Text

Current Facility Operating License DPR-64, Technical Specifications, Revised 12/27/2017
	ML052720273
Person / Time
Site:	Indian Point
Issue date:	07/11/2007
From:	Reid R; Office of Nuclear Reactor Regulation
To:	; Entergy Nuclear Operations
References
	FOIA/PA-2016-0148
	Download: ML052720273 (410)
	v • d • e

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 ENTERGY NUCLEAR INDIAN POINT 3. LLC AND ENTERGY NUCLEAR OPERATIONS. INC.

DOCKET NO. 50-286 INDIAN POINT NUCLEAR GENERATING UNIT NO. 3 AMENDED FACILITY OPERATING LICENSE Amendment No. 203 License No. DPR-64

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

A. The application for amendment by the Power Authority of the Arndt. 203 State of New York (PASNY) and Entergy Nuclear Indian Point 3, 11/27/00 LLC (ENIP3) and Entergy Nuclear Operations, Inc. (ENO),

submitted under cover letters dated May 11 and May 12, 2000, as supplemented on June 13, June 16, July 14, September 21, October 26, and November 3, 2000, 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. ENIP3 and ENO are financially and technically qualified to Arndt. 203 engage in the activities authorized by this amendment; 11/27/00 E. ENIP3 and ENO have satisfied the applicable provisions of Arndt. 203 10 CFR Part 140, "Financial Protection Requirements and 11/27/00 Indemnity Agreements" of the Commission's regulations; F. The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; Amendment No. 225

-*

G. The receipt, possession and use of source, byproduct and special nuclear material as authorized by this amendment will be in accordance with the Commission's regulations in 10 CFR Parts 30, 40 and 70 including 10 CFR Sections 30.33, 40.32, 70.23, and 70.31; and H. The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.

2. Accordingly, Facility Operating License No. DPR-64 (previously Arndt. 203 issued to Consolidated Edison Company of New York, Inc., and 11/27/00 the Power Authority of the State of New York) is hereby amended in its entirety and transferred to ENIP3 and ENO on November 21, 2000, to read as follows:

A. This amended license applies to the Indian Point Nuclear Arndt. 203 Generating Unit No. 3, a pressurized water nuclear reactor 11/27/00 and associated equipment (the facility), owned by ENIP3 and operated by ENO. The facility is located in Westchester County, New York, on the east bank of the Hudson River in the Village of Buchanan, and is described in the *Final Facility Description and Safety Analysis Report" as supplemented and amended, and the Environmental Report, as amended.

8. Subject to the conditions and requirements incorporated herein, the Commission licenses:

(1) Pursuant to Section 104b of the Act and 10 CFR Part 50, Arndt. 203

ucensing of Production and Utilization Facilities,* 11/27/00 (a) ENIP3 to possess and use, and (b) ENO to possess, use and operate, the facility at the designated location in Westchester County, New York, in accordance with the procedures and limitations set forth in this amended license; (2) ENO pursuant to the Act and 10 CFR Part 70, to receive, Arndt. 203 possess, and use, at any time, special nuclear material as 11/27/00 reactor fuel, in accordance with the limitations for storage and amounts required for reactor operation, as described in the Final Facility Description and Safety Analysis Report, as supplemented and amended; (3) ENO pursuant to the Act and 10 CFR Parts 30, 40, and 70, Arndt. 203 to receive, possess, and use, at any time, any byproduct 11/27/00 source and special nuclear material as sealed neutron sources for reactor startup, sealed sources for reactor instrumentation and radiation monitoring equipment calibration, and as fission detectors in amounts as required; Amendment No. 225

(4) ENO pursuant to the Act and 10 CFR Parts 30, 40 and 70, Arndt. 203 to receive, possess, and use in amounts as required any 11/27/00 byproduct, source or special nuclear material without restriction to chemical or physical form, for sample analysis or instrument calibration; or associated with radioactive apparatus or components.

(5) ENO pursuant to the Act and 10 CFR Parts 30 and 70, to Arndt. 203 possess, but not separate, such byproduct and special 11/27/00 nuclear materials as may be produced by the operation of the facility.

C. This amended 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, Sections 50.54 and 50.59 of Part 50, and Section 70.32 of Part 70; and is subject to all applicable provisions of the Act and to the rules, regulations, and orders of the Commission now or hereafter in effect; and is subject to the additional conditions specified below:

( 1) Maximum Power Level ENO is authorized to operate the facility at steady state reactor core power levels not in excess of 3216 megawatts thermal (100% of rated power).

(2) Technical Specifications The Technical Specifications contained in Appendices A and B, as revised through Amendment No. 264, are hereby incorporated in the License. ENO shall operate the facility in accordance with the Technical Specifications.

(3) (DELETED) Arndt. 205 2-27-01 (4) (DELETED) Arndt. 205 2-27-01 D. (DELETED) Arndt. 46 2-16-83 E. (DELETED) Arndt. 37 5-14-81 F. This amended license is also subject to appropriate conditions by the New York State Department of Environmental Conservation in its letter of May 2, 1975, to Consolidated Edison Company of New York, Inc., granting a Section 401 certification under the Federal Water Pollution Control Act Amendments of 1972.

Amendment No. 264

G. ENO shall fully implement and maintain in effect all provisions of the Commission-approved physical security, training and qualification, and safeguards contingency plans including amendments made pursuant to provisions of the Miscellaneous Amendments and Search Requirements revisions to 10 CFR 73.55 (51 FR 27817 and 27822), and to the authority of 10 CFR 50.90 and CFR 50.54(p). The combined set of plans 1 for the Indian Point Energy Center, which contain Safeguards Information protected under 10 CFR 73.21, is entitled: "Physical Security, Training and Qualification, and Safeguards Contingency Plan, Revision O," and was submitted by letter dated October 14, 2004, as supplemented by letter dated May 18, 2006.

ENO shall fully implement and maintain in effect all provisions of the Commission-approved cyber security plan (CSP), including changes made pursuant to the authority of 10 CFR 50.90 and 10 CFR 50.54(p). The ENO CSP was approved by License Amendment No. 243, as supplemented by changes approved by License Amendment Nos. 254, 260, and 263.

ENO has been granted Commission authorization to use "stand alone preemption authority" under Section 161A of the Atomic Energy Act, 42 U.S.C. 2201a with respect to the weapons described in Section II supplemented with Section Ill of Attachment 1 to its application submitted by letter dated August 20, 2013, as supplemented by letters dated November 21, 2013, and July 24, 2014, and citing letters dated April 27, 2011, and January 4, 2012. ENO shall fully implement and maintain in effect the provisions of the Commission-approved authorization.

H. ENO shall implement and maintain in effect all provisions of the approved Fire Protection Program as described in the Final Safety Analysis Report for Indian Point Nuclear Generating Unit No. 3 and as approved in NRC fire protection safety evaluations (SEs) dated September 21, 1973, March 6, 1979, May 2, 1980, November 18, 1982, December 30, 1982, February 2, 1984, April 16, 1984, January 7, 1987, September 9, 1988, October 21, 1991, April 20, 1994, January 5, 1995, and supplements thereto, subject to the following provision:

ENO may make changes to the approved Fire Protection Program without prior approval of the Commission only if those changes would not adversely affect the ability to achieve and maintain safe shutdown in the event of a fire.

I. (DELETED) Arndt. 205 2/27/01 J. (DELETED) Arndt. 205 2/27/01 K. (DELETED) Arndt. 49 5-25-84 L. (DELETED) Arndt. 205 2/27/01 1

The Training and Qualification Plan and Safeguards Contingency Plan are Appendices to the Security Plan.

Amendment No. 263

M. (DELETED) Arndt. 205 2/27/01 N. (DELETED) Arndt. 49 5-25-84

0. Evaluation, status and schedule for completion Arndt. 47 of balance of plant modifications as outlined in letter 5-27-83 dated February 12, 1983, shall be forwarded to the NRC by January 1, 1984.

P. Entergy Nuclear IP3 and ENO shall take no Arndt. 203 action to cause Entergy Global Investments, Inc. 11/21/00 or Entergy International Ltd. LLC, or their parent companies to void, cancel, or modify the $70 million contingency commitment to provide funding for the facility as represented in the application for approval of the transfer of the license from PASNY to ENIP3 and ENO, without the prior written consent of the Director, Office of Nuclear Reactor Regulation.

Q. (DELETED)

R. (DELETED)

S. (DELETED)

T. (DELETED Amendment No. 262

U. (DELETED)

V. (DELETED)

W. For purposes of ensuring public health and safety, ENIP3, upon the transfer of this license to it, and upon transfer of decommissioning funds from PASNY to ENO, shall provide decommissioning funding assurance for the facility by the prepayment or equivalent method, to be held in a decommissioning trust fund for the facility, of no less than the amount required under NRC regulations at 10 CFR 50.75.

Any amount held in any decommissioning trust maintained by ENO for the facility after 1 the transfer of the facility license to ENIP3 may be credited towards the amount required under this paragraph.

X. ENIP3 shall take all necessary steps to ensure that the decommissioning trust is maintained in accordance with the application for the transfer of this license to ENIP3 and ENO, as modified by the request to transfer decommissioning funds from PASNY, and the requirements of the order approving the transfer and order approving the transfer of decommissioning funds from PASNY to ENO, and consistent with the safety evaluations supporting such orders.

AA. The following conditions relate to the amendment approving Arndt. 205 the conversion to Improved Standard Technical Specifications: 2/27/01

1. This amendment authorizes the relocation of certain Technical Specification requirements and detailed information to licensee-controlled documents as described in Table R, "Relocated Technical Specifications Amendment No. 262

u from the CTS," and Table LA, "Removed Details and Less Restrictive Administrative Changes to the CTS" attached to the NRC staff's Safety Evaluation enclosed with this amendment. The relocation of requirements and detailed information shall be completed on or before the implementation of this amendment.

2. The following is a schedule for implementing surveillance requirements (SRs):

.

For SRs that are new in this amendment, the first performance is due at the end of the first surveillance interval that begins on the date of implementation of this amendment.

For SRs that existed prior to this amendment whose intervals of performance are being reduced, the first reduced surveillance interval begins upon completion of the first surveillance performed after the date of implementation of this amendment.

For SRs that existed prior to this amendment that have modified acceptance criteria, the first performance is due at the end of the first surveillance interval that began on the date the surveillance was last performed prior to the date u of implementation of this amendment.

For SRs that existed prior to this amendment whose intervals of performance are being extended, the first extended surveillance interval begins upon completion of the last surveillance performed prior to the date of implementation of this amendment.

AB. With the reactor critical, Entergy shall maintain th~ reactor coolant system cold leg at a temperature {Tcokl) greater than or equal to 525 °F. Entergy shall maintain a record of the cumulative time that the plant is operated with the reactor critical while Tco1c1 is below 525 °F. Upon determination by Entergy that the cumulative time of plant operation with the reactor critical while Tcold is below 525 °F has exceeded one (1} year, Entergy must:

{a) within one (1} month, inform the NRC, in writing, and

{b) within six {6} months submit the results of an analysis of the impact of the operation with T cold below 525 °F on the pressurized thermal shock reference temperature (RTprs),

Amendment No. 225

AC. Mitigation Strategy License Condition The licensee shall develop and maintain strategies for addressing large fires and explosions and that include the following key areas:

(a) Fire fighting response strategy with the following elements:

1. Pre-defined coordinated fire response strategy and guidance

2. Assessment of mutual aid fire fighting assets

3. Designated staging areas for equipment and materials

4. Command and control

5. Training of response personnel (b) Operations to mitigate fuel damage considering the following:

1. Protection and use of personnel assets

2. Communications

3. Minimizing fire spread

4. Procedures for implementing integrated fire response strategy

5. Identification of readily-available pre-staged equipment

6. Training on integrated fire response strategy

7. Spent fuel pool mitigation measures

( c) Actions to minimize release to include consideration of:

1. Water spray scrubbing

2. Dose to onsite responders AD. Control Room Envelope Habitability Upon implementation of Amendment No. 239 adopting TSTF-448, Revision 3 (as supplemented), the determination of control room envelope (CRE) unfiltered air inleakage as required by Technical Specification (TS) Surveillance Requirement (SR) 3. 7.11.4, in accordance with TS 5.5.16.c.(i), the assessment of CRE habitability as required by TS 5.5.16.c.(ii), and the measurement of CRE pressure as required by TS 5.5.16.d, shall be considered met. Following implementation:

(a) The first performance of SR 3.7.11.4, in accordance with TS 5.5.16.c.(i),

shall be within the specified Frequency of 6 years, plus the 18-month allowance of SR 3.0.2, as measured from February 1, 2005, the date of the most recent successful tracer gas test, as stated in the June 28, 2005, letter response to Generic Letter 2003-01.

(b) The first performance of the periodic assessment of CRE habitability, TS 5.5.16.c.(ii), shall be within the next 9 months since the time period since the most recent successful tracer gas test is greater than 3 years.

(c) The first performance of the periodic measurement of CRE pressure, TS 5.5.16.d, shall be within 24 months, plus the 182 days allowed by SR 3.0.2, as measured from June 18, 2007, the date of the most recent successful pressure measurement test.

Amendment 239

AE. ENO may transfer IP3 spent fuel to the IP2 spent fuel pit subject to the conditions listed in Appendix C. ENO is further authorized to transfer IP3 spent fuel into NRC approved storage casks for onsite storage by ENO and ENIP3.

3. This amended license is effective at 12:01 a.m., November 21, 2000, and shall expire at midnight December 12, 2015.

Original signed by Robert W. Reid, Chief Operating Reactors Branch #4 Division of Operating Reactors Attachments:

Appendix A- Technical Specifications Appendix B - Environmental Technical Specification Requirements Appendix C - Inter-Unit Fuel Transfer Technical Specifications Date of Issuance: March 8, 1978 Amendment No. 246

APPENDIX A FACILITY OPERATING LICENSE DPR-64 TECHNICAL SPECIFICATIONS AND BASES FOR THE INDIAN POINT 3 NUCLEAR GENERATING STATION UNIT NO. 3 WESTCHESTER COUNTY, NEW YORK ENTERGY NUCLEAR INDIAN POINT 3 1 LLC (ENIP3)

AND ENTERGY NUCLEAR OPERATIONS, INC. (ENO) I DOCKET NO. 50-286 Date of Issuance:

April .15, 1976 Amendment No. 203

Facility Operating License No. DPR-64 Appendix A - Technical Specifications TABLE OF CONTENTS 1.0 USE AND APPLICATION 1.1 Definitions 1.2 Logical Connectors 1.3 Completion Times 1.4 Frequency 2.0 SAFETY LIMITS {SLs) 2.1 Safety Limits 2.2 Safety Limit Violations 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY SURVEILLANCE REQUIREMENT (SR) APPLICABILITY 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 Shutdown Margin (SOM) 3.1.2 Core Reactivity 3.1.3 Moderator Temperature Coefficient (MTC) 3.1.4 Rod Group Alignment Limits 3.1.5 Shutdown Bank Insertion Limits 3.1.6 Control Bank Insertion Limits 3.1.7 Rod Position Indication 3.1.8 PHYSICS TE'STS Exceptions-MODE 2 3.2 POWER DISTRIBUTION LIMITS 3.2.1 Heat Flux Hot Channel Factor (FQ(Z))

3.2.2 Nuclear Enthalpy Rise Hot Channel Factor (F\)

3.2.3 AXIAL FLUX DIFFERENCE (AFD) 3.2.4 QUADRANT POWER TILT RATIO (QPTR) 3.3 INSTRUMENTATION 3.3.1 Reactor Protection System (RPS) Instrumentation 3.3.2 Engineered Safety Feature Actuation System (ESFAS) Instrumentation 3.3.3 Post Accident Monitoring (PAM) Instrumentation 3.3.4 Remote Shutdown '

3.3.5 Loss of Power (LOP) Diesel Generator (DG) Start Instrumentation 3.3.6 Containment Purge System and Pressure Relief Line Isolation Instrumentation 3.3.7 Control Room Ventilation (CRVS) Actuation Instrumentation 3.3.8 Fuel Storage Building Emergency Ventil*ation System (FSBEVS)

Actuation Instrumentation (continued)

INDIP.N POINT 3 Amendment 233

Facility Operating License No. DPR-64 Appendix A - Technical Specifications TABLE OF CONTENTS 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits 3.4.2 RCS Minimum Temperature for Criticality 3.4.3 RCS Pressure and Temperature (P/T) Limits 3.4.4 RCS Loops -MODES 1. and 2 3.4.5 RCS Loops - MODE 3 3.4.6 RCS Loops - MODE 4 J.4.7 RCS Loops -MODE 5, Loops Fi 11 ed 3.4.8 RCS Loops -MODE 5, Loops Not Fi 11 ed 3.4.9

Pressurizer 3.4.10 Pressurizer Safety Valves 3.4.11 .Pressurize~ Power Operated Relief Valves (PORVs) 3.4.12 Low Temperature Overpressure Protection (LTOP) 3.4.13 RCS Operational LEAKAGE 3.4.14 RCS Pressure Isolation Valve (PIV) Leakage 3.4.15 RCS Leakage Detection Instrumentation 3.4.16 RCS Specific Activity 3.4.17 Steam Generator (SG) Tube Integrity 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.1 Accumul c;\tors 3.5.2 ECCS-Operating 3.5.3 ECCS - Shutdown 3.5.4 Refueling Water Storage Tank (RWS!)

3.6 CONTAINMENT SYSTEMS 3.6.1 Containment

.3.6.2 Containment Air Locks 3.6.3 Containment Isolation Valves 3.6.4 Containment Pressure 3.6.5 Containment Air Temperature 3.6.6 Containment Spray System and Containment *Fan Cooler System 3.6.7 Recirculation pH Control System '

3.6.8 Not Used 3.6.9 Isolation Valve Seal Water (IVSW) System 3.6.10 Weld Channel and Penetration Pressurization System (WC &PPS)

(continued)

INDIAN POINT 3 ii Amendment 236

Facility Operating License No. DPR-64 Appendix A - Technical Specifications TABLE OF CONTENTS 3.7 PLANT SYSTEMS

3. 7. 1 Main Steam Safety Valves (MSSVs) 3.7.2 Main Steam Isolation Valves (MSIVs) and Main Steam Check Valves (MSCVs) 3.7.3 Main Boiler Feedpump Discharge Valves (MBFPDVs), Main Feedwater Regulation Valves (MFRVs), Main Feedwater Inlet Isolation Valves (MFIIVs) and Main Feedwater (MF) Low Flow Bypass Valves 3.7.4 Atmospheric Dump Valves (ADVs) 3.7.5 Auxiliary Feedwater (AFW) System 3.7.6 Condensate Storage Tank (CST) 3.7.7 City Water (CW) 3.7.8 Component Cooling Water (CCW) System 3.7.9 Service Water (SW) System

3. 7 .10 Ultimate Heat Sink (UHS)

3. 7 .11 Control Room Ventilation System (CRVS)

3. 7. 12 Control Room Air Conditioning System (CRACS) 3.7.13 Fuel Storage Building Emergency Ventilation System (FSBEVS)

3. 7. 14 Spent Fuel Pit Water Level

3. 7. 15 Spent Fuel Pit Boron Concentration

3. 7. 16 Spent Fuel Assembly Storage

3. 7. 17 Secondary Specific Activity 3.8 ELECTRICAL POWER SYSTEMS 3 .8.1 AC Sources-Operating 3.8.2 AC Sources - Shutdown 3.8.3 Diesel Fuel Oil and Starting Air 3.8.4 DC Sources-Operating 3.6.5 DC Sources-Shutdown 3.8.6 Battery Cell Parameters 3.8.7 Inverters - Operating 3.8.8 Inverters-Shutdown 3.8.9 Distribution Systems-Operating 3.8.10 Dist ri but ion Sys terns - Shutdown 3.9 REFUELING OPERATIONS

3. 9. 1 Boron Concentration 3.9.2 Nuclear Instrumentation 3.9.3 Containment Penetrations 3.9.4 Residual Heat Removal (RHR) and Coolant Circulation-High Water Level 3.9.5 Residual Heat Removal (RHR) and Coolant Circulation-Low Water Level 3.9.6 Refueling Cavity Water Level (continued)

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J iii Amendment 233

Facility Operating License No. DPR-64 Appendix A - Technical Specifications TABLE OF CONTENTS 4.0 DESIGN FEATURES 4 .1 Site Location 4.2 Reactor Core 4.3 Fuel Storage 5.0 ADMINISTRATIVE CONTROLS 5.1 Responsibility 5.2 Organization 5.3 Unit Staff Qualifications 5.4 Procedures 5.5 Programs and Manuals

5. 5 .1 Offsite Dose Calculation Manual (ODCM) 5.5.2 Primary Coolant Sources Outside Containment

5. 5. 3 NOT USED 5.5.4 Radioactive Effluent Controls Program

5. 5. 5 Component Cyclic or Transient Limit 5.5.6 Reactor Coolant Pump Flywheel Inspection Program

5. 5. 7 Inservice Testing Program 5.5.8 Steam Generator (SG) Program 5.5.9 Secondary Water Chemistry Program

5. 5 .10 Ventilation Filter Testing Program (VFTP)

5. 5 .11 Explosive Gas and Storage Tank Radioactivity Monitoring Program 5.5.12 Diesel Fuel Oil Testing Program

5. 5 .13 Technical Specification (TS) Bases Control Program 5.5.14 Safety Function Determination Program (SFDP) 5.5.15 Containment Leakage Rate Testing Program 5.5.16 Control Room Envelope Habitability Program 5.6 Reporting Requirements

5. 6 .1 NOT USED 5.6.2 Annual Radiological Environmental Operating Report 5.6.3 Radioactive Effluent Release Report 5.6.4 NOT USED 5.6.5 CORE OPERATING LIMITS REPORT (COLR) 5.6.6 NOT USED 5.6.7 Post Accident Monitoring Instrumentation (PAM) Report 5.6.8 Steam Generator Tube Inspection Report 5.7 High Radiation Area INDIAN POINT 3 iv Amendment 239

Definitions 1.1 u 1.0 USE AND APPLICATION 1.1 Definitions

- - - - NOTE*******************************************

The defined terms of this section appear in capitalized type and are applicable throughout these Technical Specifications and Bases.

Ier:m Definition ACTIONS ACTIONS shall be that part of a Specification that prescribes*Required Actions to be taken under designated Conditions within specified Completion Times.

ACTUATION LOGIC TEST An ACTUATION LOGIC TEST shall be the application of various simulated or actual input combinations in conjunction with each possible interlock logic state and the verification of the required logic output. The ACTUATION LOGIC TEST, as a minimum, shall include a continuity check of output devices.

AXIAL FLUX DIFFERENCE AFD shall be the difference in normalized flux CAFD) signals between the top and bottom halves of a two section excore neutron detector.

CHANNEL CALIBRATION A CHANNEL CALIBRATION shall be the adjustment. as necessary, of the channel so that it responds within the required range and accuracy to known input. The CHANNEL CALIBRATION shall encompass the entire channel, including the required sensor, alarm, interlock, display, and trip functions. Calibration of instrument channels with resistance temperature detector CRTD) or thermocouple sensors may consist of an inplace qualitative assessment of sensor behavior and normal calibration of the remaining adjustable devices in the channel. Whenever a sensing element is replaced, the next required CHANNEL CALIBRATION shall include an inplace cross calibration that compares the other sensing elements with the (continued)

~)

INDIAN POIITT 3 1.1*1 Amenctnent 205

Definitions 1.1 1.1 Definitions CHANNEL CALIBRATION (continued) recently installed sensing element. The CHANNEL CALIBRATION may be performed by means of any series of sequential, overlapping calibrations or total channel steps so that the entire channel is calibrated.

CHANNEL CHECK A CHANNEL CHECK shall be the qualitative assessment, by observation, of channel behavior during operation. This determination shall include, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter.

CHANNEL OPERATIONAL A COT shall be the injection of a simulated or TEST (COT) actual signal into the channel as close to the sensor as practicable to verify the OPERABILITY of required alarm, interlock, display, and trip functions. The COT shall include adjustments, as necessary, of the required alarm, interlock, and trip setpoints so that the setpoints are within the required range and accuracy.*

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

CORE OPERATING LIMITS The COLR is the unit specific document that REPORT (COLR) provides cycle specific parameter limits for the current reload cycle. These-cycle specific parameter 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.

(continued)

~I INDIAN POINT 3 1.1*2 Amencknent 205

Definitions 1.1 1.1 Definitions (continued)

DOSE EQUIVALENT I-131 DOSE EQUIVALENT I-131 shall be that concentration of I-131 (microcuries per gram) that alone would produce the same dose when inhaled as the combined activities of iodine isotopes I-131, I-132, I-133, I-134, and I-135 actually present. If a specific isotope is not detected, it should be assumed to be present at the minimum detectable activity. The determination of DOSE EQUIVALENT I-131 shall be performed using Committed Effective Dose Equivalent (CEDE) dose conversion factors from Table 2.1 of EPA Federal Guidance Report No. 11, 1988.

DOSE EQUIVALENT XE-133 DOSE EQUIVALENT XE-133 shall be that concentration of Xe-133 (microcuries per gram) that alone would produce the same acute dose to the whole body as the combined activities of noble gas nuclides Kr-85m, Kr-85, Kr-87, Kr-88, Xe-13lm, Xe-133m, Xe-133, Xe-135m, Xe-i35, and Xe-138 actually present. If a specific noble gas nuclid~ is not detected, it should be assumed to be present at the minimum detectable activity. The determination of DOSE EQUIVALENT XE-133 shall be performed using effective dose conversion factors for air submersion listed in Table III.I of EPA Federal Guidance Report No. 12, 1993, "External Exposure to Radionuclides in Air, Water, and Soil".

The maximum allowable primary containment leakage rate, L,, shall be 0.1% of primary containment air weight per day at the calculated peak containment pressure (P,).

LEAKAGE LEAKAGE shall be:

a. Identified LEAKAGE

1. LEAKAGE, such as that from pump seals or valve packing (except for leakage into closed systems and reactor coolant pump (RCP) seal water injection or leakoff), that is ca~tured and conducted to collection systems or a sump or collecting tank; (Leakage into closed systems is leakage that can be accounted for and contained by a (continued)

INDIAN POINT 3 1.1 - 3 Amendment237

Definitions 1.1 1.1 Definitions LEAKAGE (continued) system not directly connected to the atmosphere.

Leakage past the pressurizer safety valve seats and leakage past the safety injection pressure isolation valves are examples of reactor coolant system leakage into closed systems.)

2. LEAKAGE into the containment atmosphere from source~ 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; or

3. Reactor Coolant System (RCS) LEAKAGE through a steam generator to the Secondary System (primary to secondary LEAKAGE);

b. Unidentified LEAKAGE A11 LEAKAGE (except for 1ea kage into c1osed sys terns and RCP seal water injection or leakoff) that is not identified LEAKAGE;

c. Pressure Boundary LEAKAGE LEAKAGE (except primary to secondary LEAKAGE) through a nonisolable fault in an RCS component body, pipe wall, or vessel wall, MASTER RELAY TEST A MASTER RELAY TEST shall consist of energ1z1ng each master relay and verifying the OPERABILITY of each relay.

The MASTER.RELAY TEST shall include a continuity check of each associated slave relay.

MODE A MODE shall correspond to any one inclusive combination of core reactivity condition, power level, average reactor coolant loop temperature, and reactor continued INDIAN POINT 3 1. 1 - 4 Amendment 233

Definitions 1.1 1.1 Definitions MODE (continued) vessel head closure bolt tensioning specified in Table 1.1-1 with fuel in the reactor vessel.

OPERABLE-OPERABILITY A system, subsystem, train, 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, train, component, or device to perform its specified safety function(s) are also capable of performing their related support function(s).

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:

a. Described in FSAR Chapter 13, Initial Tests and Operations;

b. Authorized under the provisions of 10 CFR 50.59; or u c. Otherwise approved by the Nuclear Regulatory Commission.

QUADRANT POWER TILT QPTR shall be the ratio of the maximum upper RATIO (QPTR) excore detector calibrated output to the average of the upper excore detector calibrated outputs, or the ratio of the maximum lower excore detector calibrated output to the average of the lower excore detector calibrated outputs, whichever is greater.

RATED THERMAL POWER RTP shall be a total reactor core heat transfer (RTP) rate to the reactor coolant of 3216 MWt.

(continued)

INDIAN POINT 3 1.1 - 5 Amendment 225

Definitions 1.1 1.1 Definitions (continued)

SHUTDOWN HARGIN CSDH) SDH shall be the instantaneous amount of reactivity by which the reactor is subcritical or would be subcritical from its present condition assuming:

a. All rod cluster control assemblies CRCCAs) are fully inserted except for the single RCCA of highest reactivity worth, which is assumed to be fully withdrawn. -With any RCCA not capable of being fully inserted, the reactivity worth of the RCCA must be accounted for in the determination of SDH: and

b. In HODES 1 and 2, the fuel and moderator temperatures are changed to the hot zero power level.

SLAVE RELAY TEST A SLAVE RELAY TEST shall consist of energizing each slave relay and verifying the OPERABILITY of each slave relay.

The SLAVE RELAY TEST shall include, as a minimum. a continuity check of associated testable actuation devices.

STAGGERED TEST BASIS 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.

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

(continued)

INDIAN POINT 3 1.1-6 Amencinent 205

Definitions 1.1 V

1.1 Definitions (continued)

TRIP ACTUATING DEVICE A TADOT shall consist of operating the trip OPERATIONAL TEST actuating device and verifying the OPERABILITY of CTADOT> required alarm. interlock. display. and trip functions.

The TADOT shall include adjustment. as necessary, of the trip actuating device so that it actuates at the required setpoint within the required accuracy.

INDIAN POINT 3 1.1-7 lvnenctnent 205

Definitions 1.1 Table 1.1-1 (page 1 of 1)

HODES Y. RATED AVERAGE REACTIVITY THERMAL REACTOR COOLANT HOOE TITLE CONDITION POWER(a) TEMPERATURE Ckett> (OF) 1 Power Operation ~ 0.99 > 5 NA 2 Startup ~ 0.99 :s: 5 NA 3 Hot Standby < 0.99 NA ~ 350 4 Hot Shutdown<b) < 0.99 NA 350 > Tavg > 200 5 Cold Shutdown<b) < 0.99 NA :s: 200 6 RefuelingCc) NA NA NA Ca) Excluding decay heat.

Cb) All reactor vessel head closure bolts fully tensioned.

Cc) One or more reactor vessel head closure bolts less than fully tensioned.

INDIAN POINT 3 1.1-8 Amenctnent 205

Logical Connectors 1.2 1.0 USE AND APPLICATION 1.2 Logical Connectors PURPOSE The purpose of this section is to explain the meaning of logical connectors.

Logical connectors are used in Technical Specifications (TS) to discriminate between, and yet connect. discrete Conditions, Required Actions, Completion Times. Surveillances. and Frequencies. The only logical connectors that appear in TS are AND and DB. The physical arrangement of these connectors constitutes logical conventions with specific meanings.

BACKGROUND Several levels of logic may be used to state Required Actions.

These levels are identified by the placement (or nesting) of the logical connectors and by the number assigned to each Required Action. The first level of logic is identified by the first digit of the number assigned to a Required Action and the placement of the logical connector in the first level of nesting (i.e .* left justified with the number of the Required Action). The successive levels of logic are identified by additional digits of the Required Action number and by successive indentations of the logical connectors.

When logical connectors are used to state a Condition. Completion Time. Surveillance. or Frequency, only the first level of logic is used. and the logical connector is left justified with the statement of the Condition, Completion Time, Surveillance, or Frequency.

(continued)

INDIAN POINT 3 1.2-1 lvnenonent 205

LogJcal Connectors 1.2 1.2 Logical Connectors (continued) u EXAMPLES The following examples illustrate the use of logical connectors.

EXAMPLE 1,2*1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIHE A. LCO not met. A.l Verify .

A.2 Restore . . .

In this example the logical connector AliQ is used to indicate that when in Condition A, both Required Actions A.1 and A.2 must be completed. *

(continued)

INDIAN POINT 3 1.2*2 Amenanent 205

Logical Connectors 1.2 1.2 Logical Connectors EXAMPLES EXAMPLE 1.2*2 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIHE A. LCO not met. A.1 Trip * ..

.QB A.2.1 Verify. ..

MD A.2.2.1 Reduce

.QB A.2.2.2 Perform .

.QB A.3 Align. ..

This example represents a more complicated use of logical connectors. Required Actions A.1, A.2. and A.3 are alternative choices, only one of which must be performed as indicated by the use of the logical connector .QB and the_left justified placement. Any one of these three Actions may be chosen. If A.2 is chosen, then both A.2.1 and A.2.2 must be performed as indicated by the logical connector At:!Q. Required Action A.2.2 is met by performing A.2.2.1 or A.2.2.2. The indented position of the logical connector .QB indicates that A.2.2.1 and A.2.2.2 are alternative choices, only one of which must be performed.

INDIAN POINT 3 1.2*3 lvnendnent 205

Completion Times 1.3 1.0 USE AND APPLICATION u 1.3 Completion Times PURPOSE The purpose of this section is to establish the Completion Time convention and to provide guidance for its use.

BACKGROUND Limiting Conditions for Operation {LCOs) specify minimum requirements for ensuring safe operation of the unit. The ACTIONS associated with an LCO state Conditions that typically describe the ways in which the requirements of the LCO can fail to be met.

Specified With each stated Condition are Required Action(s) and Completion Time(s).

DESCRIPTION The Completion Time is the amount of time allowed for completing a Required Action. It is referenced to the time of discovery of a situation {e.g., inoperable equipment or variable not within limits) that requires entering an ACTIONS Condition unless otherwise specified, providing the unit is in a HOOE or specified condition stated in the Applicability of the LCO. Required Actions must be completed prior to the expiration of the specified Completion Time.

An ACTIONS Condition remains in effect and the Required Actions apply until the Condition no longer exists or the unit is not within the LCO Applicability.

If situations are discovered that require entry into more than one Condition at a time Within a single LCO (multiple Conditions), the Required Actions for each Condition must be performed within the associated Completion Time. When in multiple Conditions, separate Completion Times are tracked for each Condition starting from the time of discovery of the situation that required entry into the Condition.

Once a Condition has been entered. subsequent trains, subsystems.

components, or variables expressed in the Condition, discovered to

be inoperable or not within limits, will nnt result in separate entry into the Condition. unless specifically stated. The Required Actions of the Condition continue to apply to each u (continued)

INDIAN POINT 3 1.3*1 twendment 205

Completion Times 1.3 1.3 Completion Times V DESCRIPTION additional failure, with Completion Times based on initial entry (continued) into the Condition.

However, when a subsequent train, subsystem, component, or variable expressed in the Condition is discovered to be inoperable or not within limits. the Completion Time(s) may be extended. To apply this Completion Time extension. two criteria must first be met. The subsequent inoperability:

a. Hust exist concurrent with the .fi.c.s1 inoperability; and

b. Hust remain inoperable or not within limits after the first inoperability is resolved.

The total Completion Time allowed for completing a Required Action to address the subsequent inoperability shall be limited to the more restrictive of either:

a. The stated Completion Time, as measured from the initial entry into the Condition, plus an additional 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s: or

b. The stated Completion Time as measured from discovery of the subsequent inoperability.

The above Completion Time extensions do not apply to those Specifications that have exceptions that allow completely separate re-entry into the Condition (fo*r each train, subsystem, component, or variable expressed in the Condition) and separate tracking of Completion Times based on this re-entry. These exceptions are stated in individual Specifications.

The above Completion Time extension.does not apply to a Completion Time with a modified "time zero." This modified "time zero" may be expressed as a repetitive time (i.e., "once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ," where the Completion Time is referenced from a previous completion of the Required Action versus the time of Condition entry) or as a time modified by the phrase ~from discovery .*. " Example 1.3*3 illustrates one use of this type of Completion Time. The 10 day Completion Time specified for Conditions A and Bin Example 1.3*3 may not be extended.

u (continued)

INDIAN POINT 3 /lmencinent 205

Completion Times 1.3 1.3 Completion Times (continued) u EXAMPLES The following examples illustrate the*use of Completion Times with different types of Conditions and changing Conditions.

EXAMPLE 1,3*1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIHE B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and associated Mill Completion Time not met. B.2 Be in HOOE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Condition B has two Required Actions. Each Required Action has its own separate Completion Time. Each Completion Time is referenced to the time that Condition Bis entered.

u The Required Actions of Condition Bare to be in MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ANO in HOOE 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . A total of 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months is allowed for reaching MODE 3 and a total of 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (not 42 hours4.861111e-4 days 0.0117 hours 6.944444e-5 weeks 1.5981e-5 months ) is allowed for reaching HOOE 5 from the time that Condition B was entered. If MODE 3 is reached within 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months . the time allowed for reaching MODE 5 is the next 33 hours3.819444e-4 days 0.00917 hours 5.456349e-5 weeks 1.25565e-5 months because the total time allowed for reaching HOOE 5 is 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

If Condition Bis entered while in HOOE 3, the time allowed for reaching MODE 5 is the next_36 hours.

(continued)

INDIAN POINT 3 1.3*3 Amenanent 205

Completion Times 1.3 1.3 Completion Times u EXAMPLES EXAMPLE 1.3-2 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIHE A. One pump A.1 Restore pump to 7 days inoperable. OPERABLE status.

B. Required B.1 Be in HODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and associated Mm Completion Time not met. B.2 Be in HODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months When a pump is declared inoperable. Condition A is entered. If the u pump is not restored to OPERABLE status within 7 days, Condition B is also entered and the Completion Time clocks for Required Actions B.1 and B.2 start. If the inoperable pump is restored to OPERABLE status after Condition Bis entered, Condition A and Bare exited, and therefore. the Required Actions of Condition B may be terminated.

When a second pump is declared inoperable while the first pump is

. I still inoperable. Condition A is not re-entered for the second pump .

LCO 3.0.3 is entered, since the ACTIONS do not include a Condition for more than one inoperable pump. The Completion Time clock for Condition A does not stop after LCO 3.0.3 is ente~ed, but continues to be tracked from the time Condition A was initially entered.

While in LCO 3.0.3, if one of the inoperable pumps is restored to OPERABLE status and the Completion Time for Condition A has not expired, LCO 3.0.3 may be exited and operation continued in accordance with Condition A.

(continued)

INDIAN POINT 3 1.3-4 Amencinent 205

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1,3*2 (continued>

While in LCO 3.0.3, if one of the inoperable pumps is restored to OPERABLE status and the Completion Time for Condition A has expired, LCO 3.0.3 may be exited and operation continued in accordance with Condition B. The Completion Time for Condition Bis tracked from the time the Condition A Completion*Time expired.

On restoring one of the pumps to OPERABLE status, the Condition A Completion Time is not reset, but continues from the time the first pump was declared inoperable. This Completion Time may be extended if the pump restored to OPERABLE status was the first inoperable pump. A 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months extension to the stated 7 days is allowed, provided this does not result in the second pump being inoperable for

> 7 days.

u (continued)

INDIAN POINT 3 1.3*5 Amenanent 205

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1,3*3 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One Function X A.1 Restore Function X 7 days train train to OPERABLE inoperable. status. AHO 10 days from discovery of failure to meet the LCO B. One Function Y B.1 Restore Function Y 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months train train to OPERABLE inoperable. status. AHO 10 days from V discovery of failure to meet the LCO C. One Function X C.1 Restore Function X 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months train train to OPERABLE inoperable. status.

Mm OB One Function Y C.2 Restore Function Y 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months train train to OPERABLE.

inoperable. status.

(continued)

V INDIAN POINT 3 1.3*6 Amendment 205

Completion Times 1.3 1.3 Completion Times u EXAMPLES EXAMPLE 1.3-3 (continued)

When one Function X train and one Function Y train are inoperable.

Condition A and Condition Bare concurrently applicable. The Completion Times for Condition A and Condition B are tracked separately for each train starting from the time each train was declar~d inoperable and the Condition was entered. A separate Completion Time is established for Condition C and tracked from the time the second train was.declared inoperable (i.e., the time the situation described in Condition C was discovered).

If Required Action C.2 is completed within the specified Completion Time, Conditions Band Care exited. If the Completion Time for Required Action A.1 has not expired. operation may continue in accordance with Condition A. The remaining Completion Time in Condition A is measured from the time the affected train was declared inoperable (i.e., initial entry into Condition A).

The Completion Times of Conditions A and Bare modified by a logical connector with a separate 10 day Completion Time measured from the time it was discovered the LCO was not met. In this example.

without the separate Completion Time. it would be possible to alternate between Conditions A. B. and C in such a manner that operation could continue indefinitely without ever restoring systems to meet the LCO. The separate Completion Time modified by the phrase "from discovery of failure to*meet the LCO" is designed to prevent indefinite continued operation while not meeting the LCO.

This Completion Time allows for an exception to the normal "time zero" for beginning the Completion Time "clock". In this instance.

the Completion Time "time zero" is specified as c011111encing at the time the LCO was initially not met. instead of at the time the associated Condition was entered. *

(continued)

V INDIAN POINT 3 1.3*7 Amenctnent 205

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1. 3*4 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIHE A. One or more A.1 Restore valve(s) to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months valves OPERABLE status.

inoperable.

B. Required B.1 Be in HOOE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and associated MID Completion .

Time not met. B.2 Be in HOOE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months A single Completion Time is used for any number of valves inoperable at the same time. The Completion Time associated with Condition A is based on the initial entry into Condition A and is not tracked on a per valve basis. Declaring subsequent valves inoperable. while Condition A is still in effect, does not trigger the tracking of separate Completion Times.

Once one of the valves has been restored to OPERABLE status, the Condition A Completion Time is not reset. but continues from the time the first valve was declared inoperable. The Completion Time may be extended if the valve restored to OPERABLE status was the first inoperable valve. The Condition A Completion Time may be extended for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months provided this does not result in any subsequent valve being inoperable for> 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

If the Completion Time of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months (including the extension) expires while one or more valves are still inoperable, Condition Bis entered.

(continued)

INDIAN POINT 3 1.3*8 Amendment 205

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-5 (continued)

ACTIONS

- - - - NOTE*********************************

Separate Condition entry is allowed for each inoperable valve.

CONDITION REQUIRED ACTION COMPLETION TIHE A. One or more A.1 Restore valve to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months valves OPERABLE status.

inoperable.

8. Required 8.1 Be in HOOE 3. 6 hours Action and associated MID Completion Time not met. 8.2 Be in HOOE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months V

The Note above the ACTIONS Table is a method of modifying how the Completion Time is tracked. If this method of modifying how the Completion Time is tracked was applicable only to a specific Condition, the Note would appear in that Condition rather than at the top of the ACTIONS Table.

The Note allows Condition A to be entered separately for each inoperable valve, and Completion Times tracked on a per valve basis.

When a valve is declared inoperable, Condition A is entered and its Completion Time starts. If subsequent valves are declared inoperable. Condition A is entered for each valve and separate Completion Times start and are tracked for each valve.

(continued)

V INDIAN POINT 3 1.3*9 Amendnent 205

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-5 (continued)

If the Completion Time associated with a valve in Condition A expires, Condition Bis entered for that valve. If the Completion Times associated with subsequent valves in Condition A expire, Condition Bis entered separately for each valve and separate Completion Times start and are tracked for each valve. If a valve that caused entry into Condition Bis restored to OPERABLE status.

Condition Bis exited for that valve.

Since the Note in this example allows multiple Condition entry and tracking of separate Completion Times, Completion Time extensions do not apply.

EXAMPLE 1.3-6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One channel A.1 Perform SR 3.x.x.x. Once per a hours inoperable.

OR A.2 Reduce THERMAL POWER to s 50% RTP. 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months B. Required B.1 Be in MODE 3. 6 hours Action and associated Completion Time not met.

(continued)

\..__)

INDIAN POINT 3 1.3-10 Menanent 205

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-6 (continued)

Entry into Condition A offers a choice between Required Action A.I or A.2. Required Action A.I has a "once per" Completion Time, which qualifies for the 25% extension. per SR 3.0.2. to each performance after the initial performance. The initial 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months interval of Required Action A.1 begins when Condition A is entered and the initial performance of Required Action A.1 must be complete within the first 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months interval. If Required Action A.I is followed, and the Required Action is not met within the Completion Time (plus the extension allowed by SR 3.0.2). Condition Bis entered. If Required Action A.2 is followed and the Completion Time of 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months is not met, Condition Bis entered.

If after entry into Condition B. Required Action A.I or A.2 is met.

Condition Bis exited and operation may then continue in Condition A.

u (continued)

INDIAN POINT 3 1.3-11 lwenanent 205

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-7 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIHE A. One subsystem A.l Verify affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. subsystem isolated.

Atm Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter Mill A.2 Restore subsystem to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE status.

B. Required 8.1 Be in HODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and associated Mill Completion Time not met. 8.2 Be in HODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Required Action A.1 has two Completion Times. The 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Completion Time begins at the time the Condition is entered and each "Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter" interval begins upon performance of Required Action A.1.

(continued) u INDIAN POINT 3 1.3-12 Amenonent 205

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1,3*7 (continued)

If after Condition A is entered. Required Action A.1 is not met within either the initial 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or any subsequent 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months interval from the previous performance (plus the extension allowed by SR 3.0.2). Condition Bis entered. The Completion Time clock for Condition A does not stop after Condition Bis entered, but continues from the time Condition A was initially entered. If Required Action A.1 is met after Condition Bis entered, Condition B is exited and operation may continue in accordance with Condition A, provided the Completion Time for Required Action A.2 has not expired.

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

u u

INDIAN POINT 3 1.3*13 nienanent 205

Frequency 1.4 1.0 USE AND APPLICATION u 1.4 Frequency PURPOSE The purpose of this section is to define the proper use and application of Frequency requirements.

DESCRIPTION Each Surveillance Requirement CSR) has a specified Frequency in which the Surveillance must be met in order to meet the associated LCO. An understanding of the correct application of the specified Frequency is necessary for compliance with the SR.

The "specified Frequency" is referred to throughout this section and each of the Specifications of Section 3.0, Surveillance Requirement CSR) Applicability. The "specified Frequency" consists of the requirements of the Frequency column of each SR as well as certain Notes in the Surveillance column that modify performance requirements.

Situations where a Surveillance could be required (i.e .* its Frequency could expire), but where it is.not possible or not desired that it be performed until sometime after the associated LCO is within its Applicability, represent potential SR 3.0.4 conflicts.

u To avoid these conflicts, the SR (i.e., the Surveillance or the Frequency) is stated such that it is only "required" when it can be and should be performed. With an SR satisfied, SR 3.0.4 imposes no restriction.

EXAMPLES The following examples illustrate the various ways that Frequencies are specified. In these examples, the Applicability of the LCO CLCO not shown) is HODES 1, 2, and 3.

u (continued)

INDIAN POINT 3 1.4*1 Pmenanent 205

Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4-1 (continued)

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Example 1.4-1 contains the type of SR most often encountered in the Technical Specifications (TS). The Frequency specifies an interval (12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ) during which the associated Surveillance must be performed at least one time. Performance of the Surveillance initiates the subsequent interval. Although the Frequency is stated as 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , an extension of the time interval to 1.25 times the stated Frequency is allowed by SR 3.0.2 for operational flexibility.

The measurement of this interval continues at all times, even when the SR is not required to be met per SR 3.0.1 (such as when the equipment is inoperable, a variable is outside specified limits, or the unit is outside the Applicability of the LCO). If the interval specified by SR 3.0.2 is exceeded while the unit is in a MODE or other specified condition in the Applicability of the LCO, and the performance of the Surveillance is not otherwise modified (refer to Example 1.4-3), then SR 3.0.3 becomes applicable.

If the interval as specified by SR 3.0.2 is exceeded while the unit is not in a MODE or other specified condition in the Applicability of the LCO for which performance of the SR is required, then SR 3.0.4 becomes applicable. The Surveillance must be performed within the Frequency requirements of SR 3.0.2, as modified by SR 3.0.3, prior to entry into the MODE or other specified condition or the LCO is considered not met (in accordance with SR 3.0.1} and LCO 3.0.4 becomes applicable.

(continued)

INDIAN POINT 3 1.4 - 2 Amendment 234

Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4*2 (continued)

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Verify flow is within limits. Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after

~ 25%' RTP 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter Example 1.4*2 has two Frequencies. The first is a one time performance Frequency, and the second is of the type shown in Example 1.4*1. The logical connector"~" indicates that both u Frequency requirements must be met. Each time reactor power is increased from a power level< 25%' RTP to~ 25%' RTP, the Surveillance must be performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

The use of "once" indicates a single performance will satisfy the specified Frequency (assuming no other Frequencies are connected by "Alli!"). This type of Frequency does not qualify for the 25%'

extension allowed ~Y SR 3.0.2. "Thereafter" indicates future performances must be established per SR 3.0.2. but only after a specified condition is first met (i.e .* the "once" performance in this example). If reactor power decreases to< 25% RTP. the measurement of both intervals stops. New intervals start upon reactor power reaching 25% RTP.

(continued) u INDIAN POINT 3 1.4*3 IIJllenanent 205

Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1,4*3 (continued)

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

- - - - NOTE*********************

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after~ 25% RTP.

Perform channel adjustment. 7 days The interval continues, whether or not the unit operation is

< 25% RTP between performances.

As the Note modifies the required performance of the Surveillance, it is construed to be part of the "specified Frequency." Should the 7 day interval be exceeded while operation is< 25% RTP, this Note

\._,,) allows 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after power reaches~ 25X RTP to perform the Surveillance. The Surveillance is still considered to be performed within the "specified Frequency." Therefore, if the Surveillance were not performed within the 7 day (plus the extension allowed by SR 3.0.2) interval. but operation was< 25X RTP, it would not constitute a failure of the SR or failure to meet the LCO. Also, no violation of SR 3.0.4 occurs when changing HODES, even with*the 7 day Frequency not met, provided operation does not exceed 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months with power~ 25X RTP.

Once the unit reaches 25X RTP, 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months would be allowed for completing the Surveillance. If the Surveillance were not performed within this 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months interval, there would then be a failure to perform a Surveillance within the specified Frequency, and the provisions of SR 3.0.3 would apply.

u INDIAN POINT 3 1.4*4 htenanent 205

SLs 2.0 u 2 .1 SLs

..2. 1 .1 Reactor Core SLs In MODES 1 and 2, the combination of THERMAL POWER, Reactor Vessel inlet temperature, and pressurizer pressure shall not exceed the limits specified in the COLR; and the following SLs shall not be exceeded:

2.1.1.1 The departure from nucleate boiling ratio (DNBR) shall be maintained> 1.17 for the WRB-1 DNB correlations.

2.1.1.2 The peak fuel centerline temperature shall be maintained< 5080°F, decreasing by 58°F per 10,000 MWD/MTU of burnup.

2.1.2 RCS Pressure SL In MODES 1,' 2, 3, 4, 5, and in MODE 6 wnen the reactor vessel head is on, the RCS pressure shall be maintained~ 2735 psig.

2.2 SL Violations 2.2.1 If SL 2.1.1 is violated, restore compliance and be in MODE 3 within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

u 2.2.2 If SL 2.1.2 is violated:

2.2.2.1 In MODE 1 or 2, restore compliance and be in MODE 3 within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

2.2.2.2 In MODE 3, 4, 5, or 6, restore compliance within 5 minutes.

INDIAN POINT 3 2.0-1 Amendment 225

LCO Applicability 3.0 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY LCO 3.0.1 LCOs shall be met during the MODES or other specified conditions in the Applicability, 1!xcept as provided in LCO 3.0.2 LCO 3.0.7 and 1

LCO 3.0.8.

LCO 3.0.2 Upon discovery of a failure to meet an LCO, the Required Actions of the associated Conditions shall be met, except as provided in LCO 3.0.5 and LCO 3.0.6.

If the LCO is met or is no longer applicable prior to expiration of the specified Compl1!tion Time(s). completion of the Required Action(s) is not required unless otherwise stated.

LCO 3.0.3 When an LCO is not met and the associated ACTIONS are not met, an associated ACTION is not provided, or if directed by the associated ACTIONS, the unit shall be placed in a MODE or other specified condition in which the LCO is not applicable. Action shall be initiated within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to place the unit, as applicable, in:

a. MODE 3 within 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months ;

b. MODE 4 within 13 hours1.50463e-4 days 0.00361 hours 2.149471e-5 weeks 4.9465e-6 months ; and

c. MODE 5 within 37 hours4.282407e-4 days 0.0103 hours 6.117725e-5 weeks 1.40785e-5 months .

Exceptions to this Specification are stated in the individual Specifications.

Where corrective mea.sures are completed that permit operation in accordance with the LCO or ACTIONS. completion of the actions required by LCO 3.0.3 is not required.

LCO 3.0.3 is only applicable in MODES 1, 2, 3, and 4.

(continued)

INDIAN POINT 3 3.0 - 1 Amendment 229

LCO Applicability 3.0 LCO 3.0.4 When an LCO is not met, entry into a MODE or other specified condition in the Applicability shall only be made:

a. When the associated ACTIONS to be entered permit continued operation in the MODE or other specified condition in the Applicability for an unlimited period of time;

b. After performance of a risk assessment addressing inoperable systems and components, consideration of the results, determination of the acceptability of entering the MODE or other specified condition in the Applicability, and establishment of risk management actions, if appropriate; exceptions to this Specification are stated in the individual Specifications, or

c. When an allowance is stated in the individual value, parameter, or other Specification.

This Specification shall not prevent changes in MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.*

LCO 3.0.5 Equipment removed from service or declared inoperable to comply with ACTIONS may be returned to service under administrative control solely to perform testing required to demonstrate its OPERABILITY or the OPERABILITY of other equipment. This is an exception to LCO 3.0.2 for the system returned to service under administrative control to perform the testing required to demonstrate OPERABILITY.

(continued) u INDIAN POINT 3 3.0 - 2 Amendment 226

LCO Applicability 3.0 3.0 LCO APPLICABILITY (continued)

LCO 3.0.6 When a supported system LCO is not met solely due to a support system LCO not being met, the Conditions and Required Actions associated with this supported system are not required to be entered. Only the support system LCO ACTIONS are required to be entered. This is an exception to LCO 3.0.2 for the supported system. In this event, an evaluation shall be performed in accordance with Specification 5.5.14, "Safety Function Determination Program (SFDP). 11 If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered.

When a support system's Required Action directs a supported system to be declared inoperable or directs entry into Conditions and Required Actions for a supported system, the applicable Conditions and Required Actions shall be entered in accordance with LCO 3.0.2.

LCO 3.0.7 Test Exception LCOs~ such as 3.1.8, allow specified Technical Specification (TS) ,*equirements to be changed to permit performance of special tests and operations. Unless otherwise specified, all other TS requirements remain unchanged. Compliance with Test Exception LCOs is optional. When a Test Exception LCO is desired to be met but is not mE!t, the ACTIONS of the Test Exception LCO shall be met. When a Test Exception LCO is not desired to be met, entry into a MODE or other specified condition in the Applicability shall be made in accordance with the other applicable Specifications.

LCO 3.0.8 When one or more required snubbers are unable to perform their associated support function(s), any affected supported LCO(s) are not required to be declared not met solely for this reason if risk is assessed and managed, and:

a. the snubbers not able to perform their associated support function(s) ar1! associated with only one train or subsystem of a multiple tra"in or subsystem supported system or are associated with a single train or subsystem supported system and are able to perform their associated support function within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months ; or

b. the snubbers nc1.t able to perform their associated support function(s) are associated with more than one train or subsystem of a multiple train or subsystem supported system and are able to perform their associated support function within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

At the end of the specified period the required snubbers must be able to perform their associated support function(s), or the affected supported s.ystem LCO(s) shall be declared not met.

INDIAN POINT 3 3.0 - 3 Amendment 229

SR Applicability 3.0 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY SR 3.0.1 SRs shall be met during the MODES or other specified conditions in the Applicability for individual LCOs, unless otherwise stated in the SR. Failure to meet a Surveillance, whether such failure is experienced during the performance of the Surveillance or between performances of the Surveillance, shall be failure to meet the LCO.

Failure to perform a Surveillance within the specified Frequency shall be failure to meet the LCO except as provided in SR 3.0.3.

Surveillances do not have to be performed on inoperable equipment or variables outside specified limits.

-

SR 3.0.2 The specified Frequency for each SR is met if the Surveillance is performed within 1.25 times the interval specified in the Frequency, as measured from the previous performance or as measured from the time a specified condition of the Frequency is met.

For Frequencies specified as "once," the above interval extension does not apply.

If a Completion Time requires periodic performance on a "once per *** 11 basis, the above Frequency extension applies to each performance after the initial performance.

Exceptions to this Specification are stated in the individual Specifications.

SR 3.0.3 If it is discovered that a Surveillance was not performed within its specified Frequency, then compliance with the requirement to declare the LCO not met may be delayed, from the time of discovery, up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or up to the limit of the specified Frequency, whichever is greater. This delay period is permitted to allow performance of the Surveillance. A risk evaluation shall be performed for any Surveillance delayed greater than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and the risk impact shall be managed.

If the Surveillance is not performed within the delay period, the LCO must irnnediately be declared not met, and the applicable Condition(s) must be entered.

When the Surveillance is performed within the delay period and the Surveillance is not met, the LCO must irnnediately be declared not met, and the applicable Condition(s) must be entered.

(continued) u INDIAN POINT 3 3.0 - 4 Amendment 212

SR Applicability 3.0 3.0 SR APPLICABILITY (continued)

SR 3.0.4 Entry into a MODE or other specified condition in the Applicability of an LCO shall only be made when the LCO's Surveillances have been met within their specified Frequency, except as provided by SR 3.0.3. When an LCO is not met due to Surveillances not having been met, entry into a MODE or other specified condition in the Applicability shall only be made in accordance with LCO 3.0.4.

This provision shall not prevent entry into MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.

V INDIAN POINT 3 3.0 - 5 Amendment 226

.,

SDM 3.1.1 u . 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM)

LCO 3.1.1 SDM shall be within the limits specified in the COLR.

APPLICABILITY: MODE 2 with kett < 1.0, HODES 3, 4, and 5.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIHE A. SDH not within limit. A.l Initiate boration to 15 minutes restore SDH to within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.1.1 Verify SDH is within the limits specified in the *24 hours COLR.

INDIAN POINT 3 3.1.1*1 Amenanent 205

Core Reactivity 3.1.2 3.1 REACTIVITY CONTROL SYSTEMS V

3.1.2 Core Reactivity LCO 3.1.2 The measured core reactivity shall be within+/- 1% 6k/k of predicted values.

APPLICABILITY: HODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION CO HP LET ION TI HE A. Measured core reactivity A.1 Re*evaluate core design 7 days not within limit. and safety analysis. and determine that the reactor core is acceptable for continued operation.

V MID A.2 Establish appropriate 7 days operating restrictions and SRs.

B. Required Action and B.1 Be in HOOE 3.-. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

INDIAN POINT 3 3.1.2*1 Amenanent 205

Core Reactivity 3.1.2 SURVEILLANCE REQUIREHENTS SURVEILLANCE FREQUENCY SR 3.1.2.1 ---------------------NOTE -----. -----------------

The predicted reactivity values may be adjusted (normalized) to correspond to the measured core reactivity prior to exceeding a fuel burnup of 60 effective full power days CEFPD) after each fuel loading.

Verify measured core reactivity is within Once prior to

+/- 1% ~k/k of predicted values. entering HOOE 1 after each refueling

NOTE---**-

Only required after 60 EFPD V 31 EFPD thereafter INDIAN POINT 3 3.1.2*2 Amenonent 205

HTC 3.1.3 3.1 REACTIVITY CONTROL SYSTEHS u 3.1.3 Hoderator Temperature Coefficient (HTC)

LCO 3.1.3 The HTC shall be maintained within the limits specified in the COLR.

The maximum upper limit shall be~ 0.0 Ak/k°F at hot zero power.

APPLICABILITY: HOOE 1 and HOOE 2 with kett ~ 1.0 for the upper HTC limit, HODES 1, 2, and 3 for the lower HTC limit.

ACTIONS CONDITION REQUIRED ACTION COHPLETION TIHE A. HTC not within upper A.1 Establish administrative 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months limit. withdrawal limits for control banks to maintain HTC within limit.

B. Required Action and B.1 Be in HOOE 2 with 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion kett < 1.0.

Time of Condition A not met.

C. HTC not within 1ower C.1 Be in HOOE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months limit.

INDIAN POINT 3 3.1.3*1 Amenctnent 205

MTC 3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.3.1 Verify MTC is within upper limit. Once prior to entering MODE 1 after each refueling SR 3.1.3.2 -------------------NOTES----------------

1. Not required to be performed until 7 effective full power days (EFPD) after reaching the equivalent of an equilibrium RTP all rods out (ARO) boron concentration of 300 ppm.

2. SR 3.1.3.2 is not required to be performed by measurement provided that the benchmark criteria in WCAP-137 49-P-A are satisfied and the Revised Predicted MTC satisfies the 300 ppm surveillance limit specified in the COLR.

3. If the MTC is more negative than the 300 ppm Surveillance limit (not LCO limit) specified in the COLR, SR 3.1.3.2 shall be repeated once per 14 EFPD during the remainder of the fuel cycle.

4. SR 3.1.3.2 need not be repeated if the MTC measured at the equivalent of equilibrium RTP-ARO boron concentration of s 60 ppm is less negative than the 60 ppm Surveillance limit specified in the COLR.

Verify MTC is within lower limit. Once each cycle INDIAN POINT 3 3.1.3-2 Amendment 261

Rod Group Alignment Limits 3.1.4 3.1 REACTIVITY CONTROL SYSTEMS u 3.1.4 Rod Group Alignment Limits LCO 3.1.4 All shutdown and control rods shall be OPERABLE, with rod group alignment limits as follows:

a. *when THERMAL POWER is> 85% RTP, the difference between each individual indicated rod position and its group step counter* demand position shall be within the limits specified in Table 3.1.4-1 for the group step counter demand position: and

b. When THERMAL POWER is~ 85% RTP, the difference between each individual indicated rod position and its group step counter demand position shall be within 24 steps.

APPLICABILITY: HODES 1 and 2.

ACTIONS u CONDITION REQUIRED ACTION COMPLETION TIME A. One or more rod(s) A.1.1 Verify SDM is within the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months untrippable. limits specified in the COLR.

OB A.1.2 Initiate boration to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore SDM to within limit.

MD A.2 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months (continued)

INDIAN POINT 3 3.1.4-1 lwendment 205

Rod Group Alignment Limits 3.1.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIHE B. One rod not within B.1 Restore rod to within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months alignment limits. alignment limits.

QB B.2.1.1 Verify SOM is within the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months limits specified in the COLR.

QB 8.2.1.2 Initiate boration to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore SDM to within limit.

ANO B.2.2 Reduce THERMAL POWER to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months

~ 75% RTP.

ANO

B.2.3 Verify SDH is within the Once per limits specified in the 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months COLR.

Mm B.2.4 Perform SR 3.2.1.1. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Mm '

B.2.5 Perform SR 3.2.2.1. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months ANO

{continued) u INDIAN POINT 3 3.1.4*2 Amenanent 205

Rod Group Alignment Limits 3.1.4 ACTIONS u CONDITION REQUIRED ACTION COMPLETION TIHE B (continued) B.2.6 Re-evaluate safety 5 days analyses and confirm results remain valid for duration of operation under these conditions.

C. Required Action and C.1 Be in HOOE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition B not met.

D. Hore than one rod not D.1.1 Verify SDH is within the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months within alignment limit. limits specified in the COLR.

OR D.1.2 Initiate boration to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore required SDH to within .limit.

M:!Q D.2 Be in HOOE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months u

INDIAN POINT 3 3.1.4-3 .t.mendment 205

Rod Group Alignment Limits 3.1.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.4.1 ****************** NOTE************************

Not required to be met for individual control rods until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after completion of control rod movement.

Verify individual rod positions within alignment 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months limit.

SR 3.1.4.2 Verify rod freedom of movement Ctrippability) by 92 days moving each rod not fully inserted in the core

~ 10 steps in one direction.

SR 3.1.4.3 Verify rod drop time of each rod, from the fully Prior to reactor withdrawn position. is$ 1.8 seconds from the criticality after loss of stationary gripper coil voltage to each removal of dashpot entry, with: the reactor head

a. Tavg ~ 500°F: and

b. All reactor coolant pumps operating.

INDIAN POINT 3 3.1.4*4 Amenanent 205

Rod Group Alignment Limits 3.1.4 Table 3.1.4*1 Haximum Permissible Rod Hisalignment (Indicated Rod Position minus Group Step Counter Demand Position)

When> 85 X RTP Step Counter Demand Maximum Permissible Deviations Position CIRPI Position.minus Step Counter Demand Position)

(steps) (steps)

~ 212 ~ *12 and ~ +12 213 to 225 ~ *12 and ~ +17.

226 ~ *13 and ~ +17 227 ~ -14 and ~ +17 228 ~ *15 and ~ +17 229 ~ *16 and ~ +17

~ 230 ~ *17 and ~ +17 V

INDIAN POINT 3 3.1.4*5 . Amenanent 205

Shutdown Bank Insertion Limits 3.1.5 3.1 REACTIVITY CONTROL SYSTEHS 3.1.5 Shutdown Bank Insertion Limits LCO 3.1.5 Each shutdown bank shall be within insertion limits specified in the COLR.

APPLICABILITY: HOOE 1, HOOE 2 with any control bank not fully inserted.

*-----------------*-----NOTE----*-*-------*******---**--

This LCO is not applicable while performing SR 3.1.4.2.

ACTIONS CONDITION REQUIRED ACTION COHPLETI ON TI HE A. One or more shutdown A.1.1 Verify SDH is within the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months u banks not within limits. limits specified in the COLR.

QR A.1.2 Initiate boration to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore SDH to within limit.

AHO A.2 Restore shutdown banks 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to within limits.

B. Required Action and B.1 Be in HOOE 3. 6 hours associated Completion Time not met.

u INDIAN POINT 3 3.1.5*1 Amenanent 205

Shutdown Bank Insertion Limits 3.1.5 SURVEILLANCE REQUIREMENTS u SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify each shutdown bank is within the limits 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months specified in the COLR.

INDIAN POINT 3 3.1.5*2 Amenanent 205

Control Bank Insertion Limits 3.1.6 3.1 REACTIVITY CONTROL SYSTEHS 3.1.6 Control Bank Insertion Limits LCO 3.1.6 Control banks shall be within the insertion, sequence. and overlap limits specified in the COLR.

APPLICABILITY: HOOE 1, HOOE 2 with kett ~ 1.0.

- - - - NOTE*******************************

This LCO is not applicable while performing SR 3.1.4.2.

ACTIONS CONDITION REQUIRED ACT! ON COMPLETION TIHE A. Control bank insertion A.1.1 Verify SOM is within the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months limits not met. limits specified in the COLR.

OB A.1.2 Initiate boration to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore SOM to within limit.

A.2 Restore control bank(s) 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to within limits.

(continued)

INDIAN POINT 3 3.1.6*1 Amenanent 205

Control Bank Insertion Limits 3.1.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIHE B. Control bank sequence or B.1.1 Verify SDH is within the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months overlap limits not met. limits specified in the COLR.

QB B.1.2 Initiate boration to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore SDH to within limit.

MID

*B.2 Restore control bank 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months sequence and overlap to within ,-imits.

C. Required Action and C.1 Be in HOOE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months u associated Completion Ti me not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.1 Verify estimated critical control bank position Within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months is within the limits specified in the COLR. prior to achieving criticality (continued) u INDIAN POINT 3 3.1.6*2 Amencinent 205

Control Ban~ Insertion Limits 3.1.6 SURVEILLANCE REQUIREHENTS (continued)

SURVEILLANCE FREQUENCY SR 3.1.6.2 Verify each control bank insertion is within the 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months limits specified in the COLR.

SR 3.1.6.3 Verify sequence and overlap limits specified in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months the COLR are met for control banks not fully withdrawn from the core.

u INDIAN POINT 3 3.1.6*3 Ameminent 205

Rod Position Indication 3.1.7 3.1 REACTIVITY CONTROL SYSTEMS 3.1.7 Rod Position Indication LCO 3.1. 7 The Individual Rod Position Indication (!RPI) System and the Demand Position Indication System shall be OPERABLE.

APPLICABILITY: HODES 1 and 2.

ACTIONS

- - - - NOTE********************************************

Separate Condition entry is allowed for each inoperable rod position indicator and each demand position indicator.

CONDITION REQUIRED ACTION

COMPLETION TIME A. One !RPI per group A.l Verify the position of Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months inoperable for one or the rods with inoperable more groups. position indicators indirectly by using movable incore detectors.

A.2 Reduce THERMAL POWER to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months

!: 50% RTP.

(continued) u INDIAN POINT 3 3.1. 7*1 twenanent 205

Rod Position Indication 3.1.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIHE

8. Hore than one IRPI per 8.1 Place the control rods Inunediately group inoperable. under manual control.

MID 8.2 Monitor and record RCS Once per 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Tavg._

MID 8.3 Verify the position of Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months the rods with inoperable position indicators indirectly by u*sing the movable incore detectors.

Mill 8.4 Restore inoperable 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months position indicators to OPERABLE status such that a maximum of one IRPI per group is inoperable.

C. One or more rods with C.1 Verify the position of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months inoperable position the rods with inoperable indicators have been position indicators moved in excess of indirectly by using 24 steps in one direction movable incore since the last detectors.

determination of the rod's position. QB C.2 Reduce THERMAL POWER to

~ SOX RTP. 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months (continued)

INDIAN POINT 3 3.1. 7-2 Amenanent 205

Rod Position Indication 3.1. 7 ACTIONS (continued)

CONDITION REQUIRED ACTION COHPLETION TIHE D. One demand position D.1.1 Verify by administrative Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months indicator per bank means all IRPis for. the inoperable for one or affected banks are more banks. OPERABLE.

MID D.1.2 Verify the most Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months withdrawn rod and the least withdrawn rod of the affected banks are

~ 12 steps apart when

> 85% RTP and~ 24 steps apart when~ 85% RTP .

.QR D.2 Reduce THERHAL POWER to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months

~ SOY. RTP.

E. Required Action and E.1 Be in HODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated CCMTipletion Time not met.

INDIAN POINT 3 3.1. 7*3 . Amendment 205

Rod Position Indication 3.1.7

~ SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1. 7.1 Verify each IRPI agrees within 12 steps of the Prior to reactor group demand position for the full indicated criticality after range of rod travel.

each removal of the reactor vessel head V

INDIAN POINT 3 3.1. 7.4 Amenctnent 205

PHYSICS TESTS Exceptions -HOOE 2 3.1.8 3.1 REACTIVITY CONTROL SYSTEHS 3.1.8 PHYSICS TESTS Exceptions- HODE 2 LCO 3.1.8 During the performance of PHYSICS TESTS, the requirements of LCO 3.1. 3, "Hoder ator Temperature Coefficient CHTC) ":

LCO 3.1.4, "Rod Group Alignment Limits";

LCO 3.1.5, "Shutdown Bank Insertion Limits":

LCO 3.1.6, "Control Bank Insertion Limits": and LCO 3.4.2, "RCS Hinimum Temperature for Criticality" may be suspended, provided:

a. RCS lowest loop average temperature is~ 540°F; and

b. SDH is within the limits specified in the COLR; and

c. THERHAL POWER IS s: 5% RTP.

APPLICABILITY: HODE 2.during PHYSICS TESTS.

V ACTIONS CONDITION REQUIRED ACTION COHPLETION TIHE A. SDH not within limit. A.1 Initiate boration to 15 minutes restore SDH to within limit.

AHO A.2 Suspend PHYSICS TESTS 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months exceptions.

B. THERHAL POWER not within B.l Open reactor trip Immediately limit. breakers.

u (continued)

INDIAN POINT 3 3.1.8*1 hnenanent 205

PHYSICS TESTS Excepti ans - MODE 2 3.1.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. RCS lowest loop average C.1 Restore RCS lowest loop 15 minutes temperature not within average temperature to limit. within limit.

D. Required Action and D.1 Be in MODE 3. 15 minutes associated Completion Time of Condition C not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY u SR 3.1.8.1 Perform a CHANNEL OPERATIONAL TEST on power range Prior to and intermediate range channels per SR 3.3.1.7. initiation of SR 3.3.1.8. and Table 3.3.1*1. PHYSICS TESTS SR 3.1.8.2 Verify the RCS lowest loop average temperature is 30 minutes

~ 540°F.

SR 3.1.8.3 Verify THERHAL POWER is*~ 5% RTP. 30 minutes SR 3.1.8.4 Verify SDH is within the limits specified in the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months COLR.

INDIAN POINT 3 3.1.8-2 Amenctnent 205

FoCZ) 3.2.1 3.2 POWER DISTRIBUTION LIHITS 3.2.1 Heat Flux Hot Channel Factor CF0 CZ))

LCO 3.2.1 F0 CZ> shall be within the limits specified in the COLR.

APPLICABILITY: HODE 1.

ACTIONS CONDITION REQUIRED ACTION COHPLETION TIME A. F0 (Z) not within limit. A.1 Reduce THERMAL POWER 15 minutes after

~ 1% RTP for each each F0 (Z) 1% F0 (Z) exceeds limit. determination AtID A.2 Reduce Power Range 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after u Neutron Flux - High trip setpoints ~ 1% for each each F0 CZ) determination 1% F0 CZ) exceeds limit.

AtID A.3 Reduce Overpower ~r trip 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after setpoints ~ lX for each each F0 CZ) 1% F0 (Z) exceeds limit. determination Mill A.4 Perform SR 3.2.1.1.

Prior to increasing THERMAL POWER above the limit of Required Action A;l (continued) u INDIAN POINT 3 3.2.1-1 Amendnent 205

FQCZ) 3.2.1 ACTIONS (continued) u CONDITION REQUIRED ACTION COMPLETION TIME B.1 Be in HOOE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months B. Required Action and associated Completion Time not met.

INDIAN POINT 3 3.2.1*2 Amenanent 205

FoCZ) 3.2.1 SURVEILLANCE REQUIREHENTS

- - - - NOTE********************************************

During power escalation at the beginning of each cycle, THERHAL POWER may be increased until an equilibrium power level has been achieved, at which a power distribution map is obtained.

SURVEILLANCE FREQUENCY SR 3.2.1.1 Verify F0 CZ) is within limit. Once after each refueling prior to THERHAL POWER exceeding 75~ RTP Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after achieving equi 1i bri um conditions after u exceeding, by

i: 10~ RTP. the THERHAL POWER at which F0 CZ) was 1ast verified 31 EFPD thereafter INDIAN POINT 3 3.2.1-3 Amendment 205

3.2 POWER DISTRIBlTTION LIHITS 3.2.2 Nuclear Enthalpy Rise Hot Channel Factor CF!H>

LCO 3.2.2 F!H shall be within the limits specified in the COLR.

APPLICABILITY: HOOE 1.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIHE A. *********NOTE********* A.1.1 Restore F!H to within 4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months s*

Required Actions A.2 limit.

and A.3 must be completed whenever Condition A is OR entered.

....*.**..*........... A.1.2.1 Reduce THERHAL POWER to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months u F!H not within limit.

< 50%" RTP.

MID A.1.2.2 Reduce Power Range 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Neutron Flux - High trip setpoints to~ 55%" RTP.

MID A.2 Perform SR 3.2.2.1.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months MID (continued}

INDIAN POINT 3 3.2.2*1 /vnencinent 205

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3 ********NOTE*********

THERMAL POWER does not have to be reduced to comply with this Required Action .

..***..*.....*......

Perform SR 3.2.2.1. Prior to THERMAL POWER exceeding 50% RTP MID Prior to THERMAL POWER exceeding 75% RTP RID 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after THERMAL POWER reaching

!: 95% RTP B. Required Action and B.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

INDIAN POINT 3 3.2.2*2 Amendment 205

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify F!H is within limits specified in the COLR. Once after each refueling prior to THERMAL POWER exceeding 75% RTP 31 EFPD thereafter u

INDIAN POINT 3 3.2.2*3 lvnendment 205

AFD (CAOC Methodology) 3.2.3 3.2 POWER DISTRIBlJTION LIMITS 3.2.3 AXIAL FLUX DIFFERENCE CAFD) {Constant Axial Offset Control CCAOC)

Methodology)

LCO 3.2.3 The AFD:

a. . Shall be maintained within the target band about the target flux difference. The target band is specified in the COLR.

b. Hay deviate outside the target band with THERMAL POWER

< 90% RTP but~ SOX RTP. provided AFD is within the acceptable operation limits and cumulative penalty deviation time is

~ 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months during the previous 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . The acceptable operation limits are specified in the COLR.

c. Hay deviate outside the target band with THERMAL POWER

< 50% RTP .

.............................. NOTES******************************

1. The AFD shall be considered outside the target band when two or more OPERABLE excore channels indicate AFD to be outside the target band.

u 2. With Thermal Power ~ 50.t RTP. penalty deviation time shall be accumulated on the basis of a 1 minute penalty deviation for each 1 minute of power operation with AFD outside the target band. *

3. With Thermal Power*< 50.t RTP and> 15% RTP. penalty deviation time shall be accumulated on the basis of a 0.5 minute penalty deviation for each 1 minute of power operation with AFD outside the*target band.

4. A total of 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months of operation may be accumulated with AFD outside the target band without penalty deviation time during surveillance of power range channels in accordance with

SR 3.3.1.6, provided AFD is maintained within acceptable operation limits.

APPLICABILITY: HOOE 1 with THERMAL POWER> 15% RTP.

ACTIONS INDIAN POINT 3 3.2.3*1 Amenanent 205

AFD (CAOC Methodology) 3.2.3 CONDITION REQUIRED ACTION COMPLETION TIME A. THERHAL POWER~ 90% RTP. A.1

Restore AFD to within 15 minutes target band.

Rm AFD not within the target band.

B. Required Action and B.1 Reduce THERMAL POWER to 15 minutes associated Completion < 90% RTP.

Time of Condition A not met.

C. *********NOTE********* C.l Reduce THERMAL POWER to 30 minutes Required Action C.1 must < 50% RTP.

be completed whenever Condition C is entered.

V *..........*..........

THERMAL POWER< 90% and

~ 50% RTP with cumulative penalty deviation time>

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months during the previous 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

QB THERMAL POWER< 90% and

~ 50% RTP with AFD not within the acceptable operation limits.

SURVEILLANCE*REQUIREHENTS INDIAN POINT 3 3.2.3*2 Amenanent 205

AFD (CAOC Methodology) 3.2.3 SURVEILLANCE FREQUENCY SR 3.2.3.1 Verify AFD is within target band for each 7 days OPERABLE excore channel.

SR 3.2.3.2 *******************NOTE********************

Assume logged values of AFD exist during the preceding time interval.

Verify AFD is within target band and log AFD for *****NOTE******

each OPERABLE excore channel. Only required to be performed if AFD monitor alarm is inoperable Once within 15 minutes and every 15 minutes.

thereafter when THERMAL POWER

t 90% RTP Once within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and every 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months thereafter when THERMAL POWER< 90% RTP (continued}

INDIAN POINT 3 3.2.3*3 Amenctnent 205

AFD (CAOC Hethodology) 3.2.3 SURVEILLANCE REQUIREHENTS (continued)

SURVEILLANCE FREQUENCY SR 3.2.3.3 Update target flux difference of each OPERABLE Once within excore channel by: 31 EFPD after each refueling

a. Determining the target flux difference in accordance with SR 3. 2. 3. 4. or Mill

b. Using linear interpolation between the most 31 EFPD recently measured value, and either the thereafter predicted value for the end of cycle or 0% AFD.

SR 3.2.3.4 ----------------**--NOTE----**-***--*------

The initial target flux difference after each refueling may be determined from design predictions.

u Determine, by measurement, the target flux difference of each OPERABLE excore channel.

Once within 31 EFPD after each refueling 92 EFPD thereafter INDIAN POINT 3 3.2.3*4 Mtencinent 205

QPTR 3.2.4 3.2 POWER DISTRIBlJTION LIHITS 3.2.4 QUADRANT POWER TILT RATIO (QPTR)

LCD 3.2.4 . The QPTR shall be~ 1.02.

APPLICABILITY: HOOE 1 with THERHAL POWER > SOY. RTP.

ACTIONS CONDITION REQUIRED ACTION COHPLETION TIHE A. QPTR not within limit. A.1 Reduce THERHAL POWER 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after each

~ 3% from RTP for each QPTR determination lY. of QPTR > 1.00.

A.2 Determine QPTR after Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months achieving equilibrium conditions from a THERHAL POWER reduction per Required Action A.1.

A.3 Perform SR 3.2.1.1 and 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after SR 3.2.2.1. achieving equilibrium conditions from a Thermal Power reduction per Required Action A.1.

Once per 7 days thereafter (continued)

INDIAN POINT 3 3.2.4-1 Amenanent 205

QPTR 3.2.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TI HE A. (continued) A.4 Re-evaluate safety Prior to analyses and confirm increasing THERHAL results remain valid for POWER above the duration of operation limit of Required under this condition. Action A.1 AND A.5 ********NOTES*********

1. Perform Required Action A.5 only after Required Action A.4 is completed.

2. Required Action A.6 shall be completed whenever Required Action A;S is performed.

Normalize excore Prior to detectors to restore increasing THERMAL QPTR to within limits. POWER above the limit of Required Action A.1 (continued) u INDIAN POINT 3 3.2.4*2 Amendment 205

QPTR 3.2.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.6 --------NOTE---------

Perform.Required Action A.6 only after Required Action A.5 is completed.

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

Perform SR 3.2.1.1 and Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SR 3.2.2.1. after achieving equilibrium conditions at RTP not to exceed 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months after increasing THERMAL POWER above the limit of Required Action A.1 B. Required Action and B.1 Reduce THERMAL POWER to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion $ 50% RTP.

Time not met.

u INDIAN POINT 3 3.2.4-3 Amenanent 205

QPTR 3.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.1 ******************NOTES*************************

1. With input from one Power Range Neutron Flux channel inoperable and THERMAL POWER

~ 75X RTP, the remaining three power range channels can be used for calculating QPTR.

2. SR 3.2.4.2 may tie performed in lieu of this Surveillance.

Verify QPTR is within limit by calculation. 7 days SR 3.2.4.2 *******************NOTE*************************

Not required to be performed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after input from one or more Power Range Neutron Flux channels are inoperable with THERMAL POWER

> 75X RTP.

u Verify QPTR is within limit*using the movable 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months incore detectors.

INDIAN POINT 3 3.2.4-4 Amenanent 205

RPS Instrumentation 3.3.1 3.3 INSTRUMENTATION u 3.3.1 Reactor Protection System (RPS) Instrumentation LCO 3.3.1 The.RPS instrumentation for each Function in Table 3.3.1*1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.1-1.

ACTIONS

- - - - NOTE****************************************

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions A.1 Enter the Condition IR111edi atel y with one or more required referenced in channels or trains Table 3.3.1*1 for the i noperab1e. channelCs) or train Cs).

B. One Manual Reactor Trip B.1 Restore channel to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months channel inoperable. OPERABLE status.

QR B.2 Be in HOOE 3. 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months (continued) u INDIAN POINT 3 3.3.1*1 Amenctnent 205

RPS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COHPLETION TI HE C. One channel or train C.1 Restore channel or train 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months inoperable. to OPERABLE status .

.QR C.2.1 Initiate action to fully 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months insert all rods.

Mm C.2.2 Place the Rod Control 49 hours5.671296e-4 days 0.0136 hours 8.101852e-5 weeks 1.86445e-5 months System in a condition incapable of rod withdrawal.

D. One Power Range Neutron **************NOTES*************

Flux- High channel 1. The inoperable channel may be inoperable. bypassed for up to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months for surveillance testing and setpoint adjustment of other channels.

2. Requirements of SR 3.2.4.2 are applicable if the Power Range Neutron Flux input to QPTR is inoperable *

...***....**....***.............

D.1 Place channel in trip. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months

.QR

- D.2 Be in HOOE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

INDIAN POINT 3 3.3.1*2 Amenanent 205

RPS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION *REQUIRED ACTION COMPLETION TIHE E. One channel inoperable. --**----*-----NOTE--------------

The inoperable channel may be bypassed for up to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months for surveillance testing of other channels *

..**.**......................*..

E.l Place channel in trip. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months QR '

E.2 Be in HOOE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

-

F. Required Intermediate F.l Suspend operations Imme di ate1y Range Neutron Flux involving positive channel inoperable. reactivity additions.

MID F.2 Reduce THERMAL POWER to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months

< P-6.

G. Required Source Range G.l Open Reactor Trip Immediately Neutron Flux channel Breakers CRTBs).

inoperable.

(continued) u INDIAN POINT 3 3.3.1*3 Amendment 205

RPS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TI HE H. One channel inoperable. ******---~---*NOTE**************

The inoperable channel may be bypassed for up to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months for surveillance testing of other channels.

- - - - -***

H.1 Place channel in trip. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Q8 H.2 Reduce THERMAL POWER to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

< P-7.

I. One Reactor Coolant Pump *************NOTE***************

Breaker Position channel The inoperable channel may be inoperable. bypassed for up to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months for surveillance testing of other channels .

..*........*...............*...*

I.1 Restore channel to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OPERABLE status.

OR 1.2 Reduce THERMAL POWER to 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months

< P-8.

(continued)

INDIAN POINT 3 3.3.1*4 Amendment 205

RPS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIHE J. One Turbine Trip channel **************NOTE**************

inoperable. The inoperable channel may be bypassed for up to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months for surveillance testing of other channels .

...**..***......*.......*.*.....

J.1 Place channel in trip. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months QR J.2 Reduce THERMAL POWER to 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months

< P-8.

K. One train inoperable. *************NOTE***************

One train may be bypassed for up to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months for surveillance t~sting provided the other train is OPERABLE .

..****....................***...

K.1 Restore train to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OPERABLE status.

OB K.2 Be in HOOE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

INDIAN POINT 3 3.3.1-5 Amenonent 205

RPS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIHE L. One RTB train inoperable. **************NOTES*************

1. One train may be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing, provided the other train is OPERABLE.

2. One RTB may be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for maintenance on undervoltage or shunt trip mechanisms, provided the other train is OPERABLE.

.**......**.....................

L.1 Restore train to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months OPERABLE status.

08 L.2 Be in HOOE 3. 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months H. One or more channels H.1 Verify interlock is in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

inoperable. required state for existing unit conditions.

08 H.2 Be in HOOE 3. 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months (continued) u INDIAN POINT 3 3.3.1*6 Menonent 205

RPS Instrumentation 3.3.1 ACTIONS (continued)

V CONDITION REQUIRED ACTION COMPLETION TI HE N. One or more channels *N.1 Verify interlock is in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. required state for existing unit conditions.

QR N.2 Be in HOOE 2. 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months

0. One trip mechanism 0.1 Restore inoperable trip 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months inoperable for one RTB. mechanism to OPERABLE status.

QR 0.2. Be in HOOE 3. 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months V

u INDIAN POINT 3 3.3.1-7 Amenanent 205

RPS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS

- - - - ~*****************************NOTE*****************************************

Refer to Table 3.3.1*1 to determine which SRs apply for each RPS Function.

SURVEILLANCE FREQUENCY

SR 3.3.1.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.1.2 *******************NOTES***********************

1. Adjust NIS channel if absolute difference is > 2%'.

2. Not required to be performed until .24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after THERMAL POWER is::!: 15%' RTP.

Compare results of calorimetric heat balance 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months calculation to Nuclear Instrumentation System CNIS} channel output.

SR 3.3.1.3 *******************NOTES***********************

1. Adjust NIS channel if absolute _difference is : !: 3%'.

2. Only required to be performed when THERMAL POWER is> 90X RTP.

Compare results of the incore detector 31 effective full measurements to NIS AFD. power days CEFPD}

(continued}

u INDIAN POINT 3 3.3.1*8 MJenctnent 205

RPS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.4 *********************NOTE**********************

This Surveillance must be performed on the reactor trip bypass breaker prior to placing the bypass breaker in service.

Perform TADOT. 31 days on a STAGGERED TEST BASIS SR 3.3.1.5 Perform ACTUATION LOGIC TEST. 31 days on a STAGGERED TEST BASIS SR 3.3.1.6 *********************NOTE**********************

Only required to be performed when THERHAL POWER is > 90% RTP.

Calibrate excore channels to agree with incore 92 EFPD detector measurements.

SR 3.3.1.7 * * * * * * * * * * * * *******-NOTE************************

Not required to be performed for source range instrumentation prior to entering HOOE 3 from HOOE 2 until 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after entry into HOOE 3.

Perform COT. 92 days (continued)

INDIAN POINT 3 3.3.1*9 />Jnenanent 205

RPS Instrumentation 3.3.1 SURVEILLANCE REQUIREHENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.8 *********************NOTE**********************

This Surveillance shall include verification that interlocks P-6 and P-10 are in their required state for existing unit conditions.

Perform COT. ******NOTE******

Only required when not performed within prev1ous 92 days Prior to reactor startup Four hours after u reducing power below P-6 for source range instrumentation Twelve hours after reducing power below P-10 for power and intermediate instrumentation Every 92 days thereafter (continued) u INDIAN POINT 3 3.3.1-10 Amenanent 205

RPS Instrumentation 3.3.1 SURVEILLANCE REQUIREHENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.9 ------------------*--NOTE*---------*-----------

Verification of setpoint is not required.

Perform TADOT. 92 days SR 3.3.1.10 ------------* -* ------NOTE ----* - -------------* -*

This Surveillance shall include verification that the time constants are adjusted to the prescribed values.

Perform CHANNEL CALIBRATION. 24 months 18 months for Function 11 SR 3.3.1.11 --------------------NOTE- ------------* ---------

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION. 24 months (continued)

INDIAN POINT 3 3.3.1-11 Amenanent 205

RPS Instrumentation 3.3.1 SURVEILLANCE REQUIREHENTS (continued) u SURVEILLANCE FREQUENCY SR 3.3.1.12 --------------------NOTE-----------------------

This Surveillance shall include verification that the electronic dynamic compensation time constants are set at the required values.

Perform CHANNEL CALIBRATION. 24 months SR 3~3.1.13 Perform COT. 24 months SR 3.3.1.14 ---------------------NOTE----------------------

Verification of setpoint is not required.

u Perform TADOT. 24 months

. .J u

INDIAN POINT 3 3.3.1-12 Amendment 205

RPS Instrumentation 3.3.1 Table 3.3.1-1 (page 1 of 8)

Reactor Protection System Instrumentation APPLICABLE MODES OR FUNCTION OTHER SPECIFIED REQUIRED SURVEILLANCE CONDITIONS CHANNELS CONDITIONS REQUIREMENTS ALLOWABLE VALUE

1. Manual Reactor 1,2 2 B SR 3.3.1.14 NA Trip 3(a), 4(a), 5(a) 2 C SR 3.3.1.14 NA

2. Power Range Neutron Flux

a. High 1,2 40) D SR 3.3.1.1 S111% RTP SR 3.3.1.2 SR 3.3.1.7 SR 3.3.1.11

b. Low 1!b>,2 40) E SR 3.3.1.1 ~5%RTP

., *. ; ...~*~.t~,~ SR 3.3.1.8 SR 3.3.1.11

3. Intermediate 1!b>, 2<c) 1 F SR 3.3.1.1 NA Range Neutron SR 3.3.1.8 Flux SR 3.3.1.11 (continued)

(a) With Rod Control System capable of rod withdrawal or one or more rods not fully inserted.

(b) Below the P-10 (Power Range Neutron Flux) interlocks.

(c) Above the P-6 (Intermediate Range Neutron Flux) interlocks.

0) Only 3 channels required during Mode 2 Physics Tests, LCO 3.1.8 INDIAN POINT 3 3.3.1-13 Amendment 225 Revised by letter dated D:canber a:>, ms

RPS Instrumentation 3.3.1 Table 3.3.1*1 (page 2 of 8)

Reactor Protection System Instrunentation APPLICABLE HODES OR OTHER SPECIFIED REQUIRED SlRVEILLANCE FUNCTION CONDITIONS

CHANNELS CONDITIONS REQUIREMENTS ALLOWABLE VALUE

4. Source Range 2Cd) 1 G SR 3.3.1.1 NA Neutron Flux SR 3.3.1.8 SR 3.3.1.11 1 G SR 3.3.1.1 NA SR 3.3.1.7 SR 3.3.1.11

5. Overtemperature AT 1.2 4 E SR 3.3.1.1 Refer to Note 1 SR 3.3.1.3 SR 3.3.1.6 SR 3.3.1.7 SR 3.3.1.12 V 6. Overpower AT 1.2 4 E SR 3.3.1.1 Refer to Note 2 SR 3.3.1.7 SR 3.3.1.12 (continued)

(a) With Rod Control System capable of rod withdrawal or one or more rods not fully inserted.

(d) Below the P*6 (Intermediate Range Neutron Flux) interlocks.

INDIAN POINT 3 3.3.1-14 Amenanent 205

RPS Instrumentation 3.3.1 u Table 3.3.1-1 (page 3 of 8)

Reactor Protection System Instrumentation APPLICABLE MODES OR FUNCTION OTHER SPECIFIED REQUIRED SURVEILLANCE CONDITIONS CHANNELS CONDITIONS REQUIREMENTS ALLOWABLE VALUE

7. Pressurizer Pressure

a. Low 1<e) 4 H SR 3.3.1.1 ~1900 psig SR 3.3.1.7 SR 3.3.1.10 SR 3.3.1.1

b. High 1,2 3 E SR 3.3.1.7 S2400 psig SR 3.3.1.10

8. Pressurizer 1<e) 3 H SR 3.3.1.1 S97%

Water Level - SR 3.3.1.7 High SR 3.3.1.10 u 9. Reactor Coolant Flow-Low 1<e) 3 per loop H SR 3.3.1.1 SR 3.3.1.7 SR 3.3.1.10

~90%

(continued)

(e) Above the P-7 (Low Power Reactor Trips Block) interlock.

u INDIAN POINT 3 3.3.1-15 Amendment 225

RPS Instrumentation 3.3.1 Table 3.3.1*1 (page 4 of 8) u Reactor Protection System Instrl.JT'lentation APPLICABLE HODES OR OTHER SPECIFIED REQUIRED Sl.RVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS ALLOWABLE VALUE

10. Reactor Coolant P~ (RCP) Breaker Position

a. Single Loop 1(f) 1 per RCP I SR 3.3.1.14 NA

b. Two Loops 1Cg) 1 per RCP H SR 3.3.1.14 NA

11. Undervoltage 1<e) 1 per bus H SR 3.3.1.9 NA RCPs (6.9 kV bus) SR 3.3.1.10

12. Under frequency 1Ce) l per bus H SR 3.3.1.9 2 57.22 Hz RCPs (6.9 kV bus) SR 3.3.1.10

13. Steam 1.2 3 per SG E SR 3.3.1.1 2 4.0l' HR Generator (SG) SR 3.3.1.7 u Water Level - Low Low SR 3.3.1.10

14. SG Water 1.2 2 per SG E SR 3.3.l.1 NA Level - Low SR 3.3.1.7 SR 3.3.1.10 Coincident with 1.2 2 per SG E SR 3.3.1.1 NA Steam Flow/ SR 3.3.1.7 Feect,,;,ater Flow SR 3.3.1.10 Mismatch Ccontinued)

(e) Above the p.7 (Low Power Reactor Trips Block) interlock.

Cf) Above the P*B (Power Range Neutron Flux) interlock.

(g) Above the p.7 (Low Power Reactor Trips Block) interlock and below the P*B (Power Range Neutron Flux) interlock.

u INDIAN POINT 3 3.3.1-16 Amenanent 205

RPS Instrumentation 3.3.1 Table 3.3.1*1 (page 5 of 8) u Reactor Protection System Instrllllentation APPLICABLE HODES OR OTHER SPECIFIED REQUIRED SI.RVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS ALLOWABLE VALUE

15. Turbine Trip*Auto* 1Ch) 3 J SR 3.3.1.10 NA Stop Oil Pressure SR 3.3.1.14

16. Safety Injection 1.2 2 trains K SR 3.3.1.14 NA (SI) Input from Engineered Safety Feature Actuation System (ESFAS)

17. Reactor Trip System Interlocks

a. Intermediate 2Cd) 2 trains H SR 3.3.1.11 NA Range Neutron SR 3.3.1.13 Flux. P*6

b. Low Power 1 2 trains N SR 3.3.1.11 NA Reactor Trips SR 3.3.1.13 Block, p.7

c. Power Range 1 4 N SR 3.3.1.11 NA Neutron Flux. SR 3.3.1.13 P*8

d. Power Range 1.2 4 H SR 3.3.1.11 NA Neutron Flux, SR 3.3.1.13 P*lO

e. Turbine First 1 2 N SR 3.3.1.1 NA Stage Pressure. SR 3.3.1.10 p.7 Input

SR 3.3.1.13 (contfoued) j Cd) Below the P*6 (Intermediate Range Neutron Flux) interlocks.

(h) Above the P*8 (Power Range Neutron Flux) interlock..

u INDIAN POINT 3 3.3.1-17 Amencinent 205

RPS Instrumentation 3.3.1 Table 3.3.1*1 (page 6 of 8)

Reactor Protection System InstrLJnentation APPLICABLE HODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS ALLOWABLE VALUE

18. Reactor Trip . 1.2 2 trains L SR 3.3.1.4 NA Breakers(RTBs)Ci) 3(a). 4 ca>. 5ca) 2 trains C SR 3.3.1.4 NA

19. Reactor Trip 1.2 1 each 0 SR 3.3.1.4 NA Breaker per RTB Undervoltage and Shunt Trip 3ca>. 4 Ca>. 5Ca) 1 each C SR 3.3.1.4 NA Mechanisms per RTB

20. Automatic Trip 1.2 2 trains K SR 3.3.1.5 NA Logic 3Ca>, 4 ca>. 5(a) 2 trains C SR 3.3.1.5 NA (a) With Rod Control System capable of rod withdrawal or one or more rods not fully inserted.

u Ci) Including any reactor trip bypass breakers that are racked in and closed for bypassing an RTB.

u INDIAN POINT 3 3.3.1*18 Amenanent 205

RPS Instrumentation

3. 3 .1 Table 3.3.1-1 (page 7 of 8)

Reactor Protection System Instrumentation Note 1: Overtemperature 6T The Overtemperature ~T Function Allowable Value shall not exceed the following Trip Setpoint by more than 2.8% of ~ T span:

Where: ~Tis measured RCS ~T. °F.

~T 0 is the indicated ~Tat RTP, °F.

s is the Laplace transform operator, sec- 1

Tis the measured RCS average temperature, °F.

T' is the nominal Tavg at RTP,::;; [ * ]°F.

Pis the measured pressurizer pressure, psig P' is the nominal RCS operating pressure, ~ [ *] psig K1 ::;; [ * ] K2 ~ [ * ] /°F K3 ~ [ * ] /psi g r, ~ [ * ] sec r2 ::;; [ * ] sec f 1(~1) = [ *] {[ *] - (qt - qb)} when qt - qb::;; [ * ]% RTP 0% of RTP when [ * ]% RTP < qt - qb::;; [ * ]% RTP

[ * ] { (qt - qb) - [ * ] } when qt - qb > [ * ]% RTP Where qt and qb are percent RTP in the upper and lower halves of the core, respectively, and qt+ qb is the total THERMAL POWER in percent RTP.

The values denoted with [ *] are specified in the COLR.

I INDIAN POINT 3 3.3.1-19 Amendment 234

RPS Instrumentation

3. 3 .1 Table 3.3.1-1 {page 8 of 8)

Reactor Protection System Instrumentation Note 2: Overpower ~T The Overpower tJ. T Function A11 owab 1e Va 1ue sha 11 not exceed the fo 11 owing Trip Set point by more than 1.8% of tJ. T span:

Where: b.T is measured RCS /:J.T, °F.

/:J.T 0 is the indicated !J.T at RTP, °F.

s is the Laplace transform operator, sec- 1

Tis the measured RCS average temperature, °F.

T" is the nominal T.~ at RTP, s [ * ]°F.

K5 ~ [ * ] /°F for increasing Tavg K6 ~ [ * ] /°F when T > T'

[ *] /°F for decreasing T.~ [ * ] /°F when T :5: T' r3 ~ [ * ] sec

The values denoted with [ *] are specified in the COLR ..

INDIAN POINT 3 3.3.1-20 Amendment 234

ESFAS Instrumentation 3.3.2 3.3 INSTRUMENTATION 3.3.2 Engineered Safety Feature Actuation System (ESFAS) Instrumentation LCO 3.3.2 The ESFAS instrumentation for each Function in Table 3.3.2-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.2-1.

ACTIONS

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

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Enter the Condition Immediately Functions with referenced in Table one or more 3.3.2-1 for the required channels channel(s) or or trains train(s).

inoperable.

B. One channel or B.1 Restore channel or 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months train inoperable. train to OPERABLE status.

-OR B.2.1 Be in MODE 3. 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months AND

--

NOTE --------

LCO 3.0.4.a is not applicable when entering MODE 4.

B.2.2 Be in MODE 4. 60 hours6.944444e-4 days 0.0167 hours 9.920635e-5 weeks 2.283e-5 months (continued)

INDIAN POINT 3 3.3.2-1 Amendment 252

ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One train C.l ------NOTE----------

inoperable. One train may be bypassed for up to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months for surveillance testing provided the other train is OPERABLE.

Restore train to OPERABLE 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months status.

OR C.2.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND

- -

NOTE LCO 3.0.4.a is not applicable when entering MODE 4.

-----

C.2.2 Be in MODE 4. 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months D. One channel D.1 ---------NOTE- ---

inoperable. The inoperable channel may be bypassed for up to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months for surveillance testing of other channels.

-------

Place channel in trip. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OR D.2.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND

- -

D.2.2 Be in MODE 4. 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months (continued)

INDIAN POINT 3 3.3.2 - 2 Amendment 252

ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COHPLETION TI HE E. One Containment Pressure E.1 *********NOTE**********

channel i~operable in one One additional channel or both sets of three. may be bypassed for up to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months for surveillance testing .

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

Place channel in trip. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months QR E.2.1 Be in HOOE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Mm E.2.2 Be in HOOE 4. 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months u F. One channel or train inoperable.

F.1 Restore channel or train to OPERABLE status.

48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months

-

QR F.2.1 Be in HOOE 3. 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months Mm F.2.2 Be in HOOE 4. *. 60 hours6.944444e-4 days 0.0167 hours 9.920635e-5 weeks 2.283e-5 months (continued) u INDIAN POINT 3 3.3.2*3 Amencinent 205

ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIHE G. One train inoperable.

G.1 * ********NOTE**********

One train may be bypassed for up to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months for surveillance testing provided the other train is OPERABLE.

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

Restore train to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OPERABLE status.

08 G.2.1 Be in HOOE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Mm G.2.2 Be in HOOE 4. 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months H. One train inoperable. H.1 *********NOTE**********

One train may be bypassed for up to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months for surveillance testing provided the other train is OPERABLE.

- - - - -*****

Restore train to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OPERABLE status.

08 H.2 Be in HOOE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued) u INDIAN POINT 3 3.3.2*4 .Amendment 205

ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME I. Hain Feedwater Pump trip I.1 Verify one channel Invnedi ately

.channel(s) inoperable. associated with an operating HBFP is OPERABLE.

MID I.2 Restore one channel 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months associated with each operating HBFP to OPERABLE status.

J. Required Action and J.1 Be in HOOE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition I not met.

\_)

K. One or more channels K.1 Verify interlock is in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. required state for existing unit condition.

OR K.2.1 Be in HOOE 3. 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months AtiQ K.2.2 Be in HOOE 4. 13 hours1.50463e-4 days 0.00361 hours 2.149471e-5 weeks 4.9465e-6 months u

INDIAN POINT 3 3.3.2*5 lvnenanent 205

ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREHENTS

--------------------------------*---*-NOTE------------------*--*-*----------------

Refer to Table 3.3.2-1 to determine which SRs apply for each ESFAS Function.

SURVEILLANCE FREQUENCY SR 3.3.2.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.2.2 Perform ACTUATION LOGIC TEST. 31 days on a STAGGERED TEST BASIS SR 3.3.2.3 Perform HASTER RELAY TEST.

31 days on a STAGGERED TEST BASIS SR 3.3.2.4 Perform COT. 92 days SR 3.3.2.5 Perform SLAVE RELAY TEST. 24 months SR 3.3.2.6 --------------*-----NOTE----------------------

Verification of setpoint not required for manual initiation functions .

- - ...**...****.**...***.....*...........*...

Perform TADOT. 24 months

{continued)

INDIAN POINT 3 3.3.2-6 Amendment 205

ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.2.7 -------------------NOTE--------------------

This Surveillance shall include verification that the time constants are adjusted to the prescribed values.

Perform CHANNEL CALIBRATION. 24 months u

INDIAN POINT 3 3.3.2-7 Amenanent 205

ESFAS Instrumentation 3.3.2 u Table 3.3.2-1 (page 1 of 6)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR FUNCTION OTHER SPECIFIED REQUIRED SURVEILLANCE CONDITIONS CHANNELS CONDITIONS REQUIREMENTS ALLOWABLE VALUE

1. Safety Injection

a. Manual Initiation 1,2,3,4 2 8 SR 3.3.2.6 NA

b. Automatic 1,2,3,4 2 trains C SR 3.3.2.2 NA Actuation Logic SR 3.3.2.3 and Actuation SR 3.3.2.5 Relays C. Containment 1,2,3 3 D SR 3.3.2.1 s4.80 psig Pressure-Hi SR 3.3.2.4 SR 3.3.2.7

d. Pressurizer 1,2,3(b) 3 D SR 3.3.2.1 ~1710 psig Pressure-Low SR 3.3.2.4 u High Differential 1,2,3 3 per D SR 3.3.2.7 SR 3.3.2.1 NA e.

Pressure steam line SR 3.3.2.4 Between Steam SR 3.3.2.7 Lines

f. High Steam 1,2(d),3!d) 2 per D SR 3.3.2.1 (c}

Flow in Two steam line SR 3.3.2.4 Steam Lines SR 3.3.2.7 Coincident with 1,2<d>,3(d) 1 per loop D SR 3.3.2.1 ~540.5°F Tavg- Low SR 3.3.2.4 SR 3.3.2.7

{continued)

(a} Not used (b} Above the Pressurizer Pressure interlock.

(c} Less than or equal to turbine first stage pressure corresponding to 54% full steam flow below 20% load, and increasing linearly from 54% full steam flow at 20% load to 120% full steam flow at 100% load, and corresponding to 120% full steam flow above 100% load. Time delay for SI :56 seconds.

(d} Except when all MSIVs are closed.

\.._)

INDIAN POINT 3 3.3.2-8 Amendment 225

ESFAS I nstr).Jmentati on 3.3.2 Table 3,3.2*1 (page 2 of 6)

Engineered Safety Feature Actuation System Instrunentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SI.RVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS ALLOWABLE VALUE

1. Safety Injection (continued)

g. High Steam Flow in 1. 2<d> , 3Cd) 2 per D SR 3.3.2.1 (C)

Two Steam Lines steam SR 3.3.2.4 line SR 3.3.2.7 Coincident with 1,2Cd),3Cd) 1 per 0 SR 3.3.2.1 2 500 Steam Line steam SR 3.3.2.4 psig Pressure-Low line SR 3.3.2.7

2. Containment Spray a *. Manual Initiation 1.2.3,4 2 per B SR 3.3.2.6 NA train, 2 trains

b. Automatic 1.2,3,4 2 trains C SR 3.3.2.2 NA Actuation Logic SR 3.3.2.3 and Actuation SR 3.3.2.5 u Relays

c. Containment 1.2.3 2 sets E SR 3.3.2.1 " 24 psig Pressure (Hi *Hi) of 3 SR 3.3.2.4 SR 3.3.2.7 (continued)

(c) Less than or equal to turbine first stage pressure corresponding to 54% full steam flow below 20% load, and increasing linearly from 54% full steam flow at 20% load to 120% full steam flow at 100% load, and corresponding to 120% full steam flow above 100% load. Time delay for SI~ 6 seconds.

(d) Except when all HSIVs are closed.

INDIAN POINT 3 3.3.2-9 Amendment 213

ESFAS Instrumentation 3.3.2 Table 3.3.2*1 (page 3 of 6)

Engineered Safety Feature Actuation System Instrunentation APPLICABLE HODES OR OTHER SPECIFIED REQUIRED SlRVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREHENTS ALLOWABLE VALUE

3. Containment Isolation

a. Phase A Isolation (1) Manual 1.2.3.4 2 B SR 3.3.2.6 NA Initiation (2) Automatic 1.2.3,4 2 trains C SR 3.3.2.2 NA Actuation SR 3.3.2.3 Logic and SR 3.3.2.5 Actuation Relays (3) Safety Refer to Function l (Safety Injection) for all initiation functions and Injection requirements.

b. Phase B Isolation (1) Manual 1.2.3.4 2 B SR 3.3.2.6 NA Initiation (2) Automatic 1.2.3.4 2 trains C SR 3.3.2.2 NA Actuation SR 3.3.2.3 Logic and SR 3.3.2.5 Actuation Relays (3) Contairvnent i".2.3 2 sets E SR 3.3.2.1 s 24 psig Pressure of three SR 3.3.2.4 (Hi* Hi)

SR 3.3.2.7 (continued)

I

\,__)

INDIAN POINT 3 3.3.2-10 Amenonent 205

ESFAS Instrumentation 3.3.2 u Table 3.3.2-1 (page 4 of 6)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR FUNCTION OTHER SPECIFIED REQUIRED SURVEILLANCE CONDITIONS CHANNELS CONDITIONS REQUIREMENTS ALLOWABLE VALUE

4. Steam Line Isolation

a. Manual Initiation 1,idl,3(d} 2 per F SR 3.3.2.6 NA steam line

b. Automatic 1,2<d>,3(d) 2 trains G SR 3.3.2.2 NA Actuation Logic SR 3.3.2.3 and Actuation SR 3.3.2.5 Relays

c. Containment 1.2{dl, 2 sets of 3 E SR 3.3.2.1 S24 Pressure (Hi-Hi) 3(d) SR 3.3.2.4 psig SR 3.32.7

d. High Steam Flow 1,2<d>, 2 per D SR 3.3.2.1 (c)

V in Two Steam Lines 3{d) steam line SR 3.3.2.4 SR 3.3.2.7 Coincident with 1,2(dl, 1 per loop D SR 3.3.2.1 ~540.5°F 3(d) SR 3.3.2.4 Tavg*Low SR 3.3.2.7

e. High Steam Flow 1,2<d>, 2 per steam D SR 3.3.2.1 (c) in Two Steam 3(d) line SR 3.3.2.4 Lines SR 3.3.2.7 Coincident with 1,2<d>, 1 per steam D SR 3.3.2.1 ~500 psig Steam Line 3(d) line SR 3.3.2.4 Pressure-Low SR 3.3.2.7 (c) Less than or equal to turbine first stage pressure corresponding to 54% full steam flow below 20% load, and increasing linearly from 54% full steam flow at 20% load to 120% full steam flow at 100% load, and corresponding to 120% full steam flow above 100% load. Time delay for SI :::;6 seconds.

(d) Except when all MSIVs are closed.

"-.__)

INDIAN POINT 3 3.3.2-11 Amendment 225

ESFAS Instrumentation 3.3.2 Table 3.3.2*1 (page 5 of 6)

Engineered Safety Feature Actuation System Instrllllentation APPLICABLE HODES OR OTHER SPECIFIED REQUIRED SI.RVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE

5. Feea.,ater Isolation

a. Safety Injection 1.2Ce) 2 trains H SR 3.3.2.2 NA SR 3.3.2.5

b. SG Water Level* 1.2Ce) 3 per SG D SR 3.3.2.1 s au NR High High SR 3.3.2.4 SR 3.3.2.7

6. Auxiliary Feect.later

a. Automatic 1.2.3 2 trains G SR 3.3.2.2 Actuation Logic SR 3.3.2.5 NA and Actuation Relays

b. SG Water Level* 1.2.3 3 per D SR 3.3.2.1 ~ 4.0.t NR Low Low SG SR 3.3.2.4 SR 3.3.2.7

c. Safety Refer to Function 1 (Safety Injection) for all initiation functions and Injection (g) requirements.

d. Loss of Offsite 1.2.3 2 F SR 3.3.2.6 ~ 200 V Power (Non SI SR 3.3.2.7 Blackout Sequence Signal)

e. Trip of Hain l (f)

2 Cf) 1 per I SR 3.3.2.6 NA Boiler Feect.later MBFP PI.Jll)S (continued)

(e) Except when all HBFPDVs, or HBFRVs and associated bYPass valves are closed or isolated by a closed manual valve.

Cf) Only required for HBFPs that are in operation.

(g) Not required if AFW Pl.Ill> not required to be OPERABLE.

u INDIAN POINT 3 3~3.2-12 Amencinent 205

ESFAS Instrumentation 3.3.2 Table 3.3.2*1 (page 6 of 6)

Engineered Safety Feature Actuation System lnstrunentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SlRVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS ALLOWABLE VALUE

7. ESFAS 1.2.3 3 K SR 3.3.2.1 NA Interlocks* SR 3.3.2.4 Pressurizer SR 3.3.2.7 Pressure u

INDIAN POIITT 3 3.3.2*13 /IJnenanent 205

PAM Instrumentation 3.3.3

\.__) 3.3 INSTRUMENTATION 3.3.3 Post Accident Monitoring (PAM) Instrumentation LCO 3.3.3 The PAM instrumentation for each Function in Table 3.3.3-1 shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

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

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions A.1 Restore one channel to 30 days with one required channels OPERABLE status.

inoperable.

B. Required Action and 8.1 Initiate action in Immediately associated Completion accordance with Time of Condition A not Specification 5.6.7 met.

(continued)

INDIAN POINT 3 3.3.3-1 Amendment 226

.,

PAM Instrumentation 3.3.3 u ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more Functions C.1 Restore one channel to 7 days with two required OPERABLE status.

channels inoperable.

OR One required Thot channel and two required Core Exit Temperature channels inoperable.

QB One required Tcold channel and two required SG Pressure channels inoperable.

OR One required Main Steam Line Radiation channel u and two required SG Water Level (Narrow Range) channels inoperable.

D. Required Action and 0.1 -Enter the Condition Immediately associated Completion referenced in Table.

Time of Condition C not 3.3.3*1 for the met. channel.

E. As required by Required E.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action D.1 and referenced in rum Table 3.3.3*1.

E.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months F. As required by Required F.l Initiate action in Inunediately Action D.l and accordance with referenced in Specification 5.6.7.

Table 3.3.3*1.

INDIAN POINT 3 3.3.3-2 Amendment -2B5. 211

PAH Instrumentation 3.3.3 SURVEILLANCE REQUIREHENTS

- - - - NOTE*********************************************

SR 3.3.3.1 and SR 3.3.3.2 apply to each PAH instrumentation Function in Table 3.3.3*1.

SURVEILLANCE FREQUENCY SR 3.3.3.1 Perform CHANNEL CHECK for each required 31 days instrumentation channel that is normally energized.

SR 3.3.3.2 *******************NOTE********************

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION. As specified in Table 3.3.3-1 u

u INDIAN POINT 3 3.3.3*3 Amen<inent 205

PAM Instrumentation 3.3.3 Table 3.3.3-1 (page 1 of 2)

Post Accident Monitoring Instrumentation CONDITION REFERENCED FROM REQUIRED SR 3.3.3.2 FUNCTION REQUIRED CHANNELS ACTION D. l FREQUENCY

1. Neutron Flux 2 F 24 months

2. RCS Hot Leg Temperature (Wide Range) per loop E 24 months (T hotl

3. RCS Cold Leg Temperature (Wide Range) per loop E 24 months (T cold)

4. RCS Pressure (Wide Range) 2 E 24 months

5. Reactor Vessel Water Level 2 E 24 months

6. Containment Water Level (Wide Range) 2 E 24 months

7. Containment Water Level (Recirculation 2 E 24 months Sump)

8. Containment Pressure 2 E 18 months

9. Automatic Containment Isolation Valve 2 per penet rat 1 on fl ow F 24 months Position path{,) 101

10. Containment Area Radiation (High Range) 2 F 24 months

11. NOT USED

12. Pressurizer Level 2 24 months

13. SG Water Level (Narrow Range) 2 per SG 24 months

14. SG Water Level (Wide Range) and each per SG 24 months, SGL Auxiliary Feedwater Flow 18 months, AFF

15. NOT USED

16. Steam Generator Pressure 2 per SG E 24 months

17. Condensate Storage Tank Level 2 F 24 months

18. Core Exit Thermocouples-Quadrant 2 (c) E 24 months

19. Core Exit Thermocouples-Quadrant 2 2 (c) E 24 months

20. Core Exit Thennocouples-Quadrant 3 2 (c) E 24 months

21. Core Exit Thennocoupl es-Quadrant 4 2 {c) E 24 months

22. Main Steam Line Radiation per steam line F 24 months

23. Gross Failed Fuel Detector 2 F 24 months

24. RCS Subcooling Margin 2 E 24 months See NOTES, next page.

INDIAN POINT 3 3.3.3-4 Amendment 228 Revised by letter dated August 5, 2009

PAM Instrumentation 3.3.3 TABLE 3.3.3-1 (page 2 of 2)

Post Accident Monitoring Instrumentation NOTES:

(a) Not required for isolation valves whose associated penetration is isolated by at least one closed and deactivated *automatic valve, closed manual valve, blind flange, or check valve with flow through the valve secured.

(b) Only one position indication channel is required for penetration flow paths with only one installed control room indication channel.

(c) A channel consists of two core exit thermocouples (CETs).

\

u INDIAN POINT 3 3.3.3-5 Amendment 228

Remote Shutdown 3.3.4 3.3 INSTRUMENTATION 3.3.4 Remote Shutdown LCO 3.3.4 The Remote Shutdown Functions shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

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

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Restore required Function 30_days Functions inoperable. to OPERABLE status.

B. Required Action and 8.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND 8.2 Be in MODE4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months INDIAN POINT 3 3.3.4-1 Amendment 226

.,

Remote Shutdown 3.3.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.4.1 Perform CHANNEL CHECK for each required 31 days instrumentation channel that is normally energized.

SR 3.3.4.2 Verify each required control circuit and transfer 24 months switch is capable of performing the intended function.

SR 3.3.4.3 -------*-----------NOTE--------------*-----

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION for each required 24 months instrumentation channel.

INDIAN POINT 3 3.3.4-2 Arnendnent 205

LOP DG Start Instrumentation 3.3.5 3.3 INSTRUMENTATION 3.3.5 Loss of Power CLOP) Diesel Generator CDG) Start Instrumentation LCO 3.3.5 One channel per bus of the Undervoltage (480 V bus) Function and two channels per bus of the Degraded Voltage (480 V bus) Function shall be OPERABLE.

APPLICABILITY: HODES 1, 2, 3, and 4, When associated DG is required to be OPERABLE by LCO 3. 8. 2. "AC Sources - Shutdown."

ACTIONS

- - - - NOTE*********************************************

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIHE u A. One required channel of Undervoltage Function A.1 Restore channel to OPERABLE status.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable in one or more buses.

B. One channel of Degraded 8.1 Place channel in trip. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Voltage Function inoperable in one or more buses.

(continued)

INDIAN POINT 3 3.3.5-1 Amendment 205

LOP DG Start Instrumentation 3.3.5 ACTIONS (continued)

CONDmON REQUIRED ACTION COMPLETION TIME C. Required Action and associated C.1 Enter applicable Immediately Completion Time not met. Condition(s) and Required Action(s) for the associated DG made inoperable by LOP 00 Two channels of Degraded start instrumentation.

Voltage Function inoperable in one or more buses.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

~~------------~-----------N01'E-----~-------~---~~-~~--

Verification of setpoint not required 31 days SR 3.3.5.1 Perform T ADOT.

SR 3.3.5.2 Perform CHANNEL CALIBRATION with Allowable Value as follows:

a. Undervoltage (480 V bus) Relay Allowable 24months Value~ 200 V.

b. Degraded Voltage (480 V bus) Relay (Non-SI) 18 months Allowable Value~ 414 V with a time delay 5 45 seconds.

c. Degraded Voltage (480 V bus) Relay 18 months (Coincident SI) Allowable Value~ 414 V with a time delay S 10 seconds.

INDIAN POINT 3 3.3.5-2 Amendment 2 31

Containment Purge System and Pressure Relief Line Isolation Instrumentation 3.3.6 3.3 INSTRUMENTATION u 3.3.6 Containment Purge System and Pressure Relief Line Isolation Instrumentation LCO 3.3.6 The Containment purge System and Pressure Relief Line Isolation instrumentation for each Function in Table 3.3.6*1 shall be OPERABLE.

APPLICABILITY: HODES 1, 2, 3, and 4, During CORE ALTERATIONS, During movement of irradiated fuel assemblies within containment.

ACTIONS

- - - - NOTE*********************************************

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIHE A. One radiation monitoring A.l Restore the affected 7 days u channel inoperable. channel to OPERABLE status.

(continued)

INDIAN POINT 3 3.3.6*1 Amenanent 205

Containment Purge System and Pressure Relief Line Isolation Instrumentation 3.3.6 ACTIONS (continued) u CONDITION REQUIRED ACTION COMPLETION TIHE B. *********NOTE********* B.1 Enter applicable Irrmediately Only applicable in Conditions and Required HOOE 1, 2, 3, or 4. Actions of LCO 3.6.3, "Containment Isolation Valves," for containment One or more pressure pressure relief line relief line isolation isolation valves made Functions with one or inoperable by isolation more automatic actuation instrumentation.

trains inoperable .

.Two radiation monitoring channels inoperable.

Required Action and u associated Completion Time of Condition A not met.

(continued) u INDIAN POINT 3 3.3.6*2 Mencinent 205

Containment Purge System and Pressure Relief Line Isolation Instrumentation 3.3.6 ACTIONS (continued) u CONDITION REQUIRED ACTION COMPLETION TIME C. *********NOTE********* C.1 .Place and maintain Invnediately Only applicable during containment purge system CORE ALTERATIONS or supply and exhaust movement of irradiated valves in closed fuel assemblies within position.

containment.

One or more containment C.2 Enter applicable Immediately purge system isolation Conditions and Required Functions with one or Actions of LCO 3.9.3, more automatic actuation "Containment trains inoperable. Penetrations," for containment purge system supply and exhaust isolation valves made Two radiation monitoring inoperable by isolation channels inoperable. instrumentation.

u Required Action and associated Completion Time for Condition A not met.

u INDIAN POINT 3 3.3.6*3 lwenanent 205

Containment Purge System and Pressure Relief Line Isolation Inst~umentation 3.3.6 u SURVEILLANCE REQUIREHENTS

*~-------------NOTE--------------------------------------------

Refer to Table 3.3.6-1 to determine which SRs apply for each Containment Purge System and Pressure Relief Line Isolation Function.

SURVEILLANCE FREQUENCY SR 3.3.6.1 Perform CHANNEL CHECK. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SR 3.3.6.2 Perform ACTUATION LOGIC TEST. 31 days on a STAGGERED TEST BASIS SR 3.3.6.3 Perform COT. 92 days u SR 3.3.6.4 --------------------NOTE-----------------

Verification of setpoint is not required.

Perform TADOT. 24 months SR 3.3.6.5 Perform CHANNEL CALIBRATION. 24 months u

INDIAN POINT 3 3.3.6-4 lwenanent 205

Containment Purge System and Pressure Relief Line Isolation Instrumentation 3.3.6 Table 3.3.6*1 (page 1 of 1)

Containment Purge System and Pressure Relief line Isolation Instrl.lllentation FUNCTION REQUIRED SURVEILLANCE TRIP SETPOINT CHANNELS REQUIREHENTS

1. Automatic Actuation logic and 2 trains SR 3.3.6.2 NA Actuation Relays SR 3.3.6.4

2. Gaseous Radiation Monitor (R*l2) 1 SR 3.3.6.1 (b)

SR 3.3.6.3 SR 3.3.6.5

3. Particulate Radiation Monitor 1 SR 3.3.6.1 (b)

CR*ll) SR 3.3.6.3 SR 3.3.6.5

4. ESFAS Function 1. Safety Injection. Refer to LCO 3.3.2. ESFAS Instrl.lllentation, Functions 1 and 2.

and ESFAS Function 2. Containment for all initiation functions and requirements.

Spr11y Ca) u Ca)

Cb)

Only required in HCX>ES 1. 2. 3 and 4 as specified in LCO 3.3.2.

As specified in the IP3 Offsite Dose Calculation H11nua1:

.\_..I INDIAN POINT 3 3.3.6*5 Amenanent 205

CRVS Actuation Instrumentation 3.3.7 3.3 INSTRUMENTATION 3.3.7 Control Room Ventilation System (CRVS) Actuation Instrumentation LCO 3.3.7 The CRVS actuation instrumentation for each Function in Table 3.3.7-1 shall be OPERABLE.

APPLICABILITY: MODES l, 2, 3, 4 ACTIONS

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

Separate Condition entry is allowed for each Function.

COMPLETION REQUIRED ACTION TIME CONDITION A. One or more A. l Place CRVS in CRVS 7 days Functions with one Mode 3.

channel or train inoperable.

B. One or more B .1.1 Place CRVS in CRVS 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Functions with two Mode 3.

channels or two trains inoperable.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time for AND

- -

Condition A or B not ----- NOTE --------

met. LCO 3.0.4.a is not applicable when entering MODE 4.

C.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months INDIAN POINT 3 3.3.7 - 1 Amendment 252

CRVS Actuation Instrumentation 3.3.7 u SURVEILLANCE REQUIREMENTS

- - - - NOTE*********************************************

Refer to Table 3.3.7-1 to determine which SRs apply for each CRVS Actuation Function.

SURVEILLANCE FREQUENCY SR 3.3.7.1 Perform actuation logic test 31 days staggered test basis

SR 3.3. 7.2 **********************NOTE*********************

Verification of setpoint is not required.

Perform TADOT. 24 months INDIAN POINT 3 3.3.7*2 Menanent 205

CRVS Actuation Instrumentation 3.3.7 u Table 3.3.7*1 (page 1 of 1)

CRVS Actuation Instr1.111entation sm.VEILL.ANCE FUNCTION REQUIRED CHANNELS REQUIREMENTS TRIP SETPOINT

1. Hanual Initiation 2 SR 3.3.7.2 NA

2. Automatic Actuation Logic and 2 trains SR 3.3.7.1 NA Actuation Relays

3. Safety Injection Refer to LCO 3.3.2. *EsFAS Instr1.111entation.* Function 1. for all initiation functions and requirements.

u INDIAN POINT 3 3.3.7*3 Mlenanent 205

FSBEVS Action Instrumentation 3.3.8 V 3.3 INSTRUMENTATION 3.3.8 Fuel Storage Building Emergency Ventilation System (FSBEVS) Actuation Instrumentation LCO 3.3.8 FSBEVS manual and automatic actuation instrumentation shall be OPERABLE.

APPLICABILITY: During movement of recently irradiated fuel in the fuel storage building.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A Manual or automatic A.1 Place FSBEVS in Immediately FSBEVS actuation operation.

instrumentation inoperable.

OR V A.2 Suspend movement of recently irradiated fuel in Immediately the fuel storage building.

u INDIAN POINT 3 3.3.8-1 Amendment 215 MAR 17 2003

FSBEVS Actuation Instrumentation 3.3.8

~ SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.8.1 Perform CHANNEL CHECK. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SR 3.3.8.2 Perform COT. 92 days SR 3.3.8.3 Perform CHANNEL CALIBRATION. 24 months INDIAN POINT 3 3.3.8*2 Amendment 205

RCS Pressure, Temperature, and Flow Limits 3.4.1 u 3.4 3.4.1 REACTOR COOLANT SYSTEM (RCS)

RCS ~ressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits LCO 3.4.1 RCS DNB parameters for pressurizer pressure, RCS average temperature, and RCS total flow rate shall be within the

.limits specified below:

a. Pressurizer pressure is greater than or equal to the limit specified in the COLR;

b. RCS average loop temperature is less than or equal to the limit specified in the COLR; and

c. RCS total flow rate~ 354,400 gpm and greater than or equal to the limit specified in the COLR.

APPLICABILITY: MODE.l.

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

Pressurizer pressure limit does not apply during:

a. THERMAL POWER ramp> 5% RTP per minute; or

b. THERMAL POWER step> 10% RTP.

u ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more RCS A.l Restore.RCS DNB 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months DNB parameters not parameter(s) to within limits. within limits.

B. Required action and B. l Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

u INDIAN POINT 3 3.4.1-1 Amendment 225

RCS Pressure, Temperature, and Flow Limits 3.4.1 u SURVEILLANCE REQUIREMENTS

,.. .

SURVEILLANCE FREQUENCY SR 3.4.1.1 Verify pressurizer pressure is greater 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months than or equal to the limit specified in the COLR.

SR 3.4.1.2 Verify RCS average loop temperature is 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months less than *or equal to the limit specified in the COLR.

SR 3.4.1.3 Verify RCS total flow rate is 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

~ 354,400 gpm and greater than or equal to the limit specified in the COLR.

SR 3. 4 .1. 4 -------------------NOTE----------------

Not required to be performed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after~ 90% RTP.

u Verify by precision heat balance that RCS total flow rate is~ 354,400 gprn and greater than or equal to the limit 24 months specified in the COLR.

u INDIAN POINT 3 3.4.1-2 Amendment 225

RCS Minimum Temperature for Criticality 3.4.2 u 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.2 RCS Hinimum Temperature for Criticality LCO 3.4.2 Each RCS loop average temperature CTavg> shall be 2: 540°F.

APPLICABILITY: HOOE 1, MODE 2 with kett 2: 1. 0.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TI HE A. Tavg in one or more A.1 Be in HODE 2 with 30 minutes RCS loops not within kett < 1.0.

limit.

u SURVEILLANCE REQUIREHENTS SURVEILLANCE FREQUENCY SR 3.4.2.1 Verify RCS Tavg in each loop 2: 540°F. -----NOTE------

Only required if Tavg - Tref deviation, and low Tavg alarm not reset and any RCS loop Tavg < 547°F 30 minutes thereafter INDIAN POINT 3 3.4.2-1 Amendment 205

RCS P/T Limits 3.4.3 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.3 RCS Pressure and Temperature (PIT) Limits LCO 3.4.3 RCS pressure, RCS temperature, and RCS heatup and cooldown rates shall be maintained within the limits specified in Figure 3.4.3-1 and Figure 3.4.3-2.

APPLICABILITY: At all times.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ---------NOTE--------- A.1 Restore parameter(s) to 30 minutes Required Action A.2 shall within limits.

be completed whenever this Condition is entered. AND

A.2 Determine RCS is 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Requirements of LCO not acceptable for continued met in MODE 1, 2, 3, or operation.

4.

B. Required Action and 8.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not AND met.

8.2 Be in MODE 5 with RCS 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months pressure< 500 psig.

(continued)

INDIAN POINT 3 3.4.3-1 Amendment 258

RCS P/T Limits 3.4.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. ---------NOTE---------------- C.1 Initiate action to restore Immediately Required Action C.2 shall parameter(s) be completed whenever to within limits.

this Condition is entered.

AND Requirements of LCO not C.2 Determine RCS is Prior to met any time in other acceptable for continued entering MODE 4 than MODE 1, 2, 3, or 4. operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.3.1 -------------------NOTE--------------

Only required to be performed during RCS heatup, inservice leak testing, and cooldown operations.

Verify RCS pressure, RCS temperature, and RCS 30 minutes heatup and cooldown rates are within the limits specified in the following:

a. Figure 3.4.3-1 during RCS heatup and during RCS inservice leak testing; and

b. Figure 3.4.3-2 during RCS cooldown.

INDIAN POINT 3 3.4.3-2 Amendment 258

RCS P/T Limits 3.4.3 MATERIAL PROPERTY BASIS LIMITING MATERIAL: Lower Shell Plate B-2803-3 using credible surveillance data, Position 2.1 LIMITING ART VALUES AT 37 EFPY: 1/4T, 245.0°F (Axial Flaw) 3/4T, 198.2°F (Axial Flaw)

I t-+

-

ct VJ 2250 jLeak Test Limit

-

C.

! 2000

s Acceptable Operation U)

U)

!

C.

E 1750

~

U)

>.

VJ

! 1500 0

0 0

...

~ 1250 ns

~

1000 750 500 250 0 50 100 150 200 250 300 350 400 450 500 550 Tcold Temperature (Deg. F)

Figure 3.4.3-1:

Heatup and lnservice Leak Test Limitations for Reactor Coolant System (Without instrument uncertainties)

INDIAN POINT 3 3.4.3-3 Amendment 258

RCS P/T Limits 3.4.3 MATERIAL PROPERTY BASIS LIMITING MATERIAL: Lower Shell Plate B-2803-3 using credible surveillance data, Position 2.1 LIMITING ART VALUES AT 37 EFPY: 1/4T, 245.0°F (Axial Flaw) 3/4T, 198.2°F (Axial Flaw) 2250

<2000 en

-:5 a.

Q) 1750 Unacceptable Acceptable Ill Operation Ill Operation

~

a.

~ 1500

-I ll

>,

-

en

1250 0

0

(.)

...0 ucu 1000 Q) 0:::

750 ates eg. F/Hr teady -state 500 20 0

60 100 250 0 50 100 150 200 250 300 350 400 450 500 550 T cold Temperature (Deg. F)

Figure 3.4.3-2:

Cooldown Limitations for Reactor Coolant System (Without instrument uncertainties)

INDIAN POINT 3 3.4.3-4 Amendment 258

RCS Loops - HODES 1 and 2 3.4.4 u 3.4 REACTOR COOL.ANT SYSTEH (RCS) 3.4.4 RCS Loops - HODES 1 and 2 LCO 3.4.4 Four RCS loops shall be OPERABLE and in operation.

APPLICABILITY: HODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIHE A. Req*ui rements of LCO not A.1 Be in HODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months met.*

V SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.4.1 Verify each RCS loop is in-operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ,

INDIAN POINT 3 3.4.4-1 Amenanent 205

RCS Loops - HOOE 3 3.4.5 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.5 RCS Loops-HOOE 3 LCO 3.4.5 Two RCS loops shall be OPERABLE, and either:

a. Two RCS loops shall be in operation when the Rod Control System is capable of rod withdrawal: or

b. One RCS loop shall be in operation when the Rod Control System is not capable of rod withdrawal.

* * * * * * -* * * * * * ** * * * * * * * ~ * * * * -NOTE* * * * * * * * * * -* * * * * * * * * * -* * * * * * * * * * *

All reactor coolant pumps may not be in operation for~ 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period provided:

a. No operations are permitted that would cause reduction'of the RCS boron concentration: and

b. Core outlet temperature is maintained at least l0°F below saturation temperature.

u APPLICABILITY: HOOE 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TI HE A. One required RCS loop A.1 Restore required RCS 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. loop to OPERABLE status.

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

(continued)

INDIAN POINT 3 3A.5*1 Amenanent 205

RCS Loops - HOOE 3 3.4.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIHE C. One required RCS loop C.1 Restore required RCS 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months not in operation, and loop to operation.

reactor trip breakers closed and Rod Control 08 System capable of rod withdrawal. C.2 De-energize all control 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months rod drive mechanisms (CRDHs).

~

D. Two required RCS loops D.1 De-energize all CRDMs. IRV11edi ate1y inoperable.

AfiQ 08 D.2 Suspend all operations Immediately No RCS loop in operation. involving a reduction of RCS boron concentration .

.

u AfiQ D.3 Initiate action to restore one RCS loop to Immediately OPERABLE status and in operation.

u INDIAN POINT 3 3.4.5-2 Amenonent 205

RCS Loops - HOOE 3 3.4.5 SURVEILLANCE REQUIREHENTS SURVEILLANCE FREQUENCY SR 3.4.5.1 Verify required RCS loops are in operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.5.2 Verify steam generator secondary side actual 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months water levels are~ 71~ wide range for required RCS loops.

SR 3.4.5.3 Verify correct breaker alignment and indicated 7 days power are available to the required pump that is not in operation.

u INDIAN POINT 3 3.4.5*3 Amenanent 205

RCS Loops - HOOE 4 3.4.6 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4. 6 RCS Loops - HOOE 4 LCO 3.4.6 Two loops consisting of any combination of RCS loops and residual heat removal CRHR) loops shall be OPERABLE. and one loop shall be in operation.

*---------------------*- NOTES*--------*------*----*--------

1. All reactor coolant pumps (RCPs) and RHR pumps may not be in operation for~ 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period provided:

a. No operat~ons are permitted that would cause reduction of the RCS boron concentration: and

b. Core outlet temperature is maintained at least l0°F below saturation temperature.

2. No RCP shall be started with any RCS cold leg temperature less than the LTOP arming temperature unless the requirements of LCO 3.4.12, -Low Temperature Overpressure Protection CLTOP)." are met. '

u APPLICABILITY: HODE 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIHE A. One required RCS loop A.1 Initiate action to Inrnediately inoperable. restore a second loop to OPERABLE status.

Two RHR loops inoperable.

(continued) u INDIAN POINT 3 3.4.6-1 Amendnent 205

RCS Loops - HOOE 4 3.4.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COHPLETION TIHE B. One required RHR*loop B.1 Be in HOOE 5. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months inoperable.

MlQ Two required RCS loops inoperable.

C. Required RCS or RHR loops C.1 Suspend all operations Invnediately inoperable. involving a reduction of RCS boron concentration.

QR MlQ No RCS or RHR loop in operation. C.2 Initiate action to Invnediately restore one loop to OPERABLE status and in u operation.

INDIAN POINT 3 3.4.6*2 Amenanent 205

RCS Loops - HOOE 4 3.4.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 Verify one RHR or RCS loop is in operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.6.2 Verify SG secondary side water actual level is 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

~ 71X wide range for each required RCS loop.

SR 3.4.6.3 Verify correct breaker alignment and indicated 7 days power are available to the required pump that is not in operation.

u INDIAN POINT 3 3.4.6*3 Amenctnent 205

RCS Loops - Mode 5, Loops Filled 3.4.7 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.7 RCS Loops-MODE 5, Loops Filled LCO 3.4.7 One residual heat removal (RHR) loop shall be OPERABLE and in operation, and either:

a. One additional RHR loop shall be OPERABLE; or

b. The secondary side water level of at least two steam generators (SGs) shall be~ 71% wide range.

~------------- NOTES---------------------------------

1. The RHR pump of the 1oop in operation may not be in ope rat: ion for~ I hour per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period provided:

a. No operations are permitted that would cause reduction of the RCS boron concentration; and

b. Core outlet temperature is maintained at least I0°F below saturation temperature.

2. One required RHR loop may be inoperable for up to. 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing provided that the other RHR loop is OPERABLE and in operation.

3. No reactor coolant pump shall be started with the average of the RCS cold leg temperatures~ 330°F unless the requirements of LCO 3.4.12, "Low Temperature Overpressure Protection (LTOP)," are met.

4. All RHR loops may be removed from operation during planned heatup to MODE 4 when at least on~ RCS loop is in operation.

APPLICABILITY: MODE 5 with RCS loops filled.

INDIAN POINT 3 3.4.7-1 Amendment 235

RCS Loops - HOOE 5, Loops Fi 11 ed 3.4. 7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR loop inoperable. A.1 Initiate action to I11111ediately restore a second RHR AHO loop to OPERABLE status.

Required SGs secondary Q8 side water level not within the limit. A.2 Initiate action to I11111ediately restore required SG secondary side water level to within the limit.

B. Required RHR loops B.1 Suspend all operations I11111ediately inoperable. involving a reduction of RCS boron concentration.

Q8 u No RHR loop in operation.

MfQ B.2 Initiate action to I11111ediately restore one RHR loop to OPERABLE .status and in operation.

u INDIAN POINT 3 3.4. 7*2 Amenctnent 205

RCS Loops - HOOE 5, Loops Fi 11 ed 3.4.7 SURVEILLANCE REQUIREHENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 Verify one RHR loop is in operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.7.2 Verify SG secondary side water level is~ 71% 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months wide range in required SGs.

SR 3.4.7.3 Verify correct breaker alignment and indicated 7 days power are available to the required RHR pump that is not in operation.

u u

INDIAN POINT 3 3.4.7-3 Amenanent 205

RCS Loops - HOOE 5, Loops Not Fi 11 ed 3.4.8 u 3.4 REACTOR COOLANT SYSTEH (RCS) 3 .4. 8 RCS Loops - HOOE 5, Loops Not Fi 11 ed LCO 3.4.8 Two residual heat removal CRHR) loops shall be OPERABLE and one RHR loop shall be in operation.

- - - - NOTES******************************

1. All RHR pumps may not be in operation for s 15 minutes provided:

a. The core outlet temperature is maintained at least l0°F below saturation temperature.

b. No operations are permitted that would cause a reduction of the RCS boron concentration: and

c. No draining operations to further reduce the RCS water volume are permitted.

2. One RHR loop may be inoperable for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing provided that the other RHR loop is OPERABLE and in operation.

u APPLICABILITY: HOOE 5 with RCS loops not filled.

ACTIONS CONDITION REQUIRED ACTION COHPLETION TI HE A. One RHR loop inoperable. A.1 Initiate action to IIIITlediately restore RHR loop to OPERABLE status.

(continued)

INDIAN POINT 3 3.4.8-1 Amenanent 205

RCS Loops - HOOE 5, Loops Not Fi 11 ed 3.4.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIHE B. Required RHR loops B.1 Suspend all operations Invnedi ately inoperable. involving.reduction in RCS boron concentration.

OR AfiQ No RHR loop in operation.

B.2 Initiate action to Invnediately restore one RHR loop to OPERABLE status and in operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one RHR loop is in operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.8.2 Verify correct breaker alignment and indicated 7 days power are available to the required RHR pump that is not in operation.

INDIAN POINT 3 3.4.8*2 Amencknent 205

Pressurizer 3.4.9 3.4 REACTOR COOLANT SYSTEM (RCS}

u 3.4.9 Pressurizer LCO 3.4.9 The pressurizer shall be OPERABLE with:

a. Pressurizer water level~ 54.3% in MODES 1 and 2 or< 90% in MODE 3; and

b. Two groups of pressurizer heaters OPERABLE with the capacity of.each group~ 150 kW and capable of being powered from an emergency power supply.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Pressurizer water A.1 Be in MODE 3 with 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months level not within reactor trip limit. breakers open.

u .. ANO

--

A.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months B. One required group B.1 Restore required 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months of pressurizer group of heaters inoperable. pressurizer heaters to OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of AND Condition B not met. C.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months u INDIAN POINT 3 3.4.9-1 Amendment 225

Pressurizer 3.4.9 u SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify pressurizer water level is 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

~ 54.3% in MODES 1 and 2 OR< 90% in MODE 3.

SR 3.4.9.2 Verify capacity of each required group 24 months of pressurizer heaters is~ 150 kW.

u INDIAN POINT 3 3.4.9-2 Amendment 225

Pressurizer Safety Valves 3 .4.10 3.4 REACTOR COOLANT SYSTEM (RCS)

.3.4.10 Pressurizer Safety Valves LCO 3.4.10 Three pressurizer safety valves shall be OPERABLE with lift settings set~ 2460 psig and~ 2510 psig.

APP LI CAB I LI TY: MODES 1, 2, and 3, MODE 4 with all RCS cold leg temperatures> 330°F.

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

The lift settings are not required to'be within the LCO limits during MODES 3 and 4 for the purpose of setting the pressurizer safety valves under ambient (hot) conditions. This exception is allowed for 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months following entry into MODE 3 provided? preliminary cold setting was made prior to heatup.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME

.*:

A. One pressurizer safety A. l Restore valve to 15 minutes valve inoperable. OPERABLE status.

B. Required Action and B. l Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND OR B.2 Be in MODE 4 with any 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months RCS cold leg Two or more pressurizer temperature~ 330°F.

safety valves inoperable.

INDIAN POINT 3 3.4.10-1 Amendment 235

Pressurizer Safety Valves 3.4.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.10.1 Verify each pressurizer safety valve is OPERABLE In accordance in accordance with the Inservice Testing Program. with the Following testing, lift settings shall be~ 2460 Inservice Testing psig and~ 2510 psig. Program u

INDIAN POINT 3 3.4.10*2 Amencinent 205

Pressurizer PORVs 3.4.11 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.11 Pressurizer Power Operated Relief Valves (PORVs)

LCO 3. 4 .11 Each PORV and associated block valve shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

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

Separate Condition entry is allowed for each PORV.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more PORVs A.1 Close and maintain 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable and power to capable of being associated block manually cycled. valve.

u B. One PORV inoperable B.l Close associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and not capable of block valve.

being manually cycled. AND

--

B.2 Remove power from 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated block valve.

AND

--

B.3 Restore PORV to 7 days OPERABLE status.

(continued)

INDIAN POINT 3 3.4.11-1 Amendment 226

.,

Pressurizer PORVs 3.4.11 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TI HE C. One block valve C.1 Place associated PORV in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. manual control.

MID C.2 Restore block valve to 7 days OPERABLE status.

D. Required Action and D.1 Be in HOOE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A. B, MID or C not met.

D.2 Be in HOOE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months E. Two PORVs inoperable and E.1 Close associated block 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months not capable of being valves.

manually cycled.

MID E.2 Remo_ve power from 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated block valves.

MID E.3 Be in HOOE 3.*. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months MID E.4 Be in HOOE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued) u INDIAfl POINT 3 3.4.11-2 Arnenanent 205

Pressurizer PORVs 3.4.11 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. Hore than one block valve F.1 Place associated PORVs 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. in manual control.

MID F.2 Restore one block valve 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to OPERABLE status.

G. Required Action and G.1 Be in HOOE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition F not MID met.

G.2 Be in HOOE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 * * * * * * * * * * **.*******NOTE********************

Not required to be met with block valve closed in accordance with the Required Action of Condition B or E.

Perform a complete cycle of each block valve. 92 days SR 3.4.11.2 Perform a complete cycle of each PORV. 24 months INDIAN POINT 3 3.4.11*3

Amencinent 205

LTOP 3.4.12 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12 Low Temperature Overpressure Protection (LTOP)

LCO 3.4.12 LTOP shall be OPERABLE with no high head safety injection (HHSI) pumps capable of injecting into the RCS and the accumulator discharge isolation valves closed and de-energized, and either of the following:

--~-----------------------------Note--------------------

LCO 3.4.12.a and LCO 3.4.12.b are not Applicable when all RCS cold leg temperatures are > 330°F.

a. The Overpressure Protection System (OPS) OPERABLE with two power operated relief valves (PORVs) with lift settings within the limit specified in Figure 3.4.12-1; OR

b. The RCS depressurized with an RCS vent of~ 2.00 square inches, or one blocked open PORV with its block valve disabled in the open position.

~-------------~--------NOTES-----------------------

1. Accumulator isolation is only required when accumulator pressure is greater than or equal to the maximum RCS pressure for the coldest existing RCS cold leg temperature allowed by the Prr limit curve in Figure 3.4.12-1.

2. One HHSI pump may be made capable of injecting into the RCS as needed to support emergency boration or to respond to a loss of RHR cooling.

3. One HHSI pump may be made capable of injecting into the RCS for pump testing for a period not to exceed 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

APPLICABILITY: Whenever the RHR System is not isolated from the RCS, MODE 4 when any RCS cold leg temperature is s 330°F, MODE 5, MODE 6 when the reactor vessel head is on.

INDIAN POINT 3 3.4.12 1 Amendment 258

LTOP 3.4.12 ACTIONS

NOTE:--------------------------------------------

LCO 3.0.4.b is not applicable when entering MODE: 4.

CONDITION RE:QUIRE:D ACTION COMPLE:TION TIME:

A. One or more HHSI A.1 Initiate action to verify no Immediately pump(s) capable of HHSI pumps are injecting into the RCS. capable of injecting into the RCS.

OR A.2.1 Verify RCS is vented Immediately with opening greater than or equal to one pressurizer code safety valve flange.

AND A.2.2 Verify no more than two Immediately HHSI pumps are capable of injecting into AND the RCS Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

INDIAN POINT 3 3.4.12-2 Amendment 258

LTOP

3. 4 .12 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

8. .An accumulator B.1 Close and de-energize 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months discharge isolation isolation valve for valve not closed and affected accumulator.

de-energized when the accumulator pressure is greater than or equal to the maximum RCS pressure for the coldest existing cold '

leg temperature specified in Figure 3.4.12-1.

C. Required Action and C.1.1 Increase all RCS cold 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion leg temperatures to Time of Condition B not > 330°F.

met.

AND c.1.2 Isolate the RHR System 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months from the RCS.

OR C.2 Depressurize affected 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months e

accumulator to less than the maximum RCS pressure for coldest existing cold leg temperature specified in Figure 3.4.12-1.

D. One required PORV D.l Restore required PORV 7 days inoperable. to OPERABLE status.

(continued)

I ND IAN PO INT 3 3.4.12-3 Amendment 235

LTOP 3.4.12 A CTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Two required PORVs E.1 Depressurize RCS and 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months inoperable. establish RCS vent of

2.00 square inches, or OR one blocked open PORV with its block valve Required Action and disabled in the open associated Completion position.

Time of Condition C or D not met. OR E.2.1 Increase all RCS cold 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months leg temperatures to

> 330°F.

AND E.2.2 Isolate the RHR System 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months from the RCS.

OR E.3 Verify pressurizer level, 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months RCS pressure, and RCS injection capability are AND within limits specified in Figure 3.4.12-2 and Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Figure 3.4.12-3 for OPS thereafter not OPERABLE.

F. LTOP inoperable for any F.1 Depressurize RCS and 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months reason other than establish RCS vent of Condition A, B, C, D, or ::::: 2.00 square inches, or E. one blocked open PORV with its block valve disabled in the open position.

INDIAN POINT 3 3.4.12-4 Amendment 258

LTOP 3.4.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Verify no HHSI pumps are capable of injecting into 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months the RCS.

SR 3.4.12.2 Verify each accumulator discharge isolation valve is 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months closed and de-energized; OR Verify each accumulator pressure is less than the 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months maximum RCS pressure for the coldest existing RCS cold leg temperature allowed by the Prr limit curve in Figure 3.4.12-1.

SR 3.4.12.3 -------------------NOTE-----------------------------~------~-

Only required to be met when complying with LCO 3.4.12.b.

Verify RCS vent 2 2.00 square inches, or one blocked 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for open PORV with its block valve disabled in the open unlocked open position established. vent valve(s) 31 days for locked open vent valve( s)

(continued)

INDIAN POINT 3 3.4.12-5 Amendment 258

LTOP 3 .4.12 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.12.4 -----------------NOTE--.-----------------

Only required to be met when complying with LCO 3.4.12.a.

Perform CHANNEL CHECK of Overpressure 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Protection (OPS) instrument channels.

SR 3.4.12.5 Verify PORV block valve is open for each 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months required PORV.

SR 3.4.12.6 --------------------NOTE------------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after decreasing any RCS cold leg temperature to

330°F.

Perform a COT on each required PORV, excluding* 24 months actuation.

SR 3.4.12.7 Perform CHANNEL CALIBRATION for each required OPS channel as follows:

a. OPS actuation channels; and 18 months

b. RCS pressure and temperature instruments. 24 months (continued)

INDIAN POINT 3 3.4.12-6 Amendment 235

LTOP

3. 4.12 SURVEILLANCE REQUIREMENTS (continued}

SURVEILLANCE FREQUENCY SR 3.4.12.8 --------------------NOTES----------------------

1. Not required to be met when all RCS cold leg temperatures are> 330°F.

2. Not required to be met if SR 3.4.12.9 is met.

Verify each of the following conditions are Within 15 satisfied prior to starting any RCP: minutes prior to starting any RCP

a. Secondary side water temperature of the hottest steam generator (SG) is less than or equal to the coldest RCS cold leg temperature; and

b. RCS makeup is less than or equal to RCS 1osses; and

c. Steam generator pressure is not decreasing; and d.l Overpressure Protection System (OPS) is OPERABLE; d.2~1 RCS pressure less than nominal OPS setpoint specified in Figure 3.4.12-1; and d.2.2 Pressurizer level, RCS pressure, and RCS injection capability are within limits specified in Figure 3.4.12-2 and Figure 3.4.12-3 for OPS not OPERABLE.

(continued)

INDIAN POINT 3 3.4.12-7 Amendment 235

SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.4.12.9 ------------------NO TES----------------

1. Not required to be met when all RCS cold leg temperatures are> 330°F.

2. Not required to be met if SR 3.4.12.8 is met.

Verify each of the following conditions are satisfied Within 15 minutes prior to starting any RCP: prior to starting any RCP

a. Secondary side water temperature of the hottest steam generator is ::;; 50°F above the coldest RCS cold leg temperature; and

b. RCS makeup is less than or equal to RCS losses; and

c. Overpressure Protection System (OPS) is OPERABLE; and

d. Pressurizer level is ::;; 73%.

Indian Point 3 3.4.12-8 Amendment 258

LTOP 3.4.12 800 750

""Q.

' 700

.5

~

.,

r.

~ 650

-

'""

..

.,

1600

-=

<.....

E 550 X

1

~

500 450

50 100 150 200 250 300 350 0

Auctioneered Low Indicated RCS Temperature ( F)

Figure 3.4.12-1: Maximum Allowable PORV Setpoint for LTOP (OPS), 37 EFPY INDIAN POINT 3 3.4.12-9 Amendment 258

LTOP 3.4.12 100 90

i 80

!-,

300 psig 1>

70

]

...

Cl s 400 psig 60

~:,

.

Cl

!::..

50 s 450psig

.S!

i~ 40 0

i

<,< 30

~

20

'

JO 0

0 50 100 150 200 250 300 350 400 Indicated Tcold (0 F) 3.4.12-2: Maximum Allowable Pres zer Level for LTOPS Inoperable with 1 Charging Pump Capable of Injecting, 37 EFPY INDIAN POINT 3 3.4.12-10 Amendment 258

LTOP 3.4.12 90 l:nacceptable so

Operation s 100 psig s 200 psig 10 0

0 50 100 150 200 250 300 350 400 Indicated Tcold (°f)

Figure 3.4.12-3: Maximum Allowable Pressurizer Level for LTOPS Inoperable with 3 Charging Pumps Capable of Injecting, 37 EFPY INDIAN POINT 3 3.4.12-11 Amendment 258

RCS Operational Leakage 3.4.13 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.13 RCS Operational LEAKAGE LCO 3.4.13 RCS operational LEAKAGE shall be limited to:

a. No pressure boundary LEAKAGE;

b. 1 gpm unidentified LEAKAGE;

c. 10 gpm identified LEAKAGE; and

d. 150 gallons per day primary to secondary LEAKAGE through any one steam generator (SG).

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RCS operational A.1 Reduce LEAKAGE to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months LEAKAGE not within within limits.

limits for reasons other than pressure boundary LEAKAGE or primary to secondary LEAKAGE.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of AND Condition A not ----- NOTE -------

met. LCO 3.0.4.a is not applicable when OR entering MODE 4.

Pressure boundary LEAKAGE exists. B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months OR Primary to secondary LEAKAGE not within limit.

INDIAN POINT 3 3.4.13-1 Amendment 252

RCS Operational Leakage 3.4.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.13.1 -------------------NOTES---------------------- -----NOTE----

1. Not required to be performed in MODE 3 or 4 Only required to until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months of steady state operation. be performed during steady

2. Not applicable to primary to secondary state operation LEAKAGE.

Verify RCS Operational LEAKAGE is within limits 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months by performance of RCS water inventory balance.

SR 3.4.13.2 -------------------NOTE-----------------------

Not required to be performed unti 1 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after establishment of steady state operation.

Verify primary to secondary LEAKAGE is< 150 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months gallons per day through any one SG.

INDIAN POINT 3 3.4.13-2 Amendment 233

\

RCS PIV Leakage 3.4.14 3.4 REACTOR COOLANT SYSTEH (RCS) 3.4.14 RCS Pressure Isolation Valve CPIV) Leakage LCO 3.4.14 Leakage from each RCS PIV shall be within limit:

The RHR System autoclosure interlocks CACI) and open permissive interlocks COPI) shall be OPERABLE.

APPLICABILITY: HODES 1, 2, and 3, HOOE 4, except for leakage limits for valves in the residual heat removal CRHR) flow path when in, or during the transition to or from.

the RHR mode of operation ..

ACTIONS

- - - - NOTES***************************************

1. Separate Condition entry is allowed for each flow path.

u 2. Separate Condition entry is allowed for each ACI and OPI.

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

CONDITION REQUIRED ACTION COMPLETION TI HE A. One or more flow paths **************NOTE**************

with leakage from one or Each valve used to satisfy more RCS PIVs not within Required Action A.1 and Required limit. Action A.2 must have been verified to meet SR 3.4.14.1 and be in the reactor coolant pressure boundary or the high pressure portion of the system.

(continued) u INDIAN POINT 3 3.4.14*1 Amenanent 205

RCS PIV 3.4.14 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.1 Isolate the high 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months pressure portion of the affected system from the low pressure portion by use of one closed manual, deactivated automatic, or check valve.

AND

- -

A.2.1 Isolate the high 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months pressure portion of the affected system from the low-pressure portion by use of a second closed manual, deactivated automatic, or check valve.

OR A.2.2 Restore RCS PIV to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months within limits.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time for AND

- -

Condition A not ----- NOTE ------

met. LCO 3.0.4.a is not applicable when entering MODE 4.

----

B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

INDIAN POINT 3 3.4.14-2 Amendment 252

*---*

RCS PIV Leakage 3.4.14 ACTIONS (continued) u CONDITION REQUIRED ACT! ON COMPLETION TI HE C. One or more RHR System **************NOTE**************

autoclosure interlocks or RHR System suction isolation open permissive valves with inoperable ACis or interlocks inoperable. OPis may be opened for 7 days following entry into MODE 4 from MODE 3.

C.1 Close and de-activate 7 days the affected RHR isolation valve.

MID C.2 Verify the affected RHR Once per 31 days isolation valves are thereafter closed and de-activated.

u

\__) .

INDIAN POINT 3 3.4.14*3 Amenanent 205

RCS PIV Leakage 3.4.14

SURVEILLANCE REQUIREMENTS u SURVEILLANCE FREQUENCY SR 3.4.14.1 ----------*------**NOTES------*--------------

1. Not required to be performed in HODES 3 and 4.

2. Not required to be performed on the RCS PIVs located in the RHR flow path when in the shutdown cooling mode of operation.

3. RCS PIVs actuated during the performance of this Surveillance are not required to be tested more than once if a repetitive testing loop cannot be avoided.

Verify leakage from each RCS PIV is equivalent to 24 months

~ 0.5 gpm per nominal inch of valve size up to a maximum of 5 gpm at an RCS pressure~ 2215 psig and~ 2255 *psig.

Prior to entering HOOE 2 whenever the unit has been in HOOE 5 for 7 days or more.

if leakage testing has not been performed in the previous 12 months Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months following valve actuation due to*

automatic or manual action or flow through the valve (continued)

INDIAN POINT 3 3.4.14-4 Amendnent 205

RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.14.2 Verify RHR System open permissive interlock 24 months prevents the valves from being opened with a simulated or actual RCS pressure signal

i: 450 psig.

SR 3.4.14.3 Verify RHR System autoclosure interlock causes 24 months the valves to close automatically with a simulated or actual RCS pressure signal

i: 550 psig.

u INDIAN POINT 3 3.4.14*5 Amenanent 205

RCS Leakage Detection Instrumentation 3.4.15 u 3.4 3.4.15 REACTOR COOLANT SYSTEM (RCS)

RCS Leakage Detection Instrumentation LCO 3.4.15 The following RCS leakage detection instrumentation shall be OPERABLE:

a. One containment sump discharge flow monitor;

b. One containment atmosphere radioactivity monitor (gaseous or particulate); and

c. One containment fan cooler unit condensate measuring system.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required A. l Perform SR Once per 24 containment sump 3.4.13.1. hours flow monitor inoperable. AND A.2 Restore required 30 days containment sump monitor to OPERABLE status.

(continued)

INDIAN POINT 3 3.4.15-1 Amendment 226

., t - .--.,

RCS Leakage Detection Instrumentation 3.4.15 ACTIONS (continued)

CONDITION REQUIRED ACTION CO HP LET ION TI HE B. Required containment B.1.1 Analyze grab samples of Once per atmosphere radioactivity the containment 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months monitor inoperable. atmosphere.

DR B.1.2 Perform SR 3.4.13.1. Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months AHO B.2.1 Restore required 30 days

, containment atmosphere radioactivity monitor to OPERABLE status.

u B.2.2 DR Verify containment 30 days fan cooler unit condensate measuring system is OPERABLE.

C. Required containment C.l Perform SR 3.4.15.1. Once per fan cooler unit 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months condensate measuring DR system inoperable. C.2 Perform SR 3.4.13.1. Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (continued)

INDIAN POINT 3 3.4.15*2 Amenanent 205

RCS Leakage Detection Instrumentation 3.4.15 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required containment D.1 Restore required 30 days atmosphere containment radioactivity monitor atmosphere inoperable. radioactivity monitor to AND OPERABLE status.

Required containment OR fan cooler unit condensate measuring D.2 Restore required 30 days system containment fan inoperable. cooler unit condensate measuring system to OPERABLE status.

E. Required Action and E.l Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND

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

LCO 3.0.4.a is not applicable when entering MODE 4.

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

E.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months F. All required monitors F .1 Enter LCO 3.0.3. Immediately inoperable.

INDIAN POINT 3 3. 4 .15 3 Amendment 252

RCS Leakage Detection Instrumentation 3.4.15 u SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

SR 3.4.15.1 Perform CHANNEL CHECK of the required containment 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months atmosphere radioactivity monitor.

SR 3.4.15.2 Perform COT of the required containment 92 days atmosphere radioactivity monitor.

SR 3.4.15.3 Perform CHANNEL CALIBRATION of the required 24 months containment sump flow monitor.

SR 3.4.15.4 Perform CHANNEL CALIBRATION of the required 24 months containment atmosphere radioactivity monitor.

SR 3.4.15.5 Perform CHANNEL CALIBRATION of the required 24 months containment fan cooler unit condensate measuring system.

u INDIAN POINT 3 3.4.15-4 Amencinent 205

RCS Specific Activity 3.4.16

3. 4 REACTOR COOLANT SYSTEM (RCS) 3.4.16 RCS Specific Activity LCO 3.4.16 RCS DOSE EQUIVALENT I-131 and DOSE EQUIVALENT XE-133 specific activity shall be within limits.

APPLICABILITY: MODES 1, 2, 3, and 4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. DOSE EQUIVJ\.LENT ---------- NOTE --------

I-131 not within LCO 3.0.4.c is applicable limit. ------------------------

P.** 1 Verify DOSE Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months EQUIVALENT I-131

-< 60.0 µCi/gm.

AND

- -

A.2 Restore DOSE EQUIVALENT I-131 to within limit. 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months B. DOSE EQUIVALENT ---------- NOTE -------- 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months XE-133 not within LCO 3.0.4.c is applicable limit. ------------------------

B.l Restore DOSE EQUIVALENT XE-133 within limit.

(continued)

INDIAN POINT 3 3.4.16-1 Amendment 237

.,

RCS Specific Activity 3.4.16

.

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C, Required Action and I C .1 Be in MODE 3 with 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Tavg < 500°F.

Completion Time of Condition A or B not met.

OR AND DOSE EQUIVALENT C.2 Be in MODE 5 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months I-131 > 60.0 µCi/gm.

SURVEILLANCE REQUIREMENTS "SURVEILLANCE FREQUENCY SR 3.4.16.1 -------------------NOTE----------------

Only required to be rerformed in MODE 1.

Verify reactor coolant DOSE EQUIVALENT 7 days XE-133 specific activity~ 652 µCi/gm.

SR 3.4.16.2 -------------------NOTE-~------~-------

\ Only required to be performed in MODE 1.

Verify reactor coolant DOSE EQµIVALENT 14 days I-131 specific activity~ 1.0 µCi/gm.

AND Between 2 and 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after a THERMAL POWER change of~ 15% RTP within a 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period INDIAN POINT 3 3.4.16-2 Amendment '237

SG Tube Integrity 3.4.17 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.17 Steam Generator (SG) Tube Integrity LCO 3.4.17 SG tube integrity shall be maintained.

All SG tubes satisfying the tube plugging criteria shall be plugged in accordance with the Steam Generator Program.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS

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

Se pa rate Condition entry is allowed for each SG tube.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more SG tubes A.1 Verify tube integrity of the 7 days satisfying the tube affected tube(s) is plugging criteria and not maintained until the next plugged in accordance refueling outage or SG with the Steam tube inspection.

Generator Program. AND A.2 Plug the affected tube(s) in Prior to entering accordance with the Steam MODE 4 following the Generator Program. next refueling outage or SG tube inspection B. Required Action and 8.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not met. AND OR B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SG tube integrity not maintained.

INDIAN POINT 3 3.4.17-1 Amendment No. 257

SG Tube Integrity 3.4.17 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.17.1 Verify SG tube integrity in accordance with the Steam In accordance with Generator Program. the Steam Generator Program SR 3.4.17.2 Verify that each inspected SG tube that satisfies the Prior to entering tube plugging criteria is plugged in accordance with MODE 4 following the Steam Generator Program. a SG tube inspection INDIAN POINT 3 3.4.17- 2 Amendment No. 257

Accumulators 3.5.1 3 . 5 EMERGENCY CORE CO OU NG SYSTEMS CECCS) u 3.5.1 Accumulators LCO 3.5.1 Four ECCS accumulators shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

MODE 3 with reactor coolant system pressure > 1000 psig.

* * * * * * * * * * * * * * * * * * * * * * * *NOTES* * * * * * * * * * * * * * * * * * * * * * * * - * * * * * * * - * **

1. In MODE 3, all accumulator discharge isolation valves may be closed and energized for up to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months during the performance of reactor coolant sys tern hydrostatic testing.

2. In MODE 3, one accumulator discharge isolation valve may be closed and energized for up to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months for accumulator check valve leakage testing.

ACTIONS

- -

V CONDITION REQUIRED ACTION COMPLETION TIME A. One accumulator A.1 Restore boron 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable due to concentration to boron concentration within limits of not within limits of SR 3.5.1.4.

SR 3.5.1.4.

B. One accumulator B.1 Restore accumulator to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months inoperable for OPERABLE status.

reasons other than Condition A.

(continued)

~ INDIAN POINT 3 3.5.1-1 Amendment 222

Accumulators 3.5.1 ACTIONS {continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in HOOE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A or B not Mm met.

C.2 Reduce reactor coolant 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months system pressure to

~ 1000 psig.

D. Two or more accumulators 0.1 Enter LCO 3.0.3. Immediately inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE

FREQUENCY SR 3.5.1.1 Verify each accumulator discharge isolation valve 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is fully open.

SR 3.5.1.2 Verify borated water volume in each accumulator 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is~ 775 cubic feet and~ 815 cubic feet.

SR 3.5.1.3 Verify nitrogen cover pressure in each 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months accumulator is~ 600 psig and~ 700 psig.

(continued)

INDIAN POINT 3 3.5.1-2 Amencinent 205

Accumulators 3.5.1 u SURVEILLANCE REQUIREHENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.1.4 Verify boron concentration in each accumulator is 31 days

~ 2000 ppm and~ 2600 ppm.

- - - - NOTE******

Only required to be performed for affected accumulators Once within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after each solution volume increase of 10 X of indicated level.

that is not the result of addition from the refueling water storage tank SR 3.5.1.5 Verify power is removed from each accumulator 31 days isolation valve operator when reactor*coolant system pressure is~ 2000 psig.

INDIAN POINT 3 3.5.1-3 Amenanent 205

ECCS - Operating 3.5.2 3.5 EMERGENCY CORE COOLING SYSTEHS CECCS) 3.5.2 ECCS-Operating LCO 3.5.2 Three ECCS trains shall be OPERABLE.

- - - - NOTES***********************************

1. In HOOE 3. both HHSI flow paths may be isolated by closing the isolation valves for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to perform pressure isolation valve testing per SR 3.4.14.1.

2. Operation in HOOE 3 with HHSI pumps made incapable of injecting pursuant to LCO 3.4.12. "Low Temperature Overpressure Protection CLTOP)." is allowed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or until the temperature of all RCS cold legs exceeds 375°F, whichever comes first.

APPLICABILITY: HODES 1. 2. and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIHE A. One or more trains A.l Restore trainCs) to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. OPERABLE status.

Two HHSI pumps. one RHR pump and one Containment Recirculation pump are OPERABLE.

(continued) u INDIAN POINT 3 3.5.2*1 Amenanent 205

ECCS - Operating 3.5.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COHPLETION TIHE B. Required Action and B.1 Be in HOOE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

B.2 Be in HOOE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREHENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify the following valves are in the 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months listed position with power to the valve operator removed.

Number: EQSl:tlQO FunctjQn

\__)

SI-856B Closed HHSI Loop 33 Hot Leg

Injection Stop Valve SI-856G Closed HHSI Loop 31 Hot Leg Injection Stop Valve SI-1810 Open RWST outlet isolation AC-744 Open Conrnon discharge isolation for RHR pumps SI-882 Open COC1111on RWST suction isolation for RHR pumps SI-842 Open HHSI pump minimum flow line isolation SI *843 Open HHSI pump minimum flow line isolation SI-883 Closed RHR pump return to RWST isolation AC-1870 Open RHR pump minimum flow line isolation AC-743 Open RHR pump mini mum fl ow line isolation u (continued)

INDIAN POINT 3 3.5.2*2 Amendment 205

---**--~~-

ECCS - Operating 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.2 Verify that each ECCS manual, power operated, 31 days and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.5.2.3 Verify each ECCS pump's developed head at the In accordance with test flow point is greater than or equal to the the Inservice required developed head. Testing Program SR 3.5.2.4 Verify each ECCS automatic valve in the flow 24 months path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

SR 3.5.2.5 Verify each ECCS pump starts automatically on 24 months an actual or simulated actuation signal.

SR 3.5.2.6 Verify, for each ECCS throttle valve 24 months listed below, each position stop is in the correct position.

Valve Numbers SI-856B SI-856G SI-2165 SI-2170 SI-856C SI-856H SI-2166 SI-2171 SI-856D SI-856J SI-2168 SI-2172 SI-856E SI-856K SI-2169 (continued)

INDIAN POINT 3 3.5.2-3 Amendment230

ECCS-Operating 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.7 Verify, by visual inspection, each ECCS train 24 months containment sump suction inlet and recirculation sump suction inlet is not restricted bY. debris and the suction inlet screens show no evidence of structural distress or abnormal corrosion.

u INDIAN POINT 3 3.5.2*4 Amenanent 205

ECCS Shutdown 3.5.3 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.3 ECCS-Shutdown LCO 3.5.3 Two ECCS High Head Safety Injection (HHSI) subsystems and one ECCS Residual Heat Removal (RHR) subsystem shall be OPERABLE.

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

An RHR subsystem may be considered OPERABLE during alignment and operation for decay heat removal if capable of being manually realigned to the ECCS mode of operation.

APPLICABILITY: MODE 4.

ACTIONS

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

LCO 3.0.4.b is not applicable to the ECCS High Head Safety Injection subsystems.

CONDITION REQUIRED ACTION COMPLETION TIME A. Required ECCS A.l -----NOTE------- Immediately Subsystem LCO 3.0.4.a is not inoperable. applicable when entering MODE 4.

Initiate action to restore required ECCS subsystem to OPERABLE status.

INDIAN POINT 3 3.5.3 - 1 Amendment 252

ECCS - Shutdown 3.5.3 SURVEILLANCE REQUIREHENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 The following SRs are applicable for all In accordance equipment required to be OPERABLE: with applicable SRs .

SR 3.5.2.3 SR 3.5.2.7 u

INDIAN POINT 3 3.5.3-2 Amendnent 205

RWST 3.5.4 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.4 Refueling Water Storage Tank (RWST)

LCO 3.5.4 The RWST and two channels of RWST low level alarm shall be OPERABLE.

NOTE 1 The RWST isolation valves connected to non-safety related piping may be opened under administrative controls for up to 14 days per fuel cycle for filtration until the end of refuel outage 18.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RWST boron A.1 Restore RWST to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months concentration not OPERABLE status.

within limits of SR 3.5.4.3.

OR RWST borated water temperature not within limits of SR 3.5.4.1.

B. One channel of RWST B.l Restore RWST low 7 days low level alarm level alarm to inoperable. OPERABLE status.

C. RWST inoperable for C.1 Restore RWST to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months reasons other than OPERABLE status.

Condition A or B.

D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not AND

- -

met. ----- NOTE ---

LCO 3.0.4.a is not applicable when entering MODE 4.

D.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months INDIAN POINT 3 3.5.4 1 Amendment 252

RWST 3.5.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.4.1 ------------------N()TE--------------------------------- 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Not required to be performed when ambient air temperature is .::: 35°F and ~ 95°F if heating steam supply isolation valves are locked closed.

Verify RWST borated water temperature is 2 35°F and

~ 105°F.

SR 3.5.4.2 Verify RWST borated water level is 2 35.4 feet. 7 days SR 3.5.4.3 Verify RWST boron concentration is 2 2400 ppm and 31 days

~ 2600 ppm.

SR 3.5.4.4 Perform CHANNEL CHECK of RWST level 7 days SR 3.5.4.5 Perform CHANNEL CALIBRATl()N of RWST level switch 184 days and ensure the low level alarm setpoint is 210.5 feet and s12.5 feet.

SR 3.5.4.6 Perform CHANNEL CALIBRATl()N of RWST level 18 months transmitter and ensure the low level alarm setpoint is 210.5 feet and ~12.5 feet.

INDIAN P()INT 3 3.5.4-2 Amendment 253

Containment 3.6.1 3.6 CONTAINHENT SYSTEHS 3.6.1 Containment LCO 3.6.1 Containment shall be OPERABLE.

APPLICABILITY: HODES 1, 2, 3, and 4*.

ACTIONS CONDITION REQUIRED ACTION COHPLETION TI HE A. Containment inoperable. A.1 Restore containment to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months OPERABLE status.

B. Required Action and B.1 Be -in HOOE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. eHQ B.2 Be in HOOE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months INDIAN POINT 3 3.6.1*1 lwenanent 205

Containment 3.6.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.l Perform required visual examinations and leakage In accordance rate testing except for containment air-lock with the testing, in accordance with the Containment Containment Leakage Rate Testing Program. Leakage Rate Testing Program u

INDIAN POINT 3 3.6.1*2 Amenctnent 205

Containment Air Locks 3.6.2 3.6 CONTAINMENT SYSTEMS 3.6.2 Containment Air Locks LCO 3.6.2 Two containment air locks shall be OPERABLE.

APPLICABILITY: HODES 1, 2, 3, and 4.

ACTIONS

- - - - NOTES*******************************************

1. Entry and exit is permissible to perform repairs on the affected air lock components.

2. Separate Condition entry is allowed for each air lock.

3. Enter applicable Conditions and Required Actions of LCO 3.6.1, "Containment," when air lock leakage results in ex~eeding the overall containment leakage rate.

CONDITION REQUIRED ACTION COMPLETION TIHE A. One or more containment * * * * * *******-NOTES**************

air locks with one 1. Required Actions A.1, A.2.

containment air lock door and A.3 are not applicable if inoperable. both doors in the same air lock are inoperable and Condition C is entered.

2. Entry and exit is*permissible for 7 days under administrative controls if both air locks are inoperable.

(continued)

INDIAN POINT 3 3.6.2*1 /wendment 205

Containment Air Locks 3.6.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIHE A. (continued) A.1 Verify the OPERABLE door 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months is closed in the affected air lock.

AMO A.2 Lock the OPERABLE door 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months closed in the affected air lock.

AMO A.3 ********NOTE***********

Air lock doors in high radiation areas may be verified locked closed by aaninistrative means .

...........*.*.........

Verify the OPERABLE door Once per 31 days

\~ is locked closed in the affected *air lock.

(continued)

INDIAN POINT 3 3.6.2*2

Arnenanent 205

Containment Air Locks 3.6.2 ACTIONS (continued)

~* CONDITION REQUIRED ACTION COMPLETION TIHE

8. One or more containment -------------NOTES--------------

air locks with 1. Required Actions 8.1. 8.2.

containment air lock and 8.3 are not applicable if interlock mechanism both doors in the same air inoperable. lock are inoperable and Condition C is entered.

2. Entry and exit of containment is permissible under the control of a dedicated i ndi vi dual.

8.1 Verify an OPERABLE door 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months is closed in the affected air lock.

AtID 8."2 Lock an OPERABLE door 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months closed in the affected

air lock.

AtID 8.3 ---------NOTE----------

Air lock doors in high radiation areas may be verified locked closed by atininistrative means .

..***...........**.....

Verify an OPERABLE door Once per 31 days is locked closed in the affected air lock.

(continued)

INDIAN POINT 3 3.6.2-3 Amentinent 205

Containment Air Locks 3.6.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more containment C.1 Initiate action to Invnediately air locks inoperable for evaluate overall reasons other than containment leakage rate Condition A or B. per LCO 3.6.1.

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

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

D. Required Action and D.1 Be in HOOE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months u associated Completion Time not met. Mm D.2 Be in HOOE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months INDIAN POINT 3 3.6.2*4 Amenonent 205

Containment Air Locks 3.6.2 SURVEILLANCE REQUIREHENTS SURVEILLANCE FREQUENCY SR 3.6.2.1 ------------------***NOTES**-*-*-***-**********

1. An inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test.

2. Results shall ~e evaluated against acceptance criteria applicable to SR 3.6.1.1.

Perform required air lock leakage rate testing in In accordance accordance with the Containment Leakage Rate with the Testing Program. Containment Leakage Rate Testing Program SR 3.6.2.2 Verify only one door in the air lock can be 24 months opened at a time.

'

INDIAN POINT 3 3.6.2*5 /vnenanent 205

Containment Isolation Valves 3.6.3 u 3.6 COITTAINHEITT SYSTEHS 3.6.3 Containment Isolation Valves LCO 3.6.3 Each containment isolation valve shall be OPERABLE.

APPLICABILITY: HODES 1, 2, 3, and 4.

ACTIONS

- - - - NOTES*******************************************

1. Penetration flow path(s) except for 36 inch purge valve 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 containment isolation valves.

4. Enter applicable Conditions and Required Actions of LCO 3.6.1, "Containment," when u isolation valve leakage results in exceeding the overall containment leakage rate acceptance criteria.

5. Enter applicable Conditions and Required Actions of LCO 3.6.9, "Isolation Valve Seal Water CIVSW) System," when required IVSW supply to a penetration flowpath is inoperable.

6. Enter applicable Conditions and Required Actions of LCO 3.6.10, "Weld Channel and Penetration Pressurization System CWC&PPS)," when required WC&PPS supply to a penetration flowpath is inoperable.

INDIAN POIITT 3 3.6.3*1 Amendment 205

Containment Isolation Valves 3.6.3 ACTIONS (continued)

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 Only applicable to penetration flow path by penetration flow paths use of at least one with two or more closed and de-activated containment isolation automatic valve, closed valves. manual valve, blind flange, or check valve with flow through the One or more penetration valve secured.

fl ow paths with one containment isolation valve inoperable, for reasons other than A.2 ********NOTE*********

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

Verify the affected Once per 31 days penetration flow path is for isolation isolated. devices outside containment Prior to entering HOOE 4 from HOOE 5 if not performed within the previous 92 days for isolation devices inside containment (continued)

INDIAN POINT 3 3.6.3*2 hnendment 205

Containment Isolation Valves 3.6.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIHE B. ---------NOTE--------- B.1 Isolate the affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Only applicable to penetration flow path by penetration flow paths use of at least one with two or more closed and de-activated containment isolation automatic valve, closed valves. manual valve, or blind

.....*................ flange .

One or more penetration fl ow paths with two or more containment isolation valves inoperable, for reasons other than Condition D.

C. ---------NOTE--------- C.1 Isolate the affected 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Only applicable to penetration flow path by penetration flow paths use of at least one with only one containment closed and de-activated isolation valve and a automatic valve, closed closed system. manual valve. or blind

...........***....... flange .

One or more penetration MiQ flow paths with one containment isolation C.2 --------NOTE---------

valve inoperable. Isolation devices in high radiation areas may be verified by use of acininistrative means .

......**.....*.***..

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

(continued) u INDIAN POINT 3 3.6.3-3 Amencinent 205

Containment Isolation Valves 3.6.3 ACTIONS (continued}

CONDITION REQUIRED ACTION COHPLETION TIHE D. Containment bypass D.1 Restore leakage within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for leakage or limit. containment bypass hydrostatically tested leakage valve leakage not within limit. MID 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for hydrostatically tested valve leakage E. Required Action and E.1 Be in HOOE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. MID E.2 Be in HOOE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.1 Verify each 36 inch purge supply and exhaust 31 days isolation valve is sealed closed.

SR 3.6.3.2 Verify each 10 inch pressure relief isolation 31 days valve is closed. except when these valves are open for pressure control. ALARA or air quality considerations for personnel entry, or for Surveillances that require the valves to be open.

(continued}

INDIAN POINT 3 3.6.3*4 Mendment 205

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREHENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.3.3 *********************NOTE**********************

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

Verify each containment isolation manual valve 31 days and blind flange that is located outside containment and not locked, sealed, or otherwise secured and required to be closed during accident conditions is closed, except for containment isolation valves that are open under administrative controls.

SR 3.6.3.4 ********************NOTE***********************

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

Verify each containment isolation manual valve Prior to entering and blind flange that is located inside HOOE 4 from containment and not locked, sealed or otherwise HOOE 5 if not secured and required to be closed during accident performed within conditions is closed, except for containment the previous isolation valves that are open under 92 days administrative controls.

(continued)

.'-._)

INDIAN POINT 3 3.6.3*5 Amendment 205

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.3.5 Verify the isolation time of each automatic power In accordance operated containment isolation valve is within limits. with the lnservice Testing Program SR 3.6.3.6 Verify each automatic containment isolation valve that 24 months is not locked, sealed or otherwise secured in position, actuates to the isolation position on an actual or simulated actuation signal.

SR 3.6.3.7 Verify each 10 inch containment pressure relief line 24 months isolation valve is blocked to restrict valve opening to

60 degrees.

SR 3.6.3.8 Perform one complete cycle of each manually 24 months operated containment isolation valve on essential lines.

SR 3.6.3.9 Verify leakage rate into containment from isolation In accordance with valves sealed with service water system is within the Containment limits. Leakage Rate Testing Program INDIAN POINT 3 3.6.3-6 Amendment 253

Containment Pressure 3.6.4 3.6 CONTAINMENT SYSTEMS 3.6.4 Containment Pressure LCO 3.6.4 Containment pressure shall be maintained as follows:

a. If RWST temperature is> 95°F or containment temperature is> 125°F, Containment pressure shall be 2:: -2.0 psig and :s: + 1.5 psig.

b. If RWST temperature is ::::; 95°F and containment temperature is :s: 125°F, Containment pressure shall be 2:: -2.0 psig and::::; +2.5 psig.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment pressure A.1 Restore containment 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months not within limits. pressure to within limits.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1 Verify containment pressure is within limits. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months INDIAN POINT 3 3.6.4-1 Amendment 253

Containment Air Temperature 3.6.5 3.6 CONTAINHENT SYSTEHS 3.6.5 Containment Air Temperature LCO 3.6.5 Containment average air temperature shall be> 50°F ands 130°F.

APPLICABILITY: HODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COHPLETION TIHE A. Containment average air A.1 Restore containment Immediately temperature s50 °F. average air temperature to >SO °F.

B. Containment average air B.1 Restore containment 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months V temperature >130 °F. average air temperature to within d30 °F.

C. Required Action and C.1 Be in HOOE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time Condition A or B MD not met.

C.2 Be in HOOE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1 Verify containment average air temperature is 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months within 1imits.

INDIAN POINT 3 3.6.5*1 Amendment 205

Containment Spray System and Containment Fan Cooler System 3.6.6 3.6 CONTAINMENT SYSTEMS 3.6.6 Containment Spray System and Containment Fan Cooler System LCO 3.6.6 Two Containment Spray trains and three Containment Fan Cooler trains shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One containment A.1 Restore 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months spray train containment spray inoperable. train to OPERABLE AND

--

status.

10 days from discovery of failure to meet the LCO B. red Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not ----- NOTE --

met. LCO 3.0.4.a is not applicable when entering MODE 4.

---

B.2 Be in MODE 4. 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months (continued)

INDIAN POINT 3 3.6.6-1 Amendment 252

Containment Spray System and Containment Fan Cooler System 3.6.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One containment fan C.1 Restore 7 days cooler train containment fan inoperable. cooler train to AND OPERABLE status.

10 days from discovery of failure to meet the LCO D. Two containment fan D.1 Restore one 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months cooler trains containment fan inoperable. cooler train to OPERABLE status.

E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of AND Condition C or D ---- NOTE not met, LCO 3.0.4.a is not applicable when entering MODE 4.

E.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months F. Two containment F.1 Enter LCO 3.0.3. Imrnediat spray trains inoperable.

OR Any combination of three or more trains inoperable.

INDIAN POINT 3 3.6.6-2 Amendment 252

Containment Spray System and Containment Fan Cooler System 3.6.6

\_/. SURVEILLANCE REQUIREHENTS SURVEILLANCE FREQUENCY SR 3.6.6.1 Verify each containment spray manual, power 31 days operated, and automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position.

SR 3.6.6.2 Operate each containment fan cooler unit fan for 92 days 2 15 minutes.

SR 3.6.6.3 Verify each containment fan cooler unit cooling 92 days water flow rate is 2 1400 gpm.

SR 3.6.6.4 Verify each containment spray pump's developed In accordance head at the flow test point is greater than or with the V equal to the required developed head. Inservice Testing Program SR 3.6.6.5 Verify each automatic containment spray valve in 24 months the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

SR 3.6.6.6 Verify each containment spray pump starts 24 months automatically on an actual or simulated actuation signal.

(continued)

INDIAN POINT 3 3.6.6-3 Arnencinent 205

Containment Spray System and Containment Fan Cooler System 3.6.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.6.7 Verify each containment fan cooler unit starts 24 months and dampers re-position to the emergency mode automatically on an.actual or simulated actuation signal.

SR 3.6.6.8 Perform required containment fan cooler system In accordance filter testing in accordance with the Ventilation with the VFTP Filter Testing Program CVFTP).

SR 3.6.6.9 Verify each spray nozzle is unobstructed. 10 years V

INDIAN POINT 3 3.6.6-4 /wenanent 205

Recirculation pH Control System 3.6.7 3.6 CONTAINMENT SYSTEMS 3.6.7 Recirculation pH Control System LCO 3.6.7 The Recirculation pH Control System shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Recirculation pH A. l Restore 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Control System Recirculation pH inoperable. Control System to OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND

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

LCO 3.0.4.a is not icable when entering MODE 4.

B.2 Be in MODE 4. 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.7.1 Perform a visual inspection of eight 24 Months sodium tetraborate storage baskets to verify each of the following:

a. Each storage basket is in ace and intact; and,

b. Collectively contain> 8096 pounds (160 cubic feet) of sodium tetraborate decahydrate, or equivalent.

INDIAN POINT 3 3.6.7-1 Amendment 252

Hydrogen Recombiners 3.6.8 u 3.6 CONTAINMENT SYSTEMS 3.6.8 Not Used V

\

INDIAN POINT 3 3.6.8-1 Amendment 22P.

Isolation Valve Seal Water System 3.6.9 3.6 CONTAINMENT SYSTEMS V

3.6.9 Isolation Valve Seal Water CIVSW) System LCO 3.6.9 The IVSW System shall be OPERABLE.

APPLICABILITY: HODES 1, 2. 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One IVSW system header A.l Restore IVSW system to 7 days inoperable. OPERABLE status.

QR One IVSW automatic actuation valve.

inoperable.

V B. IVSW system inoperable B.1 Restore IVSW System to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for reasons other than OPERABLE Status.

Condition A.

C. Required Action and C.1 Be in HOOE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND C.2 , Be in HOOE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months INDIAN POINT 3 3.6.9*1 Amendment 205

Isolation Valve Seal Water System 3.6.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.9.1 Verify IVSW tank pressure is~ 47 psig. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SR 3.6.9.2 Verify IVSW nitrogen supply bank is pressurized 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months with:

a. one cylinder with pressure~ 1048 psig; or

b. two cylinders with pressure~ 584 psig; or C. three cylinders with pressure~ 430 psig.

SR 3.6.9.3 Verify the IVSW tank water volume is 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

~ 144 gallons.

SR 3.6.9.4 Verify the opening time of each air operated 24 months header injection valve is within limits.

SR 3.6.9.5 Verify each automatic valve in the IVSW System 24 months actuates to the correct position on an actual or simulated actuation signal.

SR 3.6.9.6 Verify the leakage rate of water from the In accordance Isolation Valve Seal Water System is within with the

limits. Containment Leakage Rate Testing Program.

u INDIAN POINT 3 3.6.9*2 Amenanent 205

WC&PPS 3.6.10 3.6 CONTAINHENT SYSTEHS 3.6.10 Weld Channel and Penetration Pressurization System (WC&PPS)

LCO 3.6.10 Weld Channel and Penetration Pressurization System shall be OPERABLE.

APPLICABILITY: HODES 1, 2, 3, and 4.

ACTIONS

- - - - NOTES*******************************************

1. Separate Condition entry is allowed for each component supplied by WC&PPS.

2. Enter applicable Conditions and Required Actions of LCO 3.6.1, "Containment," when the overall containment leakage rate acceptance criteria is exceeded.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more components A.1 Isolate the WC&PPS 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months supplied by WC&PPS not supply to the affected within the pressure limit components by use of at of SR 3.6.10.1. least one closed and de-activated automatic valve, closed manual valve, blind flange, or check valve with flow through the valve secured.

(continued)

INDIAN POINT 3 3.6.10*1

Amenanent 205

WC&PPS 3.6.10

.--- ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)

A.2 --------NOTE---------

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

Verify the WC&PPS supply Once per 31 days to the affected for i sol ati on component is isolated. devices outside containment not locked, sealed or otherwise secured Mill Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days for isolation devices inside containment B. WC&PPS air consumption B.1 Enter applicable 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from not within the limits of Conditions and Required discovery that the SR 3.6.10.2. Actions of LCO 3.6.3, WC&PPS air "Containment *Isolation consumption Valves." 1eakage path is depressurized and not isolated from the supported containment isolation valves Mill (continued)

INDIAN POINT 3 3.6.10-2 A'nendment 205

WC&PPS 3.6.10 ACTIONS u CONDITION REQUIRED ACTION COMPLETION TIME B. (continued}

8.2 Enter applicable 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Conditions and Required discovery that the Actions of LCD 3.6.2, WC&PPS air "Containment Air Locks." consumption leakage path is depressurized and not isolated from the supported air lock MID 8.3 ********NOTE*********

Enter condition A for components not within the pressure limit of SR 3.6.10.1.

Isolate portions of 7 days WC&PPS to restore air

\_)' consumption to within limits of SR 3.6.10.2.

C. Required Action and C.1 Be in HOOE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. MID C.2 Be in HOOE 5 *. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months INDIAN POINT 3 3.6.10*3 .AJnendnent 205

WC&PPS 3.6.10 SURVEILLANCE REOUIREHENTS SURVEILLANCE FREQUENCY SR 3.6.10.1 Verify all required portions of each WC&PPS zone 31 days is pressurized to~ 43 psig.

SR 3.6.10.2 Verify the WC&PPS air consumption is s 0.2% of 31 days the containment free volume per day.

SR 3.6.10.3 Verify the leakage rate for the WC&PPS is s 0.2X *****NOTE******

of the containment free volume per day when SR 3.0.2 is not pressurized to~ 43 psi above containment applicable pressure.

36 months u

INDIAN POINT 3 3.6.10*4 Amenanent 205

HSSVs 3.7.1 3.7 PI..AITT SYSTEMS 3.7.1 Hain Steam Safety Valves CHSSVs)

LCO 3.7.1 The HSSVs shall be OPERABLE as specified.in Table 3.7.1-1 and Table 3.7.1-2.

APPLICABILITY: HODES 1, 2, and 3.

ACTIONS

- - - - NOTE*********************************************

Separate Condition entry is allowed for each HSSV.

CONDITION REQUIRED ACTION COMPLETION TI HE A. One or more required A.1 Reduce neutron flux trip 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months HSSVs inoperable. setpoint to less than or equal to the applicable V l RTP listed in Table 3.7 .l*l.

B. Required Action and B.1 Be in HOOE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AHO QR B.2 Be in HOOE 4. *. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months One or more steam generators with less than two HSSVs OPERABLE.

INDIAN POINT 3 3.7.1-1 Amenctnent 205

HSSVs 3.7.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3. 7 .1.1 ********************NOTE***********************

Only requjred to be performed in HODES 1 and 2.

Verify each required HSSV lift setpoint per Table In accordance 3.7.1*2 in accordance with the Inservice Testing with the Program. Following testing, lift setting shall Inservice Testing be within +/-lX. Program V

INDIAN POINT 3 3.7.1~2 Amenanent 205

MSSVs 3.7.1 Table 3.7.1-1 (page 1 of 1)

OPERABLE Main Steam Safety Valves versus Applicable Neutron Flux Trip Setpoint in Percent of RATED THERMAL POWER MINIMUM NUMBER OF MSSVs APPLICABLE Neutron Flux Trip PER STEAM GENERATOR Setpoint REQUIRED OPERABLE (% RTP) 4 ~ 57 3 ~ 38 2

~ 20

\._)

INDIAN POINT 3 3.7.1-3 Amendment 225

HSSVs 3.7.1 Table 3.7.1-2 (page 1 of 1)

Hain Steam Safety Valve Lift Settings VALVE NUHBER LIFT SITTING STEAM GENERATOR Cpsig +/- 3%)

31 #32 #33 #34 HS-45-1 HS-45*2 HS-45-3 HS*45*4 1065 HS-46*1 HS-46*2 HS-46-3 HS-46-4 1080 HS-47*1 HS-47*2 HS-47-3 HS-47-4 1095 HS-48*1 HS-48*2 HS-48*3 HS-48*4 1110 HS-49-1 HS-49*2 HS-49*3 HS-49*4 1120

\._)

INDIAN POINT 3 3.7.1*4 Amenanent 205

HSIVs and HSCVs 3.7.2

~* 3.7 PLANT SYSTEHS 3.7.2 Hain Steam Isolation Valves CHSIVs) and Hain Steam Check Valves CHSCVs)

LCO 3.7.2 Four HSIVs and four HSCVs shall be OPERABLE.

APPLICABILITY: HOOE 1, HODES 2 and 3 except when all HSIVs are closed.

ACTIONS CONDITION REQUIRED ACTION COHPLETION TIHE A. One or more HSCVs A.l Restore HSCVs to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months inoperable. OPERABLE status.

B. Required Action and B.1 Be in HOOE 2. 6 hours associated Completion Time of Condition A not ~

met.

B.2 Close all HSIVs. 14 hours1.62037e-4 days 0.00389 hours 2.314815e-5 weeks 5.327e-6 months

~

B.3 Verify all HSIVs Once per 7 days closed.

C. One HSIV inoperable in C.1 Restore HSIV to OPERABLE 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months HOOE 1. status.

(continued)

INDIAN POINT 3 3.7.2*1 Amencinent 205

HSIVs and HSCVs 3.7.2 ACTIONS {continued}

CONDITION REQUIRED ACTION COHPLETION TI HE D. Required Action and 0.1 Be in HOOE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition C not met.

E. -------*-NOTE-*--------- E.1 Close HSIV. 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months Separate Condition entry is allowed for each HSIV. Mill

.............**........

E.2 Verify HSIV is closed. Once per One or more HSIVs 7 days inoperable in HOOE 2 or 3.

F. One HSIV inoperable. F.1 Restore all HSCVs to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months OPERABLE status.

ANO D.B One or more HSCVs inoperable. F.2 Restore all HSIVs to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months OPERABLE status.

G. Required Action and G.1 Be in HOOE 3; 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition B, E or Mill F not met.

G.2 Be in HOOE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months u

INDIAN POINT 3 3.7.2-2 Amencinent 205

HSIVs and HSCVs 3.7.2

\....__,) SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1 ---------------------NOTE----------**----------

Only required to be performed in HODES 1 and 2.

Verify closure time of each HSIV is~ 5.0 seconds In accordance on an actual or simulated actuation signal. with the Inservice Testing Program SR 3.7.2.2 Perform visual inspection of each HSCV. In accordance with the Inservice Testing Program INDIAN POINT 3 3.7.2-3 Amenanent 205

HBFPDVs, HFRVs and HF Low Flow Bypass Valves 3.7.3

\__). 3. 7 PLANT SYSTEMS 3.7.3 Hain Boiler Feedpump Discharge Valves CHBFPDVs), Hain Feedwater Regulation Valves (MFRVs), Hain Feedwater Inlet Isolation Valves (HFIIVs) and Hain Feedwater (HF) Low Flow Bypass Valves LCO 3.7.3 Two MBFPDVs, four MFRVs, four HFIIVs and eight MF low flow bypass valves shall be OPERABLE.

APPLICABILITY: HODES 1. 2. and 3 except when each main feedwater and bypass line is isolated by a closed and de-activated motor/air operated valve or isolated by a closed manual valve.

ACTIONS

- - - - NOTE********************************************

Separate Condition entry is allowed for each valve.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or both MBFPDVs A.1 Close or isolate 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. HBFPDV.

Mill A.2 Verify HBFPOV is closed Once per or isolated. 7 days B. One or more HFRVs B.1 Close or isolate HFRV. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable.

Mill B.2 Verify HFRV is closed Once per or isolated. 7 days (continued)

INDIAN POINT 3 3.7.3-1 Amendment 207 APR 1 n 2001

MBFPDVs, MFRVs and MF Low Flow Bypass Valves *f 3.7.3 u ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more MFIIVs C.l Close or isolate MFIIV. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable.

AND C.2 Verify MFIIV is closed Once per or isolated. 7 days D. One or more D.l Close or isolate bypass 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months MF low flow valve.

bypass valves inoperable. Mill D.2 Verify bypass valve is Once per closed or isolated. 7 days u E. Two valves in series in the same flow path E.1 Isolate affected flow path.

8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months inoperable.

F. Required Action and F.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. Mill F.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months INDIAN POINT 3 3.7.3*2 Amendment 207

/,,PR 1 :J 2CD1

-

MBFPDVs, MFRVs and MF Low Flow Bypass Valves 3.7.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 Verify each MBFPDV, MFRV. MFIIV and MF low flow In accordance bypass valve closes on an actual or simulated with the actuation signal within the following limits: Inservice Testing Program

a. MBFPDV closure times 122 seconds:

b. MFRV closure times 10 seconds: and.

c. MFIIV closure times 120 seconds

d. MFRV Low Flow Bypass valve closure time

1. primary s 10 seconds

2. backups 120 seconds.

INDIAN POINT 3 3.7.3*3 Amendment 207 APR 1 O 2031

ADVs 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Atmospheric Dump Valves (ADVs)

LCO 3.7.4 Four ADV lines shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, MODE 4 when steam generator is relied upon for heat removal.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required ADV line A.1 Restore required ADV 7 days inoperable. line to OPERABLE status.

B. Two or more required 8.1 Restore all but one 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ADV lines inoperable. ADV line to OPERABLE status.

c. Required Action and C.l Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND C.2 Be in MODE 4 without 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months reliance upon steam generator for heat removal.

INDIAN POINT 3 3.7.4-1 Amendment 251

NJVs

3. 7.4 SURVEILLANCE REQUIREHENTS u SURVEILLANCE FREQUENCY SR 3. 7.4.1 Verify one complete cycle of each NJV. 24 months SR 3.7.4.2 Verify one complete cycle of each NJV 24 months block valve.

u INDIAN POINT 3 3.7.4*2 Amenanent 205

AEW System*

3.7.5 3.7 PLANT SYSTEMS 3.7.5 Auxiliary Feedwater (AFW) System LCO 3.7.5 Three AFW trains shall be OPERABLE.

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

Only one AFW train, which includes a motor driven pump capable of supporting the credited steam generator(s), is required to be OPERABLE in MODE 4.

APPLICABILITY: MODES 1, 2, and 3, MODE 4 when steam generator is relied upon for heat removal.

ACTIONS

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

LCO 3.0.4.b is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One steam supply to A.1 Restore steam 7 days turbine driven AFW supply to OPERABLE pump inoperable. status. AND

--

10 days from discovery of failure to meet the LCO B. One AFW train B.1 Restore AFW train 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable in MODE to OPERABLE 1, 2 or 3 for status. AND reasons other than --

Condition A. 10 days from discovery of failure to meet the LCO (continued)

INDIAN POINT 3 3.7.5-1 Amendment 226

.,

AFW System 3.7.5 ACTIONS (continued)

~*

CONDITION REQUIRED ACTION COMPLETION TIHE C. Required Action and C.1 Be in HOOE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time for Condition A or B Mm not met.

C.2 Be in HOOE 4. 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months

.QR Two AFW trains inoperable in HOOE 1. 2. or 3.

D. Three AFW trains ---------*---NOTE--**-----*----

inoperable in HOOE 1. LCO 3.0.3 and all other LCO

2. or 3. Required Actions requiring HOOE changes are suspended until one AFW train is restored to OPERABLE status .

....*..**.......*...........**.

D.1 Initiate action to Inrnediately restore one AFW train to OPERABLE status.

E. Required AFW train E.l Initiate action to Inrnediately inoperable in HOOE 4. restore AFW train to OPERABLE status.

INDIAN POINT 3 3.7.5-2 Amenanent 205

AFW System 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 ---------------------NOTE------------*------**-

Not applicable in HOOE 4 when steam generator is relied upon for heat removal.

Verify each AFW manual, power operated. and 31 days automatic valve in each water flow path, and in both steam supply flow paths to the steam turbine driven pump, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.7.5.2 -----*---*-*----*-*--NOTE*-**--*-***--*----*-*-

Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after~ 600 psig in the steam generator.

u Verify the developed head of each AFW pump at the In accordance flow test point is greater than or equal to the with Inservice required developed head. Testing Program SR 3.7.5.3 --*--**----*-------*-NOTE*-***-**-*-****-*-****

Not applicable in HOOE 4 when steam

generator is relied upon for heat removal.

Verify each AFW automatic valve that is not 24 months locked. sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

(continued) u INDIAN POINT 3 3.7.5*3 Mlenanent 205

AFW System 3.7.5 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.5.4 **********************NOTES********************

1. Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after~ 600 psig in the steam generator.

2. Not applicable in MODE 4 when steam generator is relied upon for heat removal.

Verify each AFW pump starts automatically on an 24 months actual or simulated actuation signal.

INDIAN POINT 3 3.7.5*4 /IJnenanent 205

CST 3.7.6 3.7 PL.ANT SYSTEMS 3.7.6 Condensate Storage Tank (CST)

LCO 3.7.6 The CST shall be OPERABLE.

APPLICABILITY: HODES 1, 2, and 3, HODE 4 when steam generator is rel1ed upon for heat removal.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TI HE A. CST inoperable. A.1 Verify by aaninistrative Immediately means OPERABILITY of City Water. MID Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter MID A.2 Restore CST to OPERABLE. 7 days B. Required Action and B.1 Be in HOOE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. Mm B.2 Be in HOOE 4, without 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months reliance on steam generator for heat removal.

INDIAN POINT 3 3.7.6*1 Amenanent 205

CST 3.7.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify the CST level is~ 360,000 gal. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months INDIAN POINT 3 3.7.6*2 Amenanent 205

CITY WATER 3.7.7 3.7 PLANT SYSTEMS 3.7.7 City Water (CW)

LCO 3.7.7 CW shall be OPERABLE.

APPLICABILITY: HODES 1. 2. and 3.

HOOE 4 when steam generator is relied upon for heat removal.

ACTIONS CONDITION REQUIRED ACTION COHPLETION TI HE A. CW inoperable. A.l Verify by acrninistrative Invnediately means OPERABILITY of Condensate Storage Tank. MID Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months MID thereafter u A.2 Restore CW to OPERABLE. 7 days B. Required Action and B.l Be in HOOE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. MID B.2 Be in HOOE 4. *.without 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months reliance on steam generators for heat removal.

INDIAN POINT 3 3.7.7-1 /wencrnent 205

CITY WATER 3.7.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1 Verify the CW header pressure is~ 30 psig. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.7.7.2 Verify the Unit 3 City Water Header Supply 31 days Isolation Valves are open.

SR 3.7.7.3 Perform testing required by Inservice In accordance Testing Program for each valve needed to with the align CW to each AFW pump suction. Inservice Testing Program INDIAN POINT 3 3.7.7-2 Amendment 218

CCW System 3.7.8 3.7 PLANT SYSTEMS 3.7.8 Component Cooling Water (CCW) System LCO 3.7.8 Two CCW loops shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One ccw loop A.1 -------NOTE-------

inoperable. Enter applicable Conditions and Required Actions of LCO 3. 4. 6, "RCS LoopsUMODE 4, II for residual heat removal loops made inoperable by ccw.

Restore ccw loop 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months to OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of AND

- -

Condition A not ----- NOTE -------

met. LCO 3.0.4.a is not applicable when entering MODE 4.

B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months INDIAN POINT 3 3.7.8-1 Amendment 252

CCW System 3.7.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.8.1 ---------------------NOTE-~------*-*--*--------

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

Verify each CCW manual, power operated, and 92 days automatic valve in the flow path servicing safety related equipment, that is not locked. sealed. or otherwise secured in position, is in the correct position.

SR 3.7.8.2 Verify each CCW automatic valve in the flow path 24 months that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

SR 3.7.8.3 Verify each CCW pump starts automatically on an 24 months actual or simulated actuation signal.

INDIAN POINT 3 3.7.8*2 Amendnent 205

sws 3.7.9 3.7 PLANT SYSTEHS 3.7.9 Service Water System (SWS)

LCO 3.7.9 Three pumps and required flow path for the essential SWS header shall be Operable:

Two pumps and required flow path for the nonessential SWS header shall be Operable.

APPLICABILITY: HODES 1, 2, 3, and 4.

-*************************************NOTE**********************************************

If LCO 3.7.9 will be met after the essential and non-essential header are swapped, then LCO 3.0.3 is not applicable for 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months while swapping the essential SWS header with the nonessential SWS header.

u ACTIONS CONDITION REQUIRED ACTION COMPLETION TIHE A. One required SWS pump on A.1 Establish 3 OPERABLE SWS 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months essential header pumps on the essential inoperable. SWS header.

B. One required SWS pump B.1 Establish 2 OPERABLE SWS 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months on nonessential header pumps on the nonessential inoperable. SWS header.

(continued)

INDIAN POINT 3 3.7.9*1 Amenanent 205

sws 3.7.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One EOG ESFAS C.1 Restore both EOG 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Service Water valve ESFAS Service inoperable. Water valves to OPERABLE status.

D. One FCU ESFAS D.l Restore both FCU 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Service Water ESFAS Service valve inoperable. Water valves to OPERABLE status.

E. SWS piping and E.1 Restore SWS to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months valves inoperable OPERABLE Status for reasons other than Conditions A, B, C, or D, with no loss of safety function.

F. Required Action and F.1 Be in MODE 3 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of AND

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

Condition A, B, C, D or E not met. LCO 3.0.4.a is not applicable when entering MODE 4.

F.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months INDIAN POINT 3 3.7.9-2 Amendment 252

sws 3.7.9 SURVEILLANCE REQUIREHENTS SURVEILLANCE FREQUENCY SR 3.7.9.1 ------*----~---------NOTE-----------*--*-------

Isolation of SWS flow to individual components does not render the SWS header inoperable.

Verify each SWS manual, power operated, and 92 days automatic valve in the flow path servicing safety related equipment, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.7.9.2 Verify each SWS automatic valve in the flow path 24 months that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

SR 3.7.9.3 Verify each SWS pump starts automatically on an 24 months actual or simulated actuation signal.

INDIAN POINT 3 3.7.9-3 lvnenanent 205

UHS 3.7.10 3.7 PLANT SYSTEMS 3.7.10 Ultimate Heat Sink (UHS)

LCO 3.7.10 The UHS shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. UHS temperature> A.1 Be in MODE 3. 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months 95°F.

AND OR -----NOTE--------

LCO 3.0.4.a is not UHS inoperable for applicable when reasons other than entering MODE 4.

temperature> 95°F.

A. 2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.10.1 Verify average water temperature of 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months UHS is ~ 95°F.

INDIAN POINT 3 3.7.10-1 Amendment 252

CRVS 3.7.11 3.7 PLANT SYSTEMS 3.7.11 Control Room Ventilation System (CRVS)

LCO 3.7.11 Two CRVS trains shall be OPERABLE.

- NOTE -

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

APPLICABILITY: MODES 1, 2, 3 and 4, During movement of recently irradiated fuel assemblies.

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

Condition B.

B. One or more CRVS trains B.1 Initiate action to implement Immediately inoperable due to mitigating actions.

inoperable CRE boundary in MODE 1, 2, 3, or 4. Al'JD B.2 Verify mitigating actions ensure CRE occupant exposures to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months radiological, chemical, and smoke hazards will not exceed limits.

AND B.3 Restore CRE boundary to OPERABLE status. 90 days C. Two CRVS trains inoperable C.1 Restore one CRVS train to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for reasons other than OPERABLE status.

Condition B INDIAN POINT 3 3.7.11-1 Amendment 239

CRVS

3. 7 .11 ACTIONS (continued)

D. Required Action and D. 1 Be in MODE 3 . 6 hours associated Completion Time of Condition A, B or C not AND met in Mode 1, 2, 3, or 4. -----NOTE------

LCO 3.0.4.a is not applicable when entering MODE 4.

D.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months E. One CRVS train inoperable E.1 Place OPERABLE CRVS train Irrmediately during movement of recently in pressurization mode.

irradiated fuel assemblies. OR E.2 Suspend movement of recently irradiated fuel assemblies. Irrmediately F. Two CRVS trains inoperable F.1 Suspend movement of Irrmediately during movement of recently recently irradiated irradiated fuel assemblies. fuel assemblies.

OR One or more CRVS trains inoperable due to an inoperable CRE boundary during movement of recently irradiated fuel assemblies.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.11.1 Operate each CRVS train for~ 15 minutes. 31 days SR 3.7.11.2 Perform required CRVS filter testing in In accordance accordance with the Ventilation Filter Testing with VFTP Program (VFTP) .

SR 3. 7 .11.3 Verify each CRVS train actuates on an actual or 24 months simulated actuation signal.

SR 3.7.11.4 Perform required CRE unfiltered air In accordance inleakage testing in accordance with the with the Control Control Room Envelope Habitability Room Envelope Program. Habitability Program INDIAN POINT 3 3.7.11-2 Amendment 252

CRACS 3.7.12 3.7 PLANT SYSTEMS 3.7.12 Control Room Air Conditioning System (CRACS)

LCO 3.7.12 Two CRACS trains shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3 and 4, ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CRACS train A.1 Restore CRACS 30 days inoperable. train to OPERABLE status.

B. Two CRACS trains B.1 Restore one CRACS 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. train to OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of AND

--

Condition A or B ----- NOTE -------

not met. LCO 3.0.4.a is not applicable when entering MODE 4.

C.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.12.1 Verify each CRACS train has the 24 months capability to remove the assumed heat load.

INDIAN POINT 3 3.7.12-1 Amendment 252

FSBEVS 3.7.13

3. 7 PLANT SYSTEMS

3. 7 .13 Fuel Storage Building Emergency Ventilation System (FSBEVS)

LCO 3.7.13 FSBEVS shall be OPERABLE.

APPLICABILITY: During movement of recently irradiated fuel assemblies in the fuel storage building.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. FSBEVS inoperable. A.1 Suspend movement of Immediately recently irradiated fuel assemblies in the fuel storage building.

u u

INDIAN POINT 3 3.7.13-1 Amendment 215

MAR 17 2003

FSBEVS 3.7.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.13.1 Verify FSBEVS charcoal filter bypass dampers are 92 days installed.

SR 3.7.13.2 Operate FSBEVS for~ 15 minutes. 31 days SR 3.7.13.3 Perform required FSBEVS filter testing in In accordance accordance with the Ventilation Filter Testing with the VFTP Program CVFTP).

SR 3. 7 .13.4 Verify FSBEVS actuates on an 92 days actual or simulated actuation signal.

SR 3.7.13.5 Verify FSBEVS can maintain a pressure 24 months

~ -0.125 inches water gauge with respect to atmospheric pressure during the post accident mode of-operation at a flow rate~ 20,000 cfm.

INDIAN POINT 3 3.7.13*2 Amenctnent 205

Spent Fuel Pit Water Level 3.7.14 3.7 PLANT SYSTEHS 3.7.14 Spent Fuel Pit Water Level LCO 3.7.14 The spent fuel pit water level shall be~ 23 ft over the top of irradiated fuel assemblies seated in the storage racks.

APPLICABILITY: During movement of irradiated fuel assemblies in the spent fuel pit.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIHE A. Spent fuel pit water A.l *********NOTE**********

level not within limit. LCO 3.0.3 is not applicable.

Suspend movement of

Inrnediately irradiated fuel assemblies in the spent fuel pit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.14.1 Verify the spent fuel pit water level is~ 23 ft 7 days above the top of the irradiated fuel assemblies seated in the storage racks.

INDIAN POINT 3 3.7.14*1 Arnenctnent 205

Spent Fuel Pit Boron Concentration 3.7.15 3.7 PLANT SYSTEMS

3. 7.15 Spent Fuel Pit Boron Concentration LCD 3.7.15 The Spent Fuel Pit boron concentration shall be~ 1000 ppm.

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

During inter-unit transfer of fuel the spent fuel pit boron concentration must also meet Appendix C LCD 3.1.1, "Boron Concentration".

APPLICABILITY: When fuel assemblies are stored in the spent fuel pit and a spent fuel pit verification has not been perfonned since the last movement of fuel assemblies in the spent fuel pit.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Spent fuel pit boron -----------NOTE----------

concentration not within LCO 3.0.3 is not applicable.

l i mi t.

A.1 Suspend movement of Immediately fuel assemblies in the spent fuel pit.

A.2.1 Initiate action to Immediately restore spent fuel pit boron concentration to within limit.

A.2.2 Initiate action to Immediately perfonn a spent fuel pit verification.

INDIAN POINT 3 3.7.15-1 l\mendment 246

Spent Fuel Pit Boron Concentration 3.7.15 SURVEILLANCE REQUIREHENTS

\ .

'\..__../

SURVEILLANCE FREQUENCY SR 3.7.15.1 Verify the spent fuel pit boron concentration is 31 days within limit.

I ,

~

INDIAN POINT 3 3.7.15-2 Amenanent 205

Spent Fuel Assembly Storage 3.7.16 3.7 PLANT SYSTEHS 3.7.16 Spent Fuel Assembly Storage LCO 3.7.16 Fuel assemblies stored in the spent fuel pit shall be classified in accordance with Figure 3.7.16*1 based on initial enrichment and burnup; and, Fuel assembly storage location within the spent fuel pit shall be restricted based on the Figure 3.7.16*1 classification as follows:

a. Fuel assemblies classified as Type 2 may be stored in any location in either Region 1 or Region 2;

b. Fuel assemblies classified as Type IA. 18 or IC shall be stored in Region 1;

c. Fuel assembly storage location within Region 1 shall be restricted as follows:

1. Type 1A assemblies may be stored anywhere in Region 1;

2. Type 18 assemblies may be stored anywhere in Region 1.

except a Type 18 assembly shall not be stored face-adjacent to a Type IC assembly;

3. Type IC assemblies shall not be stored in Row 64 or in Column ZZ; and

4. Type IC assemblies shall be stored in Region 1 locations

where all face-adjacent locations are as follows:

a) occupied by Type 2 or Type lA assemblies, or b) occupied by non-fuel components. or c) empty.

APPLICABILITY: Whenever any fuel assembly is stored in the spent fuel pit.

u INDIAN POIITT 3 3.7.16*1 Pmenonent 205

Spent Fuel Assembly Storage 3.7.16 ACTIONS CONDITION REQUIRED ACTION COHPLETION TIHE A. Requirements of the LCO A.l ---------NOTE----------

not met. LCO 3.0.3 is not applicable.

Initiate action to move Immediately fuel to restore compliance with LCO 3.7.16.

SURVEILLANCE REQUIREHENTS SURVEILLANCE FREQUENCY I ' SR 3.7.16.1 Verify by aaninistrative means the initial Prior to storing

\..J enrichment and burnup of each fuel assembly and the fuel assembly that the storage location meets LCO 3.7.16 in the spent fuel requirements. pit INDIAN POINT 3 3.7.16*2 Amenanent 205

Spent Fuel Assembly Storage 3.7.16 40000 -1

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Initia1 U-235 Enrichment (w/o)

Figure 3.7.16-1 (Page 1 of 1)

Fuel Assembly Classification for Storage in the Spent Fuel Pit

~!

INDIAN POINT 3 3.7.16*3 Amenonent 205

Secondary Specific Activity 3.7.17 3.7 PLANT SYSTEMS 3.7.17 Secondary Specific Activity LCO 3.7.17 The specific activity of the secondary coolant shall be~ 0.10 µCi/gn DOSE EQUIVALENT 1*131.

APPLICABILITY: HODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIHE A. Specific activity not A.l Be in HOOE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months within limit.

A.2 Be in HODE s.* 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.17.1 Verify the specific activity of the secondary 31 days coolant is~ 0.10 µCi/gn DOSE EQUIVALENT I-131.

INDIAN POINT 3 3.7.17*1 AmenO'llent 205

AC Sources - Operating 3.8.1 3.8 ELECTRICAL POWER SYSTEMS u 3.8.1 AC Sources - Operating LCO 3.8.1 The following AC electrical sources shall be OPERABLE:

a. Two qualified circuits between the offsite transmission network and the onsite Electrical Power Distribution System; and

b. Three diesel generators (DGs) (31, 32 and 33) capable of supplying the onsite power distribution subsystem(s)

Note------------------------

The 138 kV circuit is considered inoperable whenever the automatic transfer function for,the 6.9 kV buses is disabled.

APPLICABILITY: MODES 1, 2, 3, and 4.

u ACTIONS

Note-------------------------------

The LCO 3.0.4.b is not applicable to DGs or the 138kV offsite circuit.

CONDITION REQUIRED ACTION COMPLETION TIME A. One offsite A.1 Perform SR 3.8.1.1 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months circuit for OPERABLE offsite inoperable. circuit.

AND AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter (continued)

,,,,

\_J INDIAN POINT 3 3.8.1 - 1 Amendment 226

.,

AC Sources - Operating 3.8.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIHE A. (continued) *********NOTE***********

Only required if 13.8 kV offsite circuit is supplying 6.9 kV bus 5 or 6 and the Unit Auxiliary Transformer is supplying 6.9 kV bus 1, 2, 3 or 4.

A.2 Verify automatic transfer 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months of 6.9 kV buses 1, 2, 3, and 4 to 6.9 kV bus 5 and ANO

. 6 is disabled.

Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter V

A.3 Declare inoperable 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months from required feature(s) with discovery of no no offsite power automatically automatically available available offsite when its redundant power to one train required feature(s) is concurrent .with inoperable.

inoperability of redundant required feature(s)

A.4 Restore offsite circuit to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE status.

(continued)

INDIAN POINT 3 3.8.1-2 Amenonent 205

AC Sources - Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIHE.

B. One DG inoperable. B.1 Perform SR 3.8.1.1 for the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months offsite circuits.

Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter B.2 Declare inoperable the 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from required features discovery of supported by the Condition B inoperable DG when its concurrent with required redundant feature inoperability of is inoperable. redundant required feature MID B.3.1 Determine OPERABLE DG(s) 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

~I are not inoperable due to c011111on cause failure.

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

MID B.4 Restore DG to OPERABLE 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months status.

(continued)

INDIAN POINT 3 3.8.1-3 Arnendnent 205

AC Sources -Operating 3.8.1 ACTIONS {continued)

CONDITION REQUIRED ACTION COMPLETION TIHE C. Two offsite circuits C.1 Declare required features 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months from inoperable. inoperable when its discovery of redundant required feature Condition C is inoperable. concurrent with inoperability of redundant required M:!Q feature C.2 Restore one offsite 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months circuit to OPERABLE status.

0. One offsite circuit ***********NOTE**********

inoperable. Enter applicable Conditions and Required M:!Q Actions of LCO 3.8.9, "Distribution One 0G inoperable. Systems-Operating," when Condition Dis entered*

with no offsite or 0G AC power source automatically available to any train .

..*..**...**...*...*.....

0.1 Restore offsite circuit to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months OPERABLE status.

QR 0.2 Restore 0G to OPERABLE 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months status.

{continued)

INDIAN POINT 3 3.8.1-4 Amenanent 205

AC Sources - Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Two or more DGs E.l Restore at least two 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months inoperable. DGs to OPERABLE status.

F. Required Action F.l Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and associated Completion Time AND

- - --- NOTE ----

of Condition A, B, C, D, or E not LCO 3.0.4.a is not met. applicable when entering MODE 4.

F.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months G. One or more G.l Enter LCO 3.0.3. Immediately offsite circuits and two DGs inoperable.

H. Two offsite H.l Enter LCO 3.0.3. Immediately circuits and one or more DGs inoperable.

INDIAN POINT 3 3.8.1 - 5 Amendment 252

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREHENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated 7 days power availability for each offsite circuit.

SR 3.8.1.2 *********************NOTE***********************

All DG starts may be preceded by an engine prelube period.

Verify each DG starts from standby conditions and 31 days achieves:

a. in~ 10 seconds, voltage~ 422 V and frequency~ 58.8 Hz: and

b. steady state voltage~ 422 V and~ 500V, and frequency~ 58.8 Hz and~ 61.2 Hz.

SR 3.8.1.3 *********************NOTES*********************

1. DG loadings may include gradual loading as recommended by the manufacturer.

2. Momentary transients outside the load range do not invalidate this test.

3. This SR shall be conducted on only one DG at a time.

4. This SR sha11 be preceded by and irrmediately follow without shutdown a successful performance of SR 3.8.1.2.

Verify each DG is synchronized and loaded and 31 days operates for~ 60 minutes at a load~ 1575 kW and

~ 1750 kW. .

(continued)

INDIAN POINT 3 3.8.1-6 Amendment 205

AC Sources Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.4 Verify each day tank contains~ 115 gal of fuel 31 days oi 1.

SR 3.8.1.5 Check for and remove accumulated water from 31 days each day tank.

SR 3.8.1.6 Verify the fuel oil transfer system operates to 31 days automatically transfer fuel oil from DG storage tank to the day tank.

SR 3.8.1.7 --------------------NOTE-----------------------

This Surveillance shall not normally be performed in MODE 1 or 2. However this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

Verify manual transfer of AC power sources from 24 months the normal offsite circuit to the alternate offsite circuit.

INDIAN POINT 3 3.8.1 - 7 Amendment 242

AC Sources Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.8 --------------------NOTES----------------------

1. This Surveillance shall not normally be performed in MODE 1 or 2. However this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

2. Only required to be met if 138 kV offsite circuit is supplying 6.9 kV bus 5 and 6 and the Unit Auxiliary Transformer is supplying 6.9 kV bus 2 or 3.

Verify automatic transfer of AC power 24 months for 6.9 kV buses 2 and 3 from the unit auxiliary transformer to 6.9 kV buses 5 and 6.

SR 3.8.1.9 --------------------NOTE-----------------------

This Surveillance shall not normally be performed in MODE 1 or 2. However this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

Verify each DG 1 s automatic trips are bypassed 24 months on actual or simulated loss of voltage signal on the emergency bus concurrent with an actual or simulated ESF actuation signal except:

a. Engine overspeed;

b. Low lube oil pressure; and

c. Overcrank relay.

INDIAN POINT 3 3.8.1 - 8 Amendment 242

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.10 -----------------------NOTES-------------------------

1. Momentary transients outside the load and power factor ranges do not invalidate this test.

2. This Surveillance shall not normally be performed in MODE 1 or 2. However this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

3. If performed with DG synchronized with offsite power, it shall be performed at a power factor of

~ 0.85 for EOG 31, ~ 0.87 for EOG 32, and~ 0.84 for EOG 33. However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable.

4. Prior to performing SR 3.8.1.10 while connected to the 13.8 kV offsite power, the grid condition must be evaluated to show that conditions exist to reasonably allow the required power factor limits to be met or perform the SR while connected to the 138 kV offsite power.

Verify each DG operates for~ 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months s: 24 months

a. For ~ 105 minutes loaded ~ 1925kW and

~ 1941 kW; and

b. For the remaining hours of the test loaded

~ 1700kW and~ 1750 kW.

SR 3.8.1.11 ----------------------NOTE----------------------------

Load timers associated with equipment that has automatic initiation capability disabled are not required to be operable.

Verify each time delay relay functions within the 18 months required design interval.

(continued)

INDIAN POINT 3 3.8.1 - 9 Amendment 242

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SR 3.8.1.12 ---------------------NOTES---------------------

1. All DG starts may be preceded by an engine prelube period.

2. This Surveillance shall not normally be performed in MODE 1. 2. 3 or 4. However 0

portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

3. This SR may be performed on safeguards power trains one at a time, or simultaneously. Appropriate plant conditions must be established when testing three safeguards power trains simultaneously.

Verify on an actual or simulated loss of 24 months offsite power signal in conjunction with an actual or simulated ESF actuation signal:

a. De-energization of emergency buses;

b. Load shedding from emergency buses; and

c. DG auto-starts from standby condition and:

1. energizes permanently connected loads ins 10 seconds.

2. energizes auto-connected emergency loads through individual load timers,

3. achieves steady state voltage~ 422 V ands 500 V,

4. achieves steady state frequency

~ 58.8 Hz ands 61.2 Hz, and

5. supplies permanently connected and auto-connected emergency loads for

~ 5 minutes.

(continued)

INDIAN POINT 3 3.8.1 - 10 Amendment 242

AC Sources Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.13 ---------------------NOTE----------------------

1. All DG starts may be preceded by an engine prelube period.

2. Performance of SR 3.8.1.12 may be used to satisfy the requirements of this SR if all three diesel generators are started simultaneous 1y.

Verify when started simultaneously from standby 10 years condition, each DG achieves:

a. in~ 10 seconds, voltage~ 422 V and frequency~ 58.8 Hz; and

b. steady state voltage~ 422 V and~ 500V, and frequency~ 58.8 Hz and~ 61.2 Hz.

INDIAN POINT 3 3.8.1-11 Amendment 242

AC Sources - Shutdown 3.8.2 3.8 ELECTRICAL POWER SYSTEHS 3~ 8. 2 AC Sources - Shutdown LCO 3.8.2 The following AC electrical power sources shall be OPERABLE:

a. One qualified circuit between the*offsite transmission network and the onsite AC electrical power distribution subsystem(s) required by LCO 3.8.10, "Distribution Systems-Shutdown": and b.1 Two diesel generators CDGs) capable of supplying two safeguards power trains of the onsite AC electrical power distribution subsystem(s) required by LCO 3.8.10: or b.2. One DG capable of supplying necessary portions of the onsite AC electrical power distribution subsytems required by LCO 3.8.10 provided that:

Ca) The reactor has been subcritical for at least 5 days.and Cb) The water level in the refueling cavity is~ 23 feet V above the reactor vessel flange, or there is no fuel in the reactor vessel and the refueling cavity.

APPLICABILITY: HODES 5 *and 6, During movement of irradiated fuel assemblies.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIHE A. One required offsite .---* ----* ----NOTE* * * * * * * * * * * * * *

circuit inoperable. Enter applicable Conditions and Required Actions of LCO 3.8.10, with any required bus de-energized as a result of Condition A.

(continued)

~/

INDIAN POINT 3 3.8.2-1 /wendnent 205

AC Sources - Shutdown 3.8.2

~I ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.1 (contil')ued) A.1 Declare affected I11111ediately required feature(s) with no offsite power available inoperable.

QR A.2.1 Suspend CORE I11111ediately ALTERATIONS.

M:iQ A.2.2 Suspend movement of I11111ediately irradiated fuel assemblies.

M:iQ A.2.3 Initiate action to I11111ediately V suspend operations involving positive reactivity additions.

M:iQ A.2.4 Initiate action to I11111ediately restore required offsite power circuit to OPERABLE status.

(continued)

INDIAN POINT 3 3.8.2-2 Amencknent 205

AC Sources - Shutdown 3.8.2 ACTIONS

- CONDITION REQUIRED ACTION COHPLETION TI HE B. Required DG(s) inoperable B.1 Suspend CORE Invnediately ALTERATIONS.

B.2 Suspend movement of Invnediately irradiated fuel assemblies.

MID

B.3 Initiate action to Invnediately suspend operations involving positive reactivity additions.

MID,

\.J B.4 Initiate action to Invnediately restore required DGCs) to OPERABLE status.

u INDIAN POINT 3 3.8.2-3 Arnenanent 205

AC Sources - Shutdown 3.8.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.2.1 -*-------------*----NOTES-----------------------

1. The following SRs are required to be met but are not required to be performed:

SR 3.8.1.3. SR 3.8.1.10. SR 3.8.1.11. and SR 3.8.1.12.

2. Portions of SR 3.8.1.12 regarding an actual or simulated ESF actuation signal are not required to be met.

For AC sources required to be OPERABLE. the SRs In accordance of Specification 3.8.1. "AC Sources-Operating." with applicable except SR 3.8.1.8, SR 3.8.1.9. and SR 3.8.1.13. SRs are applicable.

V INDIAN POINT 3 3.8.2-4 Amenanent 205

Diesel Fuel Oil and Starting Air 3.8.3 3.8 ELECTRICAL POWER SYSTEMS 3.8.3 Diesel Fuel Oil and Starting Air LCO 3.8.3 The stored diesel fuel oil and starting air subsystem shall be within limits for each required diesel generator (DG).

APPLICABILITY: When associated DG is required to be OPERABLE.

ACTIONS

*------------------------------NOTE---------------------*----------------------

Separate Condition entry is allowed for each DG.

CONDITION REQUIRED ACTION COMPLETION TI HE A. ----------NOTE---------- A.1 Declare associated DG Immediately Only applicable in inoperable.

HODES 1, 2, 3 and 4.

........*.....*.........

One or more DGs with usable fuel oil in associated DG fuel oil storage tank< 5365 gal.

B. ----------NOTE---------- 8.1 Deel are all DGs Immediately Only applicable in inoperable.

HODES 5 and 6 and during movement of irradiated fuel *

......................*.

Total combined usable fuel oil in DG fuel oil storage tanks associated with the operable DGCs)

< 5365 gal.

(continued)

INDIAN POINT 3 3.8.3-1 Amendnent 205

Diesel Fuel Oil and Starting Air 3.8.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TI HE C. * ********NOTE*********.** C.1 Deel are all DGs I11111ediately Only applicable in HODES inoperable.

1, 2, 3 and 4*

....*.......**..........

Total useable fuel oil in reserve storage tank(s)

< 26,826 gal.

D. One or more 0G fuel oil D.1 Restore fuel oil total 7 days for DG fuel storage tanks or reserve particulates within oil storage tank fuel oil storage tanks limit.

with fuel oil total Mm particulates not within limits. 30 days for reserve fuel oil storage tank E. One or more DG fuel oil E.1 Restore fuel oil 30 days for DG storage tanks or reserve properties to within fuel oil storage fuel oil storage tanks limits. tank with fuel oil properties other than particulates Mm not within limits.

60 days for reserve fuel oil storage tank F. One or more DGs with F.1 Restore starting air 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months starting air receiver receiver pressure to pressure< 250 psig and*~ ~ 250 psig.

90 psig.

(continued)

INDIAN POINT 3 3.8.3*2 Amencinent 205

Diesel Fuel Oil and Starting Air 3.8.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COHPLETION TI HE G.1 Declare associated 0G Invnediately G. Required Action and inoperable.

associated Completion Time not met.

One or more DGs diesel fuel oil or starting air subsystem not within limits for reasons other than Condition A, 8, C, D, E, or F.

INDIAN POINT 3 3.8.3-3 ,dmendnent 205

Diesel Fuel Oil and Starting Air 3.8.3 SURVEILU\NCE REQUIREMENTS SURVEILU\NCE FREQUENCY SR 3.8.3.1 *********************NOTE**********************

Only required in HODES 1, 2, 3 and 4.

Verify reserve storage tank(s) contain 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

~ 26,826 gal of fuel oil reserved for IP3 usage only.

SR 3.8.3.2 Verify DG fuel oil storage tanks contain: 31 days

a. Usable fuel oil volume~ 5365 gal in each storage tank when in HODES 1, 2, 3 and 4:

and

b. Total combined usable fuel oil volume

~ 5365 gal in any DG fuel oil storage u tank(s) that are associated with the operable DG(s) when in HODES 5 and 6 and during movement of irradiated fuel assemblies.

SR 3.8.3.3 Verify that fuel oil properties of new and stored In accordance fuel oil in the DG fuel oil storage tanks are with the Diesel tested and maintained in accordance with the Fuel Oil Testing Diesel Fuel Oil Testing Program. Program (continued) u INDIAN POINT 3 3.8.3*4 Amenanent 205

Diesel Fuel Oil and Starting Air 3.8.3 SURVEILLANCE REQUIREHENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.3.4 *********************NOTE**********************

Only required in HODES 1, 2, 3 and 4.

In accordance Verify that fuel oil properties in the reserve with the Diesel storage tankCs) are within limits specified in Fuel Oil Testing the Diesel Fuel Oil Testing Program. Program SR 3.8.3.5 Verify each DG air start receiver pressure is 31 days

~ 250 psig.

SR 3.8.3.6 Check for and remove accumulated water from each 92 days DG fuel oil storage tank.

u u

INDIAN POINT 3 3.8.3*5 Amenanent 205

DC Sources - Operating 3.8.4 3.8 ELECTRICAL POWER SYSTEMS 3.8.4 DC Sources - Operating LCO 3.8.4 The following four DC electrical power subsystems shall be OPERABLE:

Battery 31 and associated Battery Charger; Battery 32 and associated Battery Charger; Battery 33 and associated Battery Charger; and Battery 34.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. DC electrical power A.1 Declare Inverter 34 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months subsystem 34 inoperable and take Inoperable. Required Actions specified in LCO

3. 8. 7, Inverters-Operating.

B. One DC electrical B.l Restore DC 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months power subsystem (31 electrical power or 32 or 33) subsystem to inoperable. OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Associated Completion Time not AND

--

met. --- NOTE ----

LCO 3.0.4.a is not applicable when entering MODE 4.

C.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months INDIAN POINT 3 3.8.4-1 Amendment 252

DC Sources - Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify battery terminal voltage on float charge 31 days is within the following limits:

a. ~ 125.7 V for battery 31;

b. ~ 123.5 V for battery 32; and

c. ~ 127.8 V for batteries 33 and 34.

SR 3.8.4.2 ---------------------NOTE----------------------

This Surveillance shall not normally be performed in MODE l, 2, 3, or 4. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

Verify each battery charger supplies its 24 months associated battery at the voltage and current adequate to demonstrate battery charger capability requirements are met.

SR 3.8.4.3 ---------------------NOTES---------------------

This Surveillance shall not be performed in MODE 1, 2, 3, or 4.

Verify battery capacity is adequate to supply, and maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test or a modified performance discharge test. 24 months (continued)

INDIAN POINT 3 3.8.4 - 2 Amendment 242

DC Sources - Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued) u SURVEILLANCE FREQUENCY

, .. .,.

SR 3.8.4.4 ---------------------NOTE----------------------

This Surveillance shall not be perfonned in MODE 1, 2, 3, or 4.

Verify battery capacity is~ 80% of the 60 months manufacturer's rating when subjected to a perfonnance discharge test or a modified perfonnance discharge test.

12 months when battery shows degradation or has reached 85%

of expected life with capacity

< 100% of manufacturer's rating u 24 months when battery has reached 85% of the expected life with capacity

~ 100% of manufacturer's rating SR 3.8.~.5 Verify battery cells, cell plates, and racks 24 months show no visual indication of physical damage or abnonnal deterioration.

INDIAN POINT 3 3.8.4 - 3 Amendment -~ 16 MAR 2 5 2003

DC Sources - Shutdown 3.8.5 3.8 ELECTRICAL POWER SYSTEMS 3.8.5 DC Sources-Shutdown LCO 3.8.5 DC electrical power subsystems shall be OPERABLE to support the DC electrical power distribution subsystems required by LCO 3.8.10, "Di stri buti on Systems - Shutdown."

APPLICABILITY: HODES 5 and 6, During movement.of irradiated fuel assemblies.

ACTIONS CONDITION *REQUIRED ACTION COMPLETION TIME A. One or more required DC A.1 Declare affected I11111ediately electrical power required feature(s) subsystems inoperable. inoperable.

\.__,,,J QR A.2.1 Suspend CORE I11111ediately ALTERATIONS.

Mm A.2.2 Suspend movement of I11111ediately i rr adi ated f ue1 assemblies.

-

Mm A.2.3 Initiate action to I11111ediately suspend operations involving positive reactivity additions.

Mm (continued)

INDIAN POINT 3 3.8.5-1 Amendment 205

DC Sources - Shutdown 3.8.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.4 Initiate action to Invnediately restore required DC electrical power subsystems to OPERABLE status.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.5.1 *********************NOTE**********************

The following SRs are not required to be performed: SR 3.8.4.2. SR 3.8.4.3. and SR 3.8.4.4.

For DC sources required to be OPERABLE. the In accordance following SRs are applicable: with applicable SRs SR 3.8.4.1 SR 3.8.4.3 SR 3.8.4.2 SR 3.8.4.4.

INDIAN POINT 3 3.8.5*2 Amendnent 205

Battery Cell Parameters 3.8.6 3.8 ELECTRICAL POWER SYSTEMS 3.8.6 Battery Cell Parameters LCO 3.8.6 Battery cell parameters for batteries 31, 32, 33 and 34 shall be within the limits of Table 3.8.6*1.

APPL! CAB I LITY: When associated DC electrical power subsystems are required to be OPERABLE.

ACTIONS

- - - - NOTE********************************************

Separate Condition entry is allowed for each battery.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more batteries A.1 Verify pilot cells 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with one or more battery electrolyte level and cell parameters not float voltage meet within Category A or B Table 3.8.6-1 Category C limits. limits.

AHO A.2 Verify battery cell 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months parameters meet Table 3.8.6-1 Category C AHO limits.

Once per 7 days thereafter

~

A.3 Restore battery cell 31 days parameters to Category A and B limits of Table 3.8.6* l.

Ccontinued)

INDIAN POINT 3 3.8.6*1 Amenanent 205

Battery Cell Parameters 3.8.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIHE B. Required Action and B.1 Declare associated Inrnediately associated Completion battery inoperable.

Time of Condition A not met.

One or more batteries with average electrolyte temperature of the representative cells not within limits of SR 3.8.6.3.

One or more batteries with one or more battery cell parameters not within Category C values.

INDIAN POINT 3 3.8.6-2 Amencinent 205

Battery Cell Parameters 3.8.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 Verify battery cell parameters meet Table 3.8.6-1 31 days Category A limits.

SR 3.8.6.2 Verify battery cell parameters meet Table 3.8.6*1 92 days Category B limits.

SR 3.8.6.3 Verify average electrolyte ternp*erature of 92 days representative cells is within the following limits:

a. ~ 60°F for batteries 31, 32 and 34; and

b. ~ 35°F for battery 33.

INDIAN POINT 3 3.8.6*3 Amenonent 205

Battery Cell Parameters 3.8.6 Table 3.8.6-1 (page 1 of 1)

Battery Cell Parameters Requirements CATEGORY A: CATEGORY C:

LI HITS FOR EACH CATEGORY B: ALLOWABLE LIMITS

. DESIGNATED PILOT LIMITS FOR EACH FOR EACH CONNECTED PARAMETER CELL CONNECTED CELL CELL Electrolyte Level > Hinimtnn level > Hinimtnn level Above top of indication mark, indication mark, plates, and not and-~~ inch above and~~ inch above over fl ow1 ng maximtnn level maximum level indication markCa) indication markCa)

'

Float Voltage ~ 2.13 V ~ 2.13 V > 2.07 V Specific ~ 1.205 ~ 1.195 Not more than 0.020 GravityCb)(c) below average of AHO all connected cells Average of all AHO connected cells

> 1.205 Average of all connected cells

~ 1.195 Ca) It is acceptable for the electrolyte level to temporarily increase above the specified maximum during.equalizing charges provided it is not overflowing.

Cb) Corrected for electrolyte temperature.

Cc) A battery charging current of <2 amps when on float charge is acceptable for meeting specific gravity limits following a battery recharge, for a maximum of 7 days. When charging current is used to satisfy specific*gravity requirements, specific gravity of each connected cell shall be measured prior to expiration of the 7 day allowance.

INDIAN POINT 3 3.8.6*4 Amenanent 205

Inverters - Operating 3_8.7 3.8 ELECTRICAL POWER SYSTEMS V 3.8. 7 Inverters -Operating LCO 3.8.7 Inverters 31. 32, 33 and 34 shall be OPERABLE: and Two constant voltage transformers CCVTs) capable of supplying 120 V AC vital instrument bus (VIB} 34 shall be OPERABLE.

APPLICABILITY: HODES 1, 2, 3, and 4.

ACTIONS

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

Enter applicable Conditions and Required Actions of LCO 3.8.9, "Distribution Systems - Operating" with any required bus de-energized.

CONDITION REQUIRED ACTION COMPLETION TIME A. One required CVT A.l Restore CVT to OPERABLE 30 days inoperable. status.

B. Two required CVTs B.1 Restore one CVT to 7 days inoperable. OPERABLE status.

(continued) u INDIAN POINT 3 3.8.7-1 Amencinent 205

Inverters - Operating 3.8.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One inverter C.1 ----NOTE---------

inoperable. Only applicable to feature(s) that require power to perform the required safety function.

Declare required 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months from feature(s) discovery of supported by Condition C associated concurrent with inverter inoperability of inoperable when redundant the required required redundant feature(s) feature(s) is inoperable.

AND C. 2 Restore inverter to 7 days OPERABLE status.

D. Required Action and D.l Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not AND met. ----- NOTE --

LCO 3.0.4.a is not applicable when entering MODE 4.

D.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months INDIAN POINT 3 3.8.7-2 Amendment 252

Inverters - Operating 3.8.7*

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct inverter voltage, frequency, 7 days and alignment to required 120V AC vital instrument buses.

SR 3.8.7.2 Verify manual transfer of the AC power source 24 months for VIB 34 from inverter 34 to each required CVT.

INDIAN POINT 3 3.8.7 - 3 Amendment 234

Inverters - Shutdown 3.8.8 3.8 ELECTRICAL POWER SYSTEHS V

3.8.8 Inverters -Shutdown LCD 3.8.8 Inverters shall be OPERABLE to support the onsite 120 V AC vital instrument bus CVIB) electrical power distribution subsystems re qui red by LCD 3. 8 .10. "Di stri buti on Systems - Shutdown."

APPLICABILITY: HODES 5 and 6.

During movement of irradiated fuel assemblies.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIHE A. One or more required A.l Declare affected Immediately inverters inoperable. required feature(s) inoperable.

\_/' QR A.2.1 Suspend CORE Immediately ALTERATIONS.

A.2.2 Suspend movement of Immediately irradiated fuel assemblies.

A.2.3 Initiate action to Immediately suspend operations involving positive reactivity additions.

(continued)

INDIAN POINT 3 3.8.8*1 /iJnenanent 205

Inverters - Shutdown 3.8.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.4 Initiate action to Irrmediately restore required inverters to OPERABLE status.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 ******************NOTE******************

Frequency verification not required to be performed for inverter 34.

Verify correct inverter voltage. frequency. and 7 days alignments to required 120 V AC vital instrument buses.

u INDIAN POINT 3 3.8.8*2 Amendnent 205

Di stri buti on Systems - Operating 3.8.9 3.8 ELECTRICAL POWER SYSTEMS

\__,,,1 3.8.9 Distribution Systems-Operating LCO 3.8.9 AC. DC. and 120 V AC vital instrument bus VIB electrical power distribution subsystems for safeguards power trains 5A, 6A and 2A/3A shall be OPERABLE.

APPLICABILITY: HODES 1, 2. 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIHE A. One AC electrical power A.I Restore AC electrical 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months distribution subsystem power distribution inoperable With no loss* subsystem to OPERABLE Mm of safety function. status.

16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months from discovery of failure to meet LCO B. One VIB inoperable with B.1 Restore VIB to OPERABLE 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months no loss of safety status.

function. Mm 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months from discovery of failure to meet LCO (continued) t J

~

INDIAN POINT 3 3.8.9*1 .Amenanent 205

Distribution Systems - Operating 3.8.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One DC electrical C.1 Restore DC 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months power distribution electrical power subsystem distribution AND inoperable with no subsystem to loss of safety OPERABLE status. 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months from function. discovery of failure to meet LCO D. Required Action D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and associated Completion Time AND not met. -----NOTE-------

LCO 3.0.4.a is not applicable when entering MODE 4.

D.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months E. One or more trains E.1 Enter LCO 3.0.3. Immediately with inoperable distribution subsystems that result in a loss of safety function.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.9.1 Verify correct breaker alignments and 7 days voltage to required AC, DC, and VIB electrical power distribution subsystems.

INDIAN POINT 3 3.8.9 - 2 Amendment 252

Di stri buti on Systems - Shutdown 3.8.10 3.8 ELECTRICAL POWER SYSTEMS

3. 8.10 Di stri buti on Systems - Shutdown LCO 3.8.10 The necessary portion of AC, DC, and 120 V AC vital instrument bus CVIB) electrical power distribution subsystems shall be OPERABLE to support equipment required to be OPERABLE.

APPLICABILITY: HODES 5 and 6, During movement of irradiated fuel assemblies.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TI HE A. One or more required AC, A.1 Declare associated Immediately DC, or AC vital supported required instrument bus electrical feature(s) inoperable.

power distribution

\.__J subsystems inoperable. 08 A.2.1 Suspend CORE Immediately ALTERATIONS.

MfQ A.2.2 Suspend movement of Invnediately irradiated fuel assemblies.

MfQ A.2.3 Initiate action to Immediately suspend operations involving positive reactivity additions.

~

(continued) u INDIAN POINT 3 3.8.10*1 Amendment 205

Di stri buti on Systems - Shutdown 3.8.10 ACTIONS CONDITION REQUIRED ACTION COHPLETION TIHE A. (continued) A.2.4 Initiate actions to I11111ediately restore required AC. DC, and AC vital instrument bus electrical power distribution subsystems to OPERABLE status.

A.2.5 Declare associated Immediately required residual heat removal subsystem(s) inoperable and not in operationi SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.10.1 Verify correct breaker alignments and voltage to 7 days required AC. DC. and 120 V AC vital instrument bus CVIB) electrical power distribution subsystems.

INDIAN POINT 3 3.8.10*2 Amendnent 205

Boron Concentration 3.9.1 3.9 REFUELING OPERATIONS 3.9.1 Boron Concentration LCO 3.9.1 Boron concentrations of the Reactor *coolant System and the refueling cavity shall be maintained within the limit specified in the COLR.

APPLICABILITY: HOOE 6.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Boron concentration not A.l Suspend CORE Inrnediately within limit. ALTERATIONS.

Arm A.2 Suspend positive Inmedi ately

'

\.J I

reactivity additions.

Arm A.3 Initiate action to Inrnediately restore boron concentration to within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Verify boron.concentration is within the limit 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months specified in COLR.

INDIAN POINT 3 3.9.1*1 Amendment 205

Nuclear Instrumentation 3.9.2 3.9 REFUELING OPERATIONS 3.9.2 Nuclear Instrumentation LCO 3.9.2 Two source range neutron flux monitors shall be OPERABLE.

APPLICABILITY: MODE 6.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required source range A.I Suspend CORE I11111ediately neutron flux monitor ALTERATIONS.

inoperable.

MID A.2 Suspend positive I11111ediately reactivity additions.

B. Two required source range B.1 Initiate action to I11111ediately neutron flux monitors restore one source range inoperable. neutron flux monitor to OPERABLE status.

MID B.2 Perform SR 3.9.1.1. Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months INDIAN POINT 3 3.9.2*1 Amenctnent 205

Nuclear Instrumentation 3.9.2 SURVEILLANCE REQUIREHENTS u SURVEILLANCE FREQUENCY SR 3.9.2.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.9.2.2 *******************NOTE********************

Neutron detectors are excluded from CHANNEL CALIBRATION.

- - - - -~-

Perform CHANNEL CALIBRATION. 24 months u

INDIAN POINT 3 . 3.9.2*2 /vnenonent 205

Containment Penetrations 3.9.3 3.9 REFUELING OPERATIONS 3.9.3 Containment Penetrations LCO 3.9.3 The containment penetrations shall be in the following status:

a. The equipment hatch closed and held in place by at least four bolts or the equipment hatch opening is closed using an equipment hatch closure plate that may include a personnel access door that is capable of being closed;

b. One door in each air lock is capable of being closed;

c. Each penetration providing direct access from the containment atmosphere to the outside atmosphere either:

1. closed by a manual or automatic isolation valve, a blind flange, or equivalent, or

2. capable of being closed by OPERABLE Containment Purge Isolation System.

-~--------------------------NOl'E----------------~~~--~~-

Penetration flow path(s) providing direct access from the containment atmosphere to the outside atmosphere may be unisolated under administrative controls.

APPLICABILITY: During movement of recently irradiated fuel assemblies within containment.

INDJAN PO!NT 3 3.9.3-1 Amendment 215 MAR 17 2003

___ _____ ___

..,- , __,,,_ ----* .

Containment Penetrations 3.9.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A One or more containment A.1 Suspend movement of Immediately penetrations not in recently irradiated fuel required status. assemblies within containment u

INDIAN POINT 3 3.9.3-2 Amendment* 21.5 MAR 1 7 2003

Containment Penetrations 3.9.3 u SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Verify each required containment penetration is in the 7 days required status.

SR 3.9.3.2 Verify each required containment purge system valve 92 days actuates to the isolation position on an actual or simulated actuation signal.

u INDIAN POINT 3 3.9.3-3 Amendment Zl.5 MAR 17 2003

RHR and Cool ant Ci rcul ati on - High Water Level 3.9.4 3.9 REFUELING OPERATIONS 3.9.4 Residual Heat Removal CRHR) and Coolant Circulation-High Water Level LCO 3.9.4 One RHR loop shall be OPERABLE and in operation.

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

The required RHR loop may not be in operation for~ 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period, provided no operations are permitted that would cause reduction of the Reactor Coolant System boron concentration.

APPLICABILITY: HOOE 6 with the water level ~ 23 ft above the top of reactor vessel flange.

"ACTIONS CONDITION REQUIRED ACTION COMPLETION TIHE

\_) A. RHR loop requirements not A.1 Suspend operations Inrnediately met. involving a reduction in reactor coolant boron concentration.

MID A.2 Suspend loading Inrnediately irradiated fuel assemblies in the core.

MID A.3 Initiate action to Inrnediately satisfy RHR loop requirements.

(continued)

INDIAN POINT 3 3.9.4-1 .Amenanent 205

RHR and Coolant Circulation-High Water Level 3.9.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.4 Close all containment 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months penetrations providing direct access from containment atmosphere to outside atmosphere.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.4.1 Verify one RHR loop is in operation and 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

circulating reactor coolant at a flow rate of

l! 1000 gpm.

INDIAN POINT 3 3.9.4-2 Amendment 205

Residual Heat Removal CRHR) and Cool ant Ci rcul ati on - Low Water Level 3.9.5 3.9 REFUELING OPERATIONS 3.9.5 Residual Heat Removal CRHR) and Coolant Circulation-Low Water Level LCO 3.9.5 Two RHR loops shall be OPERABLE, and one RHR loop shall be in operation.

APPLICABILITY: MODE 6 with the water level< 23 ft above the top of reactor vessel flange.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Less than the required A.1 Initiate action to I11111ediately number of RHR loops restore required RHR OPERABLE. loops to OPERABLE status.

QR A.2 Initiate action to I11111ediately establish~ 23 ft of water above the top of reactor vessel flange.

B. No RHR loop in operation. B.1 Suspend operations Immediately involving a reduction in reactor coolant boron concentration.

Mm (continued)

INDIAN POINT 3 3.9.5-1 Amenanent 205

Residual Heat Removal CRHR) and Cool ant Ci rcul ati on - Low Water Level 3.9.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2 Initiate action to Inrnediately restore one RHR loop to operation.

B.3 Close all containment 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months penetrations providing direct access from containment atmosphere to outside atmosphere.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify one RHR loop is in operation and 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months circulating reactor coolant at a flow rate of

!: 1000 gpm.

SR 3.9.5.2 Verify correct breaker alignment and indicated 7 days power available to the required RHR pump that is not in operation.

u INDIAN POINT 3 3.9.5-2 Amendnent 205

. Refueling Cavity Water Level 3.9.6 3.9 REFUELING OPERATIONS I '

'-._/

3.9.6 Refueling Cavity Water Level LCO 3.9.6 Refueling cavity water level shall be maintained.~ 23 ft above the top of reactor vessel flange.

APPLICABILITY: During CORE ALTERATIONS, except during latching and unlatching of control rod drive shafts, During movement of irradiated fuel assemblies within containment.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refueling cavity water A.1 Suspend CORE Inrnedi ately level not within limit. ALTERATIONS.

A.2 Suspend movement of Inrnedi atel y i rr adi ated fuel assemblies within containment.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify refueling cavity water level is~ 23 ft 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months above the top of reactor vessel flange.

INDIAN POINT 3 3.9.6*1 Amenonent 205

Design Features 4.0 4.0 DESIGN FEATURES 4.1 Site Location Indian Point 3 is located on the east bank of the Hudson River at Indian Point, Village of Buchanan, in upper Westchester County, New York. The site is approximately 24 miles north of the New York City boundary line. The nearest city is Peekskill which is 2.5 miles northeast of Indian Point.

The minimum distance from the reactor center line to the boundary of the site exclusion area and the outer boundary of the low population zone as defined in 10 CFR 100.3 is 350 meters and 1100 meters. respectively.

4.2 Reactor Core 4.2.1 Fuel Assemblies The reactor shall contain 193 fuel assemblies. Each assembly shall consist of a matrix of Zircalloy or ZIRLO clad fuel rods with an initial composition of natural or .slightly enriched uranium dioxide CU02) as fuel material. Reload fuel will have a U*235 enrichment of s 5.0 weight percent. limited substitutions of zirconium alloy or stainless *steel filler rods for fuel rods, in accordance with approved applications of fuel rod V configurations, may be used. Fuel assemblies shall be limited to those fuel designs that have been analyzed with applicable NRC staff approved codes and methods and shown by tests or analyses to comply with all fuel safety design bases. A limited number of lead test assemblies that have not completed representative testing may be placed in nonlimiting core regions.

4.2.2 Control Rod Assemblies The reactor core shall contain 53 control rod assemblies. The control material shall be silver indium cactnium, as approved by the NRC.

(continued)

INDIAN POINT 3 4.0-1 Amenctnent 205

Design Features 4.0 4.0 DESIGN FEATURES (continued) 4.3 Fuel Storage 4.3.1 Criticality 4.3.1.1 The spent fuel storage racks are designed and shall be maintained with:

a. Fuel assemblies having a maximum U-235 enrichment of 5.0 weight percent:

b. ke,, ~ 0.95 if assemblies are inserted in accordance with Technical Specification 3.7.16. Spent Fuel Assembly Storage.

c. A nominal 9.075 inch center to center distance between fuel assemblies placed in the high density fuel storage racks CRegi on II) :

d. A nominal 10.76 inch center to center distance between fuel assemblies placed in low density fuel storage racks (Region I):

u 4.3.1.2 The new fuel storage racks are designed and shall be maintained with:

a. Fuel assemblies having a maximum U-235 enrichment of 5.0 weight percent:

b. ke,, ~ 0.95 under all possible moderation conditions (Credit may be taken for burnable integral neutron absorbers):

c. A nominal 20.5 inch center to center distance between fuel assemblies placed in the storage racks.

4.3.2 Drainage The spent fuel pit is designed and shall be maintained to prevent inadvertent draining of the pool below a nominal elevation of 88 ft.

(continued)

INDIAN POINT 3 4.0*2 Amendnent 205

Design Features 4.0 4.0 DESIGN FEATURES 4.3 Fuel Storage (continued) 4.3.3 Capacity The spent fuel pit is designed and shall be maintained with a storage capacity limited*to no more than 1345 fuel assemblies.

u INDIAN POINT 3 4.0-3 Amenanent 205

Responsibility 5.1 5.0 ADMINISTRATIVE CONTROLS 5.1 Responsibility 5.1.1 The plant manager shall be responsible for overall unit operation and shall delegate in writing the succession to this responsibility during his absence.

The plant manager or his designee shall approve. prior to implementation, each proposed test. experiment or modification to systems or equipment that affect nuclear safety.

5.1.2 The shift supervisor CSS) shall be responsible for the control room COllllland function. During any absence of the SS from the control room while the unit is in HOOE 1. 2, 3, or 4. an individual with an a~tive Senior Reactor Operator (SRO) license shall be designated to assume the control room c011111and function. During any absence of the SS from the control room while the unit is in HOOE 5 or 6. an individual with an active SRO license or Reactor Operator license shall be designated to assume the control room command function.

INDIAN POINT 3 5.0*1 lwenanent 205

Organization 5.2 5.0 ADMINISTRATIVE CONTROLS 5.2 Organization 5.2.1 Onsite and Offsite Organizations Onsite and offsite organizations shall be established for unit operation and corporate management. respectively. The onsite and offsite organizations shall include the positions for activities affecting safety of the nuclear power plant.

a. Lines of authority. responsibility. and cofllllunication shall be defined and established throughout highest management levels, intermediate levels. and all operating organization positions. These relationships shall be documented and updated, as appropriate. in organization charts. functional descriptions of departmental responsibilities and relationships. and job descriptions for key personnel positions. or in equivalent forms of documentation. These requirements. including the plant specific titles of those personnel fulfilling the responsibilities of the positions delineated in these

.Technical Specifications. shall be documented in the FSAR and Quality Assurance Plan. as appropriate:

b. The plant manager shall be responsible for overall safe operation of V _the plant and shall have control over those onsite activities necessary for safe operation and maintenance of the plant:

c. The corporate officer with direct responsibility for the plant shall have corporate responsibility for overall plant nuclear safety and shall take any measures needed to ensure acceptable performance of the staff in operating. maintaining. and providing technical support to the plant to ensure nuclear safety; and

d. The individuals who train the operating staff. carry out health physics. or perform quality assurance functions may report to the appropriate onsite manager: however. these individuals shall have sufficient organizational freedom to ensure their independence from operating pressures.

(continued)

INDIAN POINT 3 5.0*2 twenonent 205

Organization 5.2 5.2 Organization 5.2.2 Unit Staff The unit staff organization shall include the following:

a. A non-licensed operator shall be assigned to each reactor containing fuel and an additional non-licensed operator shall be assigned for each control room from which a reactor is operating in MODES 1, 2, 3, or 4.

b. Shift crew composition may be less than the minimum requirement of 10 CFR 50.54(m}(2}(i) and 5.2.2.a and 5.2.2.f for a period of time not to exceed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months in order to accolllTlodate unexpected absence of on-duty shift crew members provided illlTlediate action is taken to restore the shift crew composition to within the minimum requirements.

c. A radiation protection technician shall be on site when fuel is in the reactor. The position may be vacant for not more than 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , in order to provide for unexpected absence, provided i11111ediate action is taken to fill the required position.

d. Not Used

- - - - - - - -.. (contiriued)

INDIAN POINT 3 5.0 - 3 Amendment 240

Organization 5.2 5.2 Organization * - - - - - - - - - - - - - - - - - - - - - - - - - - - -

5.2.2 Unit Staff (continued)

e. The operations manager or assistant operations manager shall hold an SRO license.

f. When in MODES 1, 2, 3, or 4 an individual shall provide advisory technical support to the unit operations shift crew in the areas of thermal hydraulics, reactor engineering, and plant analysis with regard to the safe operation of the unit. This individual shall meet the qualifications specified by ANSI/ANS 3.1-1993 as endorsed by RG 1.8, Rev. 3, 2000.

INDIAN POINT 3 5.0 - 4 Amendment 248

Unit Staff Qualifications 5.3 5.0 ADMINISTRATIVE CONTROLS lifications 5.3.1 Each member of the unit staff shall meet or exceed the minimum qualifications of ANSI/ANS 3.1-1978 for comparable positions with exceptions specified in the Entergy Quality Assurance Program Manual (QAPM).

5.3.2 For the purpose of 10 CFR 55.4, a licensed Senior Reactor Operator (SRO) and a licensed Reactor Operator (RO) are those individuals who, in addition to meeting the requirements of TS 5.3.1, perform the functions described in 10 CFR 50.54(m).

INDIAN POINT 3 5.0 - 5 Amendment 248

Procedures 5.4 5.0 ADMINISTRATIVE CONTROLS 5.4 Procedures 5.4.1 Written procedures shall be established, implemented, and maintained covering the following activities:

a. The applicable procedures recommended in Regulatory Guide 1.33, Revision 2, Appendix A, February 1978;

b. The emergency operating procedures required to implement the requirements of NUREG-0737 and to NUREG-0737, Supplement 1, as stated in Generic Letter 82-33;

c. Quality assurance for effluent and environmental monitoring;

d. Fire Protection Program implementation; and

e. All programs specified in Specification 5.5.

INDIAN POINT 3 5.0 - 6 Amendment 234

Programs and Manuals 5.5 5.0 ADMINISTRATIVE CONTROLS 5.5 Programs and Manuals The following programs shall be established, implemented, and maintained.

5.5.1 Offsite Dose Calculation Manual COOCH>

.a. The ODCH shall contain the methodology and parameters used in the calculation of offsite doses resulting from radioactive gaseous and liquid effluents, in the calculation of gaseous and liquid effluent monitoring alarm and trip setpoints. and in the conduct of the radiological environmental monitoring program: and

b. The ODCH shall also contain the radioactive effluent controls and radiological envirorvnental monitoring activities, and descriptions of the information that should be included in the Annual Radiological Environmental Operating, and Radioactive Effluent Release Reports required by Specification 5.6.2 and Specification 5.6.3.

c. Licensee initiated changes to the ODCH:

1. Shall be documented and records of reviews performed shall be V retained. This documentation shall contain:

Ca) Sufficient information to support the change(s) together with the appropriate analyses or evaluations justifying the change(s), and Cb) A determination that the change(s) maintain the levels of radioactive effluent control required by 10 CFR 20.1302, 40 CFR 190, 10 CFR 50.36a, and 10 CFR 50, Appendix I, and not adversely impact the accuracy or reliability of effluent, dose. or setpoint calculations:

2. Shall become effective after the approval of the plant manager:

and

3. Shall be submitted to the NRC*in the form of a complete, legible copy of the entire ODCH as a part of or concurrent with the Radioactive Effluent Release Report for the period of the report (continued)

(_j INDIAN POINT 3 5.0*7 *1vnendment 205

Programs and Manuals 5.5 5.5 Programs and Manuals V

\

5.5.1 Offsite Dose Calculation Manual CPDCH> (continued>

in which any change in the ODCH was made. Each change shall be identified by markings in the margin of the affected pages, clearly indicating the area of the page that was changed. and shall indicate the date (i.e .* month and year) the change was implemented.

5.5.2 Primary Coolant Sources Outside Containment This program provides controls to minimize leakage from those portions of systems outside containment that could contain highly radioactive fluids during a serious transient or accident to levels as low as practicable. The systems include the following:

a. Residual Heat Removal System:

b. Cross Connect Between Low Head Recirculation System and High Head Safety Injection System:

C. High Head Safety Injection system (partial):

d. Reactor Coolant Sampling System:

e. Post Accident Containment Air Sampling System:

f. Volume Control Tank (including Reactor Coolant Pump seal return line):

g. Containment Hydrogen Monitoring system.

The program shall include the following:

a. Preventive maintenance and periodic visual inspection requirements:

and

b.

Integrated leak test requirements for each system at refueling cycle intervals or less.

(continued)

INDIAN POINT 3 5.0-8 Amencinent 205

?=-og=a::-s a'"l.d 1"..a.~uals 5.5 V 5.5.3 N'.JI' USED 5.5.4 Radioactive Effluent ccntrols P:n;g;c:Aa nris progiam canfonrs to 10 CFR 50.36a for the control of radioactive effluents and for maintaining the doses to ma:rbers of the public £ran radioactive effluents as lc:M as reasonably achievable. The progiam shall u be contained in the ODCM, shall be inplsrented by procedures, and shall include rsoodial actions to be taken whenever the program limits are exceeded. The progiam shall include the follc:Ming elements:

a. Limitations on the ftmctional capability of radioactive liquid and gaseous m:initoring instnnrentaticn including surveillance tests and setpoint determination in accordance with the zrethodology in the Orx:M;

b. Limitations on the concentrations of radioactive material released in liquid effluents to unrestricted areas, canfcmning to 10 timas the concentration values in 10 CFR 20, .Appendix B, Table 2, Colunn 2;

c. M:Jnitoring, sanpling, and analysis of radioactive liquid and gaseous effluents in accordance with 10 CFR 20.1302 and with the zrethodology and pararreters in the CIXM;

<continued}

INDIAN romr 3 5.0 - 9 Amendrrent ~ . 2 1 0

---~--..;.L.:...-.. . _____ - - - ~ . . .-.. ---=--

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.4 Radioactive Effluent Controls Program (continued)

d. . Limitations on the annual and quarterly doses or dose commitment to a member of the public from radioactive materials in liquid effluents released from each unit to unrestricted areas, conforming to 10 CFR 50, Appendix I;

e. Determination of cumulative dose contributions from radioactive effluents for the current calendar quarter and current calendar year in accordance with the methodology and parameters in the ODCM at least every 31 days. Determination of projected dose contributions from radioactive effluents in accordance with the methodology in the ODCM at 1east every 31 days;

f. Limitations on the functional capability and use of the liquid and gaseous effluent treatment systems to ensure that appropriate portions of these systems are used to reduce releases of radioactivity when the projected doses in a period of 31 days would exceed 2% of the guidelines for the annual dose or dose commitment, conforming to 10 CFR 50, Appendix I;

g. Limitations on the dose rate resulting from radioactive material released in gaseous effluents from the site to areas at or beyond the site boundary shall be limited to the following:

a. For noble gases: Less than or equal to a dose rate of 500 mrem/yr to the whole body and less than or equal to a dose rate of 3000 mrem/yr to the skin, and

b. For iodine-131, tritium, and for all radionuclides in particulate form with half-lives greater than 8 days: Less than or equal to dose rate of 1500 mrem/yr to any organ.

h. Limitations on the annual and quarterly air doses resulting from noble gases released in gaseous effluents from each unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I; (continued)

INDIAN POINT 3 5.0 - 10 Amendment 232

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.4 Radioactive Effluent Controls Program (continued)

i. Limitations on the annual and quarterly doses to a member of the public from iodine-131, tritium, and.all radionuclides in particulate form with half lives> 8 days in gaseous effluents released from each unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I; and

j. Limitations on the annual dose or dose commitment to any member of the public, beyond the site boundary due to releases of radioactivity and to radiation from uranium fuel cycle sources, conforming to 40 CFR 190.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Radioactive Effluents Controls Program surveillance frequency.

5.5.5 Component Cyclic or Transient Limit This program provides controls to track the FSAR, Section 4.1.5, cyclic and

. transient occurrences to ensure that components are maintained within the design limits.

5.5.6 Reactor Coolant Pump Flywheel Inspection Program This program shall provide for the inspection of each reactor coolant pump flywheel. The program shall include inspection frequencies and acceptance criteria. The inspection frequency will ensure that each reactor coolant pump flywheel is surface and volumetrically inspected at 20-year intervals.

(continued)

INDIAN POINT 3 5.0 - 11 Amendment 232

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 Inservice Testing Program This program provides controls for inservice testing of ASME Code Class 1, 2, and 3 components including applicable supports. The program shall include the following:

a. Testing frequencies applicable to the ASME Code for Operations and Maintenance of Nuclear Power Plants (ASME OM Code} and applicable Addenda as follows:

ASME OM Code and applicable Addenda terminology for Required Frequencies inservice testing for performing inservice activities testing activities Weekly At least once per 7 days Monthly At least once per 31 days Quarterly or every 3 months At least once per 92 days Semiannually or every 6 months At least once per 184 days Every 9 months At least once per 276 days Yearly or annually At least once per 366 days Biennially or every 2 years At least once per 731 days

b. The provisions of SR 3.0.2 are applicable to the above required Frequencies and to other normal and accelerated Frequencies specified as 2 years or less in the Inservice Testing Program for performing inservici testing activities;

c. The provisions of SR 3.0.3 are applicable to inservice testing activities; and

d. Nothing in the ASME OM Code shall be construed to supersede the requirements of any TS.

(continued)

INDIAN POINT 3 5.0 -12 Amendment 245

Programs and Manuals 5.5 5.5.8 Steam Generator (SG) Program A Steam Generator Program shall be established and implemented to ensure that SG tube integrity is maintained. In addition, the Steam Generator Program shall include the following:

a. Provisions for condition monitoring assessments. Condition monitoring assessment means an evaluation of the "as found" condition of the tubing with respect to the performance criteria for structural integrity and accident induced leakage. The "as found" condition refers to the condition of the tubing during an SG inspection outage, as determined from the inservice inspection results or by other means, prior to the plugging of tubes. Condition monitoring assessments shall be conducted during each outage during which the SG tubes are inspected or plugged, to confirm that the performance criteria are being met.

b. Performance criteria for SG tube integrity. SG tube integrity shall be maintained by meeting the performance criteria for tube structural integrity, accident induced leakage, and operational LEAKAGE.

1. Structural integrity performance criterion: All in-service steam generator tubes shall retain structural integrity over the full range of normal operating conditions (including startup, operation in the power range, hot standby, and cool down), all anticipated transients included in the design specification and design basis accidents. This includes retaining a safety factor of 3.0 against burst under normal steady state full power operation primary-to-secondary pressure differential and a safety factor of 1.4 against burst applied to the design basis accident primary-to-secondary pressure differentials. Apart from the above requirements, additional loading conditions associated with the design basis accidents, or combination of accidents in accordance with the design and licensing basis, shall also be evaluated to determine if the associated loads contribute significantly to burst or collapse. In the assessment of tube integrity, those loads that do significantly affect burst or collapse shall be determined and assessed in combination with the loads due to pressure with a safety factor of 1.2 on the combined primary loads and 1.0 on axial secondary loads.

2. Accident induced leakage performance criterion: The primary to secondary accident induced leakage rate for any design basis accident, other than a SG tube rupture, shall not exceed the (continued)

INDIAN POINT 3 5.0 - 13 Amendment 257

Programs and Manuals 5.5 5.5 and Manuals 5.5.8 Steam Generator (SG) Program (continued) leakage rate assumed in the accident analysis in terms of total leakage rate for all SGs and leakage rate for an individual SG. Leakage is not to exceed 0.3 gpm per SG and 1 gpm through all SGs.

3. The operational LEAKAGE performance criterion is specified in LCO 3.4.13, "RCS Operational LEAKAGE."

c. Provisions for SG tube plugging criteria. Tubes found by inservice inspection to contain flaws with a depth equal to or exceeding 40% of the nominal tube wall thickness shall be plugged.

d. Provisions for SG tube inspections. Periodic SG tube inspections shall be performed. The number and portions of the tubes inspected and methods of inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable tube plugging criteria. The tube-to-tubesheet weld is not part of the tube. In addition to meeting the requirements of d.1, d.2, and d.3 below, the inspection scope, inspection methods, and inspection intervals shall be such as to ensure that SG tube integrity is maintained until the next SG inspection. A degradation assessment shall be performed to determine the type and location of flaws to which the tubes may be susceptible and, based on this assessment, to determine which inspection methods need to be employed and at what locations.

1. Inspect 100% of the tubes in each SG during the first refueling outage following SG installation.

2. After the first refueling outage following SG installation, inspect each SG at least every 72 effective full power months or at least every third refueling outage (whichever results in more frequent inspections). In addition, the minimum number of tubes inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period as defined in a, b, c and d below. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated.

The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new INDIAN POINT 3 5.0 - 14 Amendment 257

Programs and Manuals 5.5 5.5 5.5.8 Steam Generator (SG) Program (continued) form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period. Each inspection period defined below may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.

a) After the first refueling outage following SG installation, inspect 100%

of the tubes during the next 144 effective full power months. This constitutes the first inspection period; b) During the next 120 effective full power months, inspect 100% of the tubes. This constitutes the second inspection period; c) During the next 96 effective full power months, inspect 100% of the tubes. This constitutes the third inspection period; and d) During the remaining life of the SGs, inspect 100% of the tubes every 72 effective full power months. This constitutes the fourth and subsequent inspection periods.

3. If crack indications are found in any SG tube, then the next inspection for each affected and potentially affected SG for the degradation mechanism that caused the crack indication shall not exceed 24 effective full power months or one refueling outage (whichever results in more frequent inspections). If definitive information, such as from examination of a pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a crack-line indication is not associated with a crack(s),

then the indication need not be treated as a crack.

e. Provisions for monitoring operational primary to secondary LEAKAGE.

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

Pages 5.0-16 through 5.0-19 are deleted.

Next page is 5.0-20.

INDIAN POINT 3 5.0 - 15 Amendment 257

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5:9 Secondary Water Chemistry Program This program provides controls for monitoring secondary water chemistry to inhibit SG tube degradation. The program shall include:

a. Identification of a sampling schedule for the critical variables and control points for these variables;

b. Identification of the procedures used to measure the values of the critical variables:

c. Identification of process sampling points. which shall include monitoring the condenser hot wells for evidence of condenser in leakage:

d. Procedures for the recording and management of data;

e. Procedures defining corrective actions for all off control point chemistry conditions: and

f. A procedure identifying the authority responsible for the interpretation of the data and the sequence and timing of administrative events, which is required to initiate corrective action.

(continued) u INDIAN POINT 3 5.0-20 /wendment 205

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.10 Ventilation Filter Testing Program (VFTP)

This program provides controls for implementation of required testing of the ventilation filter function for the Control Room Ventilation System and Containment Fan Cooler Units.

Applicable tests described in Specifi"cations 5.5.10.a, 5.5.10.b, 5.5.lO~c and 5.5.10.d shall be performed:

1) After 720 hours0.00833 days 0.2 hours 0.00119 weeks 2.7396e-4 months of charcoal adsorber use since the last test; and,

2) Every 24 months for the Control Room Ventilation System, and Containment Fan Cooler Units; and,

3) After each complete or partial replacement of the HEPA filter train or charcoal adsorber filter; and,

4) After any structural maintenance on the system housing that could alter system integrity; and,

5) After significant painting, fire, or chemical release in any ventilation zone communicating with the system while it is in operation.

SR 3.0.2 is applicable to the Ventilation Filter Testing Program.

(continued)

INDIAN POINT 3 5.0 - 21 Amendment 224

Programs and Manuals 5.5 u 5.5 Programs and Manuals 5.5.10 Ventilation Filter Testing Program (VFTP) (continued)

a. Demonstrate for each system that an inplace test of the high efficiency particulate air (HEPA) filters shows the specified penetration and system bypass leakage when tested in accordance with the referenced standard at the flowrate specified below.

Ventilation Removal Flovrate System Efficiency (cfm) Reference Standard 80\ to 120\

Control Room of design Ventilation 2: 99\ accident Regulatory Guide 1.52, Rev 2, system rate Sections c.5.a and c.5.c 80\ to 120\

of design Containment Fan 2: 99\ accident Regulatory Guide 1.52, Rev 2, Cooler Units rate Sections C.5.a and C.5.c (continued)

INDIAN POINT 3 5.0 - 22 Amendment 224

Programs and Manuals 5.5 u 5.5 Programs and Manuals 5.5.10 Ventilation Filter Testing Program (VFTP) (continued)

b. Demonstrate for each system that an inplace test of the charcoal adsorber shows the specified penetration and system bypass leakage when tested in accordance with the referenced standard at the flowrate specified below.

Ventilation Removal System Efficiency Flowrate (cfm) Reference Standard 80\ to 120\ of Control Room design Ventilation accident rate Regulatory Guide 1.52, Rev 2, System .2; 99"s Sections C.5.a and C.5.d 80\ to 120\ of Containment Fan design Regulatory Guide 1.52, Rev 2, Cooler Units .2: 99' accident rate Sections C.5.a and C.5.d (continued)

INDIAN POINT 3 5.0 - 23 Amendment 224

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.10 Ventilation Filter Testing Program (VFTP) (continued)

c. Demonstrate for each system that a laboratory test of a sample of the charcoal adsorber shows the methyl iodide removal efficiency specified below when tested in accordance with ASTM 03803-1989, subject to clarification below, at a temperature of 86°F and a relative humidity of 95%.

Methyl iodide removal ASTM 03803-1989 Ventilation System efficiency Cl a rifi cation

(%):

Control Room .:: 95.5 78 ft/min face velocity Ventilation System Containment Fan Cooler .:: 85 59 ft/min face velocity Units (continued)

INDIAN POINT 3 5.0 - 24 Amendment 234

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.10 Ventilation Filter Testing Program (VFTP) (continued)

d. Demonstrate for each system that the pressure drop across the combined HEPA filters, the demisters and prefilters (if installed), and the charcoal adsorbers is less than the value specified below when tested at the flowrate specified below.

Ventilation Sistem Delta P Flowrate (cfm):

(inches wq)

Control Room Ventilation System ~.901 of design accident 6 rate Containment Fan Cooler Units ~ 901 of design accident 6 rate (continued)

INDIAN POINT 3 5.0 - 25 Amendment 224

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.11 Explosive Gas and Storage Tank Radioactivity Monitoring Program This program provides controls for potentially explosive gas mixtures contained in the Waste Gas Holdup System, the quantity of radioactivity contained in gas storage tanks, and the quantity of radioactivity contained in unprotected outdoo~ liquid storage tanks. The gaseous radioactivity quantities shall be determined following the methodology in Branch Technical Position (BTP) ETSB 11-5, "Postulated Radioactive Release due to Waste Gas System Leak or Failure." The liquid radwaste quantities shall be determined in accordance with Standard Review Plan, Section 15.7.3, "Postulated Radioactive Release due to Tank Failures."

The program shall include:

a. The limits for concentrations of hydrogen and oxygen in the Waste Gas Holdup System and a surveillance program to ensure the limits are maintained. Such limits shall be appropriate to the system's design criteria (i.e., whether or not the system is designed to withstand a hydrogen explosion);

b. A surveillance program to ensure that the quantity of radioactivity contained in each gas storage tank shall be limited to less than the amount that would result in a whole body exposure of~ 0.5 rem to any individual in an unrestricted area, in the event of an uncontrolled release of the tanks' contents; and

c. A surveillance program to ensure that the quantity of radioactivity contained in all outdoor liquid radwaste tanks that are not surrounded by liners, dikes, or walls, capable of holding the tanks' contents and that do not have tank overflows and surrounding area drains connected to the Liquid Radwaste Treatment System is less than the amount that would result in concentrations less than the limits of 10 CFR 20, Appendix B, Table 2, Column 2, at the nearest potable water supply and the nearest surface water supply in an unrestricted area, in the event of an uncontrolled release of the tanks' contents.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Explosive Gas and Storage Tank Radioactivity Monitoring Program surveillance frequencies.

(continued)

INDIAN POINT 3 5.0 - 26 Amendment 232

Programs and Hanuals 5.5 5.5 Programs and Hanuals 5.5.12 Diesel fuel Oil Testing Program A diesel fuel oil testing program to implement required testing of both new fuel oil and stored fuel oil shall be established for the DG fuel oil onsite storage tanks and the DG reserve fuel oil storage tanks. The program shall include sampling and testing requirements. and acceptance criteria. all in accordance with applicable ASTH Standards. The purpose of the program is to establish the following:

a. Verification of the acceptability of new fuel oil for use prior to addition to the DG fuel oil onsite storage tanks by determining that the fuel oil has:

1. Relative density within the limits of 0.83 to 0.89.

2. kinematic viscosity within the limits of 1.8 to 5.8. and

3. a clear and bright appearance with proper color bl. Verification of the acceptability of the fuel oil in the onsite storage tanks and the reserve storage tanks every 92 days by verifying that the properties of the fuel oil in the tanks, other than those addressed in

\_) item a.* are within limits for ASTH2D fuel oil. The sampling technique for the reserve storage tanks may deviate from ASTH D270-1975 in that only a bottom sample is required.

or b2. Verification of the acceptability of each new fuel addition made subsequent to the last verification made in accordance with item bl. by verifying within 31 days following the addition that the properties of the new fuel oil, other than those properties addressed in item a. are within limits for ASTH 2D fuel oil.

c. Verification every 92 days that total particulate concentration of the fuel oil in the onsite and reserve storage tanks is less than or equal to 10 mg/1 when tested in accordance with ASTH D-2276, Method A-2 or A*

3. The sampling technique for the reserve storage tanks may deviate from ASTH D270*1975 in.that only a bottom sample is required.

(continued) u INDIAN POIITT 3 5.0-27 hnendnent 205

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.12 Diesel Fuel Oil Testing Program (continued)

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Diesel Fuel Oil.Testing Program testing frequencies.

5.5.13 Technical Specifications CTSl Bases Control Program This program provides a means for processing changes to the Bases of these Technical Specifications.

a. Changes to the Bases of the TS shall be made under appropriate actninistrative controls.and reviews.

b. Licensees may make changes to Bases without prior NRC approval provided the changes do not involve either of the following:

1. a change in the TS incorporated in the license: or

2. a change to the updated FSAR or Bases that requires NRC approval pursuant to 10 CFR 50.59.

c. The Bases Control Program shall contain provisions to ensure that the Bases are maintained consistent with the FSAR.

d. Proposed changes that do not meet the criteria of Specification 5.5.13.b above shall be reviewed and approved by the NRC prior to implementation. Changes to the Bases implemented without prior NRC approval shall be provided to the NRC on a frequency consistent with 10 CFR 50.71Ce).

5.5.14 Safety Function Determination Program CSEPP>

This program ensures loss of safety function is detected and appropriate actions taken. Upon entry into LCO 3.0.6, an evaluation shall be made to determine if loss of safety function exists. Additionally, other appropriate actions may be taken as a result of the support system inoperability and corresponding exception to entering supported system Condition and Required Actions. This program implements the requirements of LCO 3.0.6. The SFDP shall contain the following:

u (continued)

INDIAN POINT 3 5.0-28 Amenctnent 205

Programs and Hanuals 5.5 5.5 Programs and Hanuals 5.5.14 Safety Function Determination Program CSEPP> (continued)

a. Provisions for cross train checks to ensure a loss of the capability to perform the safety function assumed in the accident analysis does not go undetected;

b. Provisions for ensuring the plant is maintained in a safe condition if a loss of function condition exists:

c. Provisions to ensure that an inoperable supported system's Completion Time is not inappropriately extended as a resuit of multiple support system inoperabilities: and

d. Other appropriate limitations and remedial or compensatory actions.

A loss of safety function exists when, assuming no concurrent single.

failure. a safety function assumed in the* accident analysis cannot be performed. For the purpose of this program. a loss of safety function may exist when a support system is inoperable. and:

a. A required system redundant to the system(s) supported by the inoperable support system is also inoperable: or

b. A required system redundant to the system(s) in turn supported by the inoperable supported system is also inoperable: or

c. A required system redundant to the support systern(s) for the supported systems Ca) and Cb) above is also inoperable.

The SFDP identifies where a loss of safety function exists. If a loss of safety function is determined to exist by this program. the appropriate Conditions and Required Actions of the LCO in which the loss.of safety function exists are required to be entered.

(continued)

INDIAN POINT 3 5.0-29 Amendment 205

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.15 Containment Leakage Rate Testing Program A program shall be established to implement the leakage rate testing of the containment as required by 10 CFR 50.54(0) and 10 CFR 50, Appendix J, Option B, as modified by approved exemptions. This program shall be in accordance with NEI 94-01, Revision 2A, "Industry Guideline for Implementing Performance-Based Option I

of 10 CFR Part 50, Appendix J," October 2008, as modified by the following exception:

ANS 56.8-2002, Section 3.3.1: WCCPPS isolation valves are not Type C tested.

The maximum allowable primary containment leakage rate, La, at a minimum test pressure equal to Pa, shall be 0.1 % of primary containment air weight per day. Pa is the peak calculated containment internal pressure related to the design basis accident.

Leakage acceptance criteria are:

a. Containment leakage rate acceptance criterion is~ 1.0 La. During the first unit startup following testing in accordance with this program, the leakage rate acceptance criteria are~ 0.60 La for the Type Band C tests and~ 0.75 La for Type A tests;

b. Air lock testing acceptance criteria are:

1) Overall air lock leakage rate is ~ 0. 05 La when tested at .::: Pa,

2) For each door, leakage rate is~ 0.01 La when pressurized to.::: Pa,

c. Isolation Valve Seal Water System leakage rate acceptance criterion is~

14,700 cc/hr at.::: 1.1 Pa.

d. Acceptance criterion for leakage into containment from isolation valves sealed with the service water system is~ 0.36 gpm per fan (continued)

INDIAN POINT 3 5.0 - 30 Amendment 256

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.15 Containment Leakage Rate Testing Program (continued) cooler unit when pressurized at.:::. 1.1 Pa* This limit protects the internal recirculation pumps from flooding during the 12-month period of post accident recirculation.

The provisions of SR 3.0.3 are applicable to the Containment Leakage Rate Testing Program.

Nothing in these Technical Specifications shall be construed to modify the testing Frequencies required by 10CFR50, Appendix J.

The calculated peak containment internal pressure for the design basis loss of coolant accident, Pa, is 42.38 psig. The containment design pressure is 47 psig.

The maximum allowable primary containment leakage rate, La, at Pa, shall be 0.1 %

of primary containment air weight per day.

5.5.16 Control Room Envelope Habitability Program A Control Room Envelope (CRE) Habitability Program shall be established and implemented to ensure that CRE habitability is maintained such that, with an OPERABLE Control Room Ventilation System (CRVS), CRE occupants can control the reactor safely under normal conditions and maintain it in a safe condition following a radiological event, hazardous chemical release, or a smoke challenge. The program shall ensure that adequate radiation protection is provided to permit access and occupancy of the CRE under design basis accident (OBA) conditions without personnel receiving radiation exposures in excess of 5 rem total effective dose equivalent (TEDE) for the duration of the accident. The program shall include the following elements:

(continued)

INDIAN POINT 3 5.0-31 Amendment 253

5.5.16 Control Room Envelope Habitability Program (continued)

a. The definition of the CRE and the CRE boundary.

b. Requirements for maintaining the CRE boundary in its design condition including configuration control and preventive maintenance.

c. Requirements for (i) determining the unfiltered air inleakage past the CRE boundary into the CRE in accordance with the testing methods and at the Frequencies specified in Sections C.l and C.2 of Regulatory Guide 1.197, "Demonstrating Control Room Envelope Integrity at Nuclear Power Reactors,"

Revision 0, May 2003, and (ii) assessing CRE habitability at the Frequencies specified in Sections C.l and C.2 of Regulatory Guide 1.197, Revision 0.

d. Measurement, at designated locations, of the CRE pressure relative to all external areas adjacent to the CRE boundary during the pressurization mode of operation by one train of the CRVS, operating at the flow rate required by the VFTP, at a Frequency of 24 months on a STAGGERED TEST BASIS. The results shall be trended and used as part of the 24 month assessment of the CRE boundary.

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

The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analysis of OBA consequences. Unfiltered air inleakage limits for hazardous chemicals must ensure that exposure of CRE occupants to these hazards will be within the assumptions in the licensing basis.

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

INDIAN POINT 3 5.0 -3la Amendment 239

Reporting Requirements 5.6 u* 5.0 ADMINISTRATIVE CONTROLS 5.6 Reporting Requirements The following reports shall be submitted in accordance with 10 CFR 50.4.

5.6.1 Not Used u 5.6.2 Annual Radiological Environmental Operating Report

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

A single submittal may be made for a multiple unit station. The submittal should combine sections corrmon to all units at the station.

The Annual Radiological Environmental Operating Report covering the operation of the unit during the previous calendar year shall be submitted by May 15 of each year. The report shall include surrmaries, interpretations, and analyses of trends of the results of the radiological environmental monitoring program for the reporting period. The material provided shall be consistent with the

\ objectives outlined in the Offsite Dose Calculation Manual (ODCM), and in 10 CFR 50 Appendix I Sections IV.B.2 IV.B.3 and IV.C.

1 1 1 1 (continued) u INDIAN POINT 3 5.0 - 32 Amendment 227

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.2 Annual Radiological Environmental Operating Report (continued}

A full listing of the infonnation to be contained in the Annual Radiological Environmental Operating Report is provided in the ODCM.

5.6.3 Radioactive Effluent Release Report

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

A single submittal may be made for a multiple unit station. The submittal shall combine sections common to all units at the station; however, for units with separate radwaste systems, the submittal shall specify the releases of radioactive material from each unit.

The Radioactive Effluent Release Report covering the operation of the unit in the previous year shall be submitted prior to May 1 of each year in accordance with 10 CFR 50.36a. The report shall include a summary of the quantities of radioactive liquid and gaseous effluents and solid waste released from the unit. The material provided shall be consistent with the objectives outlined in the ODCM and Process Control Program and in confonnance with 10 CFR Part 50.36a and 10 CFR 50, Appendix I, Section IV.B.1.

5.6.4 Not Used 5.6.5 CORE OPERATING LIMITS REPORT (COLR)

a. Core operating limits shall be established prior to each reload cycle, or prior to any remaining portion of a reload cycle, and shall be documented in the COLR for the following:

(continued)

INDIAN POINT 3 5.0 - 33 Amendment 227

Reporting Requirements 5.6 u 5.6 5-:-6. 5 Reporting Requirements CORE OPERATING LIMITS REPORT (COLR) (continued)

1. Specification 2.1, Safety Limits (SL);

2. Specification 3.1.1, Shutdown Margin;

3. Specification 3.1.3, Moderator Temperature Coefficient;

4. Specification 3.1.5, Shutdown Bank Insertion Limits;

5. Specification 3.1.6, Control Bank Insertion Limits;

6. Specification 3.2.1, Heat Flux Hot Channel Factor (FQ(Z));

7. Specification 3.2.2, Nuclear Enthalpy Rise Hot Channel Factor;

8. Specification 3.2.3, AXIAL FLUX DIFFERENCE (AFD);

9. Specification 3.3.1, Reactor Protection System Instrumentation;

10. Specification 3.4.1, RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits; and

11. Specification 3.9.1, Boron Concentration.

b. The analytical methods used to determine the core operating limits shall be those previously reviewed and approved by the NRC, specifically those described in the following documents:

1. WCAP-9272-P-A, "WESTINGHOUSE RELOAD SAFETY EVALUATION METHODOLOGY," July 1985 (W Proprietary). (Specifications 3.1.5, Shutdown Bank Insertion Limits, 3.1.6, Control Bank Insertion Limits, and 3.2.2, Nuclear Enthalpy Rise Hot Channel Factor);

2a. WCAP-8385, "POWER DISTRIBUTION CONTROL AND LOAD FOLLOWING PROCEDURES, TOPICAL REPORT," September 1974 (W Proprietary). (Specification 3.2.3, Axial Flux Difference (AFD) (Constant Axial Offset Control);

2b. T. M. Anderson to K. Kneil (Chief of Core Performance Branch, NRC) January 31, 1980 --

Attachment:

Operation and Safety Analysis Aspects of an Improved Load Follow Package. (Specification 3.2.3, Axial Flux Difference (AFD) (Constant Axial Offset Control));

2c. NUREG-0800, Standard Review Plan, U.S. Nuclear Regulatory Commission,Section 4.3,Nuclear Design,July 1981. Branch (continued)

-...__;*/

\

INDIAN POINT 3 5.0 - 34 Amendment 225

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.5 CORE OPERATING LIMITS REPORT (COLR) (continued)

Position CPB 4.3-1, Westinghouse Constant Axial Offset Control (CAOC), Rev. 2, July 1981. (Specification 3.2.3, Axial Flux Difference (AFD) (Constant Axial Offset Control));

3. WCAP-12945-P-A, Volume 1 (Revision 2) and Volumes 2 through 5 (Revision 1),

"Code Qualification Document for Best-Estimate Loss-of-Coolant-Accident Analysis," March 1998 (Westinghouse Proprietary);

4. WCAP-11397-P-A, "Revised Thermal Design Procedure," April 1989 (Specification 2.1, Safety Limits (SL)) and Specification 3.4.1, (RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits);

5. WCAP-8745-P-A, "Design Bases for the Thermal Overpower lff and Thermal Overtemperature lff Trip Functions," September 1986 (Specification 2.1, Safety Limits (SL));

6a. WCAP-10054-P-A, "SMALL BREAK ECCS EVALUATION MODEL USING NOTRUMP CODE," (W Proprietary). (Specification 3.2.1, Heat Flux Hot Channel Factor (FQ(Z));

6b. WCAP-10054-P-A, Addendum 2, Revision 1, "Addendum to the Westinghouse Small Break ECCS Evaluation Model Using the NOTRUMP Code; Safety Injection into the Broken Loop and Casi Condensation Model," July 1997 (Specification 3.2.1, Heat Flux Hot Channel Factor (FQ(Z)));

6c. WCAP-10079-P-A, "NOTRUMP NODAL TRANSIENT SMALL BREAK AND GENERAL NETWORK CODE," (W Proprietary). (Specification 3.2.1, Heat Flux Hot Channel Factor (FQ(Z)));

7. WCAP-12610, "VANTAGE+ Fuel Assembly Report," (W Proprietary). (Specification 3.2.1, Heat Flux Hot Channel Factor);

8. WCAP-137 49-P-A, "Safety Evaluation Supporting the Conditional Exemption of the Most Negative EOL Moderator Temperature Coefficient Measurement," March 1997.

(Specification 3.1.3, Moderator Temperature Coefficient);

9. WCAP-16045-P-A, "Qualification of the Two-Dimensional Transport Code PARAGON," August 2004. (Specification 3.1.1, Shutdown Margin, Specification 3.1.3, Moderator Temperature Coefficient, Specification 3.1.5, Shutdown Bank Insertion Limits, Specification 3.1.6, Control Bank Insertion Limits, Specification 3.2.1, Heat Flux Hot Channel Factor (FQ(Z)), Specification 3.2.2, Nuclear Enthalpy Rise Hot Channel Factor, Specification 3.2.3, Axial Flux Difference (AFD),

Specification 3.9.1, Boron Concentration); and

10. WCAP-10965-P-A, "ANC: A Westinghouse Advanced Nodal Computer Code,"

September 1986. (Specification 3.1.1, Shutdown Margin, Specification 3.1.3, Moderator Temperature Coefficient, Specification 3.1.5, Shutdown Bank Insertion Limits, Specification 3.1.6, Control Bank Insertion Limits, Specification 3.2.1, Heat Flux Hot Channel Factor (FQ(Z)), Specification 3.2.2, Nuclear Enthalpy Rise Hot continued INDIAN POINT 3 5.0 -35 Amendment 261

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.5 CORE OPERATING LIMITS REPORT (COLR) (continued)

Channel Factor, Specification 3.2.3, Axial Flux Difference (AFD), Specification 3.9.1, Boron Concentration).

c. The core operating limits shall be determined such that all applicable limits (e.g., fuel thermal mechanical limits, core thermal hydraulic limits, Emergency Core Cooling Systems (ECCS) limits, nuclear limits such as SDM, transient analysis limits, and accident analysis limits) of the safety analysis are met

d. The COLR, including any midcycle revisions or supplements, shall be provided for each reload cycle to the NRC.

5.6.6 NOT USED (continued)

INDIAN POINT 3 5.0 -35a Amendment 261

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.7 Post Accident Monitoring Instrumentation (PAM) Report When a report is required by LCO 3.3.3, "Post Accident Monitoring (PAM)

Instrumentation," a report shall be submitted within the next 14 days. The report shall outline the preplanned alternate method of monitoring, the cause of the inoperability, and the plans and schedule for restoring the instrumentation channels of the Function to OPERABLE status.

5.6.8 Steam Generator Tube Inspection Report A report shall be submitted within 180 days after the initial entry into MODE 4 following completion of an inspection performed in accordance with the Specification 5.5.8 Steam Generator (SG) Program. The report shall include:

a. The scope of inspections performed on each SG,

b. Degradation mechanisms found,

c. Nondestructive examination techniques utilized for each degradation mechanism,

d. Location, orientation (if linear), and measured sizes (if available) of service induced indications,

e. Number of tubes plugged during the inspection outage for each degradation mechanism,

f. The number and percentage of tubes plugged to date, and the effective plugging percentage in each SG, and

g. The results of condition monitoring, including the results of tube pulls and in-situ testing.

INDIAN POINT 3 5.0-36 Amendment 257

High Radiation Area 5.7 5.0 ADMINISTRATIVE CONTROLS 5.7 High Radiation Area As provided in paragraph 20.1601(c) of 10 CFR Part 20, the following controls shall be applied to high radiation areas in place of the controls required by paragraph 20.1601(a) and (b) of 10 CFR Part 20:

5.7.1 High Radiation Areas with Dose Rates Not Exceeding 1.0 rem/hour at 30 Centimeters from the Radiation Source or from any Surface Penetrated by the Radiation

a. Each entryway to such an area shall be barricaded and conspicuously posted as a high radiation area. Such barricades may be opened as necessary to permit entry or exit of personnel or equipment.

b.

Access to, and activities in, each such area shall be controlled by means of Radiation Work Permit (RWP) or equivalent that includes specification of radiation dose rates in the immediate work area(s) and other appropriate radiation protection equipment and measures.

c. Individuals qualified in radiation protection procedures and personnel continuously escorted by such individuals may be exempted from the requirement for an RWP or equivalent while performing their assigned duties provided that they are otherwise following plant radiation protection procedures for entry to, exit from, and work in such areas.

d. Each individual or group entering such an area shall possess:

1. A radiation monitoring device that continuously displays radiation dose rates in the area; or

2. A radiation monitoring device that continuously integrates the radiation dose rates in the area and alarms when the device's dose alarm setpoint is reached, with an appropriate alarm setpoint, or

3. A radiation monitoring device that continuously transmits dose rate and cumulative dose information to a remote receiver monitored by radiation protection personnel responsible for controlling personnel radiation exposure within the area, or (continued)

INDIAN POINT 3 5.0 - 37 Amendment 232

High Radiation Area 5.7 5.0 ADMINISTRATIVE CONTROLS 5.7 High Radiation Area 5.7.1 High Radiation Areas with Dose Rates Not Exceeding 1.0 rem/hour at 30 Centimeters from the Radiation Source or from any Surface Penetrated by the Radiation (continued)

4. A self-reading dosimeter (e.g., pocket ionization chamber or electronic dosimeter) and, (i) Be under the surveillance, as specified in the RWP or equivalent, while in the area, of an individual qualified in radiation protection procedures, equipped with a radiation monitoring device that continuously displays radiation dose rates in the area; who is*

responsible for controlling personnel exposure within the area, or (ii) Be under the surveillance as specified in the RWP or equivalent, while in the area, by mean~ of closed circuit television, of personnel qualified in radiati-0n protection procedures, responsible for controlling personnel radiation exposure in the area, and with the means to communicate with individuals in the area who

, are covered by such survei 11 ance. *

e. Except for individuals qualified in radiation protection procedures, or personnel continuously escorted by such individuals, entry into such areas shall be made only after dose rates in the area have been determined and entry personnel are knowledgeable of them. These continuously escorted personnel will receive a pre-job briefing prior to entry into such areas. This dose rate determination, knowledge, and pre-job briefing does not require documentation prior to initial entry.

(continued)

INDIAN POINT 3 5.0 - 38 Amendment 232

High Radiation Area 5.7 5.0 ADMINISTRATIVE CONTROLS 5.7 High Radiation Area 5.7.2 High Radiation Areas with Dose Rates Greater than 1.0 rem/hour at 30 Centimeters from the Radiation Source or from any Surface Penetrated by the Radiation, but less than 500 rads/hour at 1 Meter from the Radiation Source or from any Surface Penetrated by the Radiation

a. Each entryway to such an area shall be conspicuously posted as a high radiation area and shall be provided with a locked or continuously guarded door or gate that prevents unauthorized entry, and, in addition:

1. All such door and gate keys shall be maintained under the administrative control of the shift supervisor, radiation protection manager, or his or her designee.

2. Doors and gates sha11 remain 1ocked except during periods of personnel or equipment entry or exit.

b. Access to, and activities in, each such area shall be controlled by means of an RWP or equivalent that includes specification of radiation dose rates in the immediate work area(s) and other appropriate radiation protection equipment and measures.

c. Individuals qualified in radiation protection procedures may be exempted from the requirement for an RWP or equivalent while performing radiation surveys in such areas provided that they are otherwise following plant radiation protection procedures for entry to, exit from, and work in such areas.

d. Each individual or group entering such an area shill possess:

1. A radiation monitoring device that continuously integrates the radiation rates in the area and alarms when the device's dose alarm setpoint is reached, with an appropriate alarm setpoint, or

2. A radiation monitoring device that continuously transmits dose rate and cumulative dose information to a remote receiver monitored by radiation protection personnel responsible for controlling personne1 radiation exposure within the area with the means to communicate with and control every individual in the area, or (continued)

INDIAN POINT 3 5.0 - 39 Amendment 232

High Radiation Area 5.7 5.0 ADMINISTRATIVE CONTROLS 5.7 High Radiation Area 5.7.2 High Radiation Areas with Dose Rates Greater than 1.0 rem/hour at 30 Centimeters from the Radiation Source or from any Surface Penetrated by the Radiation, but less than 500 rads/hour at 1 Meter from the Radiation Source or from any Surface Penetrated by the Radiation (continued)

3. A self-reading dosimeter (e.g., pocket ionization chamber or electronic dosimeter) and, (i) -Be under the surveillance, as specified in the RWP or equivalent, while in the area, of an individual qualified in radiation protection procedures, equipped with a radiation monitoring device that continuously displays radiation dose rates in the area; who is responsible for controlling personnel exposure within the area, or (ii) Be under the surveillance as specified in the RWP or equivalent, while in the area, by means of closed circuit television, of personnel qualified in radiation protection procedures, responsible for controlling personnel radiation exposure in the area, and with the means to communicate with and control every individual in the area.

4. In those cases where options (2) and (3), above, are impractical or determined to be inconsistent with the "As Low As is Reasonably Achievable" principle, a radiation monitoring device that continuously displays radiation dose rates in the area.

e. Except for individuals qualified in radiation protection procedures, or personnel continuously escorted by such individuals, entry into such areas shall be made only after dose rates in the area have been determined and entry personnel are knowledgeable of them. These continuously escorted personnel will receive a pre-job briefing prior to entry into such areas. This dose rate determination, knowledge, and pre-job briefing does not require documentation prior to initial entry.

(continued)

INDIAN POINT 3 5.0 - 40 Amendment 232

High Radiation Area 5.7 5.7 High Radiation Area 5.7.2 High Radiation Areas with Dose Rates Greater than 1.0 rem/hour at 30 Centimeters from the Radiation Source or from any Surface Penetrated by the Radiation, but less than 500 rads/hour at 1 Meter from the Radiation Source or from any Surface Penetrated by the Radiation (continued)

f. Such individual areas that are within a larger area where no enclosure exists for the purpose of locking and where no enclosure can reasonably be constructed around the individual area need not be controlled by a locked door or gate, nor continuously guarded, but shall be barricaded, conspicuously posted, and a clearly visible flashing light ~hall be activated at the area as a warning device.

INDIAN POINT 3 5.0 - 41 Amendment 232

LIC!~!S:? 1~:r::-::r::~Y FII*::: CO*?Y V APPENDIX B TO FACILITY OPERATING LICENSE FOR ENTERGY NUCLEAR INDIAN POINT 3, LLC (ENIP3)

AND ENTERGY NUCLEAR OPERATIONS, INC. (ENO)

.

INDIAN POINT 3 NUCLEAR POWER PLANT

'

ENVIRONMENTAL TECHNICAL SPECIFICATION REQUIREMENTS u PART I: NON-RADIOLOGICAL ENVIRONMENTAL PROTECTION PLAN FACILITY LICENSE NO. DPR-64 DOCKET NUMBER 50-286 Amendment No. 3-5, 203 NOV 2 1 2000

..

INDIAN POINT NUCLEAR GENERATING PLANT UNIT 3 ENVIRONMENTAL TECHNICAL SPECIFICATION REQUIREMENTS PART I: NON-RADIOLOGICAL ENVIRONMENTAL PROTECTION PLAN TABLE OF CONTENTS

..

Section Page 1.0 Objectives ~f the Environmental Protection Plan ****************************** ~............ 1-1 2.0 Environmental Protection Issues ****** ~......... 2-1 3.0 .Consistency Requirements....................... 3-1

\__.:*.

3.1 Plant Design and.Operation..................... 3-1 3.2 Reporting Related to the NPDES Permits and State Certification.................................. 3-3 3 .* 3 Changes Required for Compliance with Other Environmental Regulations...................... 3-4 4.0 Environmental Conditions....................... 4-1 4.1 Unusual or Important Environmental Events...... 4-1 5.0 Administrative Procedures...................... 5-1 s.1 Review and Audit******************************* 5-1 s.2 Records Retention **************** ** ~............. 5-1 5.3 Changei in Environmental Protection Plan....... 5-2 5.4 Plant Reporting *Requirements ***** ****** * * * * * * * *

5-2 Amendment No. 35 APR 2 4 1981

1.0 Obj~ctives of the Environmental Protecfion Plan

..

The Environmental Protection*Plan (EPP) is to provide for pro-tection of environmental values during construction and operation of the nuclear facility. The principal objectives of the EPP are as follows:

(1) Verify that**the plant is operated in an environmentally acceptable manner, as established by the FES and other NRC environmental impact assessments.

(2) Coordinate NRC requirements and maintain consistency with other Federal, State and local requirements for environmental protection.

(3) Keep ~RC informed of the environmental effects of fa-cility construction*and operation and of actions taken to control those ef:ects.

Environmental concerns identified in the FES which relate to water quality matters are regulated by way 6£ the li-

..

censee's SPDES permit.

C Amendment No. 35 1-1 APR 2 4 1981

2.0 Environmental Protection Issues

. ;~~*

.. In the FES-OL for Unit 2 dated September 1972 and the FES-OL .*;°:'/

-..::-

_,

for Unit 3* dated February 1975, the staff considered the environmental impacts associated with operation of the Indian

. \

Point Nuclear ~enerating Plant. Certain environmental issues were identified which required study or license conditions to re~olve environmental concerns and.t6 assure adequate protection of the.environment. The Appendix B Environmental Technical Specifications issued with the licenses included monitoring programs and ~ther requirements *to protect water quality and aquatic biota during plant operation with once-I ,

through cooling. As last am~nded on July 11, 1979, the

'-._..'

Appendix BETS included monitoring and other requirements to address the following non-radiological aquatic protec-tion issues:

.(1) Controlled release of thermal discharges (ETS Sections 2.1, 3.1, 2.2.2, 3.2.2, and 4.1.1.a).

(-2) Controlled release of non~radioactive chemical dis-charges (ETS Sections 2.3 and 3.3).

(3) Controlled intake flow velocity to limit impingement of organisms on intake structures (ETS Sections 2.2.l

, and 3.2~1.

APR 2 4 1981 2-1 Amendment No. 35

(4) Monitoring of aquatic biota in the Hudson River to evaluate effects of once-through operation (ETS

.. Sec.tion 4.1.2)

Aquatic issues are now addressed by the effluent limitations, monitoring requirements and other conditions in or annexed ...

to the effective SPDES permit issued by the Department of Environmental Conservatiori of the State of New*York (DEC).

The NRC will therefore rely on the DEC for regulation of matters involvirig water quality and aquatic biota.

..,-.

~ ~.

2-2 Amendment No. 35 APR 2 4 1981

-: "" -,.._ ... :::'I C'--c--:: =~-:**.: _...:)-~--==

E~O =ay ~ake :har:;es ** s:atior. =es~;r. or cpera:!or. er perform tests or I experir.1ents affecting the en*1irom::ent pro*:ided such changes, tests or experiments do not involve an unreviewed environmental question, and do not i~volve a change in the Environmental Protection Plan.* Changes in plant design or operation or performance of tests or experiments which do not affect the environment are not subject to the requirements of this EPP. Activities governed by Section 3.3 are not subject to the requirements of this section.

Before engaging in additional construction or operatio~al activities which r.,ay affect the environ.~ent, ENO shall prepare and record an enviroru:iental I

~hen :he evaluation indicates that such ac:i v.:..ty .:..nvol *:es a:-. :Jr:re*:iewed env.:..r::::-.:..er:tal question, ENO shall provide I a written eval~atior. of such activities and obtain prior approval from the Director, Office of Nuclear Reactor Regulation. When such activity involves a change in the Environmental Protection Plan, such activity and change to the Environmental Protection Plan may be

This provision does not relieve the ENO of the requirements of 10 CFR I 50.59.

3-1 Amend'llent No. ~, 203 NOV 2 ! 2000

i~.:;:::.!.e::-.~:::e:i o::!y .:.:-. -=--- . . ~~--~ :-::::-. : .:-. -........... _. . _- . . - ::.:e:-.se ~-.o ... ...:-~-- __

set for:~ in Sectior.

.. .;no: =iosed change, tes: or experi:::ent shall be dee::ied to involve ar.

unreviewed environ::ier.tal questior. if it concerns {l) a matter which rnay result in a significant increase in any adverse environmental impact previously evaluated in the

,,. ,

.1na ... er.1:iro ..::iental stater:lent (fES) as modified by staff's testimony to the Ator:lic Safety and Licensing Boards, supplements to the fES, environmental impact appraisals, or in any decisions of the Atomic Safety and Licensing Board; or (2) a significant change in effluents or power level in accordance with 10 CfR Part 51.S(b) (2); or (3) a matter not previously reviewed and evaluated in the docu::ients specified in (1) of this Subsection, which may have a significant adverse environmental im~act.

S~O shal: ::ia!nta:n records of changes in facility design or operation and I of tests and experiments carried out pursuant to this Subsection. These records shall include a written evaluation which provides a basis for the determination that the change, test, or experiment does not involve an unreviewed environmental question nor constitute a decrease in the effectiveness of this SPP to ~eet the objectives specified in Section 1.0.

ENO shall include as part of his Annual Environmental Protection I 3-2 Amendment No * .a.;,203 lWV 2 l 2GDD

3.2 Reporti~g Related :o :~e NP:ES ~ 0 ~-,~~ a~d State Certifications Violations of the N?DES Permit o= :he State certification (pursuant to Section .;Q! of the Clear. I-late:: Act) shall be ::epo::ted to the NRC by submittal of copies of the reports required by the NPDES Permit or certification.

Changes and additions to the NPDES Permit or the State certification shall be reported to the NRC within 30 days following the date the change is approved. If a permit or certification, in part or in its entirety, is appealed and stayed, the NRC shall be notified within 30 days followir.g the date :he s:ay is g::anted.

The NRC shall be notified of changes to the effective NPDES Permit proposed by ENIP3 and ENO by providing NRC with a copy of the proposed I change at the same time it is submitted to the permitting agency. The notification of a EN!?3 and ENO 3-3 Amendment No.~. 203 rJOV 2 1 ~00

-.: . ::..:::e .

.5,* .... --:* --:..-

.

app!!::::a:.:.0:1 a: :::e sa::ie ti;ne :he appli:::a::io~

3.3 Changes Required for Co~pliance with Other Environmental Regulations Changes in plant design or operation and performance of tests or experiments which are required to achieve compliance with other Federal, State, or local environmental regulations are not subject to the requirements of Section 3.1.

3-4 Amendment No. ~. 203 NOV 2 1 2000

4.0 Environmental Conditions 4.1 Unusual or Important Environmental Events

..

Any occurrence of an unusua1*or important event that indicates or could *resuit in significant environmental impact causally related to plant operation shall be recorded an~ promptly re-ported to the NRC within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months by telephone, telegraph, or facsimile transmissions followed by a written report per Subsection 5.4.2. The following are e~amples: excessive bird impaction events, onsite plant or* animal disease outbreaks, unusual mortality or~occurrence of any species protected by

the Endangered Species Act of 1973, unusual fish kills, unusual.increase in nuisance organisms or conditions, and unanticipated or emergency discharge of waste water or chemical substances.

No routine monitoring programs are required to implement this condition.

4.2 Environmental Monitoring None 4-1 Amendment No. 35 APR 2 4 1981

.o :.*""::*:--.*:,: . . . . ::*:- =...-----.:....; ...... ~::

ENO ;::.::-ovide fo.::- a~d!: c~nplia::ce :.:it!": the I Environr.:en:al Protectio:1 ?lan. T!":e audits shall be conducted independently of the individ~al er g.::-oups .::-esponsible fot performing the specific activity. A des=.::-ipticn of the organization structure utilized to achieve the independent review and audit function and results of the audit activities shall be maintained and made available for inspection.

5.2 Records Retention Records and logs relative :c the envi.::-or..~ental aspects of plant operation shall be r.:ade and retained :n a ~anner convenient for review and inspection. 7hese .::-eco.::-ds an= ~c;s sha:: te ~ade available to NRC on request.

Records of r.-.odifications to plant st::uctures, systems and cor:iponents determined to potentially affect the continued protection of the environr.ient shall be retained for the life of the plant. All other records, data and logs relating tc 5-1 Amendment No. J!t,203 NOV 2 1 2000

this EPP shall be retained for five years or, where applic-able, in accordance with the requirements of other agencies *

..

5.3 Changes in Environmental Protection Plan Request for change in the Environmental Protection Plan shall include an assessment of the environmental impact of the pro-posed change and a ~upporting justifi~ation. Implementation

..

of such changes in the EPP shall.not c~mmence prior to NRC approval of the proposed changes in the form of a license amendment incorporati-ng che appropriate revision to the Erivironmental Protection Plan.

'

'-*/ 5.4 Plant Reporting Requirements 5.4.1 Routine Reports An Annual Environmental Protection Plan Report describing implementation of this EPP for the previous year .shall be submitted to the NRC prior to May 1 of each year. The initial report shall be submitted prior to May 1 of the year following issuance of the operating license. The period of the first report shall begin with the date of issuance of the operating license.

The report shall include summaries and analyses _of the results*

,--- of the environmental protection activities required by Sub-

\__/' s.ection 4. 2 of this Environmental Protection Plan for the APH 24 1981 5-2 Amendment No. 35

_ --- .. --

. ..... -.......

_ _..... .. - --

_....... _,,... ____ _ ... - .. . . . .:i. ... * -: - - - - -'*. - * .s: *..:::":"..:'

\ ......../

evidence of :rends towa:::ds i:-:::eversible da:::age to the em*i:::o:1ment are observed, D:C shall pro*:ide a detailed analysis cf the data and a proposed course of ac:ion :o alleviate ~he p:::ob:e:::.

The Annual Environmental Protection ?lan Report shall also include:*

(al A list of EPP noncompliances and the corrective actions taken to remedy them.

(bl A list of all changes in sta:icn design or operation, tests, and experiments made in accorda:1ce with Subsection 3.1 which involved (Cl .-. of :::e::-c-::::s s:.ib::::.:ted in accordance with Subsectio~ 5.~.2.

(dl A list of all reports subnitted in accordance with the NPDES

\_/'

permit or the State certification.

In the event that some results are not available by the report due date, the report shall be submitted noting and explaining the missing results.

The missing data shall be submitted as soon as* possible in a supple~entary report.

5-3 Amendment No . .a.;, 203 NOV 2 1 2000

5.4.2 Nonroutine Reports

.. .

A written report shall be submitted to the NRC within 30 days of occurrence of nonroutine event. The*~eport shall (a) de-scribe, analyze, and evaluate the event, including extent and magnitude of the impact and plant operating cha~acteristics, (b) describe the probable cause of the event, (c) indicate the action taken to correct the reported event, (d) indicate the corrective action taken to preclude repetition of the event and to prevent similar occurrences involving similar

..

components or systems, and (e) indicate the agencies notified and their preliminary responses.

l *

~I Events reportable under this subsection which also require reports to other Federal, State *or local agencies shall be reported in accordance with those reporting requirements in lieu of the requirements of this subsection. The NRC shall be provided a copy of such report at the same time it is submitted to the other agency.

-

APR 2 4 1981 5-4 Amendment No. 35

- -.--**-

.-.=-==- -*- --'* -** -

...

~

~ ......,

.. ,...,

ENTERGY NUCLEAR OPEE\ATIONS , I~C .

INDIAN POINT 3 I

NUCLEAR POWE~ PLANT REQU I RE:~:s:*s Amendmen t No. M, 203 11 rum

DELETED BY AMENDMENT NO. 205 1/2-1

APPENDIXC TO FACILITY OPERATING LICENSE FOR ENTERGY NUCLEAR JNDIAN POINT 3, LLC (ENIP3)

AND ENTERGY NUCLEAR OPERATIONS, INC. (ENO)

INDJAN POINT NUCLEAR GENERATING UNIT No. 3 INTER-UNIT FUEL TRANSFER TECHNICAL SPECIFICATIONS PART I: SPENT FUEL TRANSFER CANISTER AND TRANSFER CASK SYSTEM FACILITY LICENSE NO. DPR-64 DOCKET NO. 50-286 Amendment No. 246

Facility Operating License Appendix C - Inter-Unit Fuel Transfer Technical Specifications SPENT FUEL SHIELDED TRANSFER CANISTER AND TRANSFER CASK SYSTEM

1.0 DESCRIPTION

The spent fuel transfer system consists of the following components: ( 1) a spent fuel shielded transfer canister (STC), which contains the fuel; (2) a transfer cask (HI-TRAC 100D) (hereafter referred to as HI-TRAC), which contains the STC during transfer operations; and (3) a bottom missile shield.

The STC and HI-TRAC are designed to transfer irradiated nuclear fuel assemblies from the Indian Point 3 (IP3) spent fuel pit to the Indian Point 2 (IP2) spent fuel pit. A fuel basket within the STC holds the fuel assemblies and provides criticality control. The shielded transfer canister provides the confinement boundary, water retention boundary, gamma radiation shielding, and heat rejection capability. The HI-TRAC provides a water retention boundary, protection of the STC, gamma and neutron radiation shielding, and heat rejection capability. The STC contains up to 12 fuel assemblies.

The STC is the confinement system for the fuel. It is a welded, multi-layer steel and lead cylinder with a welded base-plate and bolted lid. The inner shell of the canister forms an internal cylindrical cavity for housing the fuel basket. The outer surface of the canister inner shell is buttressed with lead and steel shells for radiation shielding. The minimum thickness of the steel, lead and steel shells relied upon for shielding starting with the innermost shell are% inch steel, 2 % inch lead and% inch steel, respectively. The canister closure incorporates two 0-ring seals to ensure its confinement function. The confinement system consists of the canister inner shell, bottom plate, top flange, top lid, top lid 0-ring seals, vent port seal and cover plate, and drain port seal and coverplate. The fuel basket, for the transfer of 12 Pressurized Water Reactor (PWR) fuel assemblies, is a fully welded, stainless steel, honeycomb structure with neutron absorber panels attached to the individual storage cell walls under stainless steel sheathing.

The maximum gross weight of the fully loaded STC is 40 tons.

The HI-TRAC is a multi-layer steel and lead cylinder with a bolted bottom (or pool) and top lid.

For the fuel transfer operation the HI-TRAC is fitted with a solid top lid, an STC centering assembly, and a bottom missile shield. The inner shell of the transfer cask forms an internal cylindrical cavity for housing the STC. The outer surface of the cask inner shell is buttressed with intermediate lead and steel shells for radiation shielding. The minimum thickness of the steel, lead and steel shells relied upon for shielding starting with the innermost shell are% inch steel, 2 Ve inch lead and 1 inch steel, respectively. An outside shell called the "water jacket" contains water for neutron shielding, with a minimum thickness of 5". The HI-TRAC bottom and top lids incorporate a gasket seal design to ensure its water confinement function. The water confinement system consists of the HI-TRAC inner shell, bottom lid, top lid, top lid seal, bottom lid seal, vent port seal, vent port cap and bottom drain plug.

The HI-TRAC provides a water retention boundary, protection of the STC, gamma and neutron radiation shielding, and heat rejection capability. The bottom missile shield is attached to the bottom of the HI-TRAC and provides tornado missile protection of the pool lid bolted joint. The HI-TRAC can withstand a tornado missile in other areas without the need for additional shielding. The STC centering assembly provides STC position control within the HI-TRAC and also acts as an internal impact limiter in the event of a non-mechanistic tipover accident.

lNDIAN POINT 3 1 Amendment 246

Facility Operating License Appendix C - Inter-Unit Fuel Transfer Technical Specifications 2.0 CONDITIONS 2.1 OPERATING PROCEDURES Written operating procedures shall be prepared for cask handling, loading, movement, surveillance, maintenance, and recovery from off normal conditions such as crane hang-up. The written operating procedures shall be consistent with the technical basis described in Chapter 1O of the Licensing Report (Holtec International Report Hl-2094289).

2.2 ACCEPTANCE TESTS AND MAINTENANCE PROGRAM Written cask acceptance tests and maintenance program shall be prepared consistent with the technical basis described in Chapter 8 of the Licensing Report (Holtec International Report Hl-2094289).

2.3 PRE-OPERATIONAL TESTING AND TRAINING EXERCISE A training exercise of the loading, closure, handling/transfer, and unloading, of the equipment shall be conducted prior to the first transfer. The training exercise shall not be conducted with irradiated fuel. The training exercise may be performed in an alternate step sequence from the actual procedures, but all steps must be performed. The training exercise shall include, but is not limited to the following:

a) Moving the STC into the IP3 spent fuel pool.

b) Preparation of the HI-TRAC for STC loading.

c) Selection and verification of specific fuel assemblies and non-fuel hardware to ensure type conformance.

d) Loading specific assemblies and placing assemblies into the STC (using a single dummy fuel assembly), including appropriate independent verification.

e) Remote installation of the STC lid and removal of the STC from the spent fuel pool.

f) Placement of the STC into the HI-TRAC with the STC centering assembly.

g) STC closure, establishment of STC water level with steam, verification of STC water level, STC leakage testing, and operational steps required prior to transfer, as applicable.

h) Establishment and verification of HI-TRAC water level.

i) Installation of the HI-TRAC top lid.

j) HI-TRAC closure, leakage testing, and operational steps required prior to transfer, as applicable.

k) Movement of the HI-TRAC with STC from the IP3 fuel handling building to the IP2 fuel handling building along the haul route with designated devices.

I) Moving the STC into the IP2 spent fuel pool.

m) Manual crane operations for bare STC movements including demonstration of recovery from a crane hang-up with the STC suspended from the crane.

INDIAN POINT 3 2 Amendment 246

APPENDIX C TO FACILITY OPERATING LICENSE FOR ENTERGY NUCLEAR INDIAN POINT 3, LLC (ENIP3)

AND ENTERGY NUCLEAR OPERATIONS, INC. (ENO)

INDIAN POINT NUCLEAR GENERATING UNIT No. 3 INTER-UNIT FUEL TRANSFER TECHNICAL SPECIFICATIONS PART II: TECHNICAL SPECIFICATIONS FACILITY LICENSE NO. DPR-64 DOCKET NO. 50-286 Amendment No. 246

TABLE OF CONTENTS 1.0 USE AND APPLICATION 1.1 Definitions 1.2 Logical Connectors 1.3 Completion Times 1.4 Frequency 2.0 NOT USED 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY 3.1 INTER-UNIT FUEL TRANSFER 3.1.1 Boron Concentration 3.1.2 Shielded Transfer Canister (STC) Loading 3.1.3 Shielded Transfer Canister (STC) Initial Water Level 3.1.4 Shielded Transfer Canister (STC) Pressure Rise 3.1.5 Shielded Transfer Canister (STC) Unloading 4.0 DESIGN FEATURES 4.1 Inter-Unit Fuel Transfer 5.0 PROGRAMS 5.1 Transport Evaluation Program 5.2 Metamic Coupon Sampling Program 5.3 Technical Specifications Bases Control Program 5.4 Radiation Protection Program INDIAN POINT 3 Amendment 246

Definitions 1.1 1.0 USE AND APPLICATION 1.1 Definitions

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

The defined terms of this section appear in capitalized type and are applicable throughout these Technical Specifications and Bases.

Definition ACTIONS ACTIONS shall be that part of a Specification that prescribes Required Actions to be taken under designated Conditions within specified Completion Times.

INTACT FUEL ASSEMBLIES INTACT FUEL ASSEMBLIES are fuel assemblies without known or suspected cladding defects greater than pinhole leaks or hairline cracks, and which can be handled by normal means. Fuel assemblies without fuel rods in fuel rod locations shall not be classified as INTACT FUEL ASSEMBLIES unless dummy fuel rods are used to displace an amount of water greater than or equal to that displaced by the original fuel rod(s).

LOADING OPERATIONS LOADING OPERATIONS include all licensed activities on an STC while it is being loaded with fuel assemblies and while the STC is being placed in the HI-TRAC. LOADING OPERATIONS begin when the first fuel assembly is placed in the STC and end when the HI-TRAC is suspended from or secured on the TRANSPORTER.

NON-FUEL HARDWARE (NFH) NFH is defined as Burnable Poison Rod Assemblies (BPRAs), Thimble Plug Devices (TPDs), Wet Annular Burnable Absorbers (WABAs), Rod Cluster Control Assemblies (RCCAs), Neutron Source Assemblies (NSAs), Hafnium Flux Suppressors, and Instrument Tube Tie Rods (ITTRs).

TRANSFER OPERATIONS TRANSFER OPERATIONS include all licensed activities performed on a HI-TRAC loaded with one or more fuel assemblies when it is being moved after LOADING OPERATIONS or before UNLOADING OPERATIONS.

TRANSFER OPERATIONS begin when the HI-TRAC is first suspended from or secured on the TRANSPORTER and end when the TRANSPORTER is at its destination and the HI-TRAC is no longer secured on or suspended from the TRANSPORTER.

TRANSPORTER TRANSPORTER is the device or vehicle which moves the HI-TRAC. The TRANSPORTER can either support the HI-TRAC from underneath or the HI-TRAC can be suspended from it.

(continued)

INDIAN POINT 3 1.1-1 Amendment 246

Definitions 1.1 1.1 Definitions (continued)

Definition UNLOADING OPERATIONS UNLOADING OPERATIONS include all licensed activities on an STC or HI-TRAC while it is being unloaded of the contained fuel assemblies. UNLOADING OPERATIONS begin when the HI-TRAC is no longer suspended from or secured on the TRANSPORTER and end when the last fuel assembly is removed from the STC.

ZR ZR means any zirconium-based fuel cladding authorized for use in a commercial nuclear power plant reactor.

INDIAN POINT 3 1.1-2 Amendment 246

Logical Connectors 1.2 1.0 USE AND APPLICATION 1.2 Logical Connectors PURPOSE The purpose of this section is to explain the meaning of logical connectors.

Logical connectors are used in Technical Specifications (TS) to discriminate between, and yet connect, discrete Conditions, Required Actions, Completion Times, Surveillances, and Frequencies. The only logical connectors that appear in TS are AND and OR. The physical arrangement of these connectors constitutes logical conventions with specific meanings.

BACKGROUND Several levels of logic may be used to state Required Actions. These levels are identified by the placement (or nesting) of the logical connectors and by the number assigned to each Required Action. The first level of logic is identified by the first digit of the number assigned to a Required Action and the placement of the logical connector in the first level of nesting (Le., left justified with the number of the Required Action).

The successive levels of logic are identified by additional digits of the Required Action number and by successive indentions of the logical connectors.

When logical connectors are used to state a Condition, Completion Time, Surveillance, or Frequency, only the first level of logic is used, and the logical connector is left justified with the statement of the Condition, Completion Time, Surveillance, or Frequency.

(continued)

INDIAN POINT 3 1.2-1 Amendment 246

Logical Connectors 1.2 1.2 Logical Connectors (continued)

EXAMPLES The following examples illustrate the use of logical connectors.

EXAMPLE 1.2-1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LCO not met. A.1 VERIFY ...

AND A.2 Restore ...

In this example the logical connector AND is used to indicate that when in Condition A, both Required Actions A.1 and A.2 must be completed.

(continued)

INDIAN POINT 3 1.2-2 Amendment 246

Logical Connectors 1.2 1.2 Logical Connectors (continued)

EXAMPLES EXAMPLE 1.2-2 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LCO not met. A.1 Stop ...

OR A.2.1 Verify ...

AND A.2.2.1 Reduce ...

OR A.2.2.2 Perform ...

OR A.3 Remove ...

This example represents a more complicated use of logical connectors.

Required Actions A.1, A.2, and A.3 are alternative choices, only one of which must be performed as indicated by the use of the logical connector OR and the left justified placement. Any one of these three ACTIONS may be chosen. If A.2 is chosen, then both A.2.1 and A.2.2 must be performed as indicated by the logical connector AND. Required Action A.2.2 is met by performing A.2.2.1 or A.2.2.2. The indented position of the logical connector OR indicates that A.2.2.1 and A.2.2.2 are alternative choices, only one of which must be performed.

IN DIAN POINT 3 1.2-3 Amendment 246

Completion Times 1.3 1.0 USE AND APPLICATION 1.3 Completion Times PURPOSE The purpose of this section is to establish the Completion Time convention and to provide guidance for its use.

BACKGROUND Limiting Conditions for Operation (LCOs) specify the lowest functional capability or performance levels of equipment required for safe operation of the facility. The ACTIONS associated with an LCO state Conditions that typically describe the ways in which the requirements of the LCO can fail to be met. Specified with each stated Condition are Required Action(s) and Completion Times(s).

DESCRIPTION The Completion Time is the amount of time allowed for completing a Required Action. It is referenced to the time of discovery of a situation (e.g., equipment or variable not within limits) that requires entering an ACTIONS Condition unless otherwise specified, providing the Spent Fuel Shielded Transfer Canister and Transfer Cask System is in a specified condition stated in the Applicability of the LCO. Required Actions must be completed prior to the expiration of the specified Completion Time. An ACTIONS Condition remains in effect and the Required Actions apply until the Condition no longer exists or the Spent Fuel Shielded Transfer Canister and Transfer Cask System is not within the LCO Applicability.

Once a Condition has been entered, subsequent subsystems, components, or variables expressed in the Condition, discovered to be not within limits, will not result in separate entry into the Condition unless specifically stated. The Required Actions of the Condition continue to apply to each additional failure, with Completion Times based on initial entry into the Condition.

(continued)

INDIAN POINT 3 1.3-1 Amendment 246

Completion Times 1.3 1.3 Completion Times (continued}

EXAMPLES The following examples illustrate the use of Completion Times with different types of Conditions and changing Conditions.

EXAMPLE 1.3-1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. Required B.1 Perform Action B.1 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Action and associated Completion Time not met. B.2 Perform Action B.2 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months I

Condition B has two Required Actions. Each Required Action has its own separate Completion Time. Each Completion Time is referenced to the time that Condition B is entered.

The Required Actions of Condition B are to complete action B.1 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND complete action B.2 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . A total of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is allowed for completing action B.1 and a total of 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (not 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months ) is allowed for completing action B.2 from the time that Condition B was entered. If action B.1 is completed within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , the time allowed for completing action B.2 is the next 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months because the total time allowed for completing action B.2 is 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

(continued)

INDIAN POINT 3 1.3-2 Amendment 246

Completion Times 1.3 1.3 Completion Times (continued)

EXAMPLES EXAMPLE 1.3-2 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One system A.1 Restore system 7 days not within limit. to within limit.

B. Required B.1 Complete 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Action and action B.1.

associated Completion AND Time not met.

B.2 Complete 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months action B.2.

When a system is determined not to meet the LCO, Condition A is entered. If the system is not restored within 7 days, Condition B is also entered and the Completion Time clocks for Required Actions B.1 and B.2 start. If the system is restored after Condition B is entered, Conditions A and B are exited, and therefore, the Required Actions of Condition B may be terminated.

(continued)

INDIAN POINT 3 1.3-3 Amendment 246

Completion Times 1.3 1.3 Completion Times (continued)

EXAMPLES EXAMPLE 1.3-3 (continued)

ACTIONS

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

Separate Condition entry is allowed for each component.

CONDITION REQUIRED ACTION COMPLETION TIME A LCO not met. A.1 Restore 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months compliance with LCO.

8. Required 8.1 Complete action 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and 8.1.

associated Completion AND Time not met.

8.2 Complete action 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 8.2.

The Note above the ACTIONS table is a method of modifying how the Completion Time is tracked. If this method of modifying how the Completion Time is tracked was applicable only to a specific Condition, the Note would appear in that Condition rather than at the top of the ACTIONS Table.

The Note allows Condition A to be entered separately for each component, and Completion Times tracked on a per component basis.

When a component is determined to not meet the LCO, Condition A is entered and its Completion Time starts. If subsequent components are determined to not meet the LCO, Condition A is entered for each component and separate Completion Times start and are tracked for each component.

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

TIME INDIAN POINT 3 1.3-4 Amendment 246

Frequency 1.4 1.0 USEANDAPPLICATION 1.4 Frequency PURPOSE The purpose of this section is to define the proper use and application of Frequency requirements.

DESCRIPTION Each Surveillance Requirement (SR) has a specified Frequency in which the Surveillance must be met in order to meet the associated Limiting Condition for Operation (LCO). An understanding of the correct application of the specified Frequency is necessary for compliance with the SR.

The "specified Frequency" is referred to throughout this section and each of the Specifications of Section 3.0, Surveillance Requirement (SR)

Applicability. The "specified Frequency" consists of the requirements of the Frequency column of each SR.

Situations where a Surveillance could be required (i.e., its Frequency could expire), but where it is not possible or not desired that it be performed until sometime after the associated LCO is within its Applicability, represent potential SR 3.0.4 conflicts. To avoid these conflicts, the SR (i.e., the Surveillance or the Frequency) is stated such that it is only "required" when it can be and should be performed. With an SR satisfied, SR 3.0.4 imposes no restriction.

(continued)

INDIAN POINT 3 1.4-1 Amendment 246

Frequency 1.4 1.4 Frequency (continued)

EXAMPLES The following examples illustrate the various ways that Frequencies are specified.

EXAMPLE 1.4-1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Verify pressure within limit 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Example 1.4-1 contains the type of SR most often encountered in the Technical Specifications (TS). The Frequency specifies an interval (12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ) during which the associated Surveillance must be performed at least one time. Performance of the Surveillance initiates the subsequent interval. Although the Frequency is stated as 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , an extension of the time interval to 1.25 times the interval specified in the Frequency is allowed by SR 3.0.2 for operational flexibility. The measurement of this interval continues at all times, even when the SR is not required to be met per SR 3.0.1 (such as when the equipment or variables are outside specified limits, or the facility is outside the Applicability of the LCO). If the interval specified by SR 3.0.2 is exceeded while the facility is in a condition specified in the Applicability of the LCO, the LCO is not met in accordance with SR 3.0.1.

If the interval as specified by SR 3.0.2 is exceeded while the facility is not in a condition specified in the Applicability of the LCO for which performance of the SR is required, the Surveillance must be performed within the Frequency requirements of SR 3.0.2 prior to entry into the specified condition. Failure to do so would result in a violation of SR 3.0.4.

(continued)

INDIAN POINT 3 1.4-2 Amendment 246

Frequency 1.4 1.4 Frequency (continued)

EXAMPLES (continued) EXAMPLE 1.4-2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Verify flow is within limits. Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months prior to starting activity AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter Example 1.4-2 has two Frequencies. The first is a one time performance Frequency, and the second is of the type shown in Example 1.4-1. The logical connector "AND" indicates that both Frequency requirements must be met. Each time the example activity is to be performed, the Surveillance must be performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months prior to starting the activity.

The use of "once" indicates a single performance will satisfy the specified Frequency (assuming no other Frequencies are connected by "AND").

This type of Frequency does not qualify for the 25% extension allowed by SR 3.0.2.

"Thereafter" indicates future performances must be established per SR 3.0.2, but only after a specified condition is first met (i.e., the "once" performance in this example). If the specified activity is canceled or not performed, the measurement of both intervals stops. New intervals start upon preparing to restart the specified activity.

INDIAN POINT 3 1.4-3 Amendment 246

Not Used 2.0 2.0 NOT USED This section is intentionally left blank INDIAN POINT 3 2.0-1 Amendment 246

LCO Applicability 3.0 3.0 LIMITING CONDITIONS FOR OPERATION (LCO) APPLICABILITY LCO 3.0.1 LCOs shall be met during specified conditions in the Applicability, except as provided in LCO 3.0.2.

LCO 3.0.2 Upon discovery of a failure to meet an LCO, the Required Actions of the associated Conditions shall be met, except as provided in LCO 3.0.5.

If the LCO is met or is no longer applicable prior to expiration of the specified Completion Time(s), completion of the Required Action(s) is not required, unless otherwise stated.

LCO 3.0.3 Not applicable.

LCO 3.0.4 When an LCO is not met, entry into a specified condition in the Applicability shall not be made except when the associated ACTIONS to be entered permit continued operation in the specified condition in the Applicability for an unlimited period of time. This Specification shall not prevent changes in specified conditions in the Applicability that are required to comply with ACTIONS or that are related to the unloading of an STC.

LCO 3.0.5 Equipment removed from service or not in service in compliance with ACTIONS may be returned to service under administrative control solely to perform testing required to demonstrate it meets the LCO or that other equipment meets the LCO. This is an exception to LCO 3.0.2 for the system returned to service under administrative control to perform the testing.

INDIAN POINT 3 3.0-1 Amendment 246

SR Applicability 3.0 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY SR 3.0.1 SRs shall be met during the specified conditions in the Applicability for individual LCOs, unless otherwise stated in the SR. Failure to meet a Surveillance, whether such failure is experienced during the performance of the Surveillance or between performances of the Surveillance, shall be failure to meet the LCO. Failure to perform a Surveillance within the specified Frequency shall be failure to meet the LCO except as provided in SR 3.0.3. Surveillances do not have to be performed on equipment or variables outside specified limits.

SR 3.0.2 The specified Frequency for each SR is met if the Surveillance is performed within 1.25 times the interval specified in the Frequency, as measured from the previous performance or as measured from the time a specified condition of the Frequency is met.

For Frequencies specified as "once," the above interval extension does not apply. If a Completion Time requires periodic performance on a "once per ... " basis, the above Frequency extension applies to each performance after the initial performance.

Exceptions to this Specification are stated in the individual Specifications.

SR 3.0.3 If it is discovered that a Surveillance was not performed within its specified Frequency, then compliance with the requirement to declare the LCO not met may be delayed, from the time of discovery, up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or up to the limit of the specified Frequency, whichever is less. This delay period is permitted to allow performance of the Surveillance.

If the Surveillance is not performed within the delay period, the LCO must immediately be declared not met, and the applicable Condition(s) must be entered.

When the Surveillance is performed within the delay period and the Surveillance is not met, the LCO must immediately be declared not met, and the applicable Condition(s) must be entered.

SR 3.0.4 Entry into a specified condition in the Applicability of an LCO shall not be made unless the LCO's Surveillances have been met within their specified Frequency. This provision shall not prevent entry into specified conditions in the Applicability that are required to comply with Actions or that are related to the unloading of an STC.

INDIAN POINT 3 3.0-2 Amendment 246

Boron Concentration 3.1.1 3.1 INTER-UNIT FUEL TRANSFER 3.1.1 Boron Concentration LCO 3.1.1 The boron concentration of the water in the Spent Fuel Pit and the STC shall be ~ 2000 ppm.

APPLICABILITY: Whenever one or more fuel assemblies are in the STC.

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

Only applicable to the spent fuel pit when the STC is in the spent fuel pit ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. Boron concentration not A.1 Suspend LOADING Immediately within limit. OPERATIONS or UNLOADING OPERATIONS.

A.2 Suspend positive reactivity Immediately additions.

A.3 Initiate action to restore boron Immediately concentration to within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

NOTE------------------------ Once, within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months prior to This surveillance is only required to be performed if the STC is entering the submerged in water in the spent fuel pool or if water is added to, or Applicability of this recirculated through, the STC when the STC is in the HI-TRAC. Any LCO.

added water must meet the boron concentration requirement of LCO 3.1.1.

SR 3.1.1.1 Verify the boron concentration is within limit using two Once per 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months separate measurements.

I thereafter.

INDIAN POINT 3 3.1.1-1 Amendment 246

STC Loading 3.1.2 3.1 INTER-UNIT FUEL TRANSFER 3.1.2 Shielded Transfer Canister (STC) Loading LCO 3.1.2 INTACT FUEL ASSEMBLIES placed into the Shielded Transfer Canister (STC) shall be classified in accordance with Table 3.1.2-1 based on initial enrichment and burnup and shall be restricted based on the following:

a. INTACT FUEL ASSEMBLIES classified as Type 2 may be placed in the STC basket (see Figure 3.1.2-1) with the following restrictions:

1. Post-irradiation cooling time, initial enrichment, and allowable average burnup shall be within the limits for the cell locations as specified in Table 3.1.2-3;

2. Decay heat including NON FUEL HARDWARE s 1.2 kW (any cell);

3. Total STC Decay heat from all cell locations including NON FUEL HARDWARE s9.621 kW;

4. Post-irradiation cooling time and the maximum average burnup of NON FUEL HARDWARE shall be within the cell locations and limits specified in Table 3.1.2-2. In accordance with Table 3.1.2-2 RCCAs and Hafnium Flux Suppressors cannot be placed in locations 5, 6, 7, 8, 9, 10, 11, 12 of the STC basket.

- NOTE -

If one or more Type 1 fuel assemblies are in the STC, cells 1, 2, 3, AND 4 must be empty, with a cell blocker installed that prevents inserting fuel assemblies and/or NON-FUEL HARDWARE.

b. INTACT FUEL ASSEMBLIES classified as Type 1 or Type 2 may be placed in locations 5, 6, 7, 8, 9, 10, 11, 12 of the STC basket (see Figure 3.1.2-1) with the following restrictions:

1. Post-irradiation cooling time, initial enrichment, and allowable average burnup shall be within the limits for the cell locations as specified in Table 3.1.2-3;

2. Decay heat including NON FUEL HARDWARE s 1.2 kW;

3. Post-irradiation cooling time and the maximum average burnup of NON FUEL HARDWARE shall be within the cell locations and limits specified in Table 3.1.2-2. In accordance with Table 3.1.2-2 RCCAs and Hafnium Flux Suppressors cannot be placed in locations 5, 6, 7, 8, 9, 10, 11, 12 of the STC basket.

c. Only INTACT FUEL ASSEMBLIES with initial average enrichment s 4.4 wt% U-235 and discharged prior to IP3 Cycle 12 shall be placed in the STC basket. IP3 fuel assemblies V43 and V48 shall not be selected for transfer.

INDIAN POINT 3 3.1.2-1 Amendment No. 264

STC Loading

3.1.2 APPLICABILITY

Whenever one or more fuel assemblies are in the STC.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more fuel A.1.1 Initiate action to Immediately assemblies or NON restore compliance FUEL HARDWARE in with LCO 3.1.2.

the STC do not meet the LCO limits.

A.1.2 Initiate action to move fuel to the IP3 spent fuel pit in accordance with IP3 Appendix A Technical Specrfication LCO 3.7.16.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.2.1 Verify by administrative means that the fuel Prior to placing the fuel assembly and NON FUEL HARDWARE meets the assembly in the STC.

requirements specified in the LCO for placement in the STC.

SR 3.1.2.2 Verify by visual inspection that a cell blocker which Prior to placing a Type 1 prevents inserting fuel assemblies and/or NON- fuel assembly in the STC.

FUEL HARDWARE into cells 1, 2, 3, and 4 of the STC is installed.

INDIAN POINT 3 3.1.2-2 Amendment 246

STC Loading 3.1.2 Cell Cell 5 6 Cell Cell Cell Cell 12 1 2 7 Cell Cell Cell Cell 11 4 3 8 Cell Cell 10 9 Figure 3.1.2-1 Shielded Transfer Canister Layout (Top View)

INDIAN POINT 3 3.1.2-3 Amendment 246

STC Loading 3.1.2 Table 3.1.2-1 Minimum Burnup Requirements at Varying Initial Enrichments<a)

Configuration A(cJ Configuration s<d)

Maximum Assembly Minimum Assembly Minimum Assembly Initial Enrichment<1>( 9l Average Bumup Average Burnup (wt% U235)

(MWD/MTU)(b) (MWD/MTU)lbl I

2.0 5,400 6,000 2.5 13,800 18,800 3.0 22,100 28,600 3.5 30,000 37,300 4.0 36,900 44,600 I 4.5 42,700 52,500 I 5.0 48,700 Note (e) I (a) Fuel that does not meet the minimum assembly average burnup at a given initial enrichment is classified as Type 1 fuel. Fuel that meets the minimum assembly average burnup at a given initial enrichment is classified as Type 2 fuel.

(b) Linear interpolation between enrichment levels to determine minimum burnup requirements is permitted.

(c) Assemblies that have not been located in any cycle under a control rod bank that was permitted to be inserted during full power operation or where it can be shown that the insertion did not exceed 8 inches below the top of the active fuel.

(d) Assemblies that have been located under a control rod bank that was permitted to be inserted during full power operation and where the insertion was more than 8 inches below the top of the active fuel. This configuration also applies to fuel assemblies that have contained a Hafnium Flux Suppressor.

(e) Configuration B assemblies with enrichment greater than 4.5 are classified as Type 1 fuel.

(f) Natural or enriched uranium blankets are not considered in determining the fuel assembly average enrichment for comparison to the maximum allowed initial average enrichment.

(g) Rounding to one decimal place to determine initial enrichment is not permitted.

INDIAN POINT 3 3.1.2-4 Amendment 246

STC Loading 3.1.2 Table 3.1.2-2 NON FUEL HARDWARE(a) Post Irradiation Cooling Times and Allowable Average Burnup Maximum Burnup Post-irradiation (MWD/MTU)

Cooling Time (years) BPRAs and Hafnium Flux TPDs(b)(c) RCCAs WABAs(b,dJ Suppressors 2: 6 s 20000 N/A s 630000 s 20000 2:7 - s 20000 - -

2: 8 s 30000 - - s 30000 2: 9 s 40000 s 30000 - -

2: 10 s 50000 s 40000 - -

2: 11 s 60000 s 45000 - -

2: 12 - s 50000 - -

2: 13 - s 60000 - -

2: 14 - - - -

2:15 - s 90000 - -

2: 16 - s 630000 -

2: 20 - - - -

Allowed Up to twelve Up to twelve Up to four (4) Up to four (4)

Quantity and (12) per transfer (12) per per transfer in per transfer in Location in any location transfer in Cells 1, 2, 3, Cells 1, 2, 3, any location and/or 4 and/or 4 (a) NON-FUEL HARDWARE burnup and cooling time limits are not applicable to Instrument Tube Tie Rods (ITTRs), since they are installed post-irradiation. NSAs are not authorized for loading in the STC.

(b) Linear interpolation between points is only permitted for BPRAs, WABAs, and TPDs, with the exception that interpolation is not permitted for TPDs with burnups greater than 90 GWd/MTU and cooling times greater than 15 years.

(c) N/A means not authorized for loading at this cooling time.

(d) Burnup and Cooling time limits in this column are only applicable to Loading Patterns 1-6 in Table 3.1.2-3. For Loading Patterns 7-12 in Table 3.1.2-3, the burnup and cooling time limits for a BPRA are the same as those for the fuel assembly they are located in.

INDIAN POINT 3 3.1.2-5 Amendment No. 264

STC Loading 3.1.2 Table 3.1.2-3 (Sheet 1 of 2)

Allowable STC Loading Configurations

! Configuration<c) Cells 1, 2, 3, 4(a)(b) Cells 5, 6, 7, 8, 9, 10, 11, 12(a)(bJ I Burnup :S 55,000 MWD/MTU Burnup :S 40,000MWD/MTU 1 Cooling time ~ 10 years Cooling time ~ 25 years Initial Enrichment ~ 3.4 wt% U-235 Initial Enrichment~ 2.3 wt% U-235 I Burnup :S 45,000 MWD/MTU Burnup :S 45,000 MWD/MTU 2 Cooling time ~ 10 years Cooling time ~ 20 years Initial Enrichment ~ 3.2 wt% U-235 Initial Enrichment ~ 3.2 wt% U-235 i

Burnup :S 55,000 MWD/MTU Burnup s 45,000 MWD/MTU 3 Cooling time ~ 10 years Cooling time ~ 20 years Initial Enrichment ~ 3.4 wt% U-235 Initial Enrichment ~ 3.2 wt% U-235 Burnup :S 45,000 MWD/MTU Burnup :S40,000 MWD/MTU 4 Cooling time ~ 10 years Cooling time ~ 12 years Initial Enrichment~ 3.6 wt% U-235 Initial Enrichment ~ 3.2 wt% U-235 Burnup :S 45,000 MWD/MTU Burnup :S 40,000 MWD/MTU 5 Cooling time ~ 14 years Cooling time ~ 12 years I Initial Enrichment ~ 3.4 wt% U-235 Initial Enrichment~ 3.2 wt% U-235 Burnup :S 45,000 MWD/MTU Burnup :S 40,000 MWD/MTU 6 Cooling time ~ 20 years Cooling time ~ 20 years Initial Enrichment~ 3.2 wt% U-235 Initial Enrichment ~ 2.3 wt% U-235 INDIAN POINT 3 3.1.2-6 Amendment No. 264

STC Loading 3.1.2 Table 3.1.2-3 (Sheet 2 of 2)

Allowable STC Loading Configurations Configuration(cJ Cells 1, 2, 3, 4(a)(bJ Cells 5, 6, 7, 8, 9, 10, 11, 12(a)(b)

Burnup :s; 45,000 MWD/MTU Burnup :s; 45,000 MWD/MTU 7

Cooling time:::: 10 years Cooling time 2: 12 years Initial Enrichment 2: 3.2 wt% U-235 Initial Enrichment :::: 3.2 wt% U-235 Burnup :s; 55,000 MWD/MTU Burnup :s; 55,000 MWD/MTU 8

Cooling time 2: 10 years Cooling time 2: 15 years Initial Enrichment 2: 3.4 wt% U-235 Initial Enrichment 2: 3.4 wt% U-235 Burnup :s; 55,000 MWD/MTU Burnup s 45,000 MWD/MTU 9

Cooling time 2: 11 years Cooling time 2: 12 years Initial Enrichment 2: 3.4 wt% U-235 Initial Enrichment 2: 3.2 wt% U-235 Burnup::; 45,000 MWD/MTU Burnup ::; 55,000 MWD/MTU 10 Cooling time :::: 10 years Cooling time 2: 15 years Initial Enrichment 2: 3.2 wt% U-235 Initial Enrichment 2: 3.4 wt% U-235 Burnup s 45,000 MWD/MTU Burnup :s; 45,000 MWD/MTU 11 Cooling time 2: 6 years Cooling time 2: 14 years Initial Enrichment 2: 3.2 wt% U-235 Initial Enrichment 2: 3.2 wt% U-235 Burnup ::; 60,000 MWD/MTU Burnup :s; 50,000 MWD/MTU 12 Cooling time :::: 9 years Cooling time:::: 14 years Initial Enrichment 2: 4.2 wt% U-235 Initial Enrichment 2: 3.6 wt% U-235 (a) Initial enrichment is the assembly average enrichment. Natural or enriched uranium blankets are not considered in determining the fuel assembly average enrichment for comparison to the minimum allowed initial average enrichment.

(b) Rounding to one decimal place to determine initial enrichment is permitted.

(c) Fuel with five middle lnconel spacers are limited to cells 1, 2, 3, and 4 for all loading configurations except loading configuration 6 which allows fuel with lnconel spacers in all cells.

INDIAN POINT 3 3.1.2-7 Amendment No. 264

STC Initial Water Level 3.1.3 3.1 INTER-UNIT FUEL TRANSFER 3.1.3 Shielded Transfer Canister (STC) Initial Water Level LCO 3.1.3 The established water level in the STC shall be 9.0+0.5/-1.5 inches below the bottom of the STC lid.

APPLICABILITY: Prior to TRANSFER OPERATIONS when the STC is in the HI-TRAC and the STC lid has been installed.

ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. STC water level not within -----------------NOTE------------- Immediately limit.

Water used for level restoration must meet the boron concentration requirement of LCO 3.1.1.

A.1 Initiate action to restore STC water level.

I I

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.3.1 Verify the initial STC water level is within limit by Once prior to verifying the following during STC water level TRANSFER establishment: OPERATIONS.

a. steam is emitted from the STC drain tube; and

b. the volume of water removed is ~ 35.4 gallons and~ 47.9 gallons.

INDIAN POINT 3 3.1.3-1 Amendment 246

STC Pressure Rise 3.1.4 3.1 INTER-UNIT FUEL TRANSFER 3.1.4 Shielded Transfer Canister (STC) Pressure Rise LCO 3.1.4 The pressure rise in the STC cavity shall bes 0.2 psi/hr averaged over a rolling 4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months period.

APPLICABILITY: Over a 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period after successful completion of LCO 3.1.3 and prior to TRANSFER OPERATIONS when the STC is in the HI-TRAC and the STC lid has been installed.

ACTIONS COMPLETION CONDITION I REQUIRED ACTION TIME A. Rate of STC cavity A.1.1 Establish a vent path on the Immediately pressure rise not within STC.

limit.

AND

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

Water used for recirculation must meet the boron concentration requirement of LCO 3.1.1.

A.1.2 Begin circulation of borated water in the STC to establish and maintain the STC water exit temperature < 180°F.

AND A.1.3 Begin actions to determine the reason for exceeding the pressure rise limit.

(continued)

INDIAN POINT 3 3.1.4-1 Amendment 246

STC Pressure Rise 3.1.4 ACTIONS {continued)

COMPLETION CONDITION REQUIRED ACTION TIME B. Required Action A.1.3 B.1.1 Return the STC to the spent 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months indicates a fuel mislead. fuel pool and remove the STC lid.

AND B.1.2 Return any misloaded fuel to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months the IP3 spent fuel pit in accordance with IP3 Appendix A Technical Specification LCO 3.7.16.

C. Required Action A.1.3 C.1 Develop and initiate 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months does not indicate a fuel corrective actions necessary mislead. to return the STC to compliance with LCO 3.1.3 and LCO 3.1.4.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.4.1 ---------------------------NOTE-------------------------- Once prior to Pre ssu re measurements shall be taken once upon TRANSFER establishing required water level AND hourly OPERATIONS.

thereafter for 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . Pressure may initially drop during pressure stabilization.

Verify by direct measurement that the rate of STC cavity pressure rise is within limit.

SR 3.1.4.2 Verify that an ASME code compliant pressure relief During valve or rupture disc and two channels of pressure performance of SR instrumentation with a range of at least 0.1 psia to 15 3.1.4.1.

psia and calibrated to within 1% accuracy within the past 12 months are installed on the STC.

INDIAN POINT 3 3.1.4-2 Amendment 246

STC Unloading 3.1.5 3.1 INTER-UNIT FUEL TRANSFER 3.1.5 Shielded Transfer Canister (STC) Unloading

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

1. Only IP3 spent fuel assemblies are permitted to be in the STC.

2. Once each IP3 spent fuel assembly removed from the STC has been placed in an IP2 spent fuel rack location and disconnected from the spent fuel pit bridge crane, it may not be returned to the STC.

LCO 3.1.5 IP3 spent fuel assemblies transferred to IP2 via the STC must be either in an approved IP2 spent fuel pit storage rack location per IP2 Appendix A Technical Specification LCO 3.7.13, in their authorized STC fuel basket cell, or be in transit between these two locations.

APPLICABILITY: Whenever the STC is in the Unit 2 spent fuel pit.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more fuel A.1 Initiate action to Immediately assemblies not in the restore compliance required location. with LCO 3. 1.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify by administrative means that a fuel Once, after each re-loaded assembly returned to the STC has been re- fuel assembly is returned to loaded into the same STC cell from which it was the STC.

removed.

INDIAN POINT 3 3.1.5-1 Amendment 246

Design Features 4.0 4.0 DESIGN FEATURES 4.1 Inter-Unit Fuel Transfer 4.1.1 Fuel Assemblies Fuel assemblies selected for inter-unit transfer of fuel shall meet the fuel characteristics specified in Table 4.1.1-1.

4.1.2 Criticality 4.1.2.1 The Shielded Transfer Canister (STC) is designed and shall be maintained with:

a. Fuel assemblies having a maximum U-235 enrichment of 5.0 weight percent:

b. ket, ~ 0.95 if fully flooded with unborated water;

c. A nominal 9.218 inch center-to-center distance between fuel assemblies placed in the STC basket;

d. Basket cell ID: 8.79 in. (nominal};

e. Basket cell wall thickness: 0.28 in. (nominal);

f. B4C in the Metamic neutron absorber:~ 31.5 wt.% and :s: 33.0 wt.%;

g. The B4C in the Metamic neutron absorber will contain boron with an isotopic B-10 content of at least 18.4%;

h. Metamic panel thickness:~ 0.102 in.;

i. The size and location of the neutron absorber panels shall be in accordance with drawing 6015, revision 6, which can be found in the Licensing Report (Holtec International Report Hl-2094289).

4.1.2.2 Drainage The STC is designed and shall be maintained to prevent inadvertent draining.

4.1.2.3 Capacity The STC is designed and shall be maintained with a capacity of no more than 12 fuel assemblies.

(continued)

INDIAN POINT 3 4.0-1 Amendment 246

Design Features 4.0 4.0 DESIGN FEATURES (continued) 4.1.3 Codes and Standards The American Society of Mechanical Engineers Boiler and Pressure Vessel Code (ASME Code), 2004 Edition, is the governing Code for the STC, as clarified below, except for Code Sections V and IX. The latest effective editions of ASME Code Sections V and IX, including addenda, may be used for activities governed by those sections, provided a written reconciliation of the later edition against the 2004 Edition, is performed. Table 4.1.3-1 lists approved alternatives to the ASME Code for the design of the STC.

4.1.4 Geometric Arrangements and Process Variables The following are geometric arrangements and process variables that require a one time verification as part of each inter-unit fuel transfer operation:

1. LOADING OPERATIONS, TRANSFER OPERATIONS, and UNLOADING OPERATIONS shall only be conducted with working area ambient temperatures

~ 0°F.

2. LOADING OPERATIONS shall only be conducted when the spent fuel pit water temperature and the fuel handling building ambient temperatures are both :s; 100°F.

3. LOADING OPERATIONS shall only be conducted when the IP3 spent fuel pit contains no unirradiated fuel assemblies.

4. LOADING OPERATIONS shall only be conducted when the irradiated fuel assemblies in the IP3 spent fuel pit have been subcritical for at least 90 days.

5. TRANSFER OPERATIONS shall only be conducted when the outside air temperature is :s; 100°F.

6. TRANSFER OPERATIONS shall only be conducted when the STC trunnions are offset from the HI-TRAC trunnions in the azimuthal direction by at least 30 degrees.

7. TRANSFER OPERATIONS shall only be conducted after STC seal leak tests have demonstrated no detected leakage when tested to a sensitivity of 1x10-3 ref-cm 3/s in accordance with the "pre-shipment" test requirements of ANSI N14.5.

8. Prior to installing the HI-TRAC lid the HI-TRAC water level shall be verified by two separate inspections to be within +0/-1 inch of the top of the STC lid.

(continued)

INDIAN POINT 3 4.0-2 Amendment 246

Design Features 4.0 4.0 DESIGN FEATURES (continued)

9. TRANSFER OPERATIONS shall only be conducted after the combined leak rate through the HI-TRAC top lid and vent port cover seals are confirmed to be water tight using an acceptable leak test from ANSI N14.5 and the pool lid seal is verified to be water tight by visual inspection.

10. TRANSFER OPERATIONS shall not occur with a TRANSPORTER that contains > 50 gallons of diesel fuel.

Table 4.1.1-1 Fuel Assembly Characteristics Fuel Assembly Class 15x151a1 No. of Fuel Rod Locations 204 Cladding Type ZR

---

Guide/Instrument Tube Type ZR Design Initial U (kg/assembly) S473 Fuel Rod Clad O.D. (in) ;? 0. 422 Fuel Rod Clad I.D. (in) s 0. 3734 Fuel Pellet Diameter (in) s 0. 3659 Fuel Rod Pitch (in) s: 0.563 Active Fuel Length (in) S 144 Fuel Assembly Length (in) s 160 Fuel Assembly Width (in) s 8.54 No. of Guide and/or Instrument Tubes 21 Guide/Instrument Tube Thickness (in) ;? 0. 017 Axial Blanket Enrichment (wt% U-235) (bJ s 3.2 Axial Blanket Length (in) !bl ~6 (a) All dimensions are design nominal values. Maximum and minimum dimensions are specified to bound variations in design nominal values among fuel assemblies within the 15x15 class.

(b) Applicable only if axial blankets are present.

INDIAN POINT 3 4.0-3 Amendment 246

Design Features 4.0 (continued) 4.0 DESIGN FEATURES (continued)

Table 4.1.3-1 (page 1 of 2)

List of ASME Code Alternatives for the STC Component Reference ASME Code Requirement Alternative, Justification &

Code Compensatory Measures Section/Article STC ND-1000 Statement of Cask confinement boundary is designed, and will Confinement requirements for Code be fabricated in accordance with ASME Code, Boundary stamping of Section Ill, Subsection ND to the maximum components. practical extent, but Code stamping is not required.

STC ND-2000 Requires materials to be Holtec approved suppliers will supply materials Confinement supplied by ASME- with CMTRs per ND-2000.

Boundary approved material supplier.

STC and STC ND-3100 Provides requirements These requirements are not applicable. The basket NG-3100 for determining design Licensing Report, serving as the Design assembly loading conditions, such Specification, establishes the service conditions as pressure, and load combinations for fuel transfer.

temperature, and mechanical loads.

STC ND-7000 Vessels are required to No overpressure protection is provided. Function Confinement have overpressure of cask vessel is as a radionuclide confinement Boundary protection. boundary under normal and hypothetical accident conditions. Cask is designed to withstand maximum internal pressure and maximum accident temperatures.

STC ND-8000 States requirement for STC to be marked and identified in accordance Confinement name, stamping and with drawing 6013Cal. Code stamping is not Boundary reports per NCA-8000 required. QA data package prepared in accordance with Holtec's approved QA program.

INDIAN POINT 3 4.0-4 Amendment 246

Design Features 4.0 4.0 DESIGN FEATURES (continued)

Table 4.1.3-1 (page 2 of 2)

List of ASME Code Alternatives for the STC Component Reference ASME Code Requirement Alternative, Justification &

Code Compensatory Measures Section/Article STC Basket NG-4420 NG-4427(a) requires a Modify the Code requirement (intended for core Assembly fillet weld in any single support structures) with the following text prepared to continuous weld may accord with the geometry and stress analysis be less than the imperatives for the fuel basket: For the longitudinal specified fillet weld STC basket fillet welds, the following criteria apply:

dimension by not 1) The specified fillet weld throat dimension must be more than 1/16 inch, maintained over at least 92 percent of the total weld provided that the total length. All regions of undersized weld must be less undersize portion of than 3 inches long and separated from each other by the weld does not at least 9 inches. 2) Areas of undercuts and porosity exceed 10 percent of beyond that allowed by the applicable ASME Code the length of the weld. shall not exceed 1/2 inch in weld length. The total Individual undersize length of undercut and porosity over any 1-foot weld portions shall not length shall not exceed 2 inches. 3) The total weld exceed 2 inches in length in which items (1) and (2) apply shall not length. exceed a total of 10 percent of the overall weld length. The limited access of the STC basket panel longitudinal fillet welds makes it difficult to perfonn effective repairs of these welds and creates the potential for causing additional damage to the basket assembly (e.g., to the neutron absorber and its sheathing) if repairs are attempted. The acceptance criteria provided in the foregoing have been established to comport with the objectives of the basket design and preserve the margins demonstrated in the supporting stress analysis.

From the structural standpoint, the weld acceptance criteria are established to ensure that any departure from the ideal, continuous fillet weld seam would not alter the primary bending stresses on which the design of the fuel baskets is predicated. Stated differently, the pennitted weld discontinuities are limited in size to ensure that they remain classifiable as local stress elevators ("peak stress", F, in the ASME Code for which specific stress intensity limits do not apply).

STC Basket NG-8000 States requirements STC basket to be marked and identified in Assembly for nameplates, accordance with drawing so15<aJ. No Code stamping stamping and reports is required. The STC basket data package is to be in per NCA-8000. confonnance with Holtec's QA program.

(a) Holtec International Report Hl-2094289 INDIAN POINT 3 4.0-5 Amendment 246

Programs 5.0 5.0 PROGRAMS The following programs shall be established, implemented and maintained.

5.1 Transport Evaluation Program

a. For lifting of the loaded STC or loaded HI-TRAC using equipment which is integral to a structure governed by 10 CFR Part 50 regulations, 10 CFR 50 requirements apply.

b. This program is not applicable when the loaded HI-TRAC is in the fuel building or is being handled by equipment providing support from underneath (e.g., on air pads).

c. The loaded HI-TRAC may be lifted to any height necessary during TRANSFER OPERATIONS provided the lifting equipment is designed in accordance with items 1, 2, and 3 below.

1. The metal body and any vertical columns of the lifting equipment shall be designed to comply with stress limits of ASME Section Ill, Subsection NF, Class 3 for linear structures. All vertical compression loaded primary members shall satisfy the buckling criteria of ASME Section Ill, Subsection NF.

2. The horizontal cross beam and any lifting attachments used to connect the load to the lifting equipment shall be designed, fabricated, operated, tested, inspected, and maintained in accordance with applicable sections and guidance of NUREG-0612, Section 5.1. This includes applicable stress limits from ANSI N14.6.

3. The lifting equipment shall have redundant drop protection features which prevent uncontrolled lowering of the load.

d. The lift height of the loaded HI-TRAC above the transport route surface or other supporting surface shall be limited to 6 inches, except as provided in Specification 5.1.c.

5.2 Metamic Coupon Sampling Program A coupon surveillance program shall be implemented to maintain surveillance of the Metamic neutron absorber material under the radiation, chemical, and thermal environment of the STC.

The surveillance program will be implemented to monitor the performance of Metamic by installing a minimum of four bare coupons near the maximum gamma flux elevation (mid height) at no less than four circumferential downcomer areas around the STC fuel basket. At any time during its use the STC must have a minimum of one coupon installed in each quadrant. Metamic coupons used for testing must have been installed during the entire fuel loading history of the STC.

The following specifications apply:

(i) Coupon size will be nominally 4" x 6". Each coupon will be marked with a unique identification number.

(continued)

INDIAN POINT 3 5.0-1 Amendment 246

Programs 5.0 5.0 PROGRAMS (continued)

(ii) Pre-characterization testing: Before installation, each coupon will be measured and weighed. The measurements shall be taken at locations pre-specified in the test program. Each coupon shall be tested by neutron attenuation before installation in the STC. The weight, length, width, thickness, and results of the neutron attenuation testing shall be documented and retained.

(iii) Four coupons shall be tested at the end of each inter-unit fuel transfer campaign. A campaign shall not last longer than two years. The coupons shall be measured and weighed and the results compared with the pre-characterization testing data. The results shall be documented and retained.

(iv) The coupons shall be examined for any indication of swelling, delamination, edge degradation, or general corrosion. The results of the examination shall be documented and retained.

(v) The coupons shall be tested by neutron attenuation and the results compared with the pre-characterization testing data. The results of the testing shall be documented and retained. Results are acceptable if the measured value is within +/-2.5% of the value measured for the same coupon at manufacturing.

(vi) The coupons shall be returned to their locations in the STC unless anomalous material behavior is found. If the results indicate anomalous material behavior, evaluation and corrective actions shall be pursued.

5.3 Technical Specifications (TS) Bases Control Program This program provides a means for processing changes to the Bases of these Technical Specifications.

a. Changes to the Bases of the TS shall be made under appropriate administrative controls and reviews.

b. Licensees may make changes to Bases without prior NRC approval provided the changes do not involve either of the following:

1. a change in the TS incorporated in the license; or

2. a change to the updated FSAR or Bases that requires NRG approval pursuant to 10 CFR 50.59.

c. The Bases Control Program shall contain provisions to ensure that the Bases are maintained consistent with the UFSAR.

d. Proposed changes that do not meet the criteria of Specification 5.3.b above shall be reviewed and approved by the NRG prior to implementation. Changes to the Bases implemented without prior NRG approval shall be provided to the NRG on a frequency consistent with 10 CFR 50.71 (e).

(continued)

INDIAN POINT 3 5.0-2 Amendment 246

Programs 5.0 5.0 PROGRAMS (continued) 5.4 Radiation Protection Program 5.4.1 The radiation protection program shall appropriately address STC loading and unloading conditions, including transfer of the loaded TRANSFER CASK outside of facilities governed by 10 CFR Part 50. The radiation protection program shall include appropriate controls for direct radiation and contamination, ensuring compliance with applicable regulations, and implementing actions to maintain personnel occupational exposures As Low As Reasonably Achievable (ALARA).

The actions and criteria to be included in the program are provided below.

5.4.2 Total (neutron plus gamma) measured dose rates shall not exceed the following:

a. 1400 mrem/hr on the top of the STC (with lid in place).

b. 5 mrem/hr on the side of the TRANSFER CASK 5.4.3 The STC and TRANSFER CASK surface neutron and gamma dose rates shall be measured as described in Section 5.4.6 for comparison against the limits established in Section 5.4.2.

5.4.4 If the measured surface dose rates exceed the limits established in Section 5.4.2, then:

a. Administratively verify that the correct contents were loaded in the correct fuel basket cell locations.

b. Perform a written evaluation to determine whether TRANSFER OPERATIONS can proceed without exceeding the dose limits of 10 CFR 72.104 or 10 CFR 20.1301.

5.4.5 If the verification and evaluation performed pursuant to Section 5.4.4 show that the fuel is loaded correctly and the dose rates from the STC and TRANSFER CASK will not cause the dose limits of 10 CFR 72.104 or 10 CFR 20.1301 to be exceeded, TRANSFER OPERATIONS may occur. Otherwise, TRANSFER OPERATIONS shall not occur until appropriate corrective action is taken to ensure the dose limits are not exceeded.

5.4.6 STC and TRANSFER CASK surface dose rates shall be measured at approximately the following locations:

a. The dose rate measurement shall be taken at the approximate center of the STC top lid. Two (2) additional measurements shall be taken on the STC lid approximately 180 degrees apart and 12 to 18 inches from the center of the lid, avoiding the areas around the inlet and outlet ports. The measurements must be taken when the STC is in the HI-TRAC after the steam space is established and prior to HI-TRAC lid installation.

(continued)

INDIAN POINT 3 5.0-3 Amendment 246

Programs 5.0 5.0 PROGRAMS (continued)

b. A minimum of four (4) dose rate measurements shall be taken on the side of the TRANSFER CASK approximately at the cask mid-height plane. The measurement locations shall be approximately 90 degrees apart around the circumference of the cask. Dose rates shall be measured between the radial ribs of the water jacket.

INDIAN POINT 3 5.0-4 Amendment 246

ML052720273

Contents

Text

Attachment:

1.0 DESCRIPTION

3.1.2 APPLICABILITY

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