Isolation Instrumentation LCO 3.3.6.2 The secondary containment isolation instrumentation for each Function in Table 3.3.6.2-1 shall be OPERABLE.

APPLICABILITY:

According to Table 3.3.6.2-1.

ACTIONS ---------------------------------NOTE-----------------------------

Separate Condition entry is allowed for each channel.

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

Function 2 AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for Functions other than Function 2 B. One or more automatic B.1 Restore isolation 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Functions with isolation capability.

capability not maintained.

C. Required Action and C.1.1 Isolate the associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated Completion penetration flow Time of Condition A or B path(s).

not met. OR C.1.2 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months secondary containment isolation valves inoperable.

AND (continued)

HATCH UNIT2 3.3-60 Amendment No. 235 ACTIONS Secondary Containment Isolation Instrumentation 3.3.6.2 CONDITION REQUIRED ACTION COMPLETION TIME C. (continued)

C.2.1 Place the associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months standby gas treatment (SGn subsystem(s) in operation.

C.2.2 Declare associated SGT subsystem(s) inoperable.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SURVEILLANCE REQUIREMENTS

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

1. Refer to Table 3.3.6.2-1 to determine which SRs apply for each Secondary Containment Isolation Function.

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

SURVEILLANCE SR 3.3.6.2.1 Perform CHANNEL CHECK. SR 3.3.6.2.2 Perform CHANNEL FUNCTIONAL TEST.

SR 3.3.6.2.3 Perform CHANNEL CALIBRATION.

HATCH UNIT2 3.3-61 FREQUENCY.

In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued)

Amendment No. 2 3 5 Secondary Containment Isolation Instrumentation 3.3.6.2 SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.6.2.4 SR 3.3.6.2.5 HATCH UNIT2 SURVEILLANCE FREQUENCY Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program 3.3-62 Amendment No. 235 FUNCTION

1. Reactor Vessel Water Level-Low Low, Level 2 2. Drywell Pressure

-High 3. Reactor Building Exhaust Radiation

-High 4. Refueling Floor Exhaust Radiation

-High Secondary Containment Isolation Instrumentation 3.3.6.2 Table 3.3.6.2-1 (page 1 of 1) Secondary Containment Isolation Instrumentation APPLICABLE MODES OR REQUIRED OTHER CHANNELS SPECIFIED PER CONDITIONS TRIP SYSTEM 1,2,3 2 1, 2, 3 2 1,2,3 2 1, 2, 3, 2 5,(a) SURVEILLANCE REQUIREMENTS SR 3.3.6.2.1 SR 3.3.6.2.2 SR 3.3.6.2.4 SR 3.3.6.2.5 SR 3.3.6.2.1 SR 3.3.6.2.2 SR 3.3.6.2.4 SR 3.3.6.2.5 SR 3.3.6.2.1 SR 3.3.6.2.3 SR 3.3.6.2.5 SR 3.3.6.2.1 SR 3.3.6.2.3 SR 3.3.6.2.5 ALLOWABLE VALUE i!:-47 Inches s 1.92 psig s 80 mR/hr s 80 mR/hr (a) During CORE ALTERATIONS and during movement of Irradiated fuel assemblies in secondary containment.

HATCH UNIT2 3.3-63 Amendment No. 2 3 5 3.3 INSTRUMENTATION 3.3.6.3 Low-Low Set (LLS) Instrumentation LLS Instrumentation 3.3.6.3 LCO 3.3.6.3 The LLS valve instrumentation for each Function in Table 3.3.6.3-1 shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One LLS valve with A.1 Restore LLS valve 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months initiation capability not initiation capability.

maintained.

8. One or more safety/relief 8.1 Restore tailpipe Prior to entering valves (S/RVs) with one pressure switches to MODE 2 or 3 from Function 3 channel OPERABLE status. MODE4 inoperable.

C. ------NOTE-----

C.1 Restore one tailpipe 14 days Separate Condition entry is pressure switch to allowed for each S/RV. OPERABLE status. ----------------------

One or more S/RVs with two Function 3 channels inoperable.

(continued)

HATCH UNIT2 3.3-64 Amendment No. 2 3 5

ACTIONS (continued)

CONDITION REQUIRED ACTION LLS Instrumentation 3.3.6.3 COMPLETION TIME D. Required Action and associated Completion Time of Condition A, B, or C not met. D.1 Declare the associated Immediately OR Two or more LLS valves with initiation capability not maintained.

SURVEILLANCE REQUIREMENTS LLS valve(s) inoperable.

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

1. Refer to Table 3.3.6.3-1 to determine which SRs apply for each Function.

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

SR 3.3.6.3.1 SR 3.3.6.3.2 HATCH UNIT2 L ... -*----***.

-. SURVEILLANCE Perform CHANNEL CHECK. Perform CHANNEL FUNCTIONAL TEST for portion of the channel outside primary containment.

3.3-65 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued)

Amendment No. 2 3 5

SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.6.3.3 SR 3.3.6.3.4 SR 3.3.6.3.5 SR 3.3.6.3.6 HATCH UNIT2 SURVEILLANCE

*----NOTE

Only required to be performed prior to entering MODE 2 during each scheduled outage > 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months when entry is made into primary containment.

Perform CHANNEL FUNCTIONAL TEST for portions of the channel inside primary containment.

Perform CHANNEL FUNCTIONAL TEST. Perform CHANNEL CALIBRATION.

Perform LOGIC SYSTEM FUNCTIONAL TEST. 3.3-66 LLS Instrumentation 3.3.6.3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 2 3 5 FUNCTION

1. Reactor Steam Dome Pressure-High 2. Low-Low Set Pressure Setpoints

3. Tailpipe Pressure Switch HATCH UNIT2 Table 3.3.6.3-1 (page 1 of 1) Low-Low Set Instrumentation REQUIRED CHANNELS PER FUNCTION 1 per LLS valve 2 per LLS valve 2 perS/RV 3.3-67 SURVEILLANCE REQUIREMENTS SR 3.3.6.3.1 SR 3.3.6.3.4 SR 3.3.6.3.5 SR 3.3.6.3.6 SR 3.3.6.3.1 SR 3.3.6.3.4 SR 3.3.6.3.5 SR 3.3.6.3.6 SR 3.3.6.3.2 SR 3.3.6.3.3 SR 3.3.6.3.5 SR 3.3.6.3.6 LLS Instrumentation 3.3.6.3 ALLOWABLE

. VALUE s 1085 pslg Low: Open :s 1010 psig Close s 860 psig Medium-Low:

Open s 1025 pslg Close s 875 psig Medium-High:

Open s 1040 psig Close s 890 psig High: Open s 1050 psig Close s 900 psig :.: 80 pslg and s 100 psig Amendment No. 2 3 s 3.3 INSTRUMENTATION MCREC System Instrumentation 3.3.7.1 3.3.7.1 Main Control Room Environmental Control (MCREC) System Instrumentation LCO 3.3.7.1 Two channels of the Control Room Air Inlet Radiation

-High Function shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary containment, During CORE AL TERA TIONS. ACTIONS --------------------------NOTE------------------------------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or both channels A.1 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery inoperable.

MCREC subsystem(s) of loss of MCREC inoperable.

initiation capability in both trip systems AND A.2 Place channel in trip. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months B. Required Action and B.1 Place the associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated Completion MCREC subsystem(s)

Time not met. in the pressurization mode of operation.

OR B.2 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months MCREC subsystem(s) inoperable.

HATCH UNIT2 3.3-68 Amendment No. 2 3 5 MCREC System Instrumentation 3.3.7.1 SURVEILLANCE REQUIREMENTS

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

When a Control Room Air Inlet Radiation

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

SR 3.3.7.1.1 SR 3.3.7.1.2 SR 3.3.7.1.3 SR 3.3.7.1.4 HATCH UNIT2 SURVEILLANCE Perform CHANNEL CHECK. Perform CHANNEL FUNCTIONAL TEST. Perform CHANNEL CALIBRATION.

The Allowable Value shall bes 1 mr/hour.

Perform LOGIC SYSTEM FUNCTIONAL TEST. 3.3-69 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 2 3 s 3.3 INSTRUMENTATION 3.3.8.1 Loss of Power (LOP) Instrumentation LOP Instrumentation 3.3.8.1 LCO 3.3.8.1 The LOP instrumentation for each Function in Table 3.3.8.1-1 shall be OPERABLE.

APPLICABILITY:

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

ACTIONS -------------NOTE------------------

Separate Condition entry is allowed for each channel.

'

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Restore channel to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable for Functions 1 OPERABLE status. and 2. B. One or more channels 8.1 Verify voltage on Once per hour inoperable for Function

3. associated 4.16 kV bus is~ 3825 V. C. Required Action and C.1 Declare associated DG Immediately associated Completion inoperable.

Time not met. HATCH UNIT2 3.3-70 Amendment No. 235 SURVEILLANCE REQUIREMENTS

NOTES------

LOP Instrumentation 3.3.8.1 1. Refer to Table 3.3.8.1-1 to determine which SRs apply for each LOP Function.

2. When a 4.16 kV Emergency Bus Undervoltage channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains initiation capability (for Functions 1 and 2) and annunciation capability (for Function 3). SURVEILLANCE SR 3.3.8.1.1 Perform CHANNEL CHECK. SR 3.3.8.1.2 Perform CHANNEL FUNCTIONAL TEST. SR 3.3.8.1.3 Perform CHANNEL CALIBRATION.

SR 3.3.8.1.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. HATCH UNIT2 3.3-71 -------------------*---------*

. **--FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 2 3 5 FUNCTION

1. 4.16 kV Emergency Bus Undervoltage (Loss of Voltage)

a. Bus Undervoltage

b. Time Delay 2. 4.16 kV Emergency Bus Undervoltage (Degraded Voltage)

a. Bus Undervoltage

b. Time Delay 3. 4.16 kV Emergency Bus Undervoltage (Annunciation)

a. Bus Undervoltage

b. Time Delay HATCH UNIT2 Table 3.3.8.1-1 (page 1 of 1) Loss of Power Instrumentation REQUIRED CHANNELS PER FUNCTION SURVEILLANCE REQUIREMENTS 2 2 2 2 3.3-72 SR 3.3.8.1.2 SR 3.3.8.1.3 SR 3.3.8.1.4 SR 3,3.8.1.2 SR 3.3.8.1.3 SR 3.3.8.1.4 SR 3.3.8.1.2 SR 3.3.8.1.3 SR 3.3.8.1.4 SR 3.3.B.1.2 SR 3.3.B.1.3 SR 3.3.B.1.4 SR 3.3.8.1.1 SR 3.3.8.1.2 SR 3.3.8.1.3 SR 3.3.8.1.4 SR 3.3.8.1.2 SR 3.3.8.1.3 SR 3.3.B.1.4 LOP Instrumentation 3.3.8.1 ALLOWABLE VALUE ~2800V :s 6.5 seconds 3280V :s 21.5 seconds .!: 3825V :s 65 seconds Amendment No. 2 3 5 3.3 INSTRUMENTATION RPS Electric Power Monitoring 3.3.8.2 3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring LCO 3.3.8.2 Two RPS electric power monitoring assemblies shall be OPERABLE for each in service RPS motor generator set or alternate power supply. APPLICABILITY:

MODES 1, 2, and 3, MODES 4 and 5 with any control rod withdrawn from a core cell containing one or more fuel assemblies or with both residual heat removal (RHR) shutdown cooling (SOC) isolation valves open. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or both inservice A.1 Remove associated 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months power supplies with one inservice power electric power monitoring supply(s) from service.

assembly inoperable.

B. One or both inservice 8.1 Remove associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months power supplies with both inservice power electric power monitoring supply(s) from service.

assemblies inoperable.

C. Required Action and C.1 ------NOTE-----

associated Completion LCO 3.0.4.a is not Time of Condition A or B applicable when not met in MODE 1, 2, or 3. entering MODE 3. ---Bein MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

HATCH UNIT2 3.3-73 Amendment No.235 ACTIONS (continued)

CONDITION D. Required Action and associated Completion Time of Condition A or B not met in MODE 4 or 5 with any control rod withdrawn from a core cell containing one or more fuel assemblies or with both RHR SOC isolation valves open. HATCH UNIT2 RPS Electric Power Monitoring 3.3.8.2 REQUIRED ACTION COMPLETION TIME D.1 Initiate action to fully Immediately insert all insertable control rods in core cells containing one or more fuel assemblies.

AND D.2.1 Initiate action to restore Immediately one electric power monitoring assembly to OPERABLE status for inservice power supply(s) supplying required instrumentation.

OR D.2.2 Initiate action to isolate Immediately the RHR SOC. 3.3-74 Amendment No. 2 3 s RPS Electric Power Monitoring 3.3.8.2 SURVEILLANCE REQUIREMENTS

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

When an RPS electric power monitoring assembly is placed in an inoperable status solely for performance of required Surveillances, entry into the associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the other RPS electric power monitoring assembly for the associated power supply maintains trip capability.

SR 3.3.8.2.1 SR 3.3.8.2.2 SR 3.3.8.2.3 HATCH UNIT2 SURVEILLANCE

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

Only required to be performed prior to entering MODE 2 or 3 from MODE 4, when in MODE 4 for 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . Perform CHANNEL FUNCTIONAL TEST. Perform CHANNEL CALIBRATION.

The Allowable Values shall be: a. Overvoltage s 132 V, with time delay set to S4 seconds.

b. Undervoltage

2: 108 V, with time delay set to s 4 seconds.

c. Underfrequency 57 Hz, with time delay set to s 4 seconds.

Perform a system functional test. 3.3-75 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 235 ECCS -Operating 3.5.1 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY

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

APPLICABILITY:

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

LCO 3.0.4.b is not applicable to HPCI. --------------------------------------,

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

subsystem(s) to OPERABLE status. OR One LPCI pump in both LPCI subsystems inoperable.

8. Required Action and B.1 -------NOTE----

associated Completion LCO 3.0.4.a is not Time of Condition A not applicable when met. entering MODE 3. --------------

Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

HATCH UNIT2 3.5-1 Amendment No. 235 RPV Water Inventory Control 3.5.2 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY

CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control LCO 3.5.2 DRAIN TIME of RPV water inventory to the top of active fuel (TAF) shall be 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . One low pressure ECCS injection/spray subsystem shall be OPERABLE.

APPLICABILITY:

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

subsystem to OPERABLE status. B. Required Action and B.1 Initiate action to Immediately associated Completion establish a method of Time of Condition A not water injection capable met. of operating without offsite electrical power. C. DRAIN TIME < 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months C.1 Verify secondary 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . containment boundary is capable of being established in less than the DRAIN TIME. AND C.2 Verify each secondary 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months containment penetration flow path is capable of being isolated in less than the DRAIN TIME. (continued}

HATCH UNIT2 3.5-7 Amendment No. 2 3 5 ACTIONS CONDITION C. (continued)

AND C.3 D. DRAIN TIME < 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . D.1 AND 0.2 AND D.3 HATCH UNIT2 RPV Water Inventory Control 3.5.2 REQUIRED ACTION COMPLETION TIME Verify required standby 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months gas treatment subsystem(s) are capable of being placed in operation in less than the DRAIN TIME. ----NOTE----

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

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

Initiate action to isolate Immediately each secondary containment penetration flow path or verify it can be manually isolated from the control room. (continued) 3.5-8 Amendment No. 235 RPV Water Inventory Control 3.5.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. (continued)

AND D.4 Initiate action to verify Immediately required standby gas treatment subsystem(s) are capable of being placed in operation.

E. Required Action and E.1 Initiate action to restore Immediately associated Completion DRAIN TIME to~ 36 Time of Condition C or D hours. not met. OR DRAIN TIME< 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . SURVEILLANCE REQUIREMENTS SR 3.5.2.1 SR 3.5.2.2 SR 3.5.2.3 HATCH UNIT2 SURVEILLANCE Verify DRAIN TIME.!! 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . Verify, for a required low pressure coolant injection (LPCI) subsystem, the suppression pool water level is :ii?: 146 inches. Verify, for a required Core Spray (CS) subsystem, the: a. Suppression pool water level is 146 inches; or b. Condensate storage tank water level is 15 ft. 3.5-9 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued)

Amendment No. 235 RPV Water Inventory Control 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SR 3.5.2.4 SR 3.5.2.5 SR 3.5.2.6 SR 3.5.2.7 SR 3.5.2.8 HATCH UNIT2 SURVEILLANCE Verify, for the required ECCS injection/spray subsystem, locations susceptible to gas accumulation are sufficiently filled with water. -----------NOTES-------*-------

1. A Low Pressure Coolant Injection (LPCI) subsystem may be considered OPERABLE during alignment and operation for decay heat removal if capable of being manually realigned and not otherwise inoperable.

2. Not required to be met for system vent flowpaths opened under administrative control.

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.

Operate the required ECCS injection/spray subsystem through the recirculation line for .!: 10 minutes.

Verify each valve credited for automatically isolating a penetration flow path actuates to the isolation position on an actual or simulated isolation signal. ------------NOTE------------

Vessel injection/spray may be excluded.

Verify the required ECCS injection/spray subsystem can be manually operated.

3.5-10 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 2 3 s RCIC System 3.5.3 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY

CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.3 RCIC System LCO 3.5.3 The RCIC System shall be OPERABLE.

APPLICABILITY:

MODE 1, MODES 2 and 3 with reactor steam dome pressure

> 150 psig. ACTIONS -----------------------------NOTE-------------------------

LCO 3.0.4.b is not applicable to RCIC. CONDITION REQUIRED ACTION COMPLETION TIME A. RCIC System inoperable.

A.1 Verify by administrative 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months means high pressure coolant injection (HPCI) System is OPERABLE.

AND A.2 Restore RCIC System 14 days to OPERABLE status. B. Required Action and 8.1 --------NOTE------

associated Completion LCO 3.0.4.a is not Time not met. applicable when entering MODE 3. ---------------------

Bein M0DE3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months HATCH UNIT2 3.5-11 Amendment No. 2 3 5 SURVEILLANCE REQUIREMENTS SR 3.5.3.1 SR 3.5.3.2 SR 3.5.3.3 SR 3.5.3.4 HATCH UNIT2 SURVEILLANCE Verify the RCIC System locations susceptible to gas accumulation are sufficiently filled with water. ---------------NOTE---------

Not required to be met for system vent flowpaths opened under administrative control.

Verify each RCIC System manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

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

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure and flow are adequate to perform the test. Verify, with reactor pressure s 1058 psig and e? 920 psig, the RCIC pump can develop a flow rate e? 400 gpm against a system head corresponding to reactor pressure.

NOTE----------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure and flow are adequate to perform the test. Verify, with reactor pressures 165 psig, the RCIC pump can develop a flow rate e? 400 gpm against a system head corresponding to reactor pressure.

3.5-12 RCIC System 3.5.3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance

_Frequency Control Program (continued)

Amendment No. 235

--SURVEILLANCE REQUIREMENTS continued SR 3.5.3.5 HATCH UNIT2 SURVEILLANCE

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

Vessel injection may be excluded.

Verify the RCIC System actuates on an actual or simulated automatic initiation signal. 3.5-13 RCIC System 3.5.3 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment No. 235 3.6 CONTAINMENT SYSTEMS PCIVs 3.6.1.3 3.6.1.3 Primary Containment Isolation Valves (PCIVs) LCO 3.6.1.3 Each PCIV, except reactor building-to-suppression chamber vacuum breakers, shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3. ACTIONS --------------------------------------------------------NOTES-----------------------------------------------------------

1. Penetration flow paths except for 18 inch purge valve penetration flow paths may be unisolated intermittently under administrative controls.

2. Separate Condition entry is allowed for each penetration flow path. 3. Enter applicable Conditions and Required Actions for systems made inoperable by PCIVs. 4. Enter applicable Conditions and Required Actions of LCO 3.6.1.1, "Primary Containment,"

when PCIV leakage results in exceeding overall containment leakage rate acceptance criteria.

CONDITION A. -----------NOTE---------------

A.1 Only applicable to penetration flow paths with two PCIVs. One or more penetration flow paths with one PCIV inoperable except due to leakage not within limit. HATCH UNIT2 REQUIRED ACTION COMPLETION TIME Isolate the affected 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months except for penetration flow path by main steam line use of at least one closed and de-activated AND automatic valve, closed manual valve, blind 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months for main flange, or check valve steam line with flow through the valve secured.

(continued) 3.6-7 Amendment No. 235 ACTIONS (continued)

CONDITION C. -~~~-~-NOl"E--~-~--~-~

C.1 Only applicable to penetration flow paths with only one PCIV. -------------------------------------

One or more penetration flow paths with one PCIV inoperable except due to leakage not within limits. AND C.2 D. One or more penetration 0.1 flow paths with leakage not within limit. E. Required Action and E.1 associated Completion Time of Condition A, B, C, AND or D not met in MODE 1, 2, or 3. E.2 HATCH UNll" 2 REQUIRED ACTION Isolate the affected penetration flow path by use of at least one closed and de-activated automatic valve, closed manual valve, or blind flange. ----~---NOl"E~--~-~-~-

1. Valves and blind flanges in high radiation areas may be verified by use of administrative means. 2. Isolation devices that are locked, sealed, or otherwise secured may be verified by administrative means. ------------------------

Verify the affected penetration flow path is isolated.

Restore leakage to within limit. Be in MODE 3. Be in M0DE4. 3.6-9 PCIVs 3.6.1.3 COMPLETION TIME 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months except for excess flow check valve (EFCV) line and penetrations with a closed system AND 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for EFCV line and penetrations with a closed system Once per 31 days 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months 12 hours 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Amendment No.235 I

SURVEILLANCE REQUIREMENTS SR 3.6.1.3.1 SR 3.6.1.3.2 SR 3.6.1.3.3 HATCH UNIT 2 SURVEILLANCE

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

Not required to be met when the 18 inch primary containment purge valves are open for inerting, de-inerting, pressure

control, ALARA, or air quality considerations for personnel entry, or Surveillances that require the valves to be open. Verify each 18 inch primary containment purge valve is closed. ------------------------------N()TES----------------------~-

1. Valves and blind flanges in high radiation areas may be verified by use of administrative means. 2. Not required to be met for PCIVs that are open under administrative controls.

Verify each primary containment isolation manual valve and blind flange that is located outside primary containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. -----------------------------1',J()l"ES-------------------~-----

1. Valves and blind flanges in high radiation areas may be verified by use of administrative means. 2. Not required to be met for PCIVs that are open under administrative controls.

Verify each primary containment manual isolation valve and blind flange that is located inside primary containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. 3.6-10 PCIVs 3.6.1.3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Prior to entering MODE 2 or 3 from MODE 4 if primary containment was de-inerted while in M()DE 4, if not performed within the previous 92 days (continued)

Amendment No~us f SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE SR 3.6.1.3.4 Verify continuity of the traversing incore probe (TIP) shear isolation valve explosive charge. SR 3.6.1.3.5 Verify the isolation time of each power operated, automatic PCIV, except for MSIVs, is within limits. SR 3.6.1.3.6 Verify the isolation time of each MSIV is 3 seconds and s 5 seconds.

SR 3.6.1.3.7 Verify each automatic PCIV, excluding EFCVs, actuates to the isolation position on an actual or simulated isolation signal. SR 3.6.1.3.8 Verify each reactor instrumentation line EFCV (of a representative sample) actuates to restrict flow to within limits. SR 3.6.1.3.9 Remove and test the explosive squib from each shear isolation valve of the TIP system. SR 3.6.1.3.10 Verify the combined leakage rate for all secondary containment bypass leakage paths is s 0.02 La when pressurized to~ Pa HATCH UNIT2 3.6-11 PCIVs 3.6.1.3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the lnservice Testing Program In accordance with the lnservice Testing Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Primary Containment Leakage Rate Testing Program (continued)

Amendment No. 2 3 s I SURVEILLANCE REQUIREMENTS (continued)

SR 3.6.1.3.11 SR 3.6.1.3.12 SR 3.6.1.3.13 HATCH UNIT 2 SURVEILLANCE Verify combined MSIV leakage rate for all four main steam lines is~ 100 scfh when tested at~ 28.8 psig and< 47.3 psig. OR Verify combined MSIV leakage rate for all four main steam lines is s 144 scfh when tested at~ 47.3 psig. Deleted Cycle each 18 inch excess flow isolation damper to the fully closed and fully open position.

3.6-12 PCIVs 3.6.1.3 FREQUENCY In accordance with the Primary Containment Leakage Rate Testing Program In accordance with the Surveillance Frequency Control Program Amendment No. 2 3 5 I 3.6 CONTAINMENT SYSTEMS 3.6.4.1 Secondary Containment LCO 3.6.4.1 The secondary containment shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3, Secondary Containment 3.6.4.1 During movement of irradiated fuel assemblies in the secondary containment, During CORE AL TERA TIONS. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Secondary containment A.1 Restore secondary 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months inoperable in MODE 1, 2, containment to or 3. OPERABLE status. 8. Required Action and 8.1 -----NOTE----

associated Completion LCO 3.0.4.a is not Time of Condition A not applicable when met. entering MODE 3. -------------

Bein MODE3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months C. Secondary containment C.1 ----NOTE----------

inoperable during LCO 3.0.3 is not movement of irradiated fuel applicable.

assemblies in the -----------------

secondary containment or during CORE Suspend movement of Immediately ALTERATIONS.

irradiated fuel assemblies in the secondary containment.

AND (continued)

HATCH UNIT2 3.6-33 Amendment No. 2 3 s -----. -* *-*----*--**--

ACTIONS CONDITION REQUIRED ACTION C. (continued)

C.2 Suspend CORE ALTERATIONS.

SURVEILLANCE REQUIREMENTS SR 3.6.4.1.1 SR 3.6.4.1.2 SURVEILLANCE Verify all secondary containment equipment hatches are closed and sealed. Verify one secondary containment access door in each access opening is closed, except when the access opening is being used for entry and exit. Secondary Containment 3.6.4.1 COMPLETION TIME Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program SR 3.6.4.1.3

~~---------~--~--~-~---NOTE:~~--~-~----~--~-~~~

HATCH UNIT2 The number of standby gas treatment (SGT) subsystem(s) required for this Surveillance is dependent on the secondary containment configuration, and shall be one less than the number required to meet LCO 3.6.4.3, "Standby Gas Treatment (SGT) System,"

for the given configuration.

Verify secondary containment can be drawn down to 0.20 inch of vacuum water gauge in s 1 O minutes using required standby gas treatment (SGT) subsystem(s).

3.6-34 In accordance with the Surveillance Frequency Control Program (continued)

Amendment No. 2 3 5 3.6 CONTAINMENT SYSTEMS 3.6.4.2 Secondary Containment Isolation Valves (SCIVs) LCO 3.6.4.2 Each SCIV shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3, SCIVs 3.6.4.2 During movement of irradiated fuel assemblies in the secondary containment, During CORE AL TERA TIONS. ACTIONS ---NOTES-----------------------

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

2. Separate Condition entry is allowed for each penetration flow path. 3. Enter applicable Conditions

.and Required Actions for systems made inoperable by SCIVs. CONDITION A. One or more penetration flow paths with one SCIV inoperable.

HATCH UNIT2 REQUIRED ACTION COMPLETION TIME A.1 Isolate the affected 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months AND penetration flow path by use of at least one closed and de-activated automatic valve, closed manual valve, or blind flange. A.2 ------NOTES-----

1. Isolation devices in high radiation areas may be verified by use of administrative means. 3.6-36 (continued)

Amendment No.2 3 5 ----------------------------

ACTIONS CONDITION A. (continued)

B. One or more penetration 8.1 flow paths with two SCIVs inoperable.

C. Required Action and C.1 associated Completion Time of Condition A or B AND not met in MODE 1, 2, or 3. C.2 D. Required Action and D.1 associated Completion Time of Condition A or B not met during movement of irradiated fuel assemblies in the secondary containment or during CORE AL TERA TIONS. HATCH UNIT2 REQUIRED ACTION 2. Isolation devices that are locked, sealed, or otherwise secured may be verified by administrative means. --------------

Verify the affected penetration flow path is isolated.

Isolate the affected penetration flow path by use of at least one closed and de-activated automatic valve, closed manual valve, or blind flange. Be in MODE 3. Be in MODE 4. ----NOTE------

LCO 3.0.3 is not applicable.

Suspend movement of irradiated fuel assemblies in the secondary containment.

3.6-37 SCIVs 3.6.4.2 COMPLETION TIME Once per 31 days 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months 12 hours 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Immediately (continued)

Amendment No. 2 3 5

-**~*-*-**---------------------------------------------

ACTIONS CONDITION D. (continued)

REQUIRED ACTION SCIVs 3.6.4.2 COMPLETION TIME AND D.2 Suspend CORE ALTERATIONS.

Immediately SURVEILLANCE REQUIREMENTS SR 3.6.4.2.1 SR 3.6.4.2.2 SR 3.6.4.2.3 HATCH UNIT2 SURVEILLANCE

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

1. Valves and blind flanges in high radiation areas may be verified by use of administrative means. 2. Not required to be met for SCIVs that are open under administrative controls.

Verify each secondary containment isolation manual valve and blind flange that is not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. Verify the isolation time of each power operated, automatic SCIV is within limits. Verify each automatic SCIV actuates to the isolation position on an actual or simulated actuation signal. I 3.6-38 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 235 3.6 CONTAINMENT SYSTEMS 3.6.4.3 Standby Gas Treatment (SGT) System

. ----***-SGT System 3.6.4.3 LCO 3.6.4.3 The Unit 1 and Unit 2 SGT subsystems required to support LCO 3.6.4.1, "Secondary Containment,"

shall be OPERABLE.

APPLICABILITY:

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

ACTIONS ---------------------------NOTE-----------------------

When two Unit 1 SGT subsystems are placed in an inoperable status solely for inspection of the Unit 1 hardened vent rupture disk, entry into associated Conditions and Required Actions may be delayed for up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , provided both Unit 2 SGT subsystems are OPERABLE.

CONDITION A One required Unit 1 SGT subsystem inoperable while: 1. Four SGT subsystems required

OPERABLE, and 2. Unit 1 reactor building-to-refueling floor plug not installed.

HATCH UNIT2 A.1 REQUIRED ACTION Restore required Unit 1 SGT subsystem to OPERABLE status. 3.6-39 COMPLETION TIME 30 days from discovery of failure to meet the LCO (continued)

Amendment No. 2 3 5

~~~

ACTIONS (continued)

CONDITION B. One required Unit 2 SGT subsystem inoperable.

OR One required Unit 1 SGT subsystem inoperable for reasons other than Condition A. C. Required Action and associated Completion Time of Condition A or B not met in MODE 1, 2, or 3. D. Required Action and associated Completion Time of Condition A or B not met during movement of irradiated fuel assemblies in the secondary containment or during CORE ALTERATIONS.

HATCH UNIT2 REQUIRED ACTION 8.1 Restore required SGT subsystem to OPERABLE status. C.1 ----NOTE---

LCO 3.0.4.a is not applicable when entering MODE 3 . . ----------

Bein MODE3. --------NOTE---------

LCO 3.0.3 is not applicable.

D.1 Place remaining OPERABLE SGT subsystem(s) in operation.

OR D.2.1 Suspend movement of irradiated fuel assemblies In secondary containment.

AND D.2.2 Suspend CORE AL TERA TIONS. 3.6-40 SGT System 3.6.4.3 COMPLETION TIME 7days 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Immediately Immediately Immediately (continued)

Amendment No. 2 3 s ACTIONS (continued)

CONDITION REQUIRED ACTION E. Two or more required SGT E.1 ---NOTE---

subsystems inoperable in LCO 3.0.4.a is not MODE 1, 2, or 3. applicable when entering MODE 3. ---Be in M0DE3. F. Two or more required SGT F.1 -------NOTE---

subsystems inoperable LCO 3.0.3 is not during movement of applicable.

irradiated fuel assemblies in the secondary containment or during Suspend movement of CORE AL TERA TIONS. irradiated fuel assemblies in secondary containment.

AND F.2 Suspend CORE AL TERA TIONS. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.6.4.3.1 Operate each required SGT subsystem for ;:: 15 continuous minutes.

SGT System 3.6.4.3 COMPLETION TIME 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Immediately Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program SR 3.6.4.3.2 Perform required SGT filter testing in accordance In accordance with with the Ventilation Filter Testing Program_

(VFTP). the VFTP (continued)

HATCH UNIT 2 3.6-41 Amendment No. 235 MCREC System . 3.7.4 3. 7 PLANT SYSTEMS 3.7.4 Main Control Room Environmental Control (MCREC) System LCO 3.7.4 Two MCREC subsystems shall be OPERABLE.

NOTE

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

APPLICABILITY:

MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary containment, During CORE AL TERA TIONS. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One MCREC subsystem A.1 Restore MCREC 7 days inoperable for reasons subsystem to other than Condition B. OPERABLE status. B. One or more MCREC B.1 Initiate action to Immediately subsystems inoperable due implement mitigating to inoperable CRE actions.

boundary in MODE 1, 2, or 3. AND 8.2 Verify mitigating actions 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ensure CRE occupant exposures to radiological,

chemical, and smoke hazards will not exceed limits. AND B.3 Restore CRE boundary 90 days to OPERABLE status. (continued)

HATCH UNIT2 3.7-8 Amendment No. 2 3 5 ACTIONS (continued)

CONDITION C. Required Action and associated Completion Time of Condition A or B not met in MODE 1, 2, or 3. D. Required Action and associated Completion Time of Condition A not met during movement of irradiated fuel assemblies in the secondary containment or during CORE AL TERA TIONS. E. Two MCREC subsystems inoperable in MODE 1, 2, or 3 for reasons other than Condition B. HATCH UNIT2 REQUIRED ACTION C.1 ----NOTE---

LCO 3.0.4.a 'is not applicable when entering MODE 3. -------------

Be in MODE 3. -----NOTE---------

LCO 3.0.3 is not applicable.

D.1 Place OPERABLE MCREC subsystem in pressurization mode. OR D.2.1 Suspend movement of irradiated fuel assemblies in the secondary containment.

AND D.2.2 Suspend CORE ALTERATIONS.

E.1 ------NOTE----

LCO 3.0.4.a is not applicable when entering MODE 3. ----------------

Be in MODE 3. 3.7-9 MCREC System 3.7.4 COMPLETION TIME 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Immediately Immediately Immediately 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

Amendment No. 2 3 5 ACTIONS (continued}

F. CONDITION Two MCREC subsystems inoperable during movement of irradiated fuel assemblies in the secondary containment or during CORE ALTERATIONS.

REQUIRED ACTION ------NOTE---*--

LCO 3.0.3 is not applicable.

F.1 Suspend movement of irradiated fuel assemblies in the secondary containment.

One or more MCREC subsystems inoperable due F.2 to an inoperable CRE Suspend CORE ALTERATIONS.

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

SURVEILLANCE REQUIREMENTS SR 3.7.4.1 SR 3.7.4.2 SR 3.7.4.3 HATCH UNIT2 SURVEILLANCE Operate each MCREC subsystem 15 minutes.

Perform required MCREC filter testing in accordance with the Ventilation Filter Testing Program (VFTP). Verify each MCREC subsystem actuates on an actual or simulated initiation signal. 3.7-10 MCREC System 3.7.4 COMPLETION TIME Immediately Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with theVFTP In accordance with the Surveillance Frequency Control Program (continued)

Amendment No. 2 3 5 3.7 PLANT SYSTEMS 3. 7 .5 Control Room Air Conditioning (AC) System Control Room AC System 3.7.5 LCO 3.7.5 Three control room AC subsystems shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary containment, D~ring CORE ALTERATIONS.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One control room AC A.1 Restore control room 30 days subsystem inoperable.

AC subsystem to OPERABLE status. B. Two control room AC 8.1 Verify control room area Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months subsystems inoperable.

temperature

< 90°F. AND 8.2 Restore one control 7days room AC subsystem to OPERABLE status. C. Three control room AC C.1 Verify control room area Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months subsystems inoperable.

temperature

< 90°F. AND C.2 Restore one control 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months room AC subsystem to OPERABLE status. (continued)

HATCH UNIT2 3.7-12 Amendment No. 2 3 5

-* --**-----*--*-------*----

ACTIONS (continued)

CONDITION REQUIRED ACTION D. Required Action and D.1 ----NOTE----

associated Completion LCO 3.0.4.a is not Time of Condition A, B, or applicable when C not met in MODE 1, 2, or entering MODE 3. 3. ------------------

Be in MODE 3. E. Required Action and -----------NOTE-------

associated Completion LCO 3.0.3 is not applicable.

Time of Condition A not met --------------------

during movement of irradiated fuel assemblies in E.1 Place OPERABLE the secondary containment control room AC or during CORE . subsystems in ALTERATIONS.

operation.

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

AND E.2.2 Suspend CORE ALTERATIONS.

HATCH UNIT2 3.7-13 Control Room AC System 3.7.5 COMPLETION TIME 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Immediately Immediately Immediately (continued)

Amendment No. 235 ACTIONS (continued)

CONDITION F. Required Action and associated Completion Time of Condition B or C not met during movement of irradiated fuel assemblies in the secondary containment or during CORE ALTERATIONS.

REQUIRED ACTION -------NOTE---------

LCO 3.0.3 is not applicable.

Control Room AC System 3.7.5 COMPLETION TIME F.1 Suspend movement of Immediately irradiated fuel assemblies in the secondary containment.

F .2 Suspend CORE ALTERATIONS.

Immediately HATCH UNIT 2 3.7-14 Amendment No. 2 3 5 ACTIONS CONDITION A. One or more required offsite circuit(s) inoperable.

HATCH UNIT2 REQUIRED ACTION ----------NOTE--------

Enter applicable Condition and Required Actions of LCO 3.8.8, with one required 4160 V ESF bus de-energized as a result of Condition A. AC Sources -Shutdown 3.8.2 COMPLETION TIME A.1 Declare affected Immediately required feature(s),

with no offsite power available, inoperable.

A.2.1 Suspend CORE ALTERATIONS.

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

A.2.3 Initiate action to restore Immediately required offsite power circuit(s) to OPERABLE status. (continued) 3.8-21 Amendment No. 2 3 5 ACTIONS ( continued)

CONDITION B. One or more required DG(s) inoperable.

SURVEILLANCE REQUIREMENTS 8.1 AND 8.2 AND 8.3 REQUIRED ACTION Suspend CORE ALTERATIONS.

Suspend movement of irradiated fuel assemblies in secondary containment.

Initiate action to restore required DG(s) to OPERABLE status. SURVEILLANCE AC Sources -Shutdown 3.8.2 COMPLETION TIME Immediately Immediately Immediately FREQUENCY SR 3.8.2.1 --------------NOTE-------------------

SR 3.8.2.2 HATCH UNIT2 The following SRs are not required to be performed:

SR 3.8.1.2.b, SR 3.8.1.7 through SR 3.8.1.9, SR 3.8.1.11 through SR 3.8.1.14, SR 3.8.1.16, and SR 3.8.1.17.

For required Unit 2 AC sources, the SRs of LCO 3.8.1, e~cept SR 3.8.1.6, SR 3.8.1.15, and SR 3.8.1.18, are applicable.

For required Unit 1 AC sources, SR 3.8.2.1 of Unit 1 Specification 3.8.2 is applicable.

3.8-22 In accordance with applicable SRs In accordance with Unit 1 SR 3.8.2.1 Amendment No. 235 ACTIONS (continued)

CONDITION C. ( continued)

D. One or more required station service DC electrical power subsystems inoperable for reasons other than Condition B. OR Required Actions and associated Completion Times of Condition B not met. HATCH UNIT 2 REQUIRED ACTION C.2.3 Initiate action to restore required DC electrical power subsystems to OPERABLE status. 0.1 Declare affected required feature(s) inoperable.

OR 0.2.1 Suspend CORE ALTERATIONS.

AND 0.2.2 Suspend movement of irradiated fuel assemblies in the secondary containment.

AND D.2.3 Initiate action to restore required station service DC electrical power subsystems to OPERABLE status. 3.8-33 DC Sources -Shutdown 3.8.5 COMPLETION TIME Immediately Immediately Immediately Immediately Immediately Amendment No. 2 3 5 ACTIONS Distribution Systems -Shutdown 3.8.8 CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)

A.2.3 Initiate actions to Immediately restore required AC and DC electrical power distribution subsystem(s) to OPERABLE status. A.2.4 Declare associated required shutdown cooling subsystem(s) inoperable and not in operation.

Immediately SURVEILLANCE REQUIREMENTS SR 3.8.8.1 HATCH UNIT 2 SURVEILLANCE Verify correct breaker alignments and voltage to required AC and DC electrical power distribution subsystems.

3.8-44 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment Noi 3 5 UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION RELATED TO AMENDMENT NO. 290 TO RENEWED FACILITY OPERATING LICENSE NO. DPR-57 AND AMENDMENT NO. 235 TO RENEWED FACILITY OPERATING LICENSE NO. NPF-5 SOUTHERN NUCLEAR OPERATING

COMPANY, INC. EDWIN I. HATCH NUCLEAR PLANT, UNIT NOS. 1 AND 2 DOCKET NOS. 50-321 AND 50-366

1.0 INTRODUCTION

By application dated April 20, 2017 (Agencywide Documents Access and Management System (ADAMS) Accession No. ML 17114A377)

(Reference 1 ), as supplemented by letters dated September 14, 2017 (ADAMS Accession No. ML 17257 A375) (Reference 2), February 19, 2018 (ADAMS Accession No. ML 18050A052)

(Reference 3), and May 1, 2018 (ADAMS Accession No. ML 18121A398)

(Reference 4), Southern Nuclear Operating

Company, Inc. (SNC, the licensee) requested to adopt Technical Specifications Task Force (TSTF) Traveler TSTF-542, Revision 2, "Reactor Pressure Vessel Water Inventory Control,"

which would change the Technical Specifications (TSs) for the Edwin I. Hatch Nuclear Plant (HNP), Unit Nos. 1 and 2. TSTF-542, Revision 2, was approved by the U.S. Nuclear Regulatory Commission (NRC) on December 20, 2016 (ADAMS Accession No. ML 163438008)

(Reference 5). The proposed changes would replace existing TSs requirements associated with "operations with a potential for draining the reactor vessel,"

(OPDRVs) with revised TSs providing alternative requirements for Reactor Pressure Vessel (RPV) Water Inventory Control (WIC). These alternative requirements would ensure that Safety Limit 2.1.1.3 is met. HNP TS Section 2.0, "Safety Limits (SLs)," 2.1.1.3, states, "Reactor vessel water level shall be greater than the top of active irradiated fuel." Additionally, a new definition, "DRAIN TIME," would be added to the HNP TSs, Section 1.1, "Definitions."

DRAIN TIME would establish requirements for the licensee to make RPV water level inventory determinations and to calculate RPV water inventory drain rates for MODE 4 and 5 outage-related activities.

Adequate licensee management of secondary containment requirements or mitigation of certain emergency core cooling system (ECCS) safety injection/spray systems during MODE 4 and 5 requires a properly calculated DRAIN TIME. Enclosure 3 The licensee has proposed several variations from the TS changes described in the applicable parts of TSTF-542, Revision 2, as approved by the NRC in the safety evaluation for TSTF-542 (Reference 5). These are explained below in Section 2.2.5 and evaluated in Section 3.5 of this safety evaluation (SE). The supplements dated September 14, 2017, and February 19 and May 1, 2018, provided additional information that clarified the application, did not expand the scope of the application as originally

noticed, and did not change the NRC staff's original proposed no significant hazards consideration determination as published in the Federal Register on August 29, 2017 (82 FR 41071). 2.0 2.1 REGULATORY EVALUATION System Description Boiling water reactor (BWR) RPVs have a number of penetrations located below the top of active fuel (TAF). These penetrations provide entry for control rods, recirculation flow, and shutdown cooling.

Since these penetrations are below the TAF, this creates a potential to drain the reactor vessel water inventory and lose effective core cooling.

The loss of water inventory and effective core cooling can potentially lead to fuel cladding failure and radioactive release.

During operation in Modes 1 (Power Operation

-Reactor Mode Switch in Run), 2 (Startup

-Reactor Mode Switch in Refuel (with all reactor vessel head closure bolts fully tensioned) or Startup/Hot Standby),

and 3 (Hot Shutdown

-Reactor Mode Switch in Shutdown and average reactor coolant temperature>

212 degrees Fahrenheit

(°F)), the TS for instrumentation and ECCS require operability of sufficient equipment to ensure large quantities of water will be injected into the vessel should level decrease below the preselected value. These requirements are designed to mitigate the effects of a loss-of-coolant accident (LOCA), but also provide protection for other accidents and transients that involve a water inventory loss. During BWR operation in Mode 4 (Cold Shutdown

-Reactor Mode Switch in Shutdown with all reactor vessel head closure bolts fully tensioned and average reactor coolant temperature

212 °F), and Mode 5 (Refueling

-one or more reactor vessel head closure bolts less than fully tensioned and Reactor Mode Switch in Shutdown or Refuel),

the pressures and temperatures that could cause a LOCA are not present.

During certain phases of refueling (Mode 5), a large volume of water is available above the RPV (i.e., the RPV head is removed, the water level is .:: 22 feet-1/8 inches over the top of the RPV flange, and the spent fuel storage pool gates are removed).

The large volume of water available in and above the RPV during much of the time when in Mode 5 provides time for operator detection and manual operator action to stop and mitigate an RPV draining event. However, at other times during a refueling outage, such as during Cold Shutdown (Mode 4) or Refueling (Mode 5), there may be a potential for significant drainage paths from certain outage activities, human error, and other events when it is more likely to have some normally available equipment, instrumentation, and systems inoperable due to maintenance and outage activities.

There may not be as much time for operator action as compared to times when there are large volumes of water above the RPV. In comparison to Modes 1, 2, and 3, with typical high temperatures and pressures (especially in Modes 1 and 2), Modes 4 and 5 generally do not have the high pressure and temperature considered necessary for a postulated LOCA due to a high energy pipe failure.

Thus, while the potential sudden loss of a large volume of water from a LOCA is not expected, operators still monitor BWR RPV water level to detect any decrease from potential significant or unexpected drainage paths. These potential drainage paths in Modes 4 and 5 generally would require less water replacement capability to maintain water above TAF. To address the drain down potential during Modes 4 and 5, the current HNP TSs contain specifications that are applicable during an OPDRV, or require suspension of OPDRVs if certain equipment is inoperable.

The term OPDRV is not specifically defined in the TS and historically has been subject to inconsistent application by licensees.

The changes discussed in this SE are intended to resolve ambiguity by creating a new RPV WIC TS with associated equipment operability requirements, required

actions, and surveillance requirements (SRs), and conforming deletion of references to OPDRVs throughout the TSs. 2.2 Proposed TS Changes Section 2.2.1 discusses the proposed addition of a new definition, "DRAIN TIME" (evaluated below in Section 3.1 ). Section 2.2.2 discusses the proposed revisions to TS 3.3, "Instrumentation,"

including the proposed revisions to TS 3.3.5.1, "Emergency Core Cooling System (ECCS) Instrumentation,"

the proposed addition of new TS 3.3.5.2, "Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation" (including Table 3.3.5.2-1

), and the proposed renumbering of existing TS 3.3.5.2, "Reactor Core Isolation Cooling (RCIC) System Instrumentation" to 3.3.5.3.

Section 2.2.3 discusses the proposed revisions to TS 3.5, "Emergency Core Cooling System (ECCS) and Reactor Core Isolation Cooling (RCIC) System,"

including the proposed revisions to TS 3.5.2, "ECCS -Shutdown" (evaluated below in Section 3.3). Section 2.2.4 discusses the proposed deletion of existing TS references to OPDRVs (evaluated below in Section 3.6). Section 2.2.5 discusses HNP plant-specific variations to TSTF-542, Revision 2 (evaluated below in Section 3.5). 2.2.1 Addition of DRAIN TIME Definition The following definition of "DRAIN TIME" would be added to Section 1.1, "Definitions":

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

a. The water inventory above the TAF is divided by the limiting drain rate; b. The limiting drain rate is the larger of the drain rate through a single penetration flow path with the highest flow rate, or the sum of the drain rates through multiple penetration flow paths susceptible to a common mode failure (e.g., seismic event, loss of normal power, single human error), for all penetration flow paths below the 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. 2.2.2 TS 3.3, "Instrumentation" The following subsections describe the existing and proposed changes to the HNP TS, Section 3.3, "Instrumentation."

2.2.2.1 TS 3.3.5.1, "Emergency Core Cooling System (ECCS) Instrumentation" Proposed changes to TS 3.3.5.1 include the deletion of Note 1 in Required Actions 8.1, C.1, and E.1 which states: "Only applicable in Modes 1, 2 and 3." For Table 3.3.5.1-1, the applicability in Modes 4 and 5 was proposed for deletion because the instrumentation requirements during shutdown would be consolidated into the new TS 3.3.5.2, "Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation."

Modes 4 and 5 Applicability and associated requirements would be deleted for the following functions:

1. Core Spray System; (a) Reactor Vessel Water Level -Low Low Low, Level 1 (c) Reactor Steam Dome Pressure

-Low (Injection Permissive)

(d) Core Spray Pump Discharge Flow-Low (Bypass)

2. Low Pressure Coolant Injection (LPCI) System; (a) Reactor Vessel Water Level -Low Low Low, Level 1 (c) Reactor Steam Dome Pressure

-Low (Injection Permissive)

(f) Low Pressure Coolant Injection Pump Start -Time Delay Relay (Pumps A, B, C, and D) (g) Low Pressure Coolant Injection Pump Discharge Flow -Low (Bypass)

Table 3.3.5.1-1 Footnote (a), which states, "When associated subsystem(s) are required to be OPERABLE,"

would be deleted.

As a result, existing Footnotes (b), (c), and (d) would be renumbered (a), (b),

and (c), respectively.

2.2.2.2 New TS 3.3.5.2, "Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation" The proposed new TS 3.3.5.2 would contain functions that are comprised of requirements moved from TSs 3.3.5.1 and 3.3.6.1, as well as new requirements.

The proposed new TS 3.3.5.2 is shown below: 3.3.5.2 LCO 3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation The RPV Water Inventory Control instrumentation for each Function in Table 3.3.5.2-1 shall be OPERABLE.

APPLICABILITY:

According to Table 3.3.5.2-1.

ACTIONS ---------------------------------------------------NOTE------------------------------------------------------------------

Separate Condition entry is allowed for each channel.

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

1 for the channel.

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

isolation.

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

D. As required by D.1 Restore channel to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Required Action A.1 OPERABLE status. and referenced in Table 3.3.5.2-1.

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

not met. SURVEILLANCE REQUIREMENTS

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

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

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

SR 3.3.5.2.2 Perform CHANNEL FUNCTl()NAL TEST. In accordance with the Surveillance Frequency Control Program.

1. 2. 3. 4. Table 3.3.5.2-1 (Page 1 of 1) RPV Water lnventorv Control lnstrumentaf APPLICABLE CONDITIONS MODES REQUIRED REFERENCED OR OTHER CHANNELS FROM SURVEILLANCE SPECIFIED PER REQUIRED REQUIREMENTS ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 VALUE Core Spray System a. Reactor Steam Dome Pressure

-Low (Injection 4,5 4(a) C SR 3.3.5.2.1 s; 476 psig Permissive)

SR 3.3.5.2.2

b. Core Spray Pump Discharge Flow-Low (Bypass) 4,5 1 per D SR 3.3.5.2.1 e:: 610 gpm and subsystem (a) SR 3.3.5.2.2 s; 825 gpm Low Pressure Coolant Injection (LPCI) System a. Reactor Steam Dome Pressure

-Low (Injection 4,5 4(a) C SR 3.3.5.2.1 s; 476 psig Permissive)

SR 3.3.5.2.2

b. Low Pressure Coolant Injection Pump Discharge 4,5 1 per D SR 3.3.5.2.1 e:: 1670 gpm and Flow-Low (Bypass) subsystem SR 3.3.5.2.2 s; 2205 gpm (a),(c) RHR System Isolation

a. Reactor Vessel Water Level -Low, Level 3 (b) 2 in one trip B SR 3.3.5.2.1 2: 0 / system SR 3.3.5.2.2 inches Reactor Water Cleanup (RWCU) System Isolation

a. Reactor Vessel Water Level -Low Low, Level 2 (b) 2 in one trip B SR 3.3.5.2.1 e:: -47 system SR 3.3.5.2.2 inches (a) Associated with an ECCS subsystem required to be OPERABLE by LCO 3.5.2, "Reactor Pressure Vessel Water Inventory Control."

(b) When automatic isolation of the associated penetration flow path(s) is credited in calculating DRAIN TIME. (c) Function not required to be OPERABLE while associated pump is operating in decay heat removal when minimum flow valves is closed and deactivated. 2.2.2.3 TS 3.3.5.2, "Reactor Core Isolation Cooling (RCIC) System Instrumentation" The existing TS 3.3.5.2, "Reactor Core Isolation Cooling (RCIC) System Instrumentation,"

and its subsections would be renumbered to TS 3.3.5.3 in order to maintain the TS numbering conventions.

2.2.2.4 TS 3.3.6.1, "Primary Containment Isolation Instrumentation" In TS Table 3.3.6.1-1, Function 6.b, Residual Heat Removal (RHR) Shutdown Cooling System Isolation, Reactor Vessel Water Level -Low, Level 3, the applicability in Modes 4 and 5 was proposed for deletion.

Also, Footnote (d) to Table 3.3.6.1-1 was proposed to be deleted, as it is applicable only to Function 6.b during Modes 4 and 5. This function would be moved to the new TS Table 3.3.5.2-1, Function 3.a, as shown in Section 2.2.2.2 of this SE. In TS LCO 3.3.6.1, Required Action J.2 was proposed for deletion since it was associated with the isolation of Residual Heat Removal/Shutdown Cooling (RHR/SDC) during Modes 4 and 5. 2.2.3 TS Section 3.5, "Emergency Core Cooling System (ECCS) and Reactor Core Isolation Cooling (RCIC) System" The title of TS Section 3.5 would be revised from "Emergency Core Cooling System (ECCS) and Reactor Core Isolation Cooling (RCIC) System" to "Emergency Core Cooling Systems (ECCS), RPV Water Inventory

Control, and Reactor Core Isolation Cooling (RCIC) System."

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

and TS 3.5.2 would be revised as follows:

LCO 3.5.2 DRAIN TIME of RPV water inventory to the top of active fuel (TAF) shall be ;;:: 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . One low pressure ECCS injection/spray subsystem shall be OPERABLE.

APPLICABILITY:

MODES 4 and 5 ACTIONS CONDITION A. Required ECCS injection/spray subsystem inoperable.

B. Required Action and associated Completion Time of Condition A not met. C. DRAIN TIME < 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months and 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . REQUIRED ACTION COMPLETION TIME A.1 Restore required ECCS 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months injection/spray subsystem to OPERABLE status. 8.1 Initiate action to establish a Immediately method of water injection capable of operating without offsite electrical power. C.1 Verify secondary containment 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months boundary is capable of being established in less than the DRAIN TIME. AND C.2 Verify each secondary 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months containment penetration flow path is capable of being isolated in less than the DRAIN TIME. AND C.3 Verify required standby gas 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months treatment subsystem(s) are capable of being placed in operation in less than the DRAIN TIME. CONDITION REQUIRED ACTION COMPLETION TIME D. DRAIN TIME< 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . D.1--------------NOTE------------

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

Initiate action to establish an Immediately additional method of water injection with water sources capable of maintaining RPV water level > TAF for 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . AND D.2 Initiate action to establish Immediately secondary containment boundary.

AND D.3 Initiate action to isolate each Immediately secondary containment penetration flow path or verify it can be manually isolated from the control room. AND D.4 Initiate action to verify required Immediately standby gas treatment subsystem(s) are capable of being placed in operation.

E. Required Action and E.1 Initiate action to restore DRAIN Immediately associated Completion TIME to 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . Time of Condition C or D not met. OR DRAIN TIME < 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . The proposed SRs for TS 3.5.2 are shown below: SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify DRAIN TIME ..::: 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . In accordance with the Surveillance Frequency Control Program SR 3.5.2.2 Verify, for a required low pressure coolant injection In accordance with the (LPCI) subsystem, the suppression pool water level Surveillance Frequency is..::: 146 inches. Control Program SR 3.5.2.3 Verify, for a required Core Spray (CS) subsystem, In accordance with the the: Surveillance Frequency Control Program a. Suppression pool water level is ..::: 146 inches; or b. Condensate storage tank water level is ..:::13ft.

SR 3.5.2.4 Verify, for the required ECCS injection/spray In accordance with the subsystem, locations susceptible to gas accumulation Surveillance Frequency are sufficiently filled with water. Control Program SR 3.5.2.5 --------------------N()TES-----------------------------

1. A Low Pressure Coolant Injection (LPCI) subsystem may be considered

()PERABLE during alignment and operation for decay heat removal if capable of being manually realigned and not otherwise inoperable.

2. Not required to be met for system vent flowpaths opened under administrative control.

Verify for the required ECCS injection/spray In accordance with the subsystem, each manual, power operated, and Surveillance Frequency automatic valve in the flow path, that is not locked, Control Program sealed, or otherwise secured in position, is in the correct position.

SR 3.5.2.6 ()perate the required ECCS injection/spray In accordance with the subsystem through the recirculation line for Surveillance Frequency

..::: 10 minutes.

Control Program SR 3.5.2.7 Verify each valve credited for automatically isolating In accordance with the a penetration flow path actuates to the isolation Surveillance Frequency position on an actual or simulated isolation signal. Control Program SURVEILLANCE FREQUENCY SR 3.5.2.8 ---------------------N()'TE--------------------------------

Vessel injection/spray may be excluded.

Verify the required ECCS injection/spray subsystem In accordance with the can be manually operated.

Surveillance Frequency Control Program 2.2.4 Deletion of References to ()PDRVs 'The licensee proposed to delete references to ()PDRVs throughout the HNP l"Ss. 'These l"Ss contain one or more OPDRVs references, such as, the conditional Applicability "during operations with a potential for draining the reactor vessel (OPDRVS),"

or if certain conditions are not met, the required actions direct the licensee to "initiate action to suspend operations with a potential for draining the reactor vessel (()PDRVs)."

'The following table is a list of these l"Ss and their affected sections:

HNP LC() Location of OPDRVs References 3.3.6.1, Primary Containment Isolation

'Table 3.3.6.1-1 Footnote (d) Instrumentation (see Section 2.2.2.4 of this SE) 3.3.6.2, Secondary Containment Isolation

'Table 3.3.6.2-1 Footnote (a) Instrumentation 3.3.7.1, Main Control Room Environmental Applicability Control (MCREC) System Instrumentation 3.6.1.3, Primary Containment Isolation Required Action F.1 Valves (PCIVs) 3.6.4.1, Secondary Containment Applicability, and Condition C, Required Action C.3 3.6.4.2, Secondary Containment Isolation Applicability, and Condition D, Required Valves (SCIVs) Action D.3 3.6.4.3, Standby Gas 'Treatment (SG'T) Applicability; Condition D, Required Action System D.2.3; and Condition F, Required Action F.3 3.7.4, Main Control Room Environmental Applicability; Condition D, Required Action Control (MCREC) System D.2.3; and Condition F, Required Action F.3 3.7.5, Control Room Air Conditioning (AC) Applicability; Condition E, Required Action System E.2.3; and Condition F, Required Action F.3 3.8.2, AC Sources -Shutdown Condition A, Required Action A,2,3, and Condition 8, Required Action 8.3 3.8.5, DC Sources -Shutdown Condition C, Required Action C.2.3 3.8.8, Distribution Systems -Shutdown Condition A, Required Action A.2.3 2.2.5 HNP Plant-Specific TSTF-542 TS Variations The licensee proposed the following technical variations (9 total) from the TS changes described in TSTF-542 or the applicable parts of the NRC staffs SE. The licensee stated in the License Amendment Request (LAR) that these variations do not affect the applicability of TSTF-542 or the NRC staffs SE to the proposed license amendment.

Specific details of these variations are described in the LAR. 2.2.5.1 Variation 1, Supported Feature TS 3.3.5.1 Conditions 8.1, C.1, and E.1 state "Declare supported feature(s) inoperable."

The TSTF-542 markups state, "Declare supported feature(s) inoperable when its redundant feature ECCS initiation capability is inoperable."

The completion time for both HNP and the Standard Technical Specifications (STS) state, "1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery of loss of initiation capability for feature(s) in both divisions."

2.2.5.2 Variation 2, CS and LPCI Flow Transmitter The HNP core spray (CS) and low pressure coolant injection (LPCI) subsystems have one flow transmitter per ECCS subsystem to detect the associated subsystems' flow rates, whereas the STS assume one flow transmitter per ECCS pump to detect the associated subsystems' flow rates. Each HNP CS subsystem has one CS pump, and each HNP LPCI subsystem has two RHR pumps. The licensee proposes to maintain the one channel per subsystem requirement for new Table 3.3.5.2-1.

The licensee stated that, although for the CS subsystem this deviation of "1 per subsystem" versus "1 per pump" is editorial, keeping "1 per subsystem" will maintain consistency with the current language.

2.2.5.3 Variation 3, TS Table 3.3.5.2-1 Footnote The licensee is proposing to add a note to TS Table 3.3.5.2-1 to clarify the intent of allowing credit for an OPERABLE LPCI subsystem when it is aligned and operating in the decay heat removal mode of RHR. The licensee states that this is appropriate since the associated RHR pump minimum flow valve (while operating in the decay heat removal mode) is closed and deactivated to prevent inadvertent vessel drain down events. Because the minimum flow valve is closed and deactivated, the associated TS Table 3.3.5.2-1 Function 2.b would not be required to be OPERABLE.

Without the note, TS 3.3.5.2 Condition D would require that the associated RHR pump be declared inoperable, which would be contrary to the intent of the SR 3.5.2.4 (new SR 3.5.2.5)

Note which allows the LPCI subsystem to be OPERABLE when aligned for decay heat removal.

2.2.5.4 Variation 4, Manual Initiation Logic The HNP TS do not include a manual initiation logic function for the CS or LPCI subsystems.

Considering the logic design, there is not a single switch that will start all subsystems of the associated ECCS system as is assumed in the STS. HNP does, however, have the capability to manually start the ECCS pumps individually.

Since the manual initiation logic function does not exist at HNP, manual initiation functions for LPCI and CS are not proposed to be included in TS Table 3.3.5.2-1.

Additionally, since the manual initiation functions are not proposed to be included in TS Table 3.3.5.2-1, the associated Logic System Functional Test would likewise not be required for TS 3.3.5.2; therefore, TS 3.3.5.2 as proposed for HNP would not include a Logic System Functional Test surveillance requirement. As an alternative, the licensee proposes that TS 3.5.2 include an SR to verify that the HNP LPCI and CS subsystems can be manually operated through the manipulation of subsystem components from the Main Control Room. Proposed SR 3.5.2.8 would state: "Verify the required ECCS injection/spray subsystem can be manually operated."

The licensee states that the manual operations of the LPCI and CS subsystems for the control of reactor cavity or RPV inventory are relatively simple evolutions and involve the manipulation of a small number of components.

These subsystem alignments can be performed by licensed operators from the Main Control Room as described in HNP site procedures.

2.2.5.5 Variation 5, LPCI Realignment The STS Note on LCO 3.5.2 regarding realignment to the LPCI mode is located in HNP's SR 3.5.2.4 (new SR 3.5.2.5).

2.2.5.6 Variation 6, TS 3.6.1.3 Condition F HNP TS 3.6.1.3 Condition F (which corresponds to STS Condition H) does not contain the phrase "or during operations with a potential for draining the reactor vessel (OPDRVs)."

This phrase is deleted from the STS per TSTF-542.

Since OPDRVs are only performed in MODE 4 or MODE 5, this phrase that was contained in the STS was unnecessary.

2.2.5.7 Variation 7, Inverters HNP does not have an "Inverters

-Operating" or an "Inverters

-Shutdown" TS. As stated in the HNP improved TS Conversion, "Inverters, as utilized in the NUREG-1433 STS [References 7 and 8) (i.e., inverters that power many required systems and that are required to be powered by the DC sources to meet accident analysis assumptions),

do not exist in the HNP. As such, NUREG-1433 LCO 3.8.7 and LCO 3.8.8, their associated Bases, and all references to them have been deleted.

The LCOs that follow have been renumbered to reflect this deletion.

The only inverters that need to be powered from DC sources are the LPCI inverters, which only provide power to the LPCI subsystems.

These two inverters are covered by an SR in NUREG[-1433)

LCO 3.5.1 (ECCS) since they only impact the LPCI subsystems."

2.2.5.8 Variation 8, Surveillance Frequency Control Program The HNP TSs contain a Surveillance Frequency Control Program (SFCP). Therefore, the Surveillance Requirement Frequencies for Specifications 3.3.5.2 and 3.5.2 are "In accordance with the Surveillance Frequency Control Program."

HNP is adopting the recommended frequencies in TSTF-542 (within the SFCP), except that the SR 3.3.5.2.2 frequency to perform CHANNEL FUNCTIONAL TEST will be "92 days on an AL TERNA TE TEST BASIS." 2.2.5.9 Variation 9, Table 3.3.5.2-1 on Applicability of ECCS Functions In accordance with TSTF-542, TS Table 3.3.5.2-1, Function 1.a (Core Spray System, Reactor Steam Dome Pressure

-Low (Injection Permissive)),

and Function 2.a (Low Pressure Coolant Injection (LPCI), Reactor Steam Dome Pressure

-Low (Injection Permissive))

are required in Modes 4 and 5. Prior to TSTF-542

, the analogous Functions 1.c and 2.c in HNP TS Table 3.3.5.1-1 had a Mode 4 and 5 applicability modified by a footnote specifying that these functions were only required when the associated ECCS subsystem(s) were required to be operable per LCO 3.5.2, "ECCS -Shutdown."

The footnote was inadvertently omitted from Table 3.3.5.2-1, Functions 1.a and 2.a in TSTF-542.

The licensee proposed a variation to affix Footnote (a) (i.e., "Associated with an ECCS subsystem required to be OPERABLE by LCO 3.5.2, 'Reactor Pressure Vessel Water Inventory Control"')

to TS Table 3.3.5.2-1 to correct the omission.

2.3 Applicable Regulatory Requirements The regulation at Title 10 of the Code of Federal Regulations (10 CFR), Section 50.36(a)(1

), requires an applicant for an operating license to include in the application proposed TSs in accordance with the requirements of 10 CFR 50.36. The applicant must also include in the application a "summary statement of the bases or reasons for such specifications, other than those covering administrative controls."

However, per 10 CFR 50.36(a)(1

), these TS bases "shall not become part of the technical specifications."

As required by 10 CFR 50.36(c)(1

)(i)(a),

TSs will include items in the following categories:

(1) Safety limits, limiting safety system settings, and limiting control settings.

(i)(A) Safety limits for nuclear reactors are limits upon important process variables that are found to be necessary to reasonably protect the integrity of certain of the physical barriers that guard against the uncontrolled release of radioactivity.

If any safety limit is exceeded, the reactor must be shut down. The licensee shall notify the Commission, review the matter, and record the results of the review, including the cause of the condition and the basis for corrective action taken to preclude recurrence.

Operation must not be resumed until authorized by the Commission.

As required by 10 CFR 50.36(c)(2)(i),

the TSs will include LCOs, which are the lowest functional capability or performance levels of equipment required for safe operation of the facility.

Per 1 O CFR 50.36(c)(2)(i),

when an LCO of a nuclear reactor is not met, the licensee shall shut down the reactor or follow any remedial action permitted by the TSs until the condition can be met. The regulation at 1 O CFR 50.36(c)(2)(ii) requires licensees to establish TS LCOs for items meeting one or more of the listed criteria.

Specifically, Criterion 4, "A structure, system, or component which operating experience or probabilistic risk assessment has shown to be significant to public health and safety,"

supports the establishment of LCOs for RPV WIC due to insights gained via operating experience.

The regulation at 10 CFR 50.36(c)(3) requires TSs to include items in the category of SRs, which are requirements relating to test, calibration, or inspection to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the LCOs will be met. Pursuant to 10 CFR 50.90, whenever a holder of an operating license desires to amend the license, application for an amendment must be filed with the Commission fully describing the changes desired, and following as far as applicable, the form prescribed for original applications.

The technical information to be included in an application for an operating license is governed in particular by 10 CFR 50.34(b).

As described in 10 CFR 50.92(a),

in determining whether an amendment to a license will be issued to the applicant, the Commission will be guided by the considerations which govern the issuance of initial licenses to the extent applicable and appropriate.

The general considerations that guide the Commission

include, as stated in 10 CFR 50.40(a),

how the TSs provide reasonable assurance that the health and safety of the public will not be endangered.

Also, to issue an operating

license, of which TSs are a part, the Commission must make the findings of 10 CFR 50.57, including finding the 10 CFR 50.57(a)(3)(i) finding that there is reasonable assurance that the activities authorized by the operating license can be conducted without endangering the health and safety of the public. As part of the regulatory standardization effort, the NRC staff has prepared STS for each of the light-water reactor nuclear designs.

NUREG-1433, Volumes 1 and 2, Revision 4 (References 7 and 8), contains the STS for BWR/4 plants. The approved changes to the STS in TSTF-542 will be incorporated into future revisions of NUREG-1433.

The NRC staff's guidance for review of TSs is in Chapter 16, Technical Specifications, of NUREG-0800, Revision 3, "Standard Review Plan for the Review of Safety Analysis Reports for Nuclear Power Plants" (SRP), dated March 2010 (ADAMS Accession No. ML 100351425)

(Reference 6). 2.3.1 Applicable Regulatory Design Requirements for HNP Unit Nos. 1 and 2 HNP Unit No. 1 Final Safety Analysis Report (FSAR) Appendix F, "Conformance to Atomic Energy Commission (AEC) Criteria,"

describes the evaluation of the applicable design criteria.

Section F.2 of this appendix contains an evaluation of the HNP Unit No. 1 design criteria based on the current understanding of the intent of the "General Design Criteria for Nuclear Power Plant Construction,"

(GDC) issued for comment in July 1967. Section F.3 contains an evaluation of the unit's design criteria based on the current understanding of the intent of the "General Design Criteria for Nuclear Power Plants,"

effective May 21, 1971, and subsequently amended July 7, 1971. Each of the AEC criteria is followed by a discussion of the plant design. Applicable references are made to facilitate comparisons.

The HNP Unit No. 1 construction permit was received under the 70 general design criteria discussed in FSAR Section F.2. Therefore, the HNP Unit No. 1 design bases were not explicitly developed in consideration of the 64 newer general design criteria discussed in Section F.3. The applicant has, however, evaluated the HNP Unit No. 1 design bases against the newer criteria.

Therefore, the design criteria listed below were considered in the NRC staff's review of this LAR for HNP Unit No. 1. HNP Unit No. 2 FSAR Section 3.1, "Conformance with Nuclear Regulatory Commission (NRC) General Design Criteria,"

describes the evaluation of the applicable design criteria for Unit No. 2. The following design criteria were considered in the NRC staff's review of this LAR for HNP Unit No. 2. Criterion 13 -Instrumentation and control.

Instrumentation shall be provided to monitor variables and systems over their anticipated ranges for normal operation, for anticipated operational occurrences, and for accident conditions as appropriate to assure adequate safety, including those variables and systems that can affect the fission process, the integrity of the reactor core, the reactor coolant pressure boundary (RCPB), and the containment and its associated systems.

Appropriate controls shall be provided to maintain these variables and systems within prescribed operating ranges. Criterion 14 -Reactor coolant pressure boundary.

The reactor coolant pressure boundary

[RCPB] shall be designed, fabricated,

erected, and tested to have an extremely low probability of abnormal

leakage, of rapidly propagating

failure, and of gross rupture.

Criterion 30 -Quality of reactor coolant pressure boundary.

Components which are part of the [RCPB] shall be designed, fabricated,

erected, and tested to the highest quality standards practical.

Means shall be provided for detecting and, to the extent practical, identifying the location of the reactor coolant leakage source. Criterion 33 -Reactor coolant makeup. A system to supply reactor coolant makeup for protection against small breaks in the reactor coolant pressure boundary

[RCPB] shall be provided.

The system safety function shall be to assure that specified acceptable fuel design limits are not exceeded as a result of reactor coolant loss due to leakage from the [RCPB] and rupture of small piping or other small components which are part of the boundary.

The system shall be designed to assure that for onsite electric power system operation (assuming offsite power is not available) and for offsite electric power system operation (assuming onsite power is not available) the system safety function can be accomplished using the piping, pumps, and valves used to maintain coolant inventory during normal reactor operation.

Criterion 35 -Emergency core cooling.

A system to provide abundant emergency core cooling shall be provided.

The system safety function shall be to transfer heat from the reactor core following any loss of reactor coolant at a rate such that (1) fuel and clad damage that could interfere with continued effective core cooling is prevented and (2) clad metal-water reaction is limited to negligible amounts.

Suitable redundancy in components and features and suitable interconnections, leak detection, isolation, and containment capabilities shall be provided to assure that for onsite electric power system operation (assuming offsite power is not available) and for offsite electric power system operation (assuming onsite power is not available) the system safety function can be accomplished, assuming a single failure.

3.0 TECHNICAL EVALUATION Section 2.2 of this SE lists the proposed TS changes, as included in References 1 through 4, for the licensee to adopt TSTF-542, Revision

2. The following sections of the SE summarize the NRC staff's evaluation of each of these proposed changes.

3.1 Staff Evaluation of Proposed DRAIN TIME Definition As discussed in Section 2.2.1 above, the DRAIN TIME is the time it would take the RPV water inventory to drain from the current level to the TAF assuming the most limiting of the RPV penetrations flow paths with the largest flow rate, or a combination of penetration flow paths that could open due to a common mode failure, were to open and the licensee took no mitigating action. The NRC staff reviewed the proposed drain time definition from the TSTF-542 traveler.

For the purpose of NRC staff considerations, the term "break" describes a pathway for water to drain from the RPV that has not been prescribed in the "DRAIN TIME" definition in TSTF-542.

Based on information furnished by the licensee, the NRC staff has determined that the licensee is appropriately adopting the principles of Drain Time as specified in TSTF-542.

The NRC has reasonable assurance that the licensee will include all RPV penetrations below the TAF as potential pathways in the determination of drain time. As part of this evaluation, the NRC staff reviewed requests for additional information issued during the development of TSTF-542, Revision 2, which provided examples of bounding drain time calculations for three cases: ( 1) water level at or below the RPV flange; (2) water level above the RPV flange with fuel pool gates installed; and (3) water level above the RPV flange with fuel pool gates removed.

The drain time is calculated by taking the water inventory above the break and dividing by the limiting drain rate until the TAF is reached.

The limiting drain rate is a variable parameter depending on the break size and the reduction of elevation head above break location during the drain down event. The discharge point will depend on the lowest potential drain point for each RPV penetration flow path on a plant-specific basis. This calculation provides a conservative approach to determining the drain time of the RPV. The NRC staff concluded that reasonable assurance exists that the licensee will use methods resulting in conservative calculations to determine RPV drain time, thereby, protecting Safety Limit 2.1.1.3, Which meets the requirements of 10 CFR 50.36(c)(3).

Therefore, the NRC staff concludes that the licensee's proposed addition of DRAIN TIME to Section 1.1, "Definitions,"

of the HNP TSs is acceptable.

3.2 Staff Evaluation of Proposed TS 3.3.5.2, "Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation" The existing HNP TS 3.3.5.2, "Reactor Core Isolation Cooling (RCIC) System Instrumentation,"

would be renumbered as TS 3.3.5.3.

This is an administrative change that achieves consistency within the HNP TSs and is acceptable.

The purpose of the proposed new TS 3.3.5.2 regarding RPV WIC Instrumentation is to support the requirements of revised TS LCO 3.5.2, and the proposed new definition of drain time. There are instrumentation and controls and their signal functions that are required for manual pump starts, or required as permissive or operational controls on the equipment and systems that provide water injection capability, certain start commands, pump protection, and isolation functions.

These instruments are required to be operable if the systems that provide water injection and isolation functions are to be considered

operable, as described in Section 3.3 of this SE for revised TS 3.5.2. For HNP, reactor operators have alternate, often more complex, means of starting and injecting water than the preferred simple push button start. Specifically, the proposed new TS 3.3.5.2 regarding RPV WIC Instrumentation supports operation of the CS and LPCI systems, including manual starts when needed, as well as the system isolation of the RHR system and the RWCU system. The equipment involved with each of these systems is described in the evaluation of TS 3.5.2 and the Bases for LCO 3.5.2. 3.2.1 Staff Evaluation of Proposed TS 3.3.5.2 LCO and Applicability In the LAR, the licensee proposed a new TS 3.3.5.2 to provide alternative instrumentation requirements to support manual initiation of the ECCS injection/spray subsystem required in revised TS 3.5.2 and automatic isolation of penetration flow paths that may be credited in the determination of DRAIN TIME. The current TSs contain instrumentation requirements related to OPDRVs in TS Table 3.3.5.1-1, TS Table 3.3.6.1-1, TS Table 3.3.6.2-1, and TS 3.3.7.1.

The requirements from Table 3.3.5.1-1 and Table 3.3.6.1-1 would be consolidated into new TS 3.3.5.2.

The proposed LCO 3.3.5.2 would state: The RPV Water Inventory Control instrumentation for each Function in Table 3.3.5.2-1 shall be OPERABLE.

The proposed Applicability would state: According to Table 3.3.5.2-1.

TSTF-542 selected Table 3.3.5.2-1 to contain those instrumentation Functions needed to support manual initiation of the low pressure ECCS injection/spray subsystem required by LCO 3.5.2, and automatic isolation of penetration flow paths that may be credited in a calculation of drain time. The Functions in Table 3.3.5.2-1 are moved from existing TS 3.3.5.1, "Emergency Core Cooling System (ECCS) Instrumentation,"

and TS 3.3.6.1, "Primary Containment Isolation Instrumentation" Functions that are required in Modes 4 or 5 or during OPDRVs. Creation of TS 3.3.5.2 places these Functions in a single location with requirements appropriate to support the safety function for TS 3.5.2. If plant-specific design and TSs require different functions to support manual initiation of a low pressure ECCS subsystem, those functions should be included in TS 3.3.5.2.

The NRC staff concluded that the licensee's proposed alternative is acceptable for HNP since either CS or LPCI (or both) subsystems would be available to perform the intended function to inject water into the RPV, which meets the conditions of the NRG-approved TSTF-542.

3.2.2 Staff Evaluation of Proposed TS 3.3.5.2 Actions For the changes described in detail in Section 2.2.2.2 above, the NRC staff has determined that the licensee's proposed new TS 3.3.5.2 Actions are sufficient and necessary, because when one or more instrument channels are inoperable, the equipment controlled by these instruments cannot complete the required functions in the normal manner. The Actions are evaluated as follows; Action A would be applicable when one or more instrument channels are inoperable from Table 3.3.5.2-1 and directs the licensee to immediately enter the Condition referenced in Table 3.3.5.2-1 for that channel.

Action B (concerning the RHR system isolation and RWCU system isolation functions) would be applicable when automatic isolation of the associated penetration flow path is credited as a path for potential drainage in calculating drain time. If the instrumentation is inoperable, Required Action 8.1 directs an immediate declaration that the associated penetration flow path(s) are incapable of automatic isolation.

Required Action 8.2 requires an immediate re-calculation of drain time, but automatic isolation of the affected penetration flow paths cannot be credited.

Action C (concerning low reactor steam dome pressure permissive Functions necessary for low pressure ECCS subsystem manual injection valve opening) would address an event in which the permissive is inoperable.

The function must be placed in the trip condition within one hour. With the permissive function instrument in the trip condition, manual injection valve opening may now be performed using the preferred control board switches.

This one-hour completion time is acceptable,

because, despite the preferred start method being prevented, the reactor operator can take manual control of the pump and the injection valve to inject water into the RPV and achieve the safety function in that time. The time of one hour also provides reasonable time for evaluation and placing the channel in trip. Action D (concerning pump discharge flow bypass Functions) would address actions when the bypass is inoperable and then there is a risk that the associated low pressure ECCS pump could overheat when the pump is operating and the associated injection valve is not fully open. In this condition, the operator can take manual control of the pump and the injection.

Similar to the justification for Action C, while this is not the preferred method, the CS and LPCI subsystem pumps can be started manually and the valves can be opened manually.

The 24-hour completion time is acceptable, because the functions can be performed manually and it allows time for the operator to evaluate the condition and have necessary repairs completed.

Action E would be needed, and become necessary, if the Required Actions and associated Completion Times of Condition C or D were not met. If they were not met, then the associated low pressure ECCS injection/spray subsystem might be incapable of performing the intended

function, and the CS/LPCI subsystem would be declared inoperable immediately.

These Actions direct the licensee to take timely and appropriate actions upon entry into the Conditions referenced in Table 3.3.5.2-1.

The NRC staff has determined that these Actions satisfy the requirements of 10 CFR 50.36(c)(2)(i) by providing a remedial action permitted by the TSs until the LCO can be met. The NRC staff has concluded that there is reasonable assurance that the licensee will take appropriate actions during an unexpected drain event to either prevent or to mitigate RPV water level being lowered to the TAF; therefore, the proposed changes are acceptable.

3.2.3 Staff Evaluation of Proposed TS 3.3.5.2 Surveillance Requirements The proposed new TS 3.3.5.2 SRs include Channel Checks and Channel Functional Tests numbered SR 3.3.5.2.1 and SR 3.3.5.2.2, respectively.

The NRC staff finds that these tests are sufficient and adequate, because they are essential to ensure that the Functions of TS 3.3.5.2 are operable (i.e., capable of performing the specified safety function in support of TS 3.5.2 and protection from a potential drain down of the RPV in Modes 4 and 5). The NRC staff finds that the proposed SRs of LCO 3.3.5.2 are consistent with those described in Section 3.3.3 of the TSTF-542 justification, and that they satisfy 10 CFR 50.36(c)(3) by providing the specific SRs relating to test, calibration, or inspection to assure that the necessary quality of systems and components is maintained.

SR 3.3.5.2.1 would require a Channel Check and applies to system isolation functions in TS Table 3.3.5.2-1 for RHR and RWCU. Performance of the Channel Check would ensure that a gross failure of instrumentation has not occurred.

A Channel Check is normally a comparison of the parameter indicated on one channel to a similar parameter on other related channels.

A Channel Check is significant in assuring that there is a low probability of an undetected complete channel failure and is a key safety practice to verifying the instrumentation continues to operate properly between each Channel Functional Test. The frequency, in accordance with the SFCP, is consistent with the existing requirements and supports operating shift situational awareness.

SR 3.3.5.2.2 would require a Channel Functional Test and applies to all functions in TS Table 3.3.5.2-1.

A Channel Functional Test is the injection of a simulated or actual signal into the channel as close to the sensor as practicable to verify operability of all devices in the channel required for channel operability.

It would be performed on each required channel to ensure that the entire channel will perform the intended function.

The frequency would be in accordance with the SFCP. This is acceptable because it is consistent with the existing requirements for these Functions.

TSTF-542 did not include SRs to verify or adjust the instrument setpoint derived from the allowable value using a Channel Calibration or a surveillance to calibrate the trip unit. This is because a draining event in Mode 4 or 5 is not an analyzed accident and, therefore, there is no accident analysis on which to base the calculation of a setpoint.

As noted in TSTF-542:

The purpose of the Functions is to allow ECCS manual initiation or to automatically isolate a penetration flow path, but no specific RPV water level is assumed for those actions.

Therefore, the Mode 3 Allowable Value was chosen for use in Modes 4 and 5 as it will perform the desired function.

Calibrating the Functions in Modes 4 and 5 is not necessary, as TS 3.3.5.1 and TS 3.3.6.1 continue to require the Functions to be calibrated on an [established interval].

It is also noted in TSTF-542 that: A draining event in Mode 4 or 5 is not an analyzed accident and, therefore, there are no accident analysis assumptions on response time. The NRC staff has determined this is acceptable, because this is adequate to ensure that the channel responds with the required pumping systems to inject water when needed, and to isolate appropriate equipment when commanded.

Based on the above, the NRC staff has concluded that the proposed SRs of LCO 3.3.5.2 satisfy 10 CFR 50.36(c)(3) by providing the specific SRs relating to test, calibration, or inspection to assure that the necessary quality of systems and components is maintained; therefore, the proposed changes are acceptable.

3.2.4 Staff Evaluation of Proposed Table 3.3.5.2-1, "RPVWater Inventory Control Instrumentation" In order to support the requirements of proposed TS 3.5.2, "Reactor Pressure Vessel (RPV) Water Inventory Control,"

the associated instrumentation requirements would be designated in Table 3.3.5.2-1.

These instruments would be required to be operable if the systems that provide water injection and isolation functions were to be considered

operable, as described in the NRC staff's evaluation of TS 3.5.2 in Section 3.3 of this SE. Proposed Table 3.3.5.2-1 specifies the instrumentation that shall be operable for each function in the table for Modes 4 and 5 (or other specified conditions),

the required number of channels per function, conditions referenced from Required Action A.1, SR for the functions, the allowable value, and footnotes concerning items of the table. Proposed Table TS 3.3.5.2-1, "RPV Water Inventory Control Instrumentation,"

presents details on the functions required to support the equipment and functions of TS 3.5.2. The NRC staff finds the presentation in this table to be acceptable, because this section of the application sufficiently discusses the purpose of the functions, the applicability, the number of required

channels, the references to the Condition to be entered by letter (e.g., A, B, C) if the function is inoperable, the applicable SRs, the selection of the allowable value, and justification of differences between the existing and proposed TS functions.

This RPV WIC Instrumentation set of requirements is acceptable, because it is adequate to ensure that the channels of instrumentation respond with the required accuracy permitting pumping systems to operate to inject water when needed and isolating equipment when commanded to support the prevention of or to mitigate a potential RPV draining event. Each of the low pressure ECCS subsystems in Modes 4 and 5 can be started by manual alignment of a small number of components.

Automatic initiation of a low pressure ECCS injection/spray subsystem may be undesirable in some scenarios, because it could lead to overflowing the RPV cavity, due to injection rates of thousands of gallons per minute. Considering the TS 3.5.2 Action statements as the drain time decreases (e.g., the proposed TS 3.5.2, Action E, prohibits plant conditions that could result in drain times less than one hour), there is sufficient time for the reactor operators to take manual action to stop a draining event, and to manually start a low pressure ECCS injection/spray subsystem or initiate an additional method of water injection as needed. Consequently, there is no need for automatic initiation of the low pressure ECCS to respond to an unexpected draining event. This is acceptable, because a draining event is a slow evolution when compared to an at-power design basis LOCA. 3.2.4.1 Staff Evaluation of Proposed Table 3.3.5.2-1 Functions For the Table 3.3.5.2-1 Functions 1.a and 2.a, CS and LPCI Systems, Reactor Steam Dome Pressure

-Low (Injection Permissive),

these signals would be used as permissives and protection for these low pressure ECCS injection/spray subsystem manual initiation functions.

This function would ensure that the reactor pressure has fallen to a value below these subsystems' maximum design pressure before permitting the operator to open the injection valves of the low pressure ECCS subsystems.

Even though the reactor steam dome pressure is expected to always be below the low pressure ECCS maximum design pumping pressure during Modes 4 and 5, the Reactor Steam Dome Pressure

-Low signals would be required to be operable and capable of permitting initiation of the ECCS. The proposed allowable value would be s 476 psig, with four required channels per function, as it is currently in HNP TS Table 3.3.5.1-1.

For the Table 3.3.5.2-1 Functions 1.b and 2.b, CS and LPCI Systems, Pump Discharge Flow -Low (Bypass),

these minimum flow instruments were proposed to protect the associated low pressure ECCS pumps from overheating when the pump is operating and the associated injection valve is not fully open. For LPCI, the minimum flow line valve is opened when low flow is sensed, and the valve is automatically closed when the flow rate is adequate to protect the pump. The proposed required channels per function would be 1 per subsystem, as it is currently found in HNP TS Table 3.3.5.1-1. For CS, the minimum flow line valve is opened when low flow is sensed, and the valve is automatically closed when the flow rate is adequate to protect the pump, yet low enough to ensure that the closure of the minimum flow valve is initiated to allow full flow into the core. The proposed required channels per function is 1 per subsystem, as it is currently found in HNP TS Table 3.3.5.1-1.

The proposed allowable values for Functions 1.b and 2.b are as follows (current values moved from HNP TS Table 3.3.5.1-1

): cs LPCI 610 gpm and :5 825 gpm 1670 gpm and :5 2205 gpm 570 gpm and :5 7 45 gpm 1675 gpm and :5 2215 gpm For Table 3.3.5.2-1 Function 3.a, RHR System Isolation, Reactor Vessel Water Level -Low, Level 3, the function would only be required to be operable when automatic isolation of the associated penetration flow path is credited in the drain time calculation.

The proposed number of required instrument channels is 2 in one trip system. The condition that the RHR system integrity be maintained is a concept related to OPDRVs, so it would not be carried over into TS 3.3.5.2 for RPV WIC Instrumentation.

Reactor Vessel Water Level -Low, Level 3 signals are initiated from four level transmitters that sense the difference between the pressure due to a constant column of water (reference leg) and the pressure due to the actual water level (variable leg) in the vessel. While four channels (two channels per trip system) of the Reactor Vessel Water Level -Low, Level 3 Function are available, only two channels (all in the same trip system) are required to be OPERABLE.

The allowable value was chosen to be the same as the Primary Containment Isolation Instrumentation Reactor Vessel Water Level -Low, Level 3, Allowable Value from LCO 3.3.6.1, which is 0 inches. For Table 3.3.5.2-1 Function 4.a, RWCU System Isolation, Reactor Vessel Water Level -Low Low, Level 2, the function is only required to be operable when automatic isolation of the associated penetration flow path is credited in the drain time calculation.

The proposed number of required instrument channels is 2 in one trip system. Reactor Vessel Water Level -Low Low. Level 2 signals are initiated from four level transmitters that sense the difference between the pressure due to a constant column of water (reference leg) and the pressure due to the actual water level (variable leg) in the vessel. While four channels (two channels per trip system) of the Reactor Vessel Water Level -Low Low, Level 2 Function are available, only two channels (all in the same trip system) are required to be OPERABLE.

This proposed change is a new requirement in Modes 4 and 5 for the RWCU system. However, the instrumentation function is the same as current TS Table 3.3.6.1, Function 5.d, which contains the requirements for Modes 1, 2, and 3, with the same allowable value, -47 inches. The NRC staff finds that the proposed new LCO 3.3.5.2 correctly specifies the lowest functional capability or performance levels of equipment required for safe operation of the facility.

There is reasonable assurance that the Required Actions to be taken when the LCO is not met can be conducted without endangering the health and safety of the public. This meets the requirements of 10 CFR 50.36(c)(2)(i) and, therefore, the NRC staff concludes that the proposed changes to LCO 3.3.5.2 are acceptable.

3.3 Staff Evaluation of TS 3.5.2, Reactor Pressure Vessel (RPV) Water Inventory Control The NRC staff reviewed the water sources that would be applicable to the proposed TS 3.5.2. 3.3 Staff Evaluation of TS 3.5.2, Reactor Pressure Vessel (RPV) Water Inventory Control The NRC staff reviewed the water sources that would be applicable to the proposed TS 3.5.2. The proposed LCO 3.5.2 would state, in part, "One low pressure ECCS injection/spray subsystem shall be OPERABLE."

One low pressure ECCS injection/spray subsystem would consist of either one CS subsystem or one LPCI subsystem.

A CS subsystem consists of one motor driven pump, piping, and valves to transfer water from the suppression pool or condensate storage tanks to the RPV. A LPCI subsystem consists of one motor driven pump, piping, and valves to transfer water from the suppression pool to the RPV. The ECCS pumps are high-capacity pumps, with flow rates of thousands of gallons per minute (gpm). Most RPV penetration flow paths would have a drain rate on the order of tens or hundreds of gpm. The manual initiation/start of an ECCS pump would provide the necessary water source to counter the drain rates resulting from postulated events. The LPCI subsystem is to be considered operable during alignment and operation for decay heat removal if it is capable of being manually realigned and not otherwise inoperable.

Decay heat removal in Modes 4 and 5 is not affected by the proposed HNP TS change, as these requirements on the number of shutdown cooling subsystems that must be operable and in operation to ensure adequate decay heat removal from the core are unchanged.

These requirements can be found in the HNP TS 3.4.8, "Residual Heat Removal (RHR) Shutdown Cooling System -Cold Shutdown,"

TS 3.9.7, "Residual Heat Removal (RHR) -High Water Level," and TS 3.9.8, "Residual Heat Removal (RHR) -Low Water Level." These HNP decay heat removal requirements are similar to the corresponding STS; specifically, NUREG-1433 TS 3.4.9, TS 3.9.8, and TS 3.9.10. Based on these considerations, the NRC staff finds that the available water sources and systems provide reasonable assurance that the lowest functional capability required for safe plant operation is maintained for the specified operational modes, thus ensuring that the relevant safety limits are protected.

The proposed TS 3.5.2, "Reactor Pressure Vessel (RPV) Water Inventory Control,"

LCO contains two parts. The first part states that drain time of RPV water inventory to the TAF shall be 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months , and the second part states that one low pressure ECCS injection/spray subsystem shall be OPERABLE.

The proposed Applicability for TS 3.5.2 is Modes 4 and 5. The NRC staff reviewed the proposed TS 3.5.2, focusing on how the proposed changes maintain or establish requirements to ensure that the fuel remains covered with water during potential drain events. The proposed TS 3.5.2 contains Conditions A through E, which are based on either required ECCS injection/spray subsystem operability or drain time. The current TS 3.5.2 LCO states that two low pressure ECCS injection/spray subsystems shall be OPERABLE, whereas the proposed LCO 3.5.2 states that only one low pressure ECCS injection/spray subsystem shall be OPERABLE.

This change is reflected in Condition A. The change from two low pressure ECCS injection/spray subsystems OPERABLE to one low pressure ECCS injection/spray subsystem OPERABLE is because this redundancy is not required for the applicable modes. With one ECCS injection/spray subsystem

OPERABLE, and the availability of non-safety related injection sources of sufficient capacity to mitigate potential drain down events, defense-in-depth will be maintained.

This defense-in-depth approach is consistent with those for other events considered during shutdown with no additional single failure assumed.

The drain time controls, in addition to the required low pressure ECCS injection/spray subsystem, provide reasonable assurance that an unexpected draining event can be prevented or mitigated before the RPV water level would be lowered to the TAF. The proposed Mode 4 and 5 Applicability of TS 3.5.2 is appropriate, given that the TS requirements on ECCS in Modes 1, 2, and 3 will be unaffected.

The proposed Condition A states that if the required ECCS injection/spray subsystem is inoperable, it is to be restored to OPERABLE status within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . Proposed Condition B states that if Condition A is not met, a method of water injection capable of operating without offsite electrical power shall be established immediately.

The proposed Condition B provides adequate assurance of an available water source should Condition A not be met within the 4-hour completion time. The proposed Condition C states that for a DRAIN TIME < 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months and .:: 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , to (C.1) verify secondary containment boundary is capable of being established in less than the DRAIN TIME, with a completion time of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months , and (C.2) verify each secondary containment penetration flow path is capable of being isolated in less than the DRAIN TIME, with a completion time of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months , and (C.3) verify required standby gas treatment subsystem(s) are capable of being placed in operation in less than the DRAIN TIME, with a completion time of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . The proposed Condition C provides adequate protection when the DRAIN TIME is < 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months and .:: 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months because of the ability to establish secondary containment, isolate additional flow paths, and have the standby gas treatment subsystem capable of being placed in operation in less time. The proposed Condition D states that when DRAIN TIME < 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months to (D.1) immediately initiate action to establish an additional method of water injection with water sources capable of maintaining RPV water level> TAF for.:: 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months , and (D.2) immediately initiate action to establish secondary containment

boundary, and (D.3) immediately initiate action to isolate each secondary containment penetration flow path or verify it can be manually isolated from the control room, and (D.4) immediately initiate action to verify required standby gas treatment subsystem(s) are capable of being placed in operation.

Additionally, there is a note stating that required ECCS injection/spray subsystem or additional method of water injection shall be capable of operating without offsite electrical power, which is similar to proposed Condition B. The proposed Condition D provides adequate protection should the DRAIN TIME be < 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , because of the requirements to immediately establish an additional method of water injection (without offsite electrical power), establish secondary containment, isolate additional flow paths, and have the standby gas treatment subsystem capable of being placed in operation.

These are all appropriate measures in response to a potential drain down event with the plant in Modes 4 and 5. The proposed Condition E states that when the Required Action and associated Completion Time of Condition C or D are not met, or the DRAIN TIME is < 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , then immediately initiate action to restore DRAIN TIME to.:: 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . The proposed Condition Eis new, as it is not present in the current HNP TS. The proposed Condition E is acceptable, as it provides the necessary step to restore the DRAIN TIME to.:: 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months should the other conditions not be met, or if the DRAIN TIME is< 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . The NRC staff reviewed the proposed changes to TS 3.5.2 and finds them acceptable, based on the actions required to mitigate the water level reaching the TAF with the water sources available and maintaining DRAIN TIME.:: 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . LCO 3.5.2 correctly specifies the lowest functional capability or performance levels of equipment required for safe operation of the facility.

There is reasonable assurance that the required actions to be taken when the LCO is not met can be conducted without endangering the health and safety of the public and, therefore, they are acceptable.

3.3.1 Staff Evaluation of Proposed TS 3.5.2 Surveillance Requirements The proposed TS 3.5.2 SRs (listed in Section 2.2.3 above) include verification of DRAIN TIME, verification of water levels/volumes that support ECCS injection/spray subsystems, verification of water filled pipes to preclude water hammer events, verification of correct valve positions for the required ECCS injection/spray subsystem, operation of the ECCS injection/spray systems through the recirculation line, verification that valves credited for automatic isolation can be actuated to the isolation

position, and verification that the required ECCS injection/spray subsystem can be manually operated.

Each of the eight SRs are described below. SR 3.5.2.1:

The DRAIN TIME would be determined or calculated, and required to be verified to be~ 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months in accordance with the SFCP. This surveillance would verify that the LCO for DRAIN TIME is met. Numerous indications of changes in RPV level are available to the reactor operators.

The period of 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months is considered reasonable to identify and initiate action to mitigate draining of reactor coolant (normally 3 operating shifts).

Changes in RPV level would necessitate recalculation of the DRAIN TIME. SR 3.5.2.2:

This surveillance requires that the suppression pool water level is verified to be 146 inches, to ensure that adequate pump net positive suction head and vortex prevention is available for the LPCI subsystem required to be OPERABLE by the LCO. Indications are available either locally or in the control room for suppression pool water level. This surveillance would be required to be performed in accordance with the SFCP. SR 3.5.2.3:

This surveillance requires that the suppression pool water level is verified to be 146 inches, or that the condensate storage tank water level is~ 13 feet, to ensure that adequate pump net positive suction head and vortex prevention is available for the CS subsystem required to be OPERABLE by the LCO. Indications are available either locally or in the control room regarding suppression pool water level and condensate storage tank water level. This surveillance would be required to be performed in accordance with the SFCP. SR 3.5.2.4:

The surveillance requirement to verify the ECCS injection/spray subsystem piping is sufficiently filled with water would be retained from the existing TS 3.5.2. The proposed change would update the SR to reflect the change to LCO 3.5.2, which would require, in part, one low pressure ECCS injection/spray subsystem to be operable instead of two. SR 3.5.2.3 wording would change from "Verify, for each required ECCS ... " to "Verify, for the required ECCS .... " This change clarifies the requirement to maintain consistency with the proposed LCO. Maintaining the pump discharge lines of the required ECCS injection/spray subsystem sufficiently full of water ensures that the ECCS subsystem will perform properly.

This will also prevent water hammer following an ECCS initiation signal. One acceptable method of ensuring that the lines are full is to vent at the high points. This surveillance would be required to be performed in accordance with the SFCP. SR 3.5.2.5:

The SR to verify the correct alignment for manual, power operated, and automatic valves in the required ECCS subsystem flow path would be retained from the existing TS 3.5.2. Similar to the change discussed above for proposed SR 3.5.2.4, changes to SR 3.5.2.5 would clarify a proposed requirement for LCO 3.5.2. The proposed SR wording, "Verify for the required ECCS injection/spray subsystem, each manual .... " would replace "Verify each required ECCS injection/spray subsystem manual. ... " SR 3.5.2.5 would provide assurance that the proper flow path will be available for ECCS operation to support TS 3.5.2. This SR would not apply to valves that are locked, sealed, or otherwise secured in position, since these valves would be verified to be in the correct position prior to locking,

sealing, or securing.

This SR is modified by two notes: (1) A Low Pressure Coolant Injection (LPCI) subsystem may be considered operable during alignment and operation for decay heat removal if capable of being manually realigned and not otherwise inoperable, and (2) Not required to be met for system vent flowpaths opened under administrative control.

For Note 1, in Modes 4 and 5, the RHR system may operate in the shutdown cooling mode to remove decay heat and sensible heat from the reactor and the RHR valves that are required for LPCI subsystem operation may be aligned for decay heat removal. Note 1 allows a required LPCI subsystem of the RHR system to be considered operable for the ECCS function if all the required valves in the LPCI flow path can be manually realigned (remote or local) to allow injection into the RPV, and the system is not otherwise inoperable.

This will ensure adequate core cooling if an inadvertent RPV draindown should occur. For Note 2, the administrative control would allow a dedicated individual who can rapidly close the system vent flow path if directed.

This surveillance would be required to be performed in accordance with the SFCP. SR 3.5.2.6:

The required ECCS injection/spray subsystem would be required to be operated through its recirculation line for~ 10 minutes in accordance with the SFCP. This would demonstrate that the subsystem is capable for operation to support TS 3.5.2. Testing the ECCS injection/spray subsystem through the recirculation line is necessary to avoid overfilling the refueling cavity. The minimum operating time of 10 minutes is based on engineering judgement.

This surveillance would be required to be performed in accordance with the SFCP. SR 3.5.2.7:

Verification that each valve credited for automatically isolating a penetration flow path actuates to the isolation position on an actual or simulated RPV water level isolation signal would be required to prevent RPV water inventory from dropping below the TAF, should an unexpected draining event occur. This surveillance would be required to be performed in accordance with the SFCP. SR 3.5.2.8:

This SR would state, "Verify the required ECCS injection/spray subsystem can be manually operated."

It would demonstrate that the required CS or LPCI subsystem could be manually

operated, using the associated pump and valve switches, to provide additional RPV water inventory, if needed. Vessel injection/spray may be excluded from the SR, per the existing Note. This surveillance would be required to be performed in accordance with the SFCP. The NRC staff evaluated each of these proposed SRs associated with the proposed LCO 3.5.2 and concluded that they are appropriate for ensuring the operability of the equipment and instrumentation specified in LCO 3.5.2. Furthermore, the NRC staff concluded that each of the proposed SRs are acceptable, since they meet the requirements of 10 CFR 50.36(c)(2)(ii) regarding insights gained via operating experience and 10 CFR 50.36(c)(3) for surveillance requirements by ensuring that the necessary quality of systems and components are maintained. 3.4 Staff Evaluation of TS Table 3.3.5.1-1, "Emergency Core Cooling System Instrumentation" LCO 3.3.5.1 currently states that, "[t]he ECCS instrumentation for each Function in Table 3.3.5.1-1 shall be OPERABLE,"

with the applicability as stated in the table. Table 3.3.5.1-1, "Emergency Core Cooling System Instrumentation,"

currently contains requirements for function operability during Modes 4 and 5 when the associated ECCS subsystem(s) are required to be operable.

Conforming changes were proposed for the Actions of LCO 3.3.5.1 as well, to reflect the proposed changes to TS Table 3.3.5.1-1.

For the following Functions in Table 3.3.5.1-1, Mode 4 and 5 requirements would be deleted:

1. Core Spray System 2. LPCI (a) Reactor Vessel Water Level -Low Low Low, Level 1 (c) Reactor Steam Dome Pressure

-Low (Injection Permissive)

(d) Core Spray Pump Discharge Flow -Low (Bypass)

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

-Low (Injection Permissive)

(f) Low Pressure Coolant Injection Pump Start -Time Delay Relay (Pumps A, B, C, and 0) (g) Low Pressure Coolant Injection Pump Discharge Flow -Low (Bypass)

These functions would be deleted to support the consolidation of RPV WIC instrumentation requirements into proposed new TS 3.3.5.2.

The requirements for Functions 1.c, 1.d, 2.c, and 2.g would be moved to proposed TS Table 3.3.5.2-1, as discussed in Section 3.2.4.1 of this SE. For the other TS Table 3.3.5.1-1 Functions, 1.a, 2.a, and 2.f, the Mode 4 and 5 requirements would not be retained.

The HNP TS currently require automatic initiation of ECCS pumps on low Reactor Vessel water level. However, in Modes 4 and 5, automatic initiation of ECCS pumps could result in overfilling the refueling cavity or water flowing into the main steam lines, potentially damaging plant equipment.

The NRC staff finds acceptable the deletion of TS Table 3.3.5.1-1, Functions 1.a, 2.a, and 2.f, because manual ECCS initiation is preferred over automatic initiation during Modes 4 and 5, and the operators would be able to use other more appropriately sized pumps if needed to mitigate a draining event. Also, there is no STS equivalent for Function 2.f for the LPCI pump start time delay relays in Modes 4 and 5. The purpose of the time delay is to stagger the automatic start of LPCI pumps, thus limiting the starting transients on the emergency buses. The staggered starting of ECCS pumps is unnecessary for manual ECCS operation.

3.5 Staff Evaluation of Proposed Technical Variations SNC proposed the following nine technical variations from the TS changes described in TSTF-542 or the applicable parts of the NRC staffs SE for TSTF-542.

The licensee stated in the LAR and its supplements that these variations do not affect the applicability of TSTF-542 or the NRC staff's SE for TSTF-542 to the proposed license amendment.

The NRC staff evaluated each variation below. 3.5.1 Variation 1, Supported Feature HNP Unit 1 and Unit 2 TS 3.3.5.1, "Emergency Core Cooling System (ECCS) Instrumentation,"

Required Actions 8.1, C.1, and E.1 read slightly differently than the STS. For the HNP TS, the Required Actions for these conditions state (in part): Declare supported feature(s) inoperable.

For the STS and TSTF-542, the corresponding Required Actions state: Declare supported features(s) inoperable when its redundant feature ECCS initiation capability is inoperable.

The Completion Times for both HNP TS 3.3.5.1 and the STS states (in part): 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery of loss of initiation capability for feature(s) in both divisions.

The NRC staff finds that, based on when the completion time starts, the additional words shown in Required Actions 8.1, C.1, and E.1 for STS 3.3.5.1 are not needed for the corresponding HNP TSs, as the resultant action and completion time is the same. Therefore, the existing wording for the HNP TSs is acceptable.

3.5.2 Variation 2, CS and LPCI Flow Transmitter The HNP CS and LPCI subsystems have one flow transmitter per ECCS subsystem to detect the associated subsystem's flow rates, whereas the STS assume one flow transmitter per ECCS pump to detect the associated subsystem's flow rates. Each HNP CS subsystem has one CS pump, and each HNP LPCI subsystem has two RHR pumps. The licensee proposes to maintain the one channel per subsystem requirement for new Table 3.3.5.2-1, Functions 1.b. and 2.b. For the CS subsystem, this variation of "1 per subsystem" versus "1 per pump" is editorial (one pump per subsystem),

so keeping the phrase "1 per subsystem" will maintain consistency with the current HNP TS language, and is acceptable.

Existing HNP TS Table 3.3.5.1-1 for CS (Function 1.d) and LPCI (Function 2.g) specifies that the required channels per function is "1 per subsystem" for Modes 1, 2, and 3; and for Modes 4 and 5, when the associated subsystem(s) are required to be operable.

The NRC staff finds that this current instrumentation requirement provides sufficient overheating protection for the CS and LPCI injection pumps in Modes 4 and 5 and is consistent with the existing HNP TS; therefore, this variation is acceptable.

3.5.3 Variation 3, TS Table 3.3.5.2-1 Footnote The licensee is proposing to add a footnote in new TS Table 3.3.5.2-to clarify the intent of allowing credit for an operable LPCI subsystem when it is aligned and operating in the decay heat removal mode of RHR. The footnote would state: (c) Function not required to be OPERABLE while associated pump is operating in decay heat removal when minimum flow valve is closed and deactivated.

The NRC considers this appropriate since the associated RHR pump minimum flow valve (while operating in the decay heat removal mode) is closed and deactivated to prevent inadvertent vessel drain down events. Because the minimum flow valve is closed and deactivated, the associated TS Table 3.3.5.2-1, Function 2.b would not be required to be operable.

The NRC staff finds that the added footnote (c) associated with the LPCI subsystem in new TS Table 3.3.5.2-1 is appropriate.

Without the footnote, TS 3.3.5.2, Condition D would require that the associated RHR pump be declared inoperable, which would be contrary to the Note for existing SR 3.5.2.4 (new SR 3.5.2.5),

which allows the LPCI subsystem to be considered OPERABLE when aligned for decay heat removal; therefore this variation is acceptable.

3.5.4 Variation 4, Manual Initiation Logic The HNP Unit 1 and Unit 2 TS do not include a manual initiation logic function for the CS or LPCI subsystems.

Considering the logic design, there is not a single switch that will start all subsystems of the associated ECCS system, as is assumed in the STS. HNP does, however, have the capability to manually start the ECCS pumps individually.

Since the manual initiation logic function does not exist at HNP, manual initiation functions for LPCI and CS are not being included in Table 3.3.5.2-1.

Additionally, since the manual initiation functions are not included in Table 3.3.5.2-1, the associated Logic System Functional Test would likewise not be required for TS 3.3.5.2; therefore, TS 3.3.5.2 as proposed for HNP Unit 1 and Unit 2 TS does not include a Logic System Functional Test SR. The manipulation of subsystem components from the main control room would be verified in accordance with new SR 3.5.2.8.

This surveillance Would verify that the required CS or LPCI subsystem (including the associated pump switches and valve(s))

can be manually operated to provide additional RPV water inventory, if needed, using controls and indications that are currently available in the main control room. In the LAR, the licensee described how adequate time for the operators to take action is assured.

The NRC staff reviewed this variation and determined that although HNP does not have the capability to start an ECCS subsystem with a single button, the components that provide water supply and injection into the RPV can be started from the main control room as required to support Mode 4 and 5 operations.

The manipulation of subsystem components from the main control room would be verified in accordance with new SR 3.5.2.8.

This SR would verify that the required CS or LPCI subsystem (including the associated pump switches and valve(s))

can be manually operated to provide additional RPV water inventory, if needed. Therefore, the NRC staff finds that Variation 4 is acceptable.

3.5.5 Variation 5, LPCI Realignment The STS Note on LCO 3.5.2 regarding realignment to the LPCI mode is located in the HNP SR 3.5.2.4 (new SR 3.5.2.5).

This has no effect on the adoption of TSTF-542 and is an acceptable deviation. The STS Note in LCO 3.5.2, ECCS -Shutdown, shown below, is located in the current HNP SR 3.5.2.4:

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

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 The licensee has proposed a slightly modified Note 1 in new SR 3.5.2.5, which states: ----------------------------------N()l"E:--------------------------------------

A Low Pressure Coolant Injection (LPCI) subsystem may be considered

()PE:RABLE:

during alignment and operation for decay heat removal if capable of being manually realigned and not otherwise inoperable.

l"he NRC staff finds that the minor proposed change to SR 3.5.2.5 (previously SR 3.5.2.4) is appropriate, and that the Note is located in the applicable section of the HNP l"S, since it is related to verification of system alignment; therefore, this variation is acceptable.

3.5.6 Variation 6, l"S 3.6.1.3 Condition F Revised HNP l"S 3.6.1.3, Condition F (which corresponds to Sl"S Condition H) deletes the phrase, "Initiate action to suspend operations with a potential for draining the reactor vessel."

l"he NRC staff notes that this phrase is also being deleted from the Sl"S per l"Sl"F-542.

Since ()PDRVs are only performed in Mode 4 or Mode 5, this phrase that was contained in the Sl"S was unnecessary; therefore, this variation is acceptable.

3.5.7 Variation 7, Inverters HNP does not have an "Inverters

-Operating" or an "Inverters

-Shutdown" l"S. As stated in the HNP improved l"S Conversion:

Inverters, as utilized in the NURE:G-1433 Sl"S (i.e., inverters that power many required systems and that are required to be powered by the DC sources to meet accident analysis assumptions),

do not exist in the HNP. As such, NURE:G-1433 LCO 3.8.7 and LCO 3.8.8, their associated Bases, and all references to them have been deleted.

l"he LCOs that follow have been renumbered to reflect this deletion.

l"he only inverters that need to be powered from DC sources are the LPCI inverters, which only provide power to the LPCI subsystems.

l"hese two inverters are covered by an SR in NURE:G(-1433]

LC() 3.5.1 (E:CCS) since they only impact the LPCI subsystems.

l"he NRC staff finds that the inverters are not specifically addressed in the HNP l"S; therefore, no changes are required with respect to l"Sl"F-542, and this variation is acceptable.

3.5.8 Variation 8, Surveillance Frequency Control Program l"he HNP l"Ss contain a SFCP. l"herefore, the Surveillance Requirement Frequencies for new l"Ss 3.3.5.2 and 3.5.2 are "In accordance with the Surveillance Frequency Control Program."

HNP is adopting the recommended frequencies in l"Sl"F-542 (within its SFCP), except that the surveillance frequency corresponding to new SR 3.3.5.2.2.

for the performance of the CHANNE:L FUNCl"l()NAL l"E:Sl" will be "92 days on an AL l"E:RNAl"E:

l"E:Sl" BASIS." Section 3.2.3 of this SE: describes SR 3.3.5.2.2.

l"he NRC staff finds that this is consistent with the current licensing basis for existing SRs 3.3.5.1.2 and 3.3.6.1.2.

Performing these CHANNE:L FUNCl"IONAL l"E:Sl" SRs on an AL l"E:RNAl"E:

l"E:Sl" BASIS was approved by the NRC in Amendments 234 and 176, for HNP Units 1 and 2, respectively (Reference 9). In addition, since the HNP units are on two-year fuel cycles, the 18-month frequencies in TSTF-542 would be 24-month frequencies for HNP. The proposed variation retains the current licensing basis for the plant; therefore, the NRC staff finds this variation acceptable.

3.5.9 Variation 9, Table 3.3.5.2-1 on Applicability of ECCS Functions In accordance with TSTF-542, TS Table 3.3.5.2-1, Function 1.a (CS, Reactor Steam Dome Pressure

-Low (Injection Permissive)),

and Function 2.a (LPCI, Reactor Steam Dome Pressure

-Low (Injection Permissive))

are required in Modes 4 and 5. Prior to TSTF-542

, the analogous Functions 1.c and 2.c in HNP TS Table 3.3.5.1-1 had a Mode 4 and 5 applicability modified by a footnote specifying that these functions were only required when the associated ECCS subsystem(s) were required to be operable.

The footnote was omitted inadvertently from Table 3.3.5.2-1, Functions 1.a and 2.a in TSTF-542.

The licensee proposed a variation to affix Footnote (a), which would state, "Associated with an ECCS subsystem required to be OPERABLE by LCO 3.5.2, 'Reactor Pressure Vessel Water Inventory Control,"'

to the "Required Channels Per Function" column of Functions 1.a and 2.a of new TS Table 3.3.5.2-1.

Without the footnote, the Reactor Steam Dome Pressure

-Low (Injection Permissive) functions would be required to be operable for all low pressure ECCS subsystems, regardless of whether they are credited for meeting the ECCS operability requirements of LCO 3.5.2. These instruments are required to be operable only if the systems that provide water injection and isolation functions are required to be operable.

In Modes 4 and 5, with the reactor steam dome at atmospheric

pressure, these functions only serve to satisfy permissives for opening low pressure ECCS injection valves for manual actuation.

The NRC staff finds that the proposed variation is acceptable, since the CS or LPCI subsystems would still be available to perform the intended function to inject water into the RPV, which meets the intent of TSTF-542 and maintains the current licensing basis for HNP. 3.6 Staff Evaluation of Proposed Deletion of References to OPDRVs Section 2.2.4 above lists the numerous OPDRVs references proposed for deletion.

The proposed changes would replace the existing specifications related to OPDRVs with revised specifications for RPV WIC. For example, the proposed changes would remove "operations with a potential for draining the reactor vessel,"

the acronym "OPDRVs,"

and related concepts such as "RHR Shutdown Cooling System integrity maintained,"

and Required Actions to "suspend OPDRVs."

The term OPDRVs is not specifically defined in the TSs and historically has been subject to inconsistent application by licensees.

The changes discussed in this SE are intended to resolve any ambiguity by creating a new RPV WIC TS with attendant equipment operability requirements, required actions and SRs and deleting references to OPDRVs throughout the TSs. The existing HNP TSs contain instrumentation requirements related to OPDRVs in four TSs; three of them, which have the OPDRVs phrases described above, and TS 3.3.5.1.

The proposed TS 3.3.5.2 consolidates the instrumentation requirements into a single location to simplify the presentation and provide requirements consistent with TS 3.5.2. The remaining TSs with OPDRVs requirements are for containment, containment isolation valves, standby gas treatment system, control room habitability, temperature

control, and electrical sources.

Each of these systems' requirements during OPDRVs were proposed for consolidation into new TS 3.5.2 for RPV WIC, based on the appropriate plant conditions and calculated Drain Time. The NRC staff has determined that the deletion of OPDRVs references, along with the corresponding editorial

changes, are appropriate because the proposed TSs governing RPV WIC and the associated instrumentation, TSs 3.5.2 and 3.3.5.2, respectively, are a simplified alternative set of controls for ensuring water level is maintained above the TAF; therefore, these changes are acceptable.

3.7 Staff Evaluation of TS 3.10, Special Operations and TSTF-484 The current HNP TS LCO 3.10.1, "lnservice Leak and Hydrostatic Testing Operation,"

allows performance of an inservice leak test or hydrostatic test with the average reactor coolant temperature greater than 212°F, while considering operational conditions to still be in Mode 4, provided certain secondary containment LCOs are met. TSTF-484, Revision 0, "Use of TS 3.10.1 for Scram Time Testing Activities,"

(References 10, 12, 13, and 14) revised LCO 3.10.1 to expand its scope to include operations where temperature exceeds 212°F: (1) as a consequence of maintaining adequate reactor pressure for an inservice leak or hydrostatic test, or (2) as a consequence of maintaining adequate reactor pressure for control rod scram time testing initiated in conjunction with an inservice leak or hydrostatic test. By Amendment Nos. 251 and 195 (Units 1 and 2, respectively) dated May 17, 2007 (Reference 11 ), the NRC approved changes to HNP TS LCO 3.10.1 in accordance with TSTF-484.

The NRC staff's SE for these amendments stated, in part, that, "two low-pressure emergency core cooling systems (ECCS) injected/spray subsystems are required to be operable in Mode 4 by TS 3.5.2, 'ECCS-Shutdown."'

However, per the proposed new LCO 3.5.2, only one low pressure ECCS injection/spray subsystem would be required to be operable in Mode 4. The NRC staff has determined that changing from two ECCS injection/spray subsystems to one ECCS injection/spray subsystem is acceptable,

because, as stated previously in Section 3.3.1 of this SE, this level of redundancy is not required, even during application of LCO 3.10.1. When the licensee applies LCO 3.10.1 at the end of a refueling outage, an exceptionally large volume of water is present in the reactor vessel since the vessel is nearly water solid. There is much more water in the reactor vessel than is present during power operation and more than is present puring most of an outage. Small leaks from the reactor coolant system would be detected by inspections before a significant loss of inventory occurred.

In the event of a large reactor coolant system leak, the RPV would rapidly depressurize and allow operation of the low pressure ECCS. At low decay heat values, and near Mode 4 conditions, the stored energy in the reactor core will be very low. Therefore, the reasoning that operators would have time to respond with manual actions to start any ECCS pumps and properly align valves for injection from the control room remains valid. As stated in Section 3.3 of this SE, with one ECCS injection/spray subsystem and additional, non-safety related injection

sources, defense-in-depth will be maintained.

The defense-in-depth measure is consistent with other events considered during shutdown with no additional single failure assumed.

The drain time controls, in addition to the required ECCS injection/spray subsystem, provide reasonable assurance that an unexpected draining event can be prevented or mitigated before the RPV water level would be lowered to the TAF. Based on the NRC staff's assessment in this SE and its review of Reference 11, the staff determined that the proposed LCOs 3.3.5.2 and 3.5.2 are consistent with TSTF-542 and are adequate to ensure the performance of required safety functions for the applicable modes of operation, including the application of LCO 3.10.1. Therefore, the proposed changes are acceptable.

3.8 Technical Evaluation Conclusion HNP Safety Limit 2.1.1.3 requires that reactor vessel water level shall be greater than the top of active irradiated fuel. Maintaining water level above the TAF ensures that the fuel cladding fission product barrier is protected during shutdown conditions.

The proposed TS changes evaluated within this SE establish new LCO requirements that address the preventive and mitigative equipment and associated instrumentation that provide an alternative means to support Safety Limit 2.1.1.3 during Mode 4 and 5 operations.

The reactor coolant system is at a low operating temperature(~

212 °F) and is depressurized during Modes 4 and 5 conditions.

An event involving a loss of inventory while in the shutdown condition does not exceed the capacity of one ECCS subsystem.

The accidents that are postulated to occur during shutdown conditions, the Fuel Handling Accident (FSAR Section 15.3.5) and the Liquid Radwaste Tank Failure (FSAR Section 15.4.14),

do not involve a loss of inventory.

Therefore, the equipment and instrumentation associated with the Reactor Pressure Vessel WIC TS do not provide detection or mitigation related to these design basis accidents.

The proposed TS LCO 3.5.2 contains requirements for operability of one ECCS subsystem along with requirements to maintain a sufficiently long Drain Time so that plant operators would have time to diagnose and mitigate an unplanned draining event. The NRC staff has determined that new LCOs 3.5.2 and 3.3.5.2 provide for the lowest functional capability or performance levels of equipment required for safe operation of the facility and, therefore, meet the LCO requirements of 10 CFR 50.36(c)(2)(i).

Additionally, the revised TS LCOs 3.5.2 and 3.3.5.2 provide remedial actions to be taken in the event the LCO is not satisfied and, therefore, meet the requirements of 10 CFR 50.36(c)(2)(i).

The NRC staff finds that the proposed Action statements provide reasonable assurance that an unexpected draining event can be prevented or mitigated before the RPV water level would be lowered to the T AF. The NRC staff evaluated the proposed DRAIN TIME definition; TS 3.5.2, which contains the requirements for RPV WIC; and TS 3.3.5.2, which contains the requirements for instrumentation necessary to support TS 3.5.2. Based on the considerations discussed above, the NRC staff concludes that the proposed revisions are acceptable, because they consolidate and clarify the RPV WIC requirements, which meet 10 CFR 50.36(c)(2)(ii),

Criterion 4, to establish LCOs for structures,

systems, or components significant to public health and safety as evidenced by operating experience.

The licensee proposed to delete OPDRVs references from certain TS Applicability descriptions, Conditions, Required

Actions, and Footnotes statements.

The NRC staff has reviewed the proposed changes and determined that the deletion of OPDRVs references, along with the corresponding editorial

changes, are appropriate, because the proposed TSs governing RPV WIC and the associated instrumentation, TSs 3.5.2 and 3.3.5.2, respectively, are a clarified and simplified alternative set of controls for ensuring that water level is maintained above the TAF. The NRC staff reviewed the SRs associated with the new LCOs 3.5.2 and 3.3.5.2.

The NRC staff finds that the proposed SRs in TS 3.5.2 are acceptable, since they provide assurance that: (1) the drain time requirements will be met, (2) sufficient water inventory is available for ECCS injection/spray subsystem RPV injection and pump performance, (3) the ECCS injection/spray subsystems are adequately filled (mitigating the effects of gas accumulation or voiding),

(4) the subsystems are properly aligned through verified valve positions to support RPV injection, (5) pumps are verified to be capable of providing adequate flow to support drain time and RPV injection, (6) valves will actuate to the proper position on an automatic isolation signal, and (7) the ECCS injection/spray subsystems can be manually operated to inject. The NRC staff finds that the two SRs proposed for TS 3.3.5.2 are sufficient and acceptable, because they are essential to ensure that the required systems and components are capable of performing their specified safety functions in support of TS 3.5.2, thereby providing protection against a potential drain down of the RPV in Modes 4 and 5. Therefore, the NRC staff concludes that the proposed SRs satisfy 10 CFR 50.36(c)(3).

The NRC staff evaluated the proposed HNP changes against each of the unit applicable design requirements listed in Section 2.3 1 (Unit 1) and Section 2.3.2 (Unit 2) of this SE. The NRC staff finds that the proposed changes for Mode 4 and 5 operations, as they relate to the proposed TS changes for the new DRAIN TIME definition and the removal of OPDRVs references, remain consistent with the applicable design criteria, in that the HNP design requirements are maintained for instrumentation, reactor coolant leakage detection, the reactor coolant pressure

boundary, and reactor coolant makeup. The regulation at 10 CFR 50.36(a)(1) states that a summary statement of the bases or reasons for such specifications, other than those covering administrative

controls, shall also be included in the application, but shall not become part of the TSs. In accordance with this requirement, the licensee provided TS Bases changes in the proposed license amendment request (Reference 1 ). The NRC staff has concluded that the TS Bases changes provided describe the bases for the affected TS and follow the "Final Policy Statement on Technical Specifications Improvements for Nuclear Power Reactors" (58 Federal Register 39132; July 22, 1993). Additionally, the proposed TS changes were reviewed for technical clarity and consistency with the existing HNP requirements for customary terminology and formatting.

The NRC staff found that the proposed changes were consistent with TSTF-542 (Reference 5), and Chapter 16 of the SRP, NUREG-0800, Revision 3 (Reference 6).

4.0 STATE CONSULTATION

In accordance with the Commission's regulations, the Georgia State official was notified of the proposed issuance of the amendments on April 11, 2018. The NRC staff verified that the State official had no comments on April 16, 2018. 5.0 ENVIRONMENTAL CONSIDERATION The amendments change requirements with respect to the installation or use of facility components located within the restricted area as defined in 1 O CFR Part 20 and change surveillance requirements.

The NRC staff has determined that the amendments involve no significant increase in the amounts and no significant change in the types of any effluents that may be released offsite and that there is no significant increase in individual or cumulative occupational radiation exposure.

The Commission has previously issued a proposed finding that the amendments involve no significant hazards consideration, and there has been no public comment on such finding published in the Federal Register on August 29, 2017 (82 FR 41071 ). Accordingly, the amendments meet the eligibility criteria for categorical exclusion set forth in 1 O CFR 51.22(c)(9).

Pursuant to 10 CFR 51.22(b),

no environmental impact statement or environmental assessment need be prepared in connection with the issuance of the amendments.

6.0 CONCLUSION

The Commission has concluded, based on the considerations discussed above, that: (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner, (2) there is reasonable assurance that such activities will be conducted in compliance with the Commission's regulations, and (3) the issuance of the amendments will not be inimical to the common defense and security or to the health and safety of the public.

7.0 REFERENCES

1. Letter from Southern Nuclear to US NRC, Edwin I. Hatch Nuclear Plant, Units 1 and 2, Application to Revise Technical Specifications to Adopt TSTF-542, "Reactor Pressure Vessel Water Inventory Control,"

dated April 20, 2017, ADAMS Accession No. ML 17114A377.

2. Letter from Southern Nuclear to US NRC, Edwin I. Hatch Nuclear Plant, Units 1 and 2, Supplemental Pages for Application to Adopt TSTF-542, "Reactor Pressure Vessel Water Inventory Control,"

dated September 24, 2017, ADAMS Accession No. ML 17257 A375. 3. Letter from Southern Nuclear to US NRC, Edwin I. Hatch Nuclear Plant, Units 1 and 2, Supplement to Application to Adopt TSTF-542, "Reactor Pressure Vessel Water Inventory Control,"

dated February 19, 2018, ADAMS Accession No. ML 18050A052.

4. Letter from Southern Nuclear to US NRC, Edwin I. Hatch Nuclear Plant, Units 1 and 2, Supplement to License Amendment Request to Adopt TSTF-542, "Reactor Pressure Vessel Water Inventory Control,"

dated May 1, 2018, ADAMS Accession No. ML 18121A398.

5. Letter from US NRC to Technical Specifications Task Force, Final Safety Evaluation of Technical Specifications Task Force Traveler TSTF-542, Revision 2, "Reactor Pressure Vessel Water Inventory Control,"

(TAC No. MF3487),

dated December 20, 2016, ADAMS Accession No. ML 163439008.

6. U.S. Nuclear Regulatory Commission (USN RC) "Standard Review Plan for the Review of Safety Analysis Reports for Nuclear Power Plants,"

NUREG-0800, Revision 3, Chapter 16, "Technical Specifications,"

dated March 2010, ADAMS Accession No. ML 100351425.

7. U.S. Nuclear Regulatory Commission (USNRC),

"Standard Technical Specifications, General Electric BWR/4 Plants,"

NUREG-1433, Vol. 1, "Specifications,"

Rev. 4.0, dated April 2012, ADAMS Accession No. ML 12104A192. 8. U.S. Nuclear Regulatory Commission (USNRC),

"Standard Technical Specifications, General Electric BWR/4 Plants,"

NUREG-1433, Vol. 2, "Bases,"

Rev. 4.0, dated April 2012, ADAMS Accession No. ML 12104A193.

9. Letter from US NRC to Southern Nuclear Operating

Company, "Edwin I. Hatch Nuclear Plant, Units 1 and 2 Re: Issuance of Amendments (TAC Nos. MB2966 and MB2968),"

dated September 26, 2002, ADAMS Accession No. ML022700096.

10. Letter from Technical Specifications Task Force to US NRC, "TSTF-484, Revision 0, 'Use of TS 3.10.1 for Scram Time Testing Activities,"'

dated May 5, 2005, ADAMS Accession No. ML052930102.

11. Letter from US NRC to Edwin I. Hatch Nuclear Plant, "Edwin I. Hatch Nuclear Plant, Unit Nos.1 and 2, Issuance of Amendments Regarding Technical Specification Task Force (TSTF) Change TSTF-484,

'Use of TS 3.10.1 for Scram Time Testing Activities' (TAC Nos. MD4225 and MD4226),"

dated May 17, 2007, ADAMS Accession No. ML070870587.

12. Letter from US NRC to Technical Specification Task Force, "Request for Additional Information Regarding TSTF-484, Revision 0, 'Use of TS 3.10.1 for Scram Time Testing Activities,"'

dated April 7, 2006, ADAMS Accession No. ML060970568.

13. Letter from Technical Specifications Task Force to US NRC, "Response to NRC Request for Additional Information Regarding TSTF-484, Revision 0, 'Use of TS 3.10.1 for Scram Time Testing Activities,'

dated April 7, 2006," dated June 5, 2006, ADAMS Accession No. ML061560523.

14. Federal Register Notice, US NRC, "Notice of Availability of Model Safety Evaluation on Technical Specification Improvement to Modify Requirements Regarding LCO 3.10.1, lnservice Leak and Hydrostatic Testing Operation Using the Consolidated Line Item Improvement Process,"

dated October 12, 2006, ADAMS Accession No. ML062760109.

Principal Contributors:

Larry Wheeler, NRR Shie-Jeng Peng, NRR Rossnyev

Alvarado, NRR D~e: May 31, 2018 C. A. Gayheart

SUBJECT:

EDWIN I. HATCH NUCLEAR PLANT, UNIT NOS. 1 AND 2 -ISSUANCE OF AMENDMENTS TO ADOPT TSTF-542, REVISION 2, "REACTOR PRESSURE VESSEL WATER INVENTORY CONTROL" (CAC NOS. MF9662 AND MF9663; EPID L-2017-LLA-0215)

DATED MAY 31, 2018 DISTRIBUTION:

PUBLIC PM Reading File RidsNrrDssSrxb Resource RidsNrrDEEicb Resource RidsACRS_MailCTR Resource RidsNrrDorlLpl2-1 Resource RidsNrrDssStsb Resource RidsNrrLAJBurkhardt Resource RidsNrrLAKGoldstein Resource RidsNrrPMHatch Resource RidsRgn2Mail Center Resource MRazzaque, NRR RAlvarado, NRR ADAMS Accession No. ML 18123A368

via memorandum OFFICE NRR/DORL/LPL2-1

/PM NRR/DORL/LPL2-1

/LA NRR/DSS/SRXB/BC(A)

NRR/DE/EICB/BC NAME JHall KGoldstein JWhitman*

(RBeaton for) MWaters*

DATE 05/11/18 05/11/18 12/14/17 12/06/17 OFFICE NRR/DSS/STSB/BC OGC-NLO N RR/DORL/LPL2-1

/BC NRR/DORL/LPL2-1

/PM NAME VCusumano*

JWachutka MMarkley JHall (w/comments)

DATE 12/14/17 05/22/18 05/30/18 05/31/18 OFFICIAL RECORD COPY

v t e Letter Sequence Approval
CAC:MF9662, (Approved, Closed) CAC:MF9663, (Approved, Closed) EPID:L-2017-LLA-0215, TSTF-542 (Approved, Closed)
Initiation Request Acceptance Supplement, Supplement, Supplement Administration Questions Answers Results Approval Other:
MONTHYEAR2018-02-19 [Table View]

ML18123A368

Text

SUBJECT:

Dear Ms. Gayheart:

Enclosures:

Attachment:

Attachment:

1.0 INTRODUCTION

4.0 STATE CONSULTATION

6.0 CONCLUSION

7.0 REFERENCES

SUBJECT:

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