Text

Current Facility Operating License DPR-24, Tech Specs, Revised 05/07/2019
	ML053110031
Person / Time
Site:	Point Beach
Issue date:	12/22/2005
From:	Borchardt R; Office of Nuclear Reactor Regulation
To:	; Nuclear Management Co, Wisconsin Electric Power Co
	Boska J, NRR/DORL
References
	Download: ML053110031 (311)
	v • d • e

{{#Wiki_filter:I\lEXTERA ENERGY POINT BEACH, LLC DOCKET NO. 50-266 RENEWED FACILITY OPERATING LICENSE Renewed License No. DPR-24

1. The Nuclear Regulatory Commission (NRC or the Commission), having previously made the findings set forth in License DPR-24 issued on October 5, 1970, has now found that:

A. The application to renew operating License No. DPR-24 filed by Nuclear Management Company, LLC (NMC) complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations set forth in 10 CFR Chapter 1, and all required notifications to other agencies or bodies have been duly made; B. Construction of the Point Beach Nuclear Plant Unit 1 (the facility) has been substantially completed, in conformity with Provisional Construction Permit No. CPPR-32, as amended, the application as amended, the provisions of the Act, and the rules and regulations of the Commission; C. Actions have been identified and have been or will be taken with respect to (1) managing the effects of aging during the period of extended operation on the functionality of structures and components that have been identified to require review under 10 CFR 54.21 (a)(1); and (2) time-limited aging analyses that have been identified to require review under 10 CFR 54.21(c), such that there is reasonable assurance that the activities authorized by the renewed operating license will continue to be conducted in accordance with the current licensing basis, as defined in 10 CFR 54.3, for the facility, and that any changes made to the facility's current licensing basis in order to comply with 10 CFR 54.29(a) are in accordance with the Act and the Commission's regulations; D. The facility will operate in conformity with the application as amended, the provisions of the Act, and the rules and regulations of the Commission; E. There is reasonable assurance (1) that the activities authorized by the renewed operating license can be conducted without endangering the health and safety of the public, and (2) that such activities will be conducted in compliance with the regulations of the Commission set forth in 10 CFR Chapter 1; Amendment No. 237 I

                                            -2 F. NextEra Energy Point Beach is technically and financially qualified to engage in the activities authorized by this renewed operating license in accordance with the regulations of the Commission set forth in 10 CFR Chapter 1; G. The applicable provisions of 10 CFR Part 140, "Financial Protection Requirements and Indemnity Agreements," have been satisfied; and H. The issuance of this renewed operating license will not be inimical to the common defense and security or to the health and safety of the public.

2. This renewed operating license applies to the Point Beach Nuclear Plant Unit 1, a closed cycle, pressurized, light water moderated and cooled reactor, and associated steam generators and electric generating equipment (the facility). The facility is located on the Point Beach site, in the Town of Two Creeks, Manitowoc County, Wisconsin, and is described in the Final Safety Analysis Report (FSAR), as supplemented and amended.

3. Subject to the conditions and requirements incorporated herein the Commission hereby licenses: .

A. Pursuant to Section 104b of the Act and 10 CFR Part 50, "Domestic Licensing of Production and Utilization Facilities," NextEra Energy Point Beach to possess, use and operate the facility at the designated location on the Point Beach site in accordance with the procedures and limitations set forth in this renewed operating license; B. Pursuant to the Act and 10 CFR Part 70, NextEra Energy Point Beach to receive, possess and use at any time special nuclear material as reactor fuel, in accordance with the limitations for storage and amounts, required for reactor operation, as described in Final Facility Description and Safety Analysis Report, as supplemented and amended as of March 17, 1976; C. Pursuant to the Act and 10 CFR Parts 30, 40 and 70, NextEra Energy Point Beach to receive, possess and use at any time any byproduct, source, and special nuclear material as sealed neutron sources for reactor startup, sealed sources for reactor instrumentation and radiation monitoring equipment calibration, and as fission detectors in amounts as required; Renewed License No. DPR-24 Amendment No. 237

D. Pursuant to the Act and 10 CFR Parts 30, 40 and 70, NextEra Energy Point Beach to receive, possess and use in amounts as required any byproduct, source or special nuclear material without restriction to chemical or physical form, for sample analysis or instrument calibration or associated with radioactive apparatus or components; and E. Pursuant to the Act and 10 CFR Parts 30 and 70, NextEra Energy Point Beach to possess such byproduct and special nuclear materials as may be produced by the operation of the facility, but not to separate such materials retained within the fuel cladding.

4. This renewed operating license shall be deemed to contain and is subject to the conditions specified in the following Commission regulations: 10 CFR Part 20, Section 30.34 of 10 CFR Part 30, Section 40.41 of 10 CFR Part 40, Sections 50.54 and 50.59 of 10 CFR Part 50, and Section 70.32 of 10 CFR 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:

A. Maximum Power Levels NextEra Energy Point Beach is authorized to operate the facility at reactor core power levels not in excess of 1800 megawatts thermal. B. Technical Specifications The Technical Specifications contained in Appendices A and B, as revised through Amendment No. 265, are hereby incorporated in the renewed operating license. NextEra Energy Point Beach shall operate the facility in accordance with Technical Specifications. C. Spent Fuel Pool Modification The licensee is authorized to modify the spent fuel storage pool to increase its storage capacity from 351 to 1502 assemblies as described in licensee's application dated March 21, 1978, as supplemented and amended. In the eventthat the on-site verification check for poison material in the poison assemblies discloses any missing boron plates, the NRC shall be notified and an on-site test on every poison assembly shall be performed. Renewed License No. DPR-24 Amendment No. 265

D. Physical Protection NextEra Energy Point Beach 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 10 CFR 50.54(p). The combined set of plans, which contain Safeguards Information protected under 10 CFR 73.21, is entitled: "Point Beach Nuclear Plant Physical Security Plan, (Revision 4)," submitted by letter dated May 10, 2006. NextEra Energy Point Beach, LLC shall fully implement and maintain in effect all provisions of the Commission-approved Point Beach Nuclear Plant Cyber Security Plan (CSP), including changes made pursuant to the authority of 10 CFR 50.90 and 10 CFR 50.54(p). The NextEra Energy Point Beach CSP was approved by License Amendment No. 243 as supplemented by a change approved by License Amendment No. 247 and License Amendment No. 252. E. Adoption of 10 CFR 50.69, "Risk-Informed categorization and treatment of structures, systems, and components for nuclear power plants"

1. NextEra Energy Point Beach is approved to implement 10 CFR 50.69 using the processes for categorization of Risk-Informed Safety Class (RISC)-1, RISC-2, RISC-3, and RISC-4 structures, systems, and components (SSCs) using:

Probabilistic Risk Assessment (PRA) models to evaluate risk associated with internal events, including internal flooding, and internal fire; the shutdown safety assessment process to assess shutdown risk; the Arkansas Nuclear One, Unit 2 (AN0-2) passive categorization method to assess passive component risk for Class 2 and Class 3 SSCs and their associated supports; and the results of non-PRA evaluations that are based on the IPEEE Screening Assessment for External Hazards, i.e., seismic margin analysis (SMA) to evaluate seismic risk, and a screening of other external hazards updated using the external hazard screening significance process identified in ASME/ANS PRA Standard RA-Sa-2009; as specified in License Amendment No. 262 dated November 26, 2018.

2. Prior to implementation of the provisions of 10 CFR 50.69, NextEra Energy Point Beach shall complete the items below:

a. Item A in Attachment 1, List of Categorization Prerequisites, to NextEra Energy Point Beach letter NRC 2017-0043, "License Amendment Request 287, Application to Adopt 10 CFR 50.69, 'Risk-Informed Categorization and Treatment of Structures, Systems, and Components (SSCs) for Nuclear Power Plants,'" dated August 31, 2017; and

b. Attachment 1, Point Beach 10 CFR 50.69 PRA Implementation Items, in NextEra Energy Point Beach letter NRC-2018-0044, "Supplement to Response to Request for Additional Information Regarding License Amendment Request 287, Application to Adopt 10 CFR 50.69, 'Risk informed Categorization and Treatment of Structures, System, and Components (SSCs) for Nuclear Power Plar:,ts,' "dated September 28, 2018.

Renewed License No. DPR-24 Amendment No. 262

3. Prior NRC approval, under 10 CFR 50.90, is required for a change to the categorization process specified above (e.g., change from a seismic margins approach to a seismic probabilistic risk assessment approach).

F. NextEra Energy Point Beach Unit 1 shall implement and maintain in effect all provisions of the approved fire protection program that comply with 10 CFR 50.48(a) and 10 CFR 50.48(c), as specified in the license amendment request dated June 26, 2013, and supplements dated September 16, 2013, July 29, 2014, August 28, 2014, September 25, 2014, November 14, 2014, December 19, 2014, January 16, 2015, May 12, 2015, August 26, 2015, February 22, 2016, April 07, 2016, and May 3, 2016, and as approved in the safety evaluation report dated September 8, 2016. Except where NRC approval for changes or deviations is required by 10 CFR 50.48(c), and provided no other regulation, technical specification, license condition or requirement would require prior NRC approval, the licensee may make changes to the fire protection program without prior approval of the Commission if those changes satisfy the provisions set forth in 10 CFR 50.48(a) and 10 CFR 50.48(c), the change does not require a change to a technical specification or license condition, and the criteria listed below are satisfied.

1. Risk-Informed Changes that May Be Made Without Prior NRC Approval A risk assessment of the change must demonstrate that the acceptance criteria below are met. The risk assessment approach, methods, and data shall be acceptable to the NRC and shall be appropriate for the nature and scope of the change being evaluated; be based on the as-built, as-operated, and maintained plant; and reflect the operating experience at the plant. Acceptable methods to assess the risk of the change may include methods that have been used in the peer-reviewed fire PRA model, methods that have been approved by NRC through a plant-specific license amendment or NRC approval of generic methods specifically for use in NFPA 805 risk assessments, or methods that have been demonstrated to bound the risk impact.

a. Prior NRC review and approval is not required for changes that clearly result in a decrease in risk. The proposed change must also be consistent with the defense-in-depth philosophy and must maintain sufficient safety margins.

The change may be implemented following completion of the plant change evaluation.

b. Prior NRC review and approval is not required for individual changes that result in a risk increase less than 1 x 10-7/year (yr) for CDF and less than 1 x10-8/yr for LERF. The proposed change must also be consistent with the defense-in-depth philosophy and must maintain sufficient safety margins.

The change may be implemented following completion of the plant change evaluation. Renewed License No. DPR-24 Amendment No. 262

2. Other Changes that May Be Made Without Prior NRC Approval

a. Changes to NFPA 805, Chapter 3, Fundamental Fire Protection Program.

Prior NRC review and approval are not required for changes to the NFPA 805, Chapter 3, fundamental fire protection program elements and design requirements for which an engineering evaluation demonstrates that the alternative to the Chapter 3 element is functionally equivalent or adequate for the hazard. The licensee may use an engineering evaluation to demonstrate that a change to an NFPA 805, Chapter 3 element is functionally equivalent to the corresponding technical requirement. A qualified fire protection engineer shall perform the engineering evaluation and conclude that the change has not affected the functionality of the component, system, procedure, or physical arrangement, using a relevant technical requirement or standard. The licensee may use an engineering evaluation to demonstrate that changes to certain NFPA 805, Chapter 3 elements are acceptable because the alternative is "adequate for the hazard." Prior NRC review and approval would not be required for alternatives to four specific sections of NFPA 805, Chapter 3, for which an engineering evaluation demonstrates that the alternative to the Chapter 3 element is adequate for the hazard. A qualified fire protection engineer shall perform the engineering evaluation and conclude that the change has not affected the functionality of the component, system, procedure, or physical arrangement, using a relevant technical requirement or standard. The four specific sections of NFPA 805, Chapter 3, are as follows:

     * "Fire Alarm and Detection Systems" (Section 3.8);
     * "Automatic and Manual Water-Based Fire Suppression Systems" (Section 3.9);
     * "Gaseous Fire Suppression Systems" (Section 3.1 O); and,
     * "Passive Fire Protection Features" (Section 3.11 ).

(This License Condition does not apply to any demonstration of equivalency under Section 1.7 of NFPA 805.)

b. Fire Protection Program Changes that Have No More than Minimal Risk Impact Prior NRG review and approval are not required for changes to the licensee's fire protection program that have been demonstrated to have no more than a minimal risk impact. The licensee may use its screening process as approved in the NRG safety evaluation report dated September 8, 2016 to determine that certain fire protection program changes meet the minimal criterion. The licensee shall ensure that fire protection defense-in-depth and safety margins are maintained when changes are made to the fire protection program.

Renewed License No. DPR-24 Amendment No. 258

3. Transition License Conditions

a. Before achieving full compliance with 10 CFR 50.48(c), as specified by 3.b and 3.c below, risk-informed changes to the licensee's fire protection program may not be made without prior NRC review and approval unless the change has been demonstrated to have no more than a minimal risk impact, as described in 2.b above.

b. The licensee shall implement the modifications to its facility as described in Attachment S, Table S-2 "Plant Modifications Committed," of NextEra Energy Point Beach letter NRC-2016-0013 to complete the transition to full compliance with 10 CFR 50.48(c) no later than prior to startup from the second refueling outage (for each unit) after receipt of the license amendment. The licensee shall maintain appropriate compensatory measures in place until completion of these modifications.

c. The licensee shall implement the items in Attachment S, Table S-3, "Implementation Items," of NextEra Energy Point Beach letter NRC-2016-0021, with the exception of items noted below, within 12 months after NRC approval unless that falls within a scheduled outage window; then in that case, completion will occur 60 days after the startup from that scheduled outage.

i. Implementation item 120 is an exception as the industry guidance is under review by the NRC and the final resolution will occur 12 months after the guidance is available unless that falls within a scheduled outage window; then in that case, completion will occur 60 days after startup from that scheduled outage.

ii. Implementation items 142 and 150 are exceptions because they are associated with completion of committed modifications identified in LAR Attachment S, Table S-2 and will not be completed until 3 months following the last refueling outage identified in item 3.b above. Renewed License No. DPR-24 Amendment No. 258

G. Secondary Water Chemistry Monitoring Program NextEra Energy Point Beach shall implement a secondary water chemistry monitoring program to inhibit steam generator tube degradation. This program shall include:

1. Identification of a sampling schedule for the critical parameters and control points for these parameters;

2. Identification of the procedures used to quantify parameters that are critical to control points; 3 Identification of process sampling points;

4. Procedure for the recording and management of data;

5. Procedures defining corrective actions for off control point chemistry condition; and

6. A procedure for identifying the authority responsible for the interpretation of the data, and the sequence and timing of administrative events required to initiate corrective action.

H. The licensee is authorized to repair Unit 1 steam generators by replacement of major components. Repairs shall be conducted in accordance with the licensee's commitments identified in the Commission approved Point Beach Nuclear Plant Unit No. 1 Steam Generator Repair Report dated August 9, 1982 and revised March 1, 1983 and additional commitments identified in the staff's related safety evaluation. I. Deleted J. Deleted K. All capsules in the reactor vessel that are removed and tested must meet the test procedures and reporting requirements of American Society for Testing and Materials (ASTM) E 185-82 to the extent practicable for the configuration of the specimens in the capsule. Any changes to the capsule withdrawal schedule, including spare capsules, must be approved by the NRC prior to implementation. All capsules placed in storage must be maintained for future insertion. Any changes to storage requirements must be approved by the NRC, as required by 10 CFR Part 50, Appendix H. L. Mitigation Strategy Strategies shall be developed and maintained for addressing large fires and explosions that include the following key areas:

1. Fire fighting response strategy with the following elements:

a. Pre-defined coordinated fire response strategy and guidance

b. Assessment of mutual aid fire fighting assets

c. Designated staging areas for equipment and materials

d. Command and control

e. Training of response personnel Renewed License No. DPR-24 Amendment No. 258

2. Operations to mitigate fuel damage considering the following:

a. Protection and use of personnel assets

b. Communications

c. Minimizing fire spread

d. Procedures for implementing integrated fire response strategy

e. Identification of readily-available pre-staged equipment

f. Training on integrated fire response strategy

g. Spent fuel pool mitigation measures

3. Actions to minimize release to include consideration of:

a. Water spray scrubbing

b. Dose to onsite responders M. Additional Conditions The additional conditions contained in Appendix C, as revised through Amendment No. 241, are hereby incorporated into this license. NextEra Energy Point Beach shall operate the facility in accordance with the additional conditions.

5. The issuance of this renewed operating license is without prejudice to subsequent licensing action which may be taken by the Commission with regard to the ongoing rulemaking hearing on the Interim Acceptance Criteria for Emergency Core Cooling Systems (Docket No. RM 50-1 ).

6. This renewed operating license is effective as of the date of issuance, and shall expire at midnight on October 5, 2030.

FOR THE NUCLEAR REGULATORY COMMISSION Original Signed By R. W. Borchardt, Deputy Director Office of Nuclear Reactor Regulation Attachments:

1. Appendix A - Technical Specifications

2. Appendix B - Environmental Technical Specifications

3. Appendix C - Additional Conditions Date of Issuance: December 22, 2005 Renewed License No. DPR-24 Amendment No. 258

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.

Term 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 required for OPERABILITY of a logic circuit 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 (AFD) 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 output such that it responds within the necessary range and accuracy to known values of the parameter that the channel monitors. The CHANNEL CALIBRATION shall encompass all devices in the channel required for channel OPERABILITY. Calibration of instrument channels with resistance temperature detector (RTD) or thermocouple sensors may consist of an inplace qualitative assessment of sensor behavior and normal calibration of the remaining adjustable devices in the channel. The CHANNEL CALIBRATION may be performed by means of any series of sequential, overlapping, or total channel steps. 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. Point Beach 1.1-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

APPENDIX A TO FACILITY OPERATING LICENSE DPR-24 AND FACILITY OPERATING LICENSE DPR-27 FOR POINT BEACH NUCLEAR PLANT UNIT NOS. 1 AND 2 NEXTERA ENERGY POINT BEACH DOCKET NOS. 50-266 AND 50-301 Unit 1 - Amendment No. 237 Unit 2 - Amendment No. 241

Definitions 1.1 1.1 Definitions 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 OPERABILITY of all devices in the channel required for channel OPERABILITY. The COT shall include adjustments, as necessary, of the required alarm, interlock, and trip setpoints required for channel OPERABILITY such that the setpoints are within the necessary range and accuracy. The COT may be performed by means of any series of sequential, overlapping, or total channel steps. 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 5.6.4. Plant operation within these limits is addressed in individual Specifications. DOSE EQUIVALENT 1-131 DOSE EQUIVALENT 1-131 shall be that concentration of 1-131 (microcuries per gram) that alone would produce the same dose when inhaled as the combined activities of iodine isotopes 1-131, 1-132, 1-133, 1-134, and 1-135 actually present. The determination of DOSE EQUIVALENT 1-131 shall be performed using thyroid dose conversion factors from Table 2.1 of EPA Federal Guidance Report No. 11, 1988, "Limiting Values of Radionuclide Intake and Air Concentration and Dose Conversion Factors for Inhalation, Submersion, and Ingestion." DOSE EQUIVALENT DOSE EQUIVALENT Xe-133 shall be that concentration of Xe-133 Xe-133 (microcuries per gram) that alone would produce the same acute dose to the whole body Deep Dose Equivalent as the combined activities of noble gas nuclides Kr-85m, Kr-85, Kr-87, Kr-88, Xe-131m, Xe-133m, Xe-133, Xe-135m, Xe-135, and Xe-138 actually present. If a specific noble gas nuclide 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 111.1 of EPA Federal Guidance Report No. 12, 1993, "External Exposure to Radionuclides in Air, Water, and Soil" or the average gamma disintegration energies as provided in ICRP Publication 38, "Radionuclide Transformations," or similar source. INSERVICE TESTING The INSERVICE TESTING PROGRAM is the licensee PROGRAM program that fulfills the requirements of 10 CFR 50.55a(f). Point Beach 1.1-2 Unit 1 - Amendment No. 259 Unit 2 - Amendment No. 263

Definitions 1.1 1.1 Definitions The maximum allowable primary containment leakage rate. La, shall be 0.2% of primary containment air weight per day at the peak design containment pressure (P a). LEAKAGE LEAKAGE shall be:

a. Identified LEAKAGE

1. LEAKAGE, such as that from pump seals or valve packing (except reactor coolant pump (RCP) seal water injection or leakoff),

that is captured and conducted to collection systems or a sump or collecting tank;

2. LEAKAGE into the containment atmosphere from sources that are both specifically located and known either not to interfere with the operation of leakage detection systems or not to be pressure boundary LEAKAGE; or

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

b. Unidentified LEAKAGE All LEAKAGE (except 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 ReS component body, pipe wall, or vessel wall.

MASTER RELAY TEST A MASTER RELAY TEST shall consist of energizing all master relays in the channel required for OPERABILITY and verifying the OPERABILITY of each required master relay. The MASTER RELAY TEST shall include a continuity check of each associated required slave relay. The MASTER RELAY TEST may be performed by means of any series of sequential, overlapping, or total channel steps. Point Beach 1.1~3 Unit 1 - Amendment No. 240 Unit 2 - Amendment No. 244

Definitions 1.1 1.1 Definitions MODE A MODE shall correspond to any one inclusive combination of core reactivity condition, power level, average reactor coolant temperature, and reactor 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 Chapter 13, Initial Test Program of the FSAR; or

b. Authorized under the provisions of 10 CFR 50.59; or

c. Otherwise approved by the Nuclear Regulatory Commission.

PRESSURE AND The PTLR is the unit specific document that provides the TEMPERATURE LIMITS reactor vessel pressure and temperature limits, including REPORT (PTLR) heatup and cooldown rates, and the LTOP arming temperature, for the current reactor vessel fluence period. These pressure and temperature limits shall be determined for each fluence period in accordance with Specification 5.6.5. Plant operation within these operating limits is addressed in LCO 3.4.3, ORCS Pressure and Temperature (PIT) Limits," and LCO 3.4.12, 'Low Temperature Overpressure Protection (LTOP) System." 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. Point Beach 1.1-4 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Definitions 1.1 1.1 Definitions RATED THERMAL POWER RTP shall be a total reactor core heat transfer (RTP) rate to the reactor coolant of 1800 MWt. SHUTDOWN MARGIN SOM shall be the instantaneous amount of reactivity by (SOM) which the reactor is subcritical or would be subcritical from its present condition assuming:

a. All rod cluster control assemblies (RCCAs) are fully inserted except for the single RCCA of highest reactivity worth, which is assumed to be fully withdrawn. However, with all RCCAs verified fully inserted by two independent means, it is not necessary to account for a stuck RCCA in the SOM calculation;

b. With any RCCA not capable of being fully inserted, the reactivity worth of the RCCA must be accounted for in the determination of SOM; and

c. In MODES 1 and 2, the fuel and moderator temperatures are changed to the nominal zero power design level.

SLAVE RELAY TEST A SLAVE RELAY TEST shall consist of energizing all slave relays in the channel required for OPERABILITY and verifying the OPERABILITY of each required slave relay. The SLAVE RELAY TEST shall include a continuity check of associated required testable actuation devices. The SLAVE RELAY TEST may be performed by means of any series of sequential, overlapping, or total channel steps. DELETED THERMAL POWER THERMAL POWER shall be the total reactor core heat transfer rate to the reactor coolant. Point Beach 1.1-5 Unit 1 - Amendment No. 253 Unit 2 - Amendment No 257

Definitions 1.1 1.1 Definitions TRIP ACTUATING DEVICE A TADOT shall consist of operating the trip OPERATIONAL TEST actuating device and verifying the OPERABILITY of (TADOT) all devices in the channel required for trip actuating device OPERABILITY. The TADOT may be performed by means of any series of sequential, overlapping, or total channel steps. Point Beach 1.1-6 Unit I -Amendment No. 201 Unit 2 - Amendment No. 206

Definitions 1.1 Table 1.1-1 (page 1 of 1) MODES MODE TITLE REACTIVITY % RATED AVERAGE CONDITION THERMAL REACTOR COOLANT (ken) POWER(a) TEMPERATURE _ _ __ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _('IF ) 1 Power Operation 2 0.99 > 5 NA 2 Startup 2 0.99 S5 NA 3 Hot Standby < 0.99 NA 2 350 4 Hot Shutdown(b) < 0.99 NA 350 > Tatg > 200 5 Cold Shutdown(b) < 0.99 NA

200 6 Refueling(c) NA NA NA (a) Excluding decay heat.

(b) All reactor vessel head closure bolts fully tensioned. (c) One or more reactor vessel head closure bolts less than fully tensioned. Point Beach 1.1-7 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

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 (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. EXAMPLES The following examples illustrate the use of logical connectors. Point Beach 1.2-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Logical Connectors 1.2 1.2 Logical Connectors EXAMPLES (continued) EXAMPLE 1.2-1 ACTIONS CONDITION REQUIRED ACTION COMPLETlON 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. Point Beach 1.2-2 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Logical Connectors 1.2 1.2 Logical Connectors EXAMPLES (continued) EXAMPLE 1.2-2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LCO not met. A.1 Trip ... OR

                                          -A.2.1    Verify...

AND A.2.2.1 Reduce ... OR A.2.2.2 Perform ... OR 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 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. Point Beach 1.2-3 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

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 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 MODE 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 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. Point Beach 1.3-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Completion Times 1.3 1.3 Completion Times DESCRIPTION (continued) 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. Must exist concurrent with the first inoperability; and

b. Must 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 hours1 days 0.143 weeks 0.0329 months ; 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 (for 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 utime zero' may be expressed as a repetitive time (i.e., 'once per 8 hours0.333 days 0.0476 weeks 0.011 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 B in Example 1.3-3 may not be extended. Point Beach 1.3-2 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Completion Times 1.3 1.3 Completion Times 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 COMPLE-lONTIME B. Required B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months Action and associated AND Completion Time not met. B.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 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 B is entered. The Required Actions of Condition B are to be in MODE 3 within 6 hours0.25 days 0.0357 weeks 0.00822 months AND in MODE 5 within 36 hours1.5 days 0.214 weeks 0.0493 months . A total of 6 hours0.25 days 0.0357 weeks 0.00822 months is allowed for reaching MODE 3 and a total of 36 hours1.5 days 0.214 weeks 0.0493 months (not 42 hours1.75 days 0.25 weeks 0.0575 months ) is allowed for reaching MODE 5 from the time that Condition B was entered. If MODE 3 is reached within 3 hours0.125 days 0.0179 weeks 0.00411 months , the time allowed for reaching MODE 5 is the next 33 hours1.375 days 0.196 weeks 0.0452 months because the total time allowed for reaching MODE 5 is 36 hours1.5 days 0.214 weeks 0.0493 months . If Condition B is entered while In MODE 3, the time allowed for reaching MODE 5 is the next 36 hours1.5 days 0.214 weeks 0.0493 months . Point Beach 1.3-3 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Completion Times 1.3 1.3 Completion Times EXAMPLES (continued) EXAMPLE 1.3-2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One pump A.1 Restore pump 7 days inoperable. to OPERABLE status. B. Required B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months Action and associated AND Completion Time not met. B.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months When a pump is declared inoperable, Condition A is entered. If the 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 B is entered, Condition A and B are exited, and therefore, the Required Actions of Condition B may be terminated. When a second pump is declared inoperable while the first pump is 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 entered, 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. Point Beach 1.3-4 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Completion Times 1.3 1.3 Completion Times EXAMPLES (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 B is 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 hour extension to the stated 7 days is allowed, provided this does not result in the second pump being inoperable for > 7 days. Point Beach 1.3-5 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Completion Times 1.3 1.3 Completion Times EXAMPLES (continued) EXAMPLE 1.3-3 ACTIONS CONDITION REQUIRED ACTION COMPLETIONTiME A. One A.1 Restore 7 days Function X Function X train train to OPERABLE AND inoperable. status. 10 days from discovery of failure to meet the LCO B. One B.1 Restore 72 hours3 days 0.429 weeks 0.0986 months Function Y Function Y train train to OPERABLE AND inoperable. status. 10 days from discovery of failure to meet the LCO C. One C.1 Restore 72 hours3 days 0.429 weeks 0.0986 months Function X Function X train train to OPERABLE inoperable. status. AND OR One C.2 Restore 72 hours3 days 0.429 weeks 0.0986 months Function Y Function Y train train to OPERABLE Inoperable. status. Point Beach 1.3-6 Unit I - Amendment No. 201 Unit 2 - Amendment No. 206

Completion Times 1.3 1.3 Completion Times EXAMPLES (continued) When one Function X train and one Function Y train are inoperable, Condition A and Condition B are concurrently applicable. The Completion Times for Condition A and Condition B are tracked separately for each train starting from the time each train was declared 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 B and C are 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 B are 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 Ofrom 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 mclock". In this instance, the Completion Time time zero' is specified as commencing at the time the LCO was Initially not met, instead of at the time the associated Condition was entered. Point Beach 1.3-7 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Completion Times 1.3 1.3 Completion Times EXAMPLES (continued) EXAMPLE 1.3-4 ACTIONS CONDITION REQUIRED ACTION COMPLETlONTIME A. One or more A.1 Restore 4 hours0.167 days 0.0238 weeks 0.00548 months valves valve(s) to inoperable. OPERABLE status. B. Required B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months Action and associated AND Completion Time not met. B.2 Be in MODE 4. 12 hours0.5 days 0.0714 weeks 0.0164 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 hours0.167 days 0.0238 weeks 0.00548 months provided this does not result in any subsequent valve being inoperable for > 4 hours0.167 days 0.0238 weeks 0.00548 months . If the Completion Time of 4 hours0.167 days 0.0238 weeks 0.00548 months (including the extension) expires while one or more valves are still inoperable, Condition B is entered. Point Beach 1.3-8 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

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

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

Separate Condition entry is allowed for each inoperable valve. CONDITION REQUIRED ACTION COMPLEflONlIME A. One or more A.1 Restore valve 4 hours0.167 days 0.0238 weeks 0.00548 months valves to OPERABLE inoperable. status. B. Required B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months Action and associated AND Completion Time not met. B.2 Be in MODE 4. 12 hours0.5 days 0.0714 weeks 0.0164 months 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. If the Completion Time associated with a valve in Condition A expires, Condition B is entered for that valve. If the Completion Times associated with subsequent valves in Condition A expire, Point Beach 1.3-9 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Completion Times 1.3 1.3 Completion Times EXAMPLES (continued) Condition B is entered separately for each valve and separate Completion Times start and are tracked for each valve. If a valve that caused entry into Condition B is restored to OPERABLE status, Condition B is 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. Point Beach 1.3-10 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Completion Times 1.3 1.3 Completion Times EXAMPLES (continued) EXAMPLE 1.3-6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One channel A.1 Perform Once per 8 hours0.333 days 0.0476 weeks 0.011 months inoperable. SR 3.x.x.x. OR 8 hours0.333 days 0.0476 weeks 0.011 months A.2 Reduce THERMAL POWER to

50% RTP.

B. Required B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months Action and associated Completion Time not met. Entry Into Condition A offers a choice between Required Action A.1 or A.2. Required Action A.1 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 hour 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 hour Interval. If Required Action A.1 is followed, and the Required Action is not met within the Completion Time (plus the extension allowed by SR 3.0.2), Condition B is entered. If Required Action A.2 is followed and the Completion Time of 8 hours0.333 days 0.0476 weeks 0.011 months is not met, Condition B Is entered. If after entry into Condition B, Required Action A.1 or A.2 is met, Condition B Is exited and operation may then continue in Condition A. Point Beach 1.3-11 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

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Completion Times 1.3 1.3 Completion Times EXAMPLES (continued) EXAMPLE 1.3-7 ACTIONS CONDITION REQUIRED ACTION COMPLE11ON TIME A. One A.1 Verify affected 1 hour subsystem subsystem inoperable. isolated. AND Once per 8 hours0.333 days 0.0476 weeks 0.011 months thereafter AND A.2 Restore 72 hours3 days 0.429 weeks 0.0986 months subsystem to OPERABLE status. B. Required B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months Action and associated AND Completion Time not met. B.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months Required Action A.1 has two Completion Times. The 1 hour Completion Time begins at the time the Condition is entered and each "Once per 8 hours0.333 days 0.0476 weeks 0.011 months thereafter" Interval begins upon performance of Required Action A.1. If after Condition A is entered, Required Action A.1 Is not met within either the initial 1 hour or any subsequent 8 hour interval from the previous performance (plus the extension allowed by SR 3.0.2), Condition B is entered. The Completion Time clock for Condition A does not stop after Condition B is entered, but continues from the time Condition A was initially entered. If Required Action A.1 is met after Condition B is 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. Point Beach 1.3-12 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Completion Times 1.3 1.3 Completion Times IMMEDIATE When Immediately* is used as a Completion Time, the COMPLETION TIME Required Action should be pursued without delay and in a controlled manner. Point Beach 1.3-13 Unit I - Amendment No. 201 Unit 2 - Amendment No. 206

Frequency 1.4 1.0 USE AND APPLICATION 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 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 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. 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 (LCO not shown) is MODES 1, 2, and 3. Point Beach 1.4-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Frequency 1.4 1.4 Frequency EXAMPLES (continued) EXAMPLE 1.4-1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Perform CHANNEL CHECK. 12 hours0.5 days 0.0714 weeks 0.0164 months Example 1.4-1 contains the type of SR most often encountered in the Technical Specifications (TS). The Frequency specifies an interval (12 hours0.5 days 0.0714 weeks 0.0164 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 hours0.5 days 0.0714 weeks 0.0164 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 (1.25 x 12 = 15 hours0.625 days 0.0893 weeks 0.0205 months ) 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 (1.25 x 12 = 15 hours0.625 days 0.0893 weeks 0.0205 months ) 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, the Surveillance must be performed within the Frequency requirements of SR 3.0.2 (1.25 x 12 = 15 hours0.625 days 0.0893 weeks 0.0205 months ) prior to entry into the MODE or other specified condition. Failure to do so would result in a violation of SR 3.0.4. Point Beach 1.4-2 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Frequency 1.4 1.4 Frequency EXAMPLES (continued) EXAMPLE 1.4-2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Verify flow is within limits. Once within 12 hours0.5 days 0.0714 weeks 0.0164 months after 2 25% RTP AND 24 hours1 days 0.143 weeks 0.0329 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 8ANDm indicates that both Frequency requirements must be met. Each time reactor power is increased from a power level < 25% RTP to 2 25% RTP, the Surveillance must be performed within 12 hours0.5 days 0.0714 weeks 0.0164 months . The use of 'once indicates a single performance will satisfy the specified Frequency (assuming no other Frequencies are connected by 'ANDO). This type of Frequency does not qualify for the 25% extension allowed by SR 3.0.2. OThereaftern 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. Point Beach 1.4-3 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Frequency 1.4 1.4 Frequency EXAMPLES (continued) EXAMPLE 1.4-3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

                 --------------------- ;--NOTE------------------------

Not required to be performed until 12 hours0.5 days 0.0714 weeks 0.0164 months after 2 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 Derformance 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 hours0.5 days 0.0714 weeks 0.0164 months after power reaches 2 25% 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 < 25% 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 MODES, even with the 7 day Frequency not met, provided operation does not exceed 12 hours0.5 days 0.0714 weeks 0.0164 months with power 2 25% RTP. Once the unit reaches 25% RTP, 12 hours0.5 days 0.0714 weeks 0.0164 months would be allowed for completing the Surveillance. If the Surveillance were not performed within this 12 hour 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. Point Beach 1.4-4 Unit I - Amendment No. 201 Unit 2 - Amendment No. 206

SLs 2.0 2.0 SAFETY LIMITS (SLs) 2.1 SLs 2.1.1 Reactor Core SLs In MODES 1 and 2, the combination of THERMAL POWER, Reactor Coolant System (RCS) highest loop average temperature, and pressurizer pressure shall not exceed the limits specified in the COLR in order to preserve the following fuel design criteria: 2.1.1.1 The departure from nucleate boiling ratio (DNBR) shall be maintained:

                        >   1.17 for the WRB-1 correlation
                        ~  1.30 for the W-3 correlation when system pressure is
                           > 1000 psia
                        ~   1.45 for the W-3 correlation when system pressure is
                           ~  500 psia and ~ 1000 psia 2.1.1.2    The peak fuel centerline temperature shall be maintained
                        < 5080 of, decreasing by 58 of per 10,000 MWD/MTU of burnup.

2.1.2 RCS Pressure SL In MODES 1, 2, 3, 4, 5, and 6 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 hour. 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 hour. 2.2.2.2 In MODE 3, 4, 5, or 6 restore compliance within 5 minutes. Point Beach 2.0-1 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

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, except as provided In LCO 3.0.2 and LCO 3.0.7. 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 Completion 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 Inwhich the LCO Is not applicable. Action shall be initiated within 1 hour to place the unit, as applicable, In:

a. MODE 3 within 7 hours0.292 days 0.0417 weeks 0.00959 months ;

b. MODE 4 within 13 hours0.542 days 0.0774 weeks 0.0178 months ; and

c. MODE 5 within 37 hours1.542 days 0.22 weeks 0.0507 months .

Exceptions to this Specification are stated In the Individual Specifications. Where corrective measures 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. 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; Point Beach 3.0-1 Unit I -Amendment No. 21 5 Unit 2 - Amendment No. 220

LCO Applicability 3.0 3.0 LCO APPLICABILITY LCO 3.0.4 (continued)

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, Ifappropriate; 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. I LCO 3.0.5 Equipment removed from service or declared Inoperable to comply with ACTIONS may be operated 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 operated under administrative control to perform the testing required to demonstrate OPERABILITY. 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)." If a loss of safety function Is determined to exist by the SFDP evaluation, 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. Point Beach 3.0-2 Unit I -Amendment No.21 5 Unit 2 -Amendment No. 2 2 0

LCO Applicability 3.0 3.0 LCO APPLICABILITY (continued) LCO 3.0.7 Test Exception LCOs allow specified Technical Specification (TS) requirements 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 met, 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. Point Beach 3.0-3 Unit I - Amendment No.215 Unit 2 - Amendment No. 2 2 0

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 . . ." 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 hours1 days 0.143 weeks 0.0329 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 hours1 days 0.143 weeks 0.0329 months and the risk impact shall be managed. 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. Point Beach 3.0-4 Unit I -Amendment No. Ai Unit 2 - Amendment No.

- -

SR Applicability 3.0 3.0 SRAPPLICABILITY (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. I Point Beach 3.0-5 Unit I -Amendment No. 215 Unit 2 -Amendment No. 220

SOM 3.1.1 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SOM) LCO 3.1.1 SOM shall be within the limits provided in the COLR. APPLICABILITY: MODE 2 with kett < 1.0, MODES 3, 4, and 5. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SOM not within limit. A.1 Initiate boration to 15 minutes restore SOM to within limit. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.1.1 Verify SOM to be within limits. In accordance with the Surveillance Frequency Control Program Point Beach 3.1.1-1 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

Core Reactivity 3.1.2 3.1 REACTIVITY CONTROL SYSTEMS 3.1.2 Core Reactivity LCO 3.1.2 The measured core reactivity shall be within t 1% Ak/k of predicted values. APPLICABILITY: MODES 1 and 2. ACTIONS CONDITION REQUIRED ACTION COMPLETIONTIME 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. AND A.2 Establish appropriate 7 days operating restrictions and SRs. B. Required Action and B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. Point Beach 3.1.2-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Core Reactivity 3.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.2.1 ---------------------------N()TE-------------------------- 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 (EFPD) after each fuel loading. Verify measured core reactivity is within ()nee prior to

            +/- 1% ~k/k of predicted values.                                 entering M()DE 1 after each refueling AND
                                                                           -------N ()TE------

() n ly required after 60 EFPD In accordance with the Surveillance Frequency Control Program Point Beach 3.1.2-2 Unit 1 -Amendment No. 253 Unit 2 - Amendment No. 257

MTC 3.1.3 3.1 REACTIVITY CONTROL SYSTEMS 3.1.3 Moderator Temperature Coefficient (MTC) LCO 3.1.3 The upper MTC limits shall be maintained within the limits specified in the COLR. The maximum upper MTC limits shall be

5 pcm/OF for power levels *70% RTP and < 0 pcm/OF for power levels > 70% RTP.

APPLICABILITY: MODE 1, MODE 2 with kef > 1.0. ACTIONS CONDITION REQUIRED ACTION COMPLETIONTIME A. MTC not within upper A.1 Establish administrative 24 hours1 days 0.143 weeks 0.0329 months limits. limits for boron concentration to maintain MTC within limits. B. Required Action and B.1 Be in MODE 2 with 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion keff < 1.0. Time not met. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.3.1 Verify MTC is within upper limits. Once prior to entering MODE 1 after each refueling Point Beach 3.1.3-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Rod Group Alignment Limits 3.1.4 3.1 REACTIVITY CONTROL SYSTEMS 3.1.4 Rod Group Alignment Limits LCO 3.1.4 All shutdown and control rods shall be OPERABLE, with individual rod positions within limits. APPLICABILITY: MODES 1 and 2. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more rod(s) A.1.1 Verify SOM to be within 1 hour inoperable. the limits provided in the COLR. OR A.1.2 Initiate boration to 1 hour restore SOM to within limit. AND A.2 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months (continued) Point Beach 3.1.4-1 Unit 1 - Amendment No. 264 Unit 2 - Amendment No. 267

Rod Group Alignment Limits 3.1.4 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME B. One rod not within B.1.1 Verify SOM to be within 1 hour alignment limits. the limits provided in the COLR. OR B.1.2 Initiate boration to 1 hour restore SOM to within limit. AND 8.2 Reduce THERMAL 2 hours0.0833 days 0.0119 weeks 0.00274 months POWER to:=; 75% RTP. AND B.3 Verify SOM to be within Once per the limits provided in 12 hours0.5 days 0.0714 weeks 0.0164 months the COLR. AND B.4 Perform SR 3.2.1.1, 72 hours3 days 0.429 weeks 0.0986 months 3.2.1.2, and 3.2.2.1. AND B.2.5 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 MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time of Condition B not met. (continued) Point Beach 3.1.4-2 Unit 1 - Amendment No. 264 Unit 2 - Amendment No. 267

Rod Group Alignment Limits 3.1.4 ACTIONS continued CONDITION REQUIRED ACTION COMPLETION TIME D. More than one rod not D.1.1 Verify SDM to be within 1 hour within alignment limit. the limits provided in the COLR. OR D.1.2 Initiate boration to 1 hour restore required SOM to within limit. AND D.2 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months Point Beach 3.1.4-3 Unit 1 - Amendment No. 264 Unit 2 - Amendment No. 267

Rod Group Alignment Limits 3.1.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.4.1 -------------------- N()TES------------------------------ In accordance

1. Not required to be performed for rods with the associated with inoperable rod position Surveillance indicator or demand position indicator. Frequency Control Program

2. Not required to be performed until 1 hour after associated rod motion.

Verify position of individual rods within the following alignment limits:

a. +/- 18 steps of demanded position (as allowed by Table 3.1.4-1) in M()DE 1 > 85 percent RTP when bank demand position is< 215 steps;

b. +/- 24 steps of demanded position (as allowed by Table 3.1.4-2) in M()DE 1 > 85 percent RTP when bank demand position is ;::,: 215 steps;

c. +/- 24 steps of demanded position in M()DE 1 :::;; 85 percent RTP or in M()DE 2.

SR 3.1.4.2 Verify rod freedom of movement (trippability) by In accordance moving each rod not fully inserted in the core with the

            ;::,: 10 steps in either direction.                         Surveillance Frequency Control Program SR 3.1.4.3  Verify rod drop time of each rod, from the fully            Prior to reactor withdrawn position, is :::;; 2.2 seconds from the           criticality after beginning of decay of stationary gripper coil               each removal of voltage to dashpot entry, with:                             the reactor head

a. Tavg;:::: 500°F; and

b. All reactor coolant pumps operating.

Point Beach 3.1.4-4 Unit 1 - Amendment No. 264 Unit 2 - Amendment No. 267

                                                                          - Rod Group Alignment Limits 3.1.4 Table 3.1.4-1 Allowable Alignment Limits As A Function Of Measured Peaking Factor Margin (Fa(Z), F!n)

At Power Levels > 85% Of Rated Power And Bank D Demand < 215 Steps Withdrawn ALIGNMENT LIMITS REQUIRED MARGIN TO REQUIRED MARGIN TO (STEPS)* Fig LIMIT (%) Fa(Z) LIMIT (%) 12 0.00 0.00 13 0.33 0.83 14 0.67 1.67 15 1.00 2.50 16 1.33 3.33 17 1.67 4.17 18 2.00 5.00 Between the bank demand position and the RPI System. Table 3.1.4-2 Allowable Alignment LImits As A Function Of Measured Peaking Factor Margin (Fo(Z), FH.) At Power Levels > 85% Of Rated Power And Bank D Demand -215 Steps Withdrawn ALIGNMENT LIMITS REQUIRED MARGIN TO REQUIRED MARGIN TO (STEPS)* FH LIMIT (%) Fc(Z) LIMIT (%) 12 0.00 0.00 13 0.33 0.83 14 0.67 1.67 15 1.00 2.50 16 1.33 3.33 17 1.67 4.17 18 2.00 5.00 19 2.33 5.83 20 2.67 6.67 21 3.00 7.50 22 3.33 8.33 23 3.67 9.17 24 4.00 10.0

Between the bank demand position and the RPI System.

Point Beach 3.1.4-5 Unit 1 - Amendment No. 212 Unit 2 - Amendment No. 217

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

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

Not applicable to shutdown banks inserted while performing SR 3.1.4.2. APPLICABILITY: MODES 1 and 2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One shutdown bank A.1 Verify all control banks 1 hour inserted s 10 steps are within the insertion beyond the insertion limits specified in the limits specified in the COLR. COLR 1 hour A.2.1 Verify SOM is within the limits specified in the COLR. OR 1 hour A.2.2 Initiate boration to restore SOM to within limit. 24 hours1 days 0.143 weeks 0.0329 months A.3 Restore the shutdown bank to within the insertion limits specified in the COLR. (continued) Point Beach 3.1.5-1 Unit 1 - Amendment No. 264 Unit 2 - Amendment No. 267

Shutdown Bank Insertion Limits 3.1.5 CONDITION REQUIRED ACTION COMPLETION TIME B. One or more shutdown B.1.1 Verify SOM to be within 1 hour banks not within limits the limits provided in for reasons other than the COLR. Condition A. OR B.1.2 Initiate boration to 1 hour restore SOM to within limit. AND 8.2 Restore shutdown 2 hours0.0833 days 0.0119 weeks 0.00274 months banks to within limits. C. Required Action and C.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 ---------------------------- NOTE ------------------------- In accordance Not required to be performed until 1 hour after with the associated rod motion. Surveillance

                  --------------------------------------------------------------   Frequency Control Program Verify each shutdown bank is within the limits specified in the COLR.

Point Beach 3.1.5-2 Unit 1 - Amendment No. 264 Unit 2 - Amendment No. 267

Control Bank Insertion Limits 3.1.6 3.1 REACTIVITY CONTROL SYSTEMS 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.

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

Not applicable to control banks inserted while performing SR 3.1.4.2. APPLICABILITY: MODE 1, MODE 2 with ke11 :::>: 1.0. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Control bank A, B, or C A.1 Verify all shutdown banks 1 hour inserted s 1O steps are within the insertion limits beyond the insertion, specified in the COLR. sequence, or overlap limits specified in the COLR. A.2.1 Verify SOM is within the 1 hour limits specified in the COLR. OR A.2.2 Initiate boration to 1 hour restore SOM to within limit. A.3 Restore the control bank to 24 hours1 days 0.143 weeks 0.0329 months within the insertion, sequence, and limits specified in the COLR. (continued) Point Beach 3.1.6-1 Unit 1 - Amendment No. 264 Unit 2 - Amendment No. 267

Control Bank Insertion Limits 3.1.6 CONDITION REQUIRED ACTION COMPLETION TIME B. Control bank insertion B.1.1 Verify SDM to be within 1 hour limits not met for the limits provided in reasons other than the COLR. Condition A. OR B.1.2 Initiate boration to 1 hour restore SDM to within limit. AND B.2 Restore control bank(s) 2 hours0.0833 days 0.0119 weeks 0.00274 months to within limits. C. Control bank sequence C.1.1 Verify SDM to be within 1 hour or overlap limits not met the limits provided in for reasons other than the COLR. Condition A. OR C.1.2 Initiate boration to 1 hour restore SDM to within limit. AND C.2 Restore control bank 2 hours0.0833 days 0.0119 weeks 0.00274 months sequence and overlap to within limits. D. Required Action and D.1 Be in MODE 2 with 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion ken< 1.0. Time not met. Point Beach 3.1.6-2 Unit 1 - Amendment No. 264 Unit 2 - Amendment No. 267

Control Bank Insertion Limits 3.1.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.1 Verify estimated critical control bank position is Within 4 hours0.167 days 0.0238 weeks 0.00548 months within the limits specified in the COLR. prior to achieving criticality SR 3.1.6.2 ----------------------------NOTE------------------------ In accordance Not required to be performed until 1 hour after with the associated rod motion. Surveillance Frequency Control Program Verify each control bank insertion is within the limits specified in the COLR. SR 3.1.6.3 ---------------------------- NOTE ------------------------ In a cco rda n ce Not required to be performed until 1 hour after with the associated rod motion. Surveillance

             --------------------------------------------------------------  Frequency Control Program Verify sequence and overlap limits specified in the COLR are met for control banks not fully withdrawn from the core.

Point Beach 3.1.6-3 Unit 1 - Amendment No. 264 Unit 2 - Amendment No. 267

Rod Position Indication 3.1.7 3.1 REACTIVITY CONTROL SYSTEMS 3.1. 7 Rod Position Indication LCO 3.1.7 Individual control rod position indication (RPI) and bank demand indication shall be OPERABLE.

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

1ndividual RPls are not required to be OPERABLE for 1 hour following movement of the associated rods. APPLICABILITY: MODES 1 and 2. ACTIONS

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

Separate Condition entry is allowed for each inoperable RPI per group and each bank demand position indicator per bank. CONDITION REQUIRED ACTION COMPLETION TIME A. One or more RPl(s) per A.1.1 Verify the position of 8 hours0.333 days 0.0476 weeks 0.011 months group inoperable in one the rods with inoperable or more groups. RPls by using movable incore detectors. AND A.1.2 Verify the position of Once per 8 hours0.333 days 0.0476 weeks 0.011 months the rods with inoperable RPls. OR A.2 Reduce THERMAL 8 hours0.333 days 0.0476 weeks 0.011 months POWER to s 50% RTP ( continued) Point Beach 3.1.7-1 Unit 1 -Amendment No. 264 Unit 2 - Amendment No. 267

Rod Position Indication 3.1.7 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME B. One or more RPls B.1 Verify the position of 4 hours0.167 days 0.0238 weeks 0.00548 months inoperable in one or the rods with inoperable more groups and RPls. associated rod has been moved >24 steps in one direction since the last OR determination of the rod's position. B.2 Reduce THERMAL 8 hours0.333 days 0.0476 weeks 0.011 months POWER to s 50% RTP. C. One or more bank C.1.1 Verify by administrative Once per 8 hours0.333 days 0.0476 weeks 0.011 months demand position means all RPls for the indicator(s) per bank affected banks are inoperable in one or OPERABLE. more banks. AND C.1.2 Verify the most Once per 8 hours0.333 days 0.0476 weeks 0.011 months withdrawn rod and the least withdrawn rod of the affected banks are: s 12 steps apart when RTP is > 85 percent, and s 24 steps apart when RTP is s 85 percent. OR C.2 Reduce THERMAL 8 hours0.333 days 0.0476 weeks 0.011 months POWER to s 50% RTP. D. Required Action and D.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. Point Beach 3.1.7-2 Unit 1 - Amendment No. 264 Unit 2 - Amendment No. 267

Rod Position Indication 3.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.1 ---------------------------NO TE--------------------------- Once prior to Not required to be met for RPls associated with criticality after rods that do not meet LCO 3.1.4. each removal of the reactor head. Perform CHANNEL CALIBRATION of each RPI. Point Beach 3.1.7-3 Unit 1 - Amendment No. 264 Unit 2 - Amendment No. 267

PHYSICS TESTS Exceptions-MODE 2 3.1.8 3.1 REACTIVITY CONTROL SYSTEMS 3.1.8 PHYSICS TESTS Exceptions-MODE 2 LCO 3.1.8 During the performance of PHYSICS TESTS, the requirements of LCO 3.1.3, "Moderator Temperature Coefficient (MTC)"; 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 Minimum Temperature for Criticality" may be suspended and the number of required channels for LCO 3.3.1, NRPS Instrumentation," Functions 2, 5, and 17.e, may be I reduced to '3" required channels, provided:

a. RCS lowest loop average temperature is > 530*F;

b. SDM is within the limits provided In the COLR; and

c. THERMAL POWER is s 5% RTP.

APPLICABILITY: During PHYSICS TESTS initiated In MODE 2. ACTIONS CONDITION REQUIRED ACTION COMPLETlON 1IME A. SDM not within limit. A.1 Initiate boration to 15 minutes restore SDM to within limit. AND A.2 Suspend PHYSICS 1 hour TESTS exceptions. B. THERMAL POWER not B.1 Open reactor trip Immediately within limit. breakers. (continued) Point Beach 3.1.8-1 Unit 1 - Amendment No.29E, 208 Unit 2 - Amendment No.296,213

PHYSICS TESTS Exceptions- MODE 2 3.1.8 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. RCS lowest loop C.1 Restore RCS lowest 15 minutes average temperature not loop average within limit. temperature to 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 SR 3.1.8.1 Verify the RCS lowest loop average temperature In accordance is z 530°F. with the Surveillance Frequency Control Proqram SR 3.1.8.2 Verify THERMAL POWER is~ 5% RTP. In accordance with the Surveillance Frequency Control Proaram SR 3.1.8.3 Verify SDM to be within the limits provided in the In accordance COLR. with the Surveillance Frequency Control Proqram Point Beach 3.1.8-2 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

FO(Z) 3.2.1 3.2 POWER DISTRIBUTION LIMITS 3.2.1 Heat Flux Hot Channel Factor (Fa,(Z)) LCO 3.2.1 Fo(Z), as approximated by F0 (Z) and Fw (Z), shall be within the limits specified in the COLR. APPLICABILITY: MODE 1. ACTIONS CONDITION REQUIRED ACTION COMPLEI1ON lIME

     ------------NOTE------------  A.1       Reduce THERMAL                15 minutes Required Action A.4                     POWER 2 1% RTP for            after each Fa(Z) shall be completed                      each 1% Fc (Z) exceeds        determination whenever this Condition                 limit.

is entered.

         --                        AND A. Fc (Z) not within limit.      A.2       Reduce Power Range            72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> Neutron Flux-High trip        after each F0 (Z) setpoints 2 1%for each        determination 1% Fc (Z) exceeds limit.

AND A.3 Reduce Overpower AT trip setpoints 2 1% for 72 hours3 days 0.429 weeks 0.0986 months each 1% Fc (Z) exceeds after each Fc(Z) limit. determination AND (continued) Point Beach 3.2.1-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Fa(Z) 3.2.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) AA Perform SR 3.2.1.1 and Prior to SR 3.2.1.2. increasing THERMAL POWER above the limit of Required Action A.1

     -----------NOTE----------     8.1    Reduce THERMAL                 4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> Required Action BA                    POWER;;::: 1% RTP for shall be completed                   each 1% F~(Z) exceeds whenever this Condition               limit.

is entered.

     ----------------------------- AND 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> B. F~(Z) not within limits.       B.2    Reduce Power Range Neutron Flux-High trip setpoints ;;::: 1% for each 1 % F~(Z) exceeds limits.

AND (continued) Point Beach 3.2.1-2 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

FQ{Z) 3.2.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.3 Reduce the Overpower 72 hours3 days 0.429 weeks 0.0986 months I:!..T trip setpoints ~ 1% for each 1% F'6(Z) exceeds limits. AND B.4 Perform SR 3.2.1.1 and Prior to SR 3.2.1.2. increasing THERMAL POWER above the limit of Required Action B.1. C. Required Action and C.1 Be in MODE 2. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. Point Beach 3.2.1-3 Unit 1 - Amendment No. 241 Unit 2

Amendment No. 245

F0 (Z) 3.2.1 SURVEILLANCE REQUIREMENTS

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

Du ring power escalation at the beginning of each cycle, THERMAL P()WER 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 F~(Z) is within limit. ()nee after each refueling prior to THERMAL P()WER exceeding 75% RTP ()nee within 12 hours0.5 days 0.0714 weeks 0.0164 months after achieving equilibrium conditions after exceeding, by

                                                                                     ~ 10% RTP, the THERMAL P()WER at which F~(Z) was last verified In accordance with the Surveillance Frequency Control Program (continued)

Point Beach 3.2.1-4 Unit 1 -Amendment No. 253 Unit 2 - Amendment No. 257

F0 (Z) 3.2.1 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.2.1.2 --------------------------N 0 TE------------------------- 1f F~(Z) measurements indicate that the maximum over z [ E{j(Z) K(Z) ] has increased since the previous evaluation of F~(Z):

a. Increase F~(Z) by the greater of a factor of 1.02 or by an appropriate factor specified in the COLR and reverify F~(Z) is within limits; or

b. Repeat SR 3.2.1.2 once per 7 EFPD until either a. above is met, or two successive flux maps indicate that the maximum over z

[ E{j(Z) K(Z) ] has not increased. Verify F~(Z) is within limit. Once after each refueling prior to THERMAL POWER exceeding 75% RTP (continued) Point Beach 3.2.1-5 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

F0 (Z) 3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.2 (continued) Once within 12 hours0.5 days 0.0714 weeks 0.0164 months after achieving equilibrium conditions after exceeding, by

                                                   ;;:: 10% RTP, the THERMAL POWER at which F~(Z) was last verified.

In accordance with the Surveillance Frequency Control Program Point Beach 3.2.1-6 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

FAH 3.2.2 3.2 POWER DISTRIBUTION LIMITS 3.2.2 Nuclear Enthalpy Rise Hot Channel Factor (FNH) LCO 3.2.2 FNH shall be within the limits specified in the COLR. APPLICABILITY: MODE 1. ACTIONS CONDITION REQUIRED ACTION COMPLETIONTIME A. ---------- NOTE----------- A.1 .1 Restore FNH to within 4 hours0.167 days 0.0238 weeks 0.00548 months Required Actions A.2 limit. and A.3 must be completed whenever OR Condition A is entered.

              .    .A.1.2.1                   Reduce THERMAL              4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> POWER to < 50% RTP.

FNH not within limit. AND A.1.2.2 Reduce Power Range 72 hours3 days 0.429 weeks 0.0986 months Neutron Flux - High trip setpoints to < 55% RTP. AND A.2 Perform SR 3.2.2.1. 24 hours1 days 0.143 weeks 0.0329 months AND (continued) Point Beach 3.2.2-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

FlH 3.2.2 ACTIONS CONDITION REQUIRED ACTION COMPLETIONTIME 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 AND Prior to THERMAL POWER exceeding 75% RTP AND 24 hours1 days 0.143 weeks 0.0329 months after THERMAL POWER reaching 2 95% RTP B. Required Action and B.1 Be in MODE 2. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. Point Beach 3.2.2-2 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

F~H 3.2.2 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 In accordance with the Surveillance Frequency Control Program Point Beach 3.2.2-3 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

AFD 3.2.3 3.2 POWER DISTRIBUTION LIMITS 3.2.3 AXIAL FLUX DIFFERENCE (AFD) 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. May deviate outside the target band with THERMAL POWER

                      <90% RTP but::.. 50% RTP, provided AFD is within the acceptable operation limits and cumulative penalty deviation time is ~ 1 hour during the previous 24 hours1 days <br />0.143 weeks <br />0.0329 months <br />. The acceptable operation limits are specified in the COLR.

c. May 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.

2. With THERMAL POWER::.. 50% 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% 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 hours0.667 days 0.0952 weeks 0.0219 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: MODE 1 with THERMAL POWER> 15% RTP. Point Beach 3.2.3-1 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

AFD 3.2.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. THERMAL POWER A.1 Restore AFD to within 15 minutes

     ,::::,,90% RTP.                        target band.

AND AFD not within the target band B. Required Action and B.1 Reduce THERMAL 15 minutes associated Completion POWER TO <90% RTP. Time of Condition A not met. C. -----------NOTE------------ C.1 Reduce THERMAL 30 minutes Required Action C.1 POWER to < 50% RTP. must be completed whenever Condition C is entered.

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

THERMAL POWER

     < 90% and ~ 50% RTP with cumulative penalty deviation time> 1 hour during the previous 24 hours1 days <br />0.143 weeks <br />0.0329 months <br />.

OR THERMAL POWER

     < 90% and ~ 50% RTP with AFD not within the acceptable operation limits.

D. Required Action and 0.1 Reduce THERMAL 9 hours0.375 days 0.0536 weeks 0.0123 months associated Completion POWER to < 15% RTP. Time for Condition C not met. Point Beach 3.2.3-2 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

AFD 3.2.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 Verify AFD within limits for each OPERABLE In accordance excore channel. with the Surveillance Frequency Control Program SR 3.2.3.2 Update target flux difference. Once within 31 EFPD after each refueling In accordance with the Surveillance Frequency Control Program SR 3.2.3.3 --------------------------------NOTE---------------------- The initial target flux difference after each refueling may be determined for design predictions. Determine, by measurement, the target flux Once within 31 difference. EFPD after each refueling In accordance with the Surveillance Frequency Control Program Point Beach 3.2.3-3 Unit 1 - Amendment No. 253 Unit 2 - Amendment No 257

QPTR 3.2.4 3.2 POWER DISTRIBUTION LIMITS 3.2.4 QUADRANT POWER TILT RATIO (QPTR) LCO 3.2.4 The QPTR shall be < 1.02. APPLICABILITY: MODE 1 with THERMAL POWER > 50% RTP. ACTIONS CONDITION REQUIRED ACTION COMPLETlONTIME A. QPTR not within limit. A.1 Reduce THERMAL 2 hours0.0833 days 0.0119 weeks 0.00274 months after POWER 2 3% from RTP each QPTR for each 1% of QPTR determination

                                     > 1.00.

AND A.2 Determine QPTR. Once per 12 hours0.5 days 0.0714 weeks 0.0164 months AND A.3 Perform SR 3.2.1.1, 24 hours1 days 0.143 weeks 0.0329 months after SR 3.2.1.2, and achieving SR 3.2.2.1. equilibrium conditions from a thermal power reduction per Required Action A.1 AND Once per 7 days thereafter AND (continued) Point Beach 3.2.4-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

QPTR 3.2.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.4 Reevaluate safety Prior to analyses and confirm increasing results remain valid for THERMAL duration of operation POWER above under this condition. the limit of Required AND Action A.1 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 if Required Action A.5 is performed.

Normalize the excore Prior to detectors to restore increasing QPTR to within limits. THERMAL POWER above the limit of Required AND Action A.1 (continued)' Point Beach 3.2.4-2 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

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, Within 24 hours1 days 0.143 weeks 0.0329 months SR 3.2.1.2, and after achieving

                                .SR 3. 2.2.1.                equilibrium conditions at RTP. Not to exceed 48 hours2 days <br />0.286 weeks <br />0.0658 months <br /> after increasing THERMAL POWER above the limit of Required Action A.1 B. Required Action and   B.1    Reduce THERMAL              4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> associated Completion        POWER to < 50% RTP.

Time not met. Point Beach 3.2.4-3 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

QPTR 3.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.1 --------------------------N()TES-------------------------

1. With input from one Power Range Neutron Flux channel inoperable and THERMAL P()WER ~ 75% RTP, the remaining three power range channels can be used for calculating QPTR.

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

Verify QPTR is within limit by calculation. In accordance with the Surveillance Frequency Control Program SR 3.2.4.2 ---------------------------N()TE-------------------------- Not required to be performed until 12 hours0.5 days 0.0714 weeks 0.0164 months after input from one or more Power Range Neutron Flux channels are inoperable with THERMAL P()WER > 75% RTP. Verify QPTR is within limit using the movable In accordance incore detectors. with the Surveillance Frequency Control Program Point Beach 3.2.4-4 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

- - - RPS Instrumentation 3.3.1 3.3 INSTRUMENTATION 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 COMPLE17ON TIME A. One or more Functions A.1 Enter the Condition Immediately with one or more referenced in Table required channels or 3.3.1-1 for the trains inoperable. channel(s) or train(s). B. One Manual Reactor Trip B.1 Restore channel to 48 hours2 days 0.286 weeks 0.0658 months channel inoperable. OPERABLE status. OR B.2 Be in MODE 3. 54 hours2.25 days 0.321 weeks 0.074 months C. One Manual Reactor Trip C.1 Restore channel to 48 hours2 days 0.286 weeks 0.0658 months channel inoperable. OPERABLE status. OR C.2 Open reactor trip 49 hours2.042 days 0.292 weeks 0.0671 months breakers (RTBs). (continued) Point Beach 3.3.1-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

RPS Instrumentation 3.3.1 ACTIONS (continued) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ CONDITION REQUIRED ACTION COMPLETION TIME D. One channel inoperable. D.1 Place channel in trip. 1 hour OR D.2 Be in MODE 3. 7 hours0.292 days 0.0417 weeks 0.00959 months E. One channel inoperable. E.1 Place channel in trip. 6 hours0.25 days 0.0357 weeks 0.00822 months OR E.2 Reduce THERMAL 12 hours0.5 days 0.0714 weeks 0.0164 months POWER to < P-7. F. One Intermediate Range F.1 Reduce THERMAL 24 hours1 days 0.143 weeks 0.0329 months Neutron Flux channel POWER to < P-6. inoperable. OR F.2 Increase THERMAL 24 hours1 days 0.143 weeks 0.0329 months POWER to > P-10. G. Two Intermediate Range G.1 Suspend operations Immediately Neutron Flux channels involving positive inoperable. reactivity additions. AND G.2 Reduce THERMAL 2 hours0.0833 days 0.0119 weeks 0.00274 months POWER to < P-6. H. One Source Range H.1 Suspend operations Immediately Neutron Flux channel Involving positive inoperable. reactivity additions. (continued) Point Beach 3.3.1-2 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

- - RPS Instrumentation 3.3.1 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME I Two Source Range 1.1 Open RTBs. Immediately Neutron Flux channels inoperable. J. One Source Range J.1 Restore channel to 48 hours2 days 0.286 weeks 0.0658 months Neutron Flux channel OPERABLE status. inoperable. OR J.2 Open RTBs. 49 hours2.042 days 0.292 weeks 0.0671 months K. One channel inoperable. K.1 Place channel in trip. 1 hour OR K.2 Reduce THERMAL 7 hours0.292 days 0.0417 weeks 0.00959 months POWER to < P-7. L. One Reactor Coolant L.1 Place channel in trip. 1 hour Flow-Low (Single Loop) channel inoperable. OR L.2 Reduce THERMAL 5 hours0.208 days 0.0298 weeks 0.00685 months POWER to < P-8. M. One Reactor Coolant M.1 Restore channel to 1 hour Pump Breaker Position OPERABLE status. (Single Loop) channel inoperable. OR M.2 Reduce THERMAL 5 hours0.208 days 0.0298 weeks 0.00685 months POWER to < P-8. (continued) Point Beach 3.3.1-3 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

RPS Instrumentation 3.3.1 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME N. One inoperable channel. N.1 Restore channel to 1 hour OPERABLE status. OR N.2 Reduce THERMAL 7 hours0.292 days 0.0417 weeks 0.00959 months POWER to < P-7.

0. One turbine trip channel 0.1 Place channel in trip. 1 hour inoperable.

OR 0.2 Reduce THERMAL 5 hours0.208 days 0.0298 weeks 0.00685 months POWER to < P-9. P. One train inoperable. -----------------NOTE----------------- One train may be bypassed for up to 8 hours0.333 days 0.0476 weeks 0.011 months for surveillance testing provided the other train is OPERABLE. P.1 Restore train to 6 hours0.25 days 0.0357 weeks 0.00822 months OPERABLE status. OR P.2 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months (continued) Point Beach 3.3.1-4 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

RPS Instrumentation 3.3.1 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLE-lONTIME

0. One RTB inoperable. -------- NOTE-----------------

One RTB may be bypassed for up to 8 hours0.333 days 0.0476 weeks 0.011 months provided the other RTB is OPERABLE. 0.1 Restore RTB to 1 hour OPERABLE status. OR 0.2 Be in MODE 3. 7 hours0.292 days 0.0417 weeks 0.00959 months R. One or more channel(s) R.1 Verify interlock is in 1 hour inoperable. required state for existing unit conditions. OR R.2 Be in MODE 3. 7 hours0.292 days 0.0417 weeks 0.00959 months S. One or more channel(s) S.1 Verify interlock is in 1 hour inoperable. required state for existing unit conditions. OR S.2 Be in MODE 2. 7 hours0.292 days 0.0417 weeks 0.00959 months T. One RTB or trip T.1 Restore RTB or RTB 48 hours2 days 0.286 weeks 0.0658 months mechanism for one RTB trip mechanism to inoperable. OPERABLE status. OR T.2 Open RTBs. 49 hours2.042 days 0.292 weeks 0.0671 months (continued) Point Beach 3.3.1-5 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

RPS Instrumentation 3.3.1 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION 1IME U. One trip mechanism U.1 Restore inoperable trip 48 hours2 days 0.286 weeks 0.0658 months inoperable for one RTB. mechanism to OPERABLE status. OR U.2 Be in MODE 3. 54 hours2.25 days 0.321 weeks 0.074 months V. One reactor trip bypass V.1 Restore RTBB or RTBB 1 hour breaker (RTBB) or trip trip mechanism to mechanism for one OPERABLE status. RTBB inoperable. OR V.2 Be in MODE 3. 7 hours0.292 days 0.0417 weeks 0.00959 months W. One reactor trip bypass W.1 Restore RTBB or RTBB 48 hours2 days 0.286 weeks 0.0658 months breaker (RTBB) or trip trip mechanism to mechanism for one OPERABLE status. RTBB inoperable. OR W.2 Open RTBs and 49 hours2.042 days 0.292 weeks 0.0671 months RTBBs. X. One train inoperable. X.1 Restore train to 48 hours2 days 0.286 weeks 0.0658 months OPERABLE status. OR X.2 Open RTBs. 49 hours2.042 days 0.292 weeks 0.0671 months Point Beach 3.3.1-6 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

RPS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS

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

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. In accordance with the Surveillance Frequency Control Program SR 3.3.1.2 ---------------------------N ()TES-------------------------

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

2. Not required to be performed until 12 hours0.5 days 0.0714 weeks 0.0164 months after THERMAL P()WER is ~ 15%

RTP. In accordance Compare results of calorimetric heat balance with the calculation to Nuclear Instrumentation System Surveillance (NIS) channel output. Frequency Control Program SR 3.3.1.3 ---------------------------N ()TES-------------------------

1. Adjust NIS channel if absolute difference is~ 3%.

2. Not required to be performed until 24 hours1 days 0.143 weeks 0.0329 months after THERMAL P()WER is~ 50%

RTP. In accordance Compare results of the incore detector with the measurements to NIS AFD. Surveillance Frequency Control Program (continued) Point Beach 3.3.1-7 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

RPS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.3.1.4 ---------------------------- N 0 TE-------------------------- T his Surveillance must be performed on the reactor trip bypass breaker prior to placing the bypass breaker in service. In accordance Perform T ADOT. with the Surveillance Frequency Control Program SR 3.3.1.5 ---------------------------N 0 TES-------------------------

1. Not required to be performed for the Source Range Neutron Flux Trip Function until 8 hours0.333 days 0.0476 weeks 0.011 months after power is below P-6.

2. Not required to be performed for the RCP Breaker Position (Two Loops), Reactor Coolant Flow-Low (Two Loops) and Underfrequency Bus A01 and A02 Trip Functions and the P-6, P-7, P-8, P-9 and P-10 Interlocks.

In accordance Perform ACTUATION LOGIC TEST. with the Surveillance Frequency Control Program SR 3.3.1.6 ---------------------------- N 0 TE-------------------------- N ot required to be performed until 24 hours1 days 0.143 weeks 0.0329 months after THERMAL POWER is~ 50% RTP. In accordance Calibrate excore channels to agree with incore with the detector measurements. Surveillance Frequency Control Proqram (continued) Point Beach 3.3.1-8 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

RPS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.3.1.7 ----------------------------N 0 TE-------------------------- Not required to be performed for source range instrumentation prior to entering MODE 3 from MODE 2 until 4 hours0.167 days 0.0238 weeks 0.00548 months after entry into MODE 3. In accordance Perform COT. with the Surveillance Frequency Control Program (continued) Point Beach 3.3.1-9 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

RPS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.3.1.8 ----------------------------N 0 TE------------------------- This Surveillance shall include verification that interlocks P-6 and P-10 are in their required state for existing unit conditions.

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

On ly required when not performed Perform COT. within the frequency specified in the Surveillance Frequency Control Program Prior to reactor startup Four hours after reducing power below P-10 for power and intermediate range instrumentation Four hours after reducing power below P-6 for source range instrumentation In accordance with the Surveillance Frequency Control Pro ram (continued) Point Beach 3.3.1-10 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

RPS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.3.1.9 Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.10 ----------------------------N 0 TE-------------------------- T his Surveillance shall include verification that the time delays are adjusted to the prescribed values. In accordance with the Perform CHANNEL CALIBRATION. Surveillance Frequency Control Program SR 3.3.1.11 ----------------------------N 0 TE-------------------------- N e utro n detectors are excluded from CHANNEL CALIBRATION. In accordance with the Perform CHANNEL CALIBRATION. Surveillance Frequency Control Program SR 3.3.1.12 Perform COT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.13 Perform TADOT. In accordance with the Surveillance Frequency Control Program (continued) Point Beach 3.3.1-11 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

RPS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.3.1.14 Perform TADOT. Prior to exceeding the P-9 interlock whenever the unit has been in MODE 3, if not performed within previous 31 days. SR 3.3.1.15 --------------------------- N 0 TE--------------------------- This Surveillance must be performed on the RCP Breaker Position (Two Loop), Reactor Coolant Flow - Low (Two Loop) and Underfrequency Bus A01 and A02 Trip Functions and the P-6, P-7, P-8, P-9 and P-10 Interlocks. In accordance Perform ACTUATION LOGIC TEST. with the Surveillance Frequency Control Program Point Beach 3.3.1-12 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

RPS Instrumentation 3.3.1 Table 3.3.1-1 (page 1 of 8) Reactor Protecllon System Instrumentation FUNCTION APPLICABLE REQUIRED SURVElUANCE ALLOWABLE NOMINAL TRIP MODES Q-lANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT

1. Manual 1,2 2 B SR 3.3.1.13 NA NA Reactor Trip 3(a), 4(a), 5(a) 2 C SR 3.3.1.13 NA NA

2. Power Range Neutron Flux

a. High 1.2 4 D SR3.3.1.1 ~ 108% RTP 106% RTP SR 3.3.1.2 SR 3.3.1.7(m)

SR 3.3.1.11(m)

b. Low 1(b).2 4 D SR 3.3.1.1 ~ 27% RTP 20% RTP SR 3.3.1.8(m)

SR 3.3.1.11(m)

3. Intermediate 1 (b), 2(c) 2 F.G SR 3.3.1.1 ~ 43% RTP 25% RTP Range Neutron SR 3.3.1.a(m)

Flux SR 3.3.1.11!m)

4. Source Range 2(d) 2 H.I SR 3.3.1.1 ~3.0 E5 cps 1.5 E5 cps Neutron Flux SR 3.3.1.a(m)

SR 3.3.1.11(m) 3(a), 4(a). 5(a) 2 I.J SR3.3.1.1 ~3.0 E5cps 1.5 E5 cps SR 3.3.1.7(m) SR 3.3.1.11(m)

5. Overtemperature 1.2 4 D SR 3.3.1.1 Refer to Note 1 Refer to Note 1 8T SR 3.3.1.3 (Page 3.3.1-18) (Page 3.3.1-18)

SR 3.3.1.6 SR 3.3.1.7(m) SR 3.3.1.11(m)

6. Overpower 8 T 1,2 4 D SR3.3.1.1 Refer to Note 2 Refer to Note 2 SR 3.3.1.7(m) (Page 3.3.1-19) (Page 3.3.1-19)

SR 3.3.1.11(m) (continued) (a) With Reactor Trip Breakers (RTBs) closed and Rod Control System capable of rod withdrawal. (b) Below the P-10 (Power Range Neutron Flux) lnter/ock. (c) Above the P-6 (Intermediate Range Neutron Flux) interlock. (d) Below the P-6 (Intennedlate Range Neutron Flux) Interlock. (m) Table 3.3.1-1 Notes 3 and 4 are applicable Point Beach 3.3.1-13 Unit 1 - Amendment No. 239 Unit 2 - Amendment No. 243

RPS Instrumentation 3.3.1 Table 3.3.1-1 (page 2 of 8) Reactor Protection System Instrumentation APPLICABLE REQUIRED SURVEIl.IJWCE ALLOWABLE NOMINAL TRIP FUNCTION MODES CI-WlN8..S CONDITIONS REQUIREMENTS VALUE SETPOINT

7. Pressurizer Pressure

a. Low 1(e) 4 K SR 3.3.1.1 =: 1860 psig 1925 pslg SR 3.3.1.7(m)

SR 3.3.1.11(m)

b. High 1,2 3 D SR3.3.1.1 !S2380 pslg 2365 psig SR 3.3.1.7(m)

SR 3.3.1.11{m J

8. Pressurizer 1(e) 3 K SR3.3.1.1 $85% 80%

Water Level SR 3.3.1.7(m) High SR 3.3.1.11(m)

9. Reactor Coolant Flow-Low

a. Single Loop 1(f) 3 per loop L SR 3.3.1.1 :a91% 93%

SR 3.3.1. 7(m) SR 3.3.1.11{m)

b. Two Loops 1(g) 3 per loop K SR 3.3.1.1 2:91% 93%

SR3.3.1.7{m) SR 3.3.1.11(m)

10. Reactor Coolant Pump (RCP)

Breaker Position

a. 1(f)

Single Loop 1 perRCP M SR3.3.1.13 NA NA

b. Two Loops 1(g) 1 perRCP N SR 3.3.1.13 NA NA

11. Undervoltage 1(e) 2 per bus K SR 3.3.1.9 ~ 3120 V 3170 V BUsA01 &A02 SR 3.3.1.10{m)

(continued) (e) Above the P-7 (Low Power Reactor Trips Block) Interlock. (f) Above the P-8 (Power Range Neutron Flux) interlock. (g) Above the P-7 (Low Power Reactor Trips Block) Interlock and below the P-S (Power Range Neutron Flux) interlock. em) Table 3.3.1-1 Notes 3 and 4 are applicable Point Beach 3.3.1-14 Unit 1 - Amendment No. 239 Unit 2 - Amendment No. 243

RPS Instrumentation 3.3.1 Table 3.3.1-1 (page 3 of 8) Reactor Protection System Instrumentation APPLICABLE REQUIRED SURVElUANCE ALLOWABLE NOMINAL TRIP FUNCTION MODES ~N8.S CONDITIONS REQUIREMEJIITS VALUE SETPOINT

12. Underfrequency 1(e) 2 per bus e SR 3.3.1.1 Olm) ;:: 55.0 Hz 57 Hz BusA01 &A02

13. Steam Oenerator 1,2 3 per SG 0 SR3.3.1.1 ;::29.5% 31%

(SO) SR 3.3.1.7(m) Water Level- SR 3.3.1.11(m) Low Low

14. SGWater 1,2 2 perSG D SR 3.3.1.1 ~ 11% 31%

Level-Low SR 3.3.1.7(m) SR3.3.1.11(m) Coincident with 1,2 2 per SO D SR 3.3.1.1 :s; 1 E81bmlhr 0.8 E6 Ibmlhr Steam SR 3.3.1.7(m) Flow/Feedwater SR 3.3.1.11(m) Flow Mismatch

15. Turbine Trip

a. Low 10) 3 0 SR 3.3.1.14 NA NA Autostop Oil Pressure

b. Turbine 10) 2 0 SR 3.3.1.14 NA NA Stop Valve Closure

16. Safety Injecllon 1,2 2 trains P SR 3.3.1.13 NA . NA (SI) Input from Engineered Safety Feature Actuation Syslem (eSFAS)

(continued) (e) Above the P-7 (Low Power Reactor Trips Block) interlock. (j) Above the P-9 (Power Range Neutron Flux) interlock. (m) Table 3.3.1-1 Notes 3 and 4 are applicable Point Beach Unit 1 - Amendment No. 239 Unit 2 - Amendment No. 243

RPS Instrumentation 3.3.1 Table 3.3.1-1 (page 4 of 8) Reactor Protection System Instrumentation APPLICABLE REQUIRED CONDITIONS SURVElUJINCE ALLOWABLE NOMINAL TRIP FUNCTION MODES a-tANNELS REQUIREMENTS VALUE SETPOINT

17. Reactor Trip System Interlocks

a. Intermediate 2(d) 2 R SR 3.3.1.11 ;::4E-11 amp 1E-10 amp Range Neutron SR3.3.1.12 Flux, P-6

b. Low Power Reactor Trips Block, P-7 (1) Power 4 S SR 3.3.1.11 :::,13% RTP 10% RTP Range SR 3.3.1.12 Neutron Flux (2) Turbine First 2 S SR 3.3.1.11 <: 12.8% 10% turbine power Stage SR 3.3.1.12 turbine power Pressure

c. Power Range 4 S SR 3.3.1.11 .::,3B%RTP 35%RTP Neutron Flux, P-8 SR3.3.1.12

d. Power Range 1(k) 4 S SR 3.3.1.11 (h) (i)

Neutron Flux, P-9 SR3.3.1.12

e. Power Range 1,2 4 R SR 3.3.1.11 ;::6% RTPand 9%RTP Neutron Flux, P-10 SR 3.3.1.12 :::,12%RTP

18. Reactor Trip 1,2 2 trains Q SR3.3.1,4 NA NA Breakers (RTBs) 3(a), 4(a), 5(a) 2 trains T SR 3.3.1.4 NA NA

19. Reactor Trip Breaker 1,2 1 each per U SR 3.3.1,4 NA NA Undervoltage and Shunt RTB Trip Mechanisms 3(a), 4(a), 5(a) 1 each per T SR 3.3.1.4 NA NA RTB (continued)

(a) With the RTBs closed and the Rod Control System capable of rod withdrawal. (d) Below the P-6 (Intermediate Range Neutron Flux) Interlock. (h) .::: 38% RTP for full design power Tavg <: 572°F or!:. 53% RTP for full design power Tavg;:: 572°F. For EOC coastdown, P-91s not reset If Tavg decreases to <: 572°F. (I) 35% RTP for full design power Tavg <: 572°F or 50% RTP for full design power Tavg ;:: 572°F. For EOC coastdown, P-91s not reset IfTavg decreases to <: 572°F. (k) With 1 of 2 circulating water pump breakers closed and condenser vacuum ~ 22 "Hg. Point Beach 3.3.1-16 Unit 1 - Amendment No. 239 Unit 2 - Amendment No. 243

RPS Instrumentation 3.3.1 Table 3.3.1-1 (page 5 of 8) Reactor Protection System Instrumentation APPLICABLE REQUlRBJ SURVEIlLANCE ALLOWABLE NOMINAL TRIP FUNCTION MODES CHANNElS CONDITIONS REQUIREMENTS VALUE SETPOINT

20. Reactor Trip Bypass 1(1),2(1) V SR3.3.1.4 NA NA Breaker and associated Undervoltage Trip 3(1),4(1),5(1) W SR 3.3.1.4 NA NA Mechanism

21. Automatic Trip Logic 1,2, 2 trains P SR3.3.1.5 NA NA SR 3.3.1.15 3(a),4(a), 5(a) 2 trains X SR3.3.1.5 NA NA (a) With RTBs closed and Rod Control System capable of rod withdrawal.

(I) When Reactor Trip Bypass Breakers are racked in and closed and the Rod Control System is capable of rod withdrawal. Point Beach 3.3.1-17 Unit 1 - Amendment No. 239 Unit 2 - Amendment No. 243

RPS Instrumentation 3.3.1 Table 3.3.1-1 (page 6 of 8) Reactor Protection System Instrumentation Note 1: Overtemperature AT Where: ATo = indicated AT at RTP, of T = average temperature, of T' :S [*]OF P = pressurizer pressure, psig P' = [*J psig ['II] K1 K2

        -=<            ['II]

K3 = rl '1:1 = ['II] sec '1:2 = rJsec '1:3 = ['II] sec '1:4 = r]sec f(LlI) = ['II] {I'll] - (ql - qb)} when (ql- qb)~ [*]% RTP 0% ofRTP when [*]% RTP < (ql - qb).::! [*]% RTP ['II] {(ql - qb) _ ['II]} 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.

Point Beach 3.3.1-18 Unit 1 - Amendment No. 239 Unit 2 - Amendment No. 243

RPS Instrumentation 3.3.1 Table 3.3.1-1 (page 7 of 8) Reactor Protection System Instrumentation Note 2: Overpower /).T Where: ~To = indicated ~T at RTP, of T = average temperature, OF l' ::;; [*]OF ~ ::;; [*] Ks = [*] for increasing T

      =     [*] for decreasing T Ka     =     [*] for T ~ l'
      =     [*] for T < l'

'ts = [*] sec 't3 = [*] sec 't4 = [*] sec

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

Point Beach 3.3.1-19 Unit 1 - Amendment No. 239 Unit 2 - Amendment No. 243

RPS Instrumentation 3.3.1 Table 3.3.1-1 (page 8 of 8) Reactor Protection System Instrumentation Note 3: If the as-found channel setpoint is outside its predefined as-found tolerance, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. Note 4: The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Nominal Trip Setpoint (NTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable. Setpoints more conservative than the NTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the Surveillance procedures (field setting) to confirm channel performance. The methodologies used to determine the as-found and the as-left tolerances are specified in FSAR Section 7.2. Point Beach 3.3.1-20 Unit 1 - Amendment No. 239 Unit 2 - Amendment No. 243

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 Functions A.1 Enter the Condition Immediately with one or more referenced in required channels or Table 3.3.2-1 for the trains inoperable. channel(s) or train(s). B. One channel inoperable. B.1 Restore channel to 48 hours2 days 0.286 weeks 0.0658 months OPERABLE status. OR B.2.1 Be in MODE 3. 54 hours2.25 days 0.321 weeks 0.074 months AND B.2.2 Be in MODE 5. 84 hours3.5 days 0.5 weeks 0.115 months (continued) <9 Point Beach 3.3.2-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

ESFAS Instrumentation 3.3.2 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETIONTIME C. One train inoperable. C.1 Restore train to 6 hours0.25 days 0.0357 weeks 0.00822 months OPERABLE status. OR C.2.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months AND C.2.2 Be in MODE 5. 42 hours1.75 days 0.25 weeks 0.0575 months D. One channel inoperable. D.1 Place channel in trip. 1 hour OR D.2.1 Be in MODE 3. 7 hours0.292 days 0.0417 weeks 0.00959 months AND D.2.2 Be in MODE 4. 13 hours0.542 days 0.0774 weeks 0.0178 months E. One or both channel(s) E.1 Restore channel(s) to 1 hour inoperable. OPERABLE status. OR E.2.1 Be in MODE 3. 7 hours0.292 days 0.0417 weeks 0.00959 months AND E.2.2 Be in MODE 5. 37 hours1.542 days 0.22 weeks 0.0507 months (continued) Point Beach 3.3.2-2 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

ESFAS Instrumentation 3.3.2 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETIONTIME F. One channel inoperable. F.1 Restore channel to 1 hour OPERABLE status. OR F.2.1 Be in MODE 3. 7 hours0.292 days 0.0417 weeks 0.00959 months AND F.2.2 Be in MODE 4. 13 hours0.542 days 0.0774 weeks 0.0178 months G. One train inoperable. G.1 Restore train to 6 hours0.25 days 0.0357 weeks 0.00822 months OPERABLE status. OR G.2.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months AND G.2.2 Be in MODE 4. 18 hours0.75 days 0.107 weeks 0.0247 months H. One channel inoperable. H.1 Place channel in trip. 6 hours0.25 days 0.0357 weeks 0.00822 months OR H.2 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months I. One or more channels 1.1 Verify interlock is in 1 hour inoperable. required state for existing unit condition. OR 1.2.1 Be in MODE 3. 7 hours0.292 days 0.0417 weeks 0.00959 months AND 1.2.2 Be in MODE 4. 13 hours0.542 days 0.0774 weeks 0.0178 months Point Beach 3.3.2-3 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

ESFAS Instrumentation 3.3.2 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME

-----------------N 0 TE-----------------     J.1      Restore channel to               48 hours2 days <br />0.286 weeks <br />0.0658 months <br /> Se parate Condition entry is                         OPERABLE status.

allowed for each AFW pump. OR J. One channel inoperable. J.2 Declare associated AFW pump inoperable. SURVEILLANCE REQUIREMENTS

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. In accordance with the Surveillance Frequency Control Program SR 3.3.2.2 ---------------------------NOTE-------------------------- The continuity check may be excluded. In accordance with the Surveillance Perform ACTUATION LOGIC TEST. Frequency Control Program SR 3.3.2.3 Perform COT. In accordance with the Surveillance Frequency Control Program SR 3.3.2.4 Perform MASTER RELAY TEST. In accordance with the Surveillance Frequency Control Program (continued) Point Beach 3.3.2-4 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY In accordance with SR 3.3.2.5 Perform SLAVE RELAY TEST. the Surveillance Frequency Control Program SR 3.3.2.6 Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.2.7 Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.2.8 ---------------------------NOTE-------------------------- This Surveillance shall include verification that the time constants are adjusted to the prescribed values. In accordance with Perform CHANNEL CALIBRATION. the Surveillance Frequency Control Program Point Beach 3.3.2-5 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

ESFAS Instrumentation 3,3.2 Table 3.3.2-1 (page 1 of 4) Engineered Safety Feature Actuation System Instrumentation APPLICABLE REQUIRED SURVEllLANCE ALLOWABLE NOMINAL TRIP FUNCTION MODES CHANNELS CONDITIONS REOOIREMENTS VALUE SETPOINT

1. Safely Injection

a. Manual 1.2,3,4 2 B SR 3.3.2.7 NA NA Initiation

b. Automatic 1.2,3,4 2 trains C SR 3.3.2.2 NA NA Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.5 Relays

c. Containment 1.2.3 3 D SR 3.3.2.1 ::; 5.1 psig 4.8 psig Pressure-High SR 3.3.2.3(r)

SR 3.3.2.e(r)

d. Pressurizer 1,2,3(a) 3 D SR 3.3.2.1 ?: 1730 psig 1735 psig Pressure-Low SR 3.3.2.3(1)

SR 3.3.2.e(r)

e. Steam Line 1,2,3(b) 3 per D SR 3.3.2.1 ?: 535(0) pslg 545 psig Pressure-Low steam line SR 3.3.2.3(r)

SR 3.3.2.8(r)

2. Containment Spray

a. Manual 1.2.3,4 2 E SR 3.3.2.7 NA NA Initiation

b. Automatic 1.2.3.4 2 trains C SR 3.3.2.2 NA NA Acluation Logic SR 3.3.2.4 and Actuation SR 3.3.2.5 Relays

c. Containment 1.2.3 2 sets D SR 3.3.2.1 ::; 28 psig 25 psig Pressure-High of 3 SR 3.3.2.3 m High SR 3.3.2.8(1)

(continued) (a) Pressurizer Pressure> 2000 pslg. (b) Pressurizer Pressure> 2000 pslg. except during Reactor Coolant System hydrostatic testing. (c) Time constants used in the lead/lag controller are t1 ?: 18 seconds and t2 ::; 2 seconds. (f) Table 3.3.2-1 Notes 1 and 2 are applicable. Point Beach 3.3.2-6 Unit 1 - Amendment No. 239 Unit 2 - Amendment No. 243

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 2 of 4) Engineered Safety Feature Actuation System Instrumentation APPLICABLE REQUIRED SURVElUANCE ALLOWABLE NOMINAL TRIP FUNCTION MODES CHANNElS CONDITIONS REQUIREMENTS VALUE SETPOINT

3. Containment Isolation

a. Manual 1,2,3,4 2 B SR 3.3.2.7 NA NA Initiation

b. Automatic 1,2,3,4 2 trains C SR 3.3.2.4 NA NA Actuation Logic SR 3.3.2.5 and Actuation Relays

c. Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements, except Manual SI initiation.

4. Steam Line Isolation

a. Manual 1,2(d),3(0) 11100p F SR 3.3.2.7 NA NA Initiation

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

c. Containment 1,2(d),3(d) 3 D SR 3.3.2.1 s 18 psig 15 psig Pressure-High SR 3.3.2.3(1)

High SR 3.3.2.8(1)

d. High Steam 1,2(d),3 1d) 2 per D SR 3.3.2.1 :5:AP L\p corresponding Flow steam line SR 3.3.2.3(1) corresponding to 0.52 x 106 1b1hr SR 3.3.2.8(1) to 0.8 X 106 at 1005 psig Ib/hr at 1005 pslg Coincident with Refer to Function 1 (Safety Injection) for all initiation functions and reqUirements.

Safety Injection and Coincident with 1,2 Id),3(dl 3 D SR 3.3.2.1 ~ 542°F 543°F Tavg-LOW SR 3.3.2.3(1) SR 3.3.2.8(1)

e. High High 1.2(d),3(d) 2 per D SR 3.3.2.1 ~AP L\p corresponding Steam Flow steam line SR 3.3.2.3(1) corresponding to 4.85 x 106 Ib/hr SR 3.3.2.8(1) to 4.9 X 106 at 586 pslg Iblhr at 586 pslg Coincident with Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

Safety Injection (continued) (d) Except when all MSIVs are closed and de-activated. (f) Table 3.3.2-1 Notes 1 and 2 are applicable. Point Beach 3.3.2-7 Unit 1 - Amendment No. 239 Unit 2 - Amendment No. 243

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 3 of 4) Engineered Safety Feature Actuation System Instrumentation APPLICABLE REQUIRED SURVEILLANCE ALLOWABLE NOMINAL TRIP FUNCTION MODES 0i.6J'JNELS CONDITIONS REQUIREMENTS VALUE SETPOINT

5. Feedwater Isolation

a. Automatlc 2 trains G SR 3.3.2.2 NA NA 1,2(e),3(e)

Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.5 Relays

b. SG Water 1,2(e),3(e) 3 per SG D SR 3,3.2.1 ~90% 78%

Level-High SR 3.3.2.3(1) SR 3.3.2.8(f)

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

6. Auxiliary Feedwater

a. Automatic 1,2,3 2 trains G SR 3.3.2.2 NA NA Actuation Logic and Actuation Relays

b. SG Water 1,2,3 3 per SG D SR 3.3.2.1 ~ 29.5% 31%

Level- SR 3.3.2.3(f) Low Low SR 3.3.2.8(1,

c. Safety Injection Refer to Function 1 (Safety Injection) for aI/Initiation functions and requirements.

d. Undervoltage 1,2 2 per bus H SR 3.3.2.6 ;:: 3120 V 3255 V Bus A01 and SR 3.3.2.8(1)

A02

e. AFW Pump 1,2,3 1 per J SR 3.3.2.1 ~ 5.8 psig 6.1 psig Suction pump SR 3.3.2.3(1)

Transfer on SR 3.3.2.8(1) Suction Pressure - Low

7. SI Block-Pressurizer 1,2,3 3 SR 3.3.2.1 ::; 2005 psig 2000 psig Pressure SR 3.3.2.3 SR 3.3.2.8 (e) Except when all MFIVs, MFRVs and associated bypass valves are closed and de-activated.

(f) Table 3.3.2-1 Notes 1 and 2 are applicable. Point Beach 3.3.2-8 Unit 1 - Amendment No. 239 Unit 2 - Amendment No. 243

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 4 of 4) Engineered Safety Feature Actuation System Instrumentation Note 1: If the as-found channel setpoint is outside its predefined as-found tolerance, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. Note 2: The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Nominal Trip Setpoint (NTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable. Setpoints more conservative than the NTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint Implemented in the Surveillance procedures (field setting) to confirm channel performance. The methodologies used to determine the as-found and the as-left tolerances are specified in FSAR Section 7.2. Point Beach 3.3.2-9 Unit 1 - Amendment No. 238 Unit 2 - Amendment No. 242

PAM Instrumentation 3.3.3 3.3 INSTRUMENTATION 3.3.3 Post Accident Monitoring (PAM) Instrumentatlon 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.

.-  .--  -...-   -- --- -.- -- -...- ---  --. --.   --.     ....- -  .--- --. --  -. ---..-     --  --- --. -  --

I CONDITION REQUIRED ACTION COMPLETIONTIME A. One or more Functions A.1 Restore required 30 days with one required channel to OPERABLE channel inoperable. status. B. Required Action and B.1 Initiate action in Immediately associated Completion accordance with Time of Condition A not Specification 5.6.6. met. C. One or more Functions C.1 Restore one channel 7 days with two required to OPERABLE status. channels Inoperable. (continued) Point Beach 3.3.3-1 Unit I - Amendment No. 21 5 Unit 2 - Amendment No. 220 "Revised by correction letter dated January 31, 2005"

PAM Instrumentation 3.3.3 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLEflONTIME D. Required Action and D.1 Enter the Condition Immediately associated Completion referenced in Time of Condition C Table 3.3.3-1 for the not met. channel. E. As required by E.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months I Required Action D.1 and referenced in AND Table 3.3.3-1. E.2 Be in MODE 4. 12 hours0.5 days 0.0714 weeks 0.0164 months F. As required by Required F.1 Initiate action in Immediately I Action D.1 and accordance with referenced in Specification 5.6.6. Table 3.3.3-1. Point Beach 3.3.3-2 Unit 1 - Amendment No. 214 Unit 2 - Amendment No. 219

PAM Instrumentation 3.3.3 SURVEILLANCE REQUIREMENTS

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

SR 3.3.3.1 applies to each PAM instrumentation Function in Table 3.3.3-1. SR 3.3.3.2 applies to each PAM instrumentation Function in Table 3.3.3-1, except Function 12. SR 3.3.3.3 applies to Function 12 only. SURVEILLANCE FREQUENCY SR 3.3.3.1 Perform CHANNEL CHECK for each required In accordance instrumentation channel that is normally with the energized. Surveillance Frequency Control Program SR 3.3.3.2 --------------------------N()TE--------------------------- CHAN NEL CALIBRATl()N of Containment Area Radiation (High Range) detectors shall consist of verification of a response to a source. In accordance with the Perform CHANNEL CALIBRATl()N. Surveillance Frequency Control Program SR 3.3.3.3 Perform TAD()T. In accordance with the Surveillance Frequency Control Program Point Beach 3.3.3-3 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

PAM Instrumentation 3.3.3 Table 3.3.3-1 (page 1 of 1) Post Accident Monitoring Instrumentation CONDmON REFERENCED FROM FUNCTION REQUIRED CHANNELS REQUIRED ACTION DA

1. Reactor Coolant System (RCS) Subcooling Monitor 2 E

2. RCS Hot Leg Temperature (Wide Range) 2 per loop E

3. RCS Cold Leg Temperature (Wide Range) 2 per loop E

4. RCS Pressure (Wide Range) 2 E

5. RCS Pressure (Narrow Range) 2 E

6. Reactor Vessel Water Level (Wide Range) 2 E

7. Reactor Vessel Water Level (Narrow Range) 2 E

8. Containment Sump B Water Level 2 E

9. Containment Pressure (Wide Range) 2 E

10. Containment Pressure (Intermediate Range) 2 E

11. Containment Pressure (Low Range) 2 E

12. Containment Isolation Valve Position 2 per penetration flow path E (a)(b)

13. Containment Area Radiation (High Range) 2 F

14. Pressurizer Level 2 E

15. Steam Generator Water Level (Wide Range) 2 per steam generator E

16. Steam Generator Water Level (Narrow Range) 2 per steam generator E

17. Steam Generator Pressure 2 per steam generator E

18. Condensate Storage Tank Level 2 per tank E

19. Core Exit Temperature - Quadrant I 2 E

20. Core Exit Temperature - Quadrant 2 2 E

21. Core Exit Temperature - Quadrant 3 2 E

22. Core ExitTemperature- Quadrant 4 2 E

23. Auxiliary Feedwater Flow 2 E

24. Refueling Water Storage Tank Level 2 E (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. I Point Beach 3.3.3-4 Unit 1 - Amendment No. 214 Unit 2 - Amendment No. 219

LOP DG Start Instrumentation 3.3.4 3.3 INSTRUMENTATION 3.3.4 Loss of Power (LOP) Diesel Generator (DG) Start Instrumentation I LCO 3.3.4 The following LOP DG Start Instrumentation shall be OPERABLE:

a. Three channels per bus of the 4.16 kV loss of voltage Function,

b. Three channels per bus of the 4.16 kV degraded voltage Function, and

c. Three channels per bus of the 480 V loss of voltage Function.

APPLICABILITY: MODES 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 TIME A. One or more Functions A.1 Place channel in trip. 1 hour with one channel per bus inoperable. B. Two or more 4.16 kV B.1 Restore all but one 1 hour loss of voltage or channel to OPERABLE 4.16 kV degraded status. voltage channels per bus inoperable. (continued) Point Beach 3.3.4-1 Unit 1 - Amendment No. 225 Unit 2 - Amendment No. 231

LOP DG Start Instrumentation 3.3.4 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Enter applicable Immediately associated Completion Condition(s) and Time of Condition A for Required Action(s) for 4.16 kV Functions or the associated standby Condition B not met. emergency power source made inoperable by LOP DG start instrumentation. D. Two or more 480 V loss of D.1 Restore all but one 1 hour voltage channels per bus channel to OPERABLE inoperable. status. E. Required Action and E.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time of Condition A for 480 AND V loss of voltage Function or Condition D not met. E.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.4.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.4.2 Perform TADOT. In accordance with the Surveillance Frequency Control Program (continued) Point Beach 3.3.4-2 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

LOP DG Start Instrumentation 3.3.4 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.3.4.3 Perform CHANNEL CALIBRATION with Allowable In accordance with the Value as follows: Surveillance Frequency Control Program

a. 4.16 kV loss of voltage Allowable Value

                       ~ 3156 V with a time delay of~ 1.8 seconds and~ 2.3 seconds (Bus Loss of Voltage Relay) and .:::_ 1.95 seconds and ~

3.55 seconds (EOG Breaker Close Delay Relay).

b. 4.16 kV degraded voltage Allowable Value

                       ~ 3937 V with a time delay of
                       < 5.68 seconds (Bus Degraded Voltage Relay) and < 39.14 seconds (Bus Time Delay Relay).

c. 480 V loss of voltage Allowable Value 256 V

                       +/- 3% with a time delay of.:::_ 1.15 seconds and ~ 1.6 seconds.

Point Beach 3.3.4-3 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

CREFS Actuation Instrumentation 3.3.5 3.3 INSTRUMENTATION 3.3.5 Control Room Emergency Filtration System (CREFS) Actuation Instrumentation LCO 3.3.5 The CREFS actuation instrumentation for each Function in Table 3.3.5-1 shall be OPERABLE. APPLICABILITY: According to Table 3.3.5-1. ACTIONS

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

Separate Condition entry is allowed for each Function. CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions A.1 Place CREFS in the 7 days inoperable. emergency mode of operation. B. Required Action and -----------------N 0 TE----------------- associated Completion Required Action B.1 is not Time not met. applicable for inoperability of the Containment Isolation actuation function.

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

B.1 Suspend movement of Immediately irradiated fuel assemblies. AND B.2 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months AND B.3 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months Point Beach 3.3.5-1 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

CREFS Actuation Instrumentation 3.3.5 SURVEILLANCE REQUIREMENTS

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

Refer to Table 3.3.5-1 to determine which SRs apply for each CREFS Actuation Function. SURVEILLANCE FREQUENCY SR 3.3.5.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.5.2 Perform C()T. In accordance with the Surveillance Frequency Control Proqram SR 3.3.5.3 Perform CHANNEL CALIBRATl()N. In accordance with the Surveillance Frequency Control Program Point Beach 3.3.5-2 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

CREFS Actuation Instrumentation 3.3.5 Table 3.3.5-1 (page 1 of 1) CREFS Actuation Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE TRIP FUNCTION CONDITIONS CHANNELS REQUIREMENTS SETPOINT Control Room Radiation

a. Control Room Area Monitor 1, 2, 3, 4, 1 SR 3.3.5.1 NA (a) SR 3.3.5.2 SR 3.3.5.3

b. Control Room Air Intake 1, 2, 3, 4, 1 SR 3.3.5.1 NA (a) SR 3.3.5.2 SR 3.3.5.3

2. Containment Isolation Refer to LCO 3.3.2, "ESFAS Instrumentation," Function 3, for all initiation functions and requirements.

(a) During movement of irradiated fuel assemblies. Point Beach 3.3.5-3 Unit 1 - Amendment No. 224 Unit 2 - Amendment No. 230

Boron Dilution Alarm 3.3.6 3.3 INSTRUMENTATION 3.3.6 Boron Dilution Alarm LCO 3.3.6 Boron Dilution Alarm shall be OPERABLE. APPLICABILITY: MODE 5. ACTIONS CONDITION REQUIRED ACTIONS COMPLETION TIME A. Boron Dilution Alarm A.1 Close unborated water 1 hour inoperable. source isolation valve(s). SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.6.1 Perform TADOT. In accordance with the Surveillance Frequency Control Program Point Beach 3.3.6-1 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

RCS Pressure, Temperature, and Flow DNB Limits 3.4.1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 RCS Pressure, 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 limits specified in the COLR;

b. RCS average temperature is within the limits specified in the COLR; and

c. RCS total flow rate;;:; 178,000 gpm and greater than or equal to the limit specified in the COLR.

APPLICABILITY: MODE 1.

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

Pressurizer pressure limit does not apply during:

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

b. THERMAL POWER step> 10% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more RCS DNB A.1 Restore RCS DNB 2 hours0.0833 days 0.0119 weeks 0.00274 months parameters not within parameter(s) to within limits. limit. B. Required Action and B.1 Be in MODE 2. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. Point Beach 3.4.1-1 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

RCS Pressure, Temperature, and Flow DNB Limits 3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 Verify pressurizer pressure is greater than or In accordance equal to the limits specified in the COLR. with the Surveillance Frequency Control Program SR 3.4.1.2 Verify RCS average temperature is within the In accordance limits specified in the COLR. with the Surveillance Frequency Control Program SR 3.4.1.3 -------------------N 0 TE-------------------- In accordance N ot required to be performed until 24 hours1 days 0.143 weeks 0.0329 months after with the 2 90% RTP. Surveillance Frequency Control Program Verify by precision heat balance that RCS total flow rate is 2 178,000 gpm and greater than or equal to the limit specified in the COLR. Point Beach 3.4.1-2 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

RCS Minimum Temperature for Criticality 3.4.2 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.2 RCS Minimum Temperature for Criticality LCO 3.4.2 Each RCS loop average temperature (Tavg) shall be 2 540°F. APPLICABILITY: MODE 1, MODE 2 with kett 2 1.0. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. T avg in one or more A.1 Be in MODE 2 with 30 minutes RCS loops not within keff < 1.0. limit. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.2.1 Verify RCS T avg in each loop 2 540°F. In accordance with the Surveillance Frequency Control Program Point Beach 3.4.2-1 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

RCS P/T Limits 3.4.3 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.3 RCS Pressure and Temperature (P/T) Limits LCO 3.4.3 RCS pressure, RCS temperature, and RCS heatup and cooldown rates shall be maintained within the limits specified in the PTLR. APPLICABILITY: At all times. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ----------- NOTE----------- A.1 Restore parameter(s) to 30 minutes Required Action A.2 within limits. shall be completed whenever this Condition AND is entered. A.2 Determine RCS is 72 hours3 days 0.429 weeks 0.0986 months acceptable for Requirements of LCO continued operation. not met in MODE 1, 2, 3, or 4. B. Required Action and B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time of Condition A not AND met. B.2 Be in MODE 5 with RCS 36 hours1.5 days 0.214 weeks 0.0493 months pressure

                                           < 500 psig.

(continued) Point Beach 3.4.3-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

RCS PIT Limits 3.4.3 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. -----------NOTE----------- C.1 Initiate action to restore Immediately Required Action C.2 parameter(s) to within shall be completed limits. whenever this Condition is entered. AND C.2 Determine RCS is Prior to entering Requirements of LCO acceptable for MODE 4 not met any time in other continued operation. than MODE 1, 2, 3, or 4. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.3.1 --------------------------N 0 TE--------------------------- 0 n Iy required to be performed during RCS heatup and cooldown operations and RCS inservice leak and hydrostatic testing with keff < 1.0. Verify RCS pressure, RCS temperature, and In accordance RCS heatup and cooldown rates are within the with the limits specified in the PTLR. Surveillance Frequency Control Program Point Beach 3.4.3-2 Unit 1 - Amendment No. 253 Unit 2 Amendment No. 257

RCS Loops - MODES 1 and 2 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.4 RCS Loops-MODES 1 and 2 LCO 3.4.4 Two RCS loops shall be OPERABLE and in operation. APPLICABILITY: MODES 1 and 2. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of LCO A.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months not met. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.4.1 Verify each RCS loop is in operation. In accordance with the Surveillance Frequency Control Program Point Beach 3.4.4-1 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

RCS Loops-MODE 3 3.4.5 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.5 RCS Loops-MODE 3 LCO 3.4.5 Two RCS loops shall be OPERABLE, and one RCS loop shall be in operation.

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

All reactor coolant pumps may be not in operation for < 1 hour per 8 hour period provided:

a. No operations are permitted that would cause reduction of the RCS boron concentration;

b. Core outlet temperature is maintained at least 10OF below saturation temperature; and

c. The Rod Control System is not capable of rod withdrawal.

APPLICABILITY: MODE 3. ACTIONS CONDITION REQUIRED ACTION COMPLETIONTIME A. One required RCS loop A.1 Restore required RCS 72 hours3 days 0.429 weeks 0.0986 months inoperable. loop to OPERABLE status. B. Required Action and B.1 Be in MODE 4. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time of Condition A not met. (continued) Point Beach 3.4.5-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

RCS Loops-MODE 3 3.4.5 CONDITION REQUIRED ACTION COMPLETION TIME C. Two RCS loops C.1 Place the Rod Control Immediately inoperable. System in a condition incapable of rod withdrawal. No RCS loop in operation. C.2 Suspend all operations Immediately involving a reduction of RCS boron concentration. C.3 Initiate action to restore Immediately one RCS loop to OPERABLE status and operation. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.5.1 Verify one RCS loop is in operation. In accordance with the Surveillance Frequency ontrol Program SR 3.4.5.2 Verify steam generator secondary side water In accordance levels are ~ 35% narrow range for required RCS with the loops. Surveillance Frequency Control Program SR 3.4.5.3 Verify correct breaker alignment and indicated In accordance power are available to the required pump that is with the not in operation. Surveillance Frequency Control Program Point Beach 3.4.5-2 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

            - - .

RCS Loops-MODE 4 3.4.6 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.6 RCS Loops -MODE 4 LCO 3.4.6 Two loops consisting of any combination of RCS loops and residual heat removal (RHR) loops shall be OPERABLE, and one loop shall be in operation.

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

1. All reactor coolant pumps (RCPs) and RHR pumps may be not in operation for < 1 hour per 8 hour 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 10OF below saturation temperature.

2. No RCP shall be started with any RCS cold leg temperature S Low Temperature Overpressure Protection (LTOP) enabling temperature specified in the PTLR unless the secondary side water temperature of each steam generator (SG) is < 500 F above each of the RCS cold leg temperatures.

APPLICABILITY: MODE 4. ACTIONS CONDITION REQUIRED ACTION COMPLETIONTIME A. One required RCS loop A.1 Initiate action to restore Immediately inoperable. a second loop to OPERABLE status. AND Two RHR loops inoperable. (continued) Point Beach 3.4.6-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

RCS Loops - MODE 4 3.4.6 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME B. One required RHR loop B.1 Be in MODE 5. 24 hours1 days 0.143 weeks 0.0329 months inoperable. AND Two required RCS loops inoperable. C. Required RCS or RHR C.1 Suspend all operations Immediately loops inoperable. involving a reduction of RCS boron OR concentration. No RCS or RHR loop in AND operation. C.2 Initiate action to restore Immediately one loop to OPERABLE status and operation. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 Verify one RHR or RCS loop is in operation. In accordance with the Surveillance Frequency Control Proqram SR 3.4.6.2 Verify SG secondary side water levels are In accordance

                 ~ 35% narrow range for required RCS loops.              with the Surveillance Frequency Control Program SR 3.4.6.3       Verify correct breaker alignment and indicated          In accordance power are available to the required pump that is        with the not in operation.                                       Surveillance Frequency Control Proqram (continued)

Point Beach 3.4.6-2 Unit 1 - Amendment No.253 Unit 2 - Amendment No.257

RCS Loops-MODE 4 3.4.6 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.4.6.4 -------------------------N 0 TE------------------------- In accordance Not required to be performed until 12 hours0.5 days 0.0714 weeks 0.0164 months with the after entering MODE 4. Surveillance Frequency Control Program Verify required RHR loop locations susceptible to gas accumulation are sufficiently filled with water. Point Beach 3.4.6-3 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

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 one steam generator (SG) shall be ;::: 35% narrow range.

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

1. The RHR pump of the loop in operation may be not in operation for::; 1 hour per 8 hour 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 10°F below saturation temperature.

2. One required RHR loop may be inoperable for up to 2 hours0.0833 days 0.0119 weeks 0.00274 months for surveillance testing provided that the other RHR loop is OPERABLE and in operation.

3. No reactor coolant pump shall be started with one or more RCS cold leg temperatures::; Low Temperature Overpressure Protection (L TOP) arming temperature specified in the PTLR unless the secondary side water temperature of each SG is

50°F above each of the RCS cold leg temperatures.

4. All RHR loops may be removed from operation during planned heatup to MODE 4 or during the performance of required leakage or flow testing when at least one RCS loop is in operation.

APPLICABILITY: MODE 5 with RCS loops filled. Point Beach 3.4.7-1 Unit 1 - Amendment No. 246 Unit 2 - Amendment No. 250

RCS Loops-MODE 5, Loops Filled 3.4.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR loop A.1 Initiate action to restore Immediately inoperable. a second RHR loop to OPERABLE status. AND OR Required SG secondary side water level not A.2 Initiate action to restore Immediately within limits. required SG secondary side water level to within limit. B. Required RHR loops B.1 Suspend all operations Immediately inoperable. involving a reduction of RCS boron OR concentration. No RHR loop in AND operation. B.2 Initiate action to restore Immediately one RHR loop to OPERABLE status and operation. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 Verify one RHR loop is in operation. In accordance with the Surveillance Frequency Control Program SR 3.4.7.2 Verify SG secondary side water level is ~ 35% In accordance narrow range in the required SG. with the Surveillance Frequency Control Program (continued) Point Beach 3.4.7-2 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

RCS Loops-MODE 5, Loops Filled 3.4.7 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.4.7.3 Verify correct breaker alignment and indicated In accordance power are available to the required RHR pump with the that is not in operation. Surveillance Frequency Control Program SR 3.4.7.4 Verify required RHR loop locations susceptible In accordance to gas accumulation are sufficiently filled with with the water. Surveillance Frequency Control Program Point Beach 3.4.7-3 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

RCS Loops-MODE 5, Loops Not Filled 3.4.8 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.8 RCS Loops-MODE 5, Loops Not Filled LCO 3.4.8 Two residual heat removal (RHR) loops shall be OPERABLE and one RHR loop shall be in operation.

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

1. All RHR pumps may be not in operation for< 15 minutes when switching from one loop to another provided:

a. The core outlet temperature is maintained > 101F 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

2 hours0.0833 days 0.0119 weeks 0.00274 months for surveillance testing provided that the other RHR loop is OPERABLE and in operation.

APPLICABILITY: MODE 5 with RCS loops not filled. ACTIONS CONDITION REQUIRED ACTION COMPLETIONTIME A. One RHR loop A.1 Initiate action to restore Immediately inoperable. RHR loop to OPERABLE status. (continued) Point Beach 3.4.8-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

RCS Loops-MODE 5, Loops Not Filled 3.4.8 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME B. Required RHR loops B.1 Suspend all operations Immediately inoperable. involving reduction in RCS boron concentration. No RHR loop in AND operation. B.2 Initiate action to restore Immediately one RHR loop to OPERABLE status and operation. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one RHR loop is in operation. In accordance with the Surveillance Frequency Control Program SR 3.4.8.2 Verify correct breaker alignment and indicated In accordance power are available to the required RHR pump with the that is not in operation. Surveillance Frequency Control Program SR 3.4.8.3 Verify RHR loop locations susceptible to gas In accordance accumulation are sufficiently filled with water. with the Surveillance Frequency Control Program Point Beach 3.4.8-2 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

Pressurizer 3.4.9 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.9 Pressurizer LCO 3.4.9 The pressurizer shall be OPERABLE with:

a. Pressurizer water level ~ 52% in MODE 1 or ~ 88% in MODES 2 and 3; and

b. At least 100 kW of pressurizer heaters capable of being powered from an emergency power supply are OPERABLE.

APPLICABILITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Pressurizer water level A.1 Restore pressurizer 1 hour not within limit in water level to within MODE 1. limit. B. Required pressurizer B.1 Restore required 1 hour heaters inoperable. pressurizer heaters to OPERABLE status. C. Required Action and C.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND OR C.2 Be in MODE 4. 12 hours0.5 days 0.0714 weeks 0.0164 months Pressurizer water level not within limit in MODES 2 and 3. Point Beach 3.4.9-1 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

Pressurizer 3.4.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify pressurizer water level is ~ 52% in In accordance MODE 1 OR~ 88% in MODES 2 and 3. with the Surveillance Frequency Control Program SR 3.4.9.2 Verify capacity of required pressurizer heaters is In accordance

            ~ 100 kW.                                            with the Surveillance Frequency Control Program Point Beach                         3.4.9-2             Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

Pressurizer Safety Valves 3.4.10 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.10 Pressurizer Safety Valves LCO 3.4.10 Two pressurizer safety valves shall be OPERABLE with lift settings

                   ~ 2410 psig and ~ 2547 psig.

APPLICABILITY: MODES 1, 2, and 3, MODE 4 with all RCS cold leg temperatures> the LTOP enabling temperature specified in the PTLR.

                   --------------------------------------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 36 hours1.5 days 0.214 weeks 0.0493 months following entry into MODE 3 provided a preliminary cold setting was made prior to heatup. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One pressurizer safety A.1 Restore valve to 15 minutes valve inoperable. OPERABLE status. B. Required Action and 8.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND OR B.2 Be in MODE 4 with any 12 hours0.5 days 0.0714 weeks 0.0164 months RCS cold leg Two pressurizer safety temperature ~ the LTOP valves inoperable. enabling temperature specified in the PTLR. Point Beach 3.4.10-1 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

Pressurizer Safety Valves 3.4.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.10.1 Verify each pressurizer safety valve is In accordance OPERABLE in accordance with the INSERVICE with the TESTING PROGRAM. Following testing, lift INSERVICE settings shall be within .:t. 1%. TESTING PROGRAM Point Beach 3.4.10-2 Unit 1 - Amendment No. 259 Unit 2 - Amendment No. 263

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, MODE 3 with RCS average temperature (Tavg) 2 5000 F. ACTIONS

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

Separate Condition entry is allowed for each PORV and each block valve. I CONDITION REQUIRED ACTION COMPLET1ONWME A. One or more PORVs A.1 Close and maintain 1 hour inoperable and capable power to associated of being manually block valve. cycled. B. One PORV Inoperable B.1 Close associated block 1 hour and not capable of valve. being manually cycled. AND B.2 Remove power from 1 hour associated block valve. AND B.3 Restore PORV to 72 hours3 days 0.429 weeks 0.0986 months OPERABLE status. (continued) Point Beach 3.4.11-1 Unit I - Amendment No. 21 5 Unit 2 - Amendment No.2 2 0

Pressurizer PORVs 3.4.11 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. One block valve ----------------- NOTE----------------- inoperable. Required Actions C.1 and C.2 do not apply when block valve is inoperable solely as a result of complying with Required Actions B.2 or E.2 C.1 Place associated PORV 1 hour in manual control. AND C.2 Restore block valve to 72 hours3 days 0.429 weeks 0.0986 months OPERABLE status. D. Required Action and D.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time of Condition A, B, AND or C not met. D.2 Reduce Tayg to < 500 0F. 12 hours0.5 days 0.0714 weeks 0.0164 months E. Two PORVs inoperable E.1 Close associated block 1 hour and not capable of being valves. manually cycled. AND E.2 Remove power from 1 hour associated block valves. AND E.3 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months AND E.4 Reduce Tayg to < 5001F. 12 hours0.5 days 0.0714 weeks 0.0164 months (continued) Point Beach 3.4.11-2 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Pressurizer PORVs 3.4.11 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME F. Two block valves -----------------NOTE----------------- inoperable. Required Action F.1 does not apply when block valve is inoperable solely as a result of complying with Required Actions B.2 or E.2

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

F.1 Restore one block valve 2 hours0.0833 days 0.0119 weeks 0.00274 months to OPERABLE status. G. Required Action and G.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time of Condition F not AND met. G.2 Reduce Tavg to< 500°F. 12 hours0.5 days 0.0714 weeks 0.0164 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. In accordance with the Perform a complete cycle of each block valve. Surveillance Frequency Control Program SR 3.4.11.2 Perform a complete cycle of each PORV. In accordance with the Surveillance Frequency Control Program Point Beach 3.4.11-3 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

LTOP 3.4.12 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12 Low Temperature Overpressure Protection (LTOP) System LCO 3.4.12 An LTOP System shall be OPERABLE with:

a. A maximum of one Safety Injection (SI) pump capable of injecting into the RCS;

b. Each accumulator Isolated, whose pressure is 2 the maximum RCS pressure for the existing RCS cold leg temperature allowed by the PIT limit curves provided Inthe PTLR, and

c. One of the following pressure relief capabilities:

1. Two power operated relief valves (PORVs) with lift settings within the limits specified in the PTLR, or

2. The RCS depressurized and an RCS vent path with venting capability equivalent to or greater than a PORV.

- APPLICABILITY MODE 4 when any RCS cold leg temperature is S LTOP enabling temperature specified Inthe PTLR, MODE 5, MODE 6 when the reactor vessel head is on. ACTIONS NOTES

1. While this LCO Is not met, entry into MODE 6, with the reactor vessel head on, from MODE 6, with the reactor vessel head removed, is not permitted.

2. LCO 3.OA.b Is not applicable when entering MODE 4.

CONDITION REQUIRED ACTION COMPLETIONTIME A. Two SI pumps capable of A.1 Initiate action to verify a Immediately injecting into the RCS. maximum of one SI pump is capable of injecting into the RCS. (continued) Point Beach 3.4.12-1 Unit I - Amendment No. Ag Unit 2 - Amendment No.

LTOP 3.4.12 ACTIONS (continued) B. An accumulator not B.1 Isolate affected 1 hour isolated when the accumulator. accumulator pressure is greater than or equal to the maximum RCS pressure for existing cold leg temperature allowed in the PTLR. C. Required Action and C.1 Increase RCS cold leg 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion temperature to > LTOP Time of Condition B enabling temperature not met. specified in the PTLR. OR C.2 Depressurize affected 12 hours0.5 days 0.0714 weeks 0.0164 months accumulator to less than the maximum RCS pressure for existing cold leg temperature allowed in the PTLR. D. One required PORV D.1 Restore required PORV to 7 days inoperable in MODE 4. OPERABLE status. E. One required PORV E.1 Restore required PORV to 24 hours1 days 0.143 weeks 0.0329 months inoperable in MODE 5 OPERABLE status. or6. (continued) Point Beach 3.4.12-2 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

LTOP 3.4.12 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME F. Two required PORVs F.1 Depressurize RCS and 8 hours0.333 days 0.0476 weeks 0.011 months inoperable. establish RCS vent path with venting capability OR equivalent to or greater than a PORV. Required Action and associated Completion Time of Condition A, C, D or E not met. OR LTOP System inoperable for any reason other than Condition A, B, C, D or E. Point Beach 3.4.12-3 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

LTOP 3.4.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Verify a maximum of one SI pump is capable of In accordance with injecting into the RCS. the Surveillance Frequency Control Proqram SR 3.4.12.2 -------------------------------N 0 TE----------------------------- 0 n ly required when accumulator pressure is ;::: the maximum RCS pressure for existing cold leg temperature allowed by the PfT limit curves provided in the PTLR. In accordance with Verify each accumulator is isolated. the Surveillance Frequency Control Program SR 3.4.12.3 -----------------------------N 0 TE------------------------------ 0 nly required to be performed when complying with LCO 3.4.12.c.2. Verify required RCS vent path with venting capability In accordance with equivalent to or greater than a PORV. the Surveillance Frequency Control Program SR 3.4.12.4 Verify required trains of LTOP armed. In accordance with the Surveillance Frequency Control Program SR 3.4.12.5 Perform a COT on each required PORV, excluding In accordance with actuation. the Surveillance Frequency Control Program (continued) Point Beach 3.4.12-4 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

LTOP 3.4.12 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.4.12.6 Perform CHANNEL CALIBRATION for each required In accordance with PORV actuation channel. the Surveillance Frequency Control Program SR 3.4.12.7 Perform a complete cycle of each required PORV In accordance with solenoid air control valve and check valve on the the Surveillance nitrogen gas bottles. Frequency Control Program SR 3.4.12.8 Perform a complete cycle of each required PORV. In accordance with the Surveillance Frequency Control Program Point Beach 3.4.12-5 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

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. 72 gallons per day (Unit 1) and 150 gallons per day (Unit 2) 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 hours0.167 days 0.0238 weeks 0.00548 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 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time of Condition A not AND met. B.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months OR Pressure boundary LEAKAGE exists. OR Primary to secondary LEAKAGE not within limit. Point Beach 3.4.13-1 Unit 1 - Amendment No. 260 Unit 2 - Amendment No. 229

RCS Operational LEAKAGE 3.4.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.13.1 ---------------------------N 0 TES-------------------------

1. Not required to be performed until 12 hours0.5 days 0.0714 weeks 0.0164 months after establishment of steady state operation.

2. Not applicable to primary to secondary LEAKAGE.

In accordance with the Verify RCS Operational LEAKAGE is within Surveillance limits by performance of RCS water inventory Frequency balance. Control Program SR 3.4.13.2 ------- -------------------- N 0 TE--------------------------- N ot required to be performed until 12 hours0.5 days 0.0714 weeks 0.0164 months after establishment of steady state operation. In accordance Verify primary to secondary LEAKAGE is ~72 with the gallons per day (Unit 1) and ~ 150 gallons per Surveillance day (Unit 2) through any one SG. Frequency Control Program Point Beach 3.4.13-2 Unit 1 - Amendment No. 260 Unit 2 - Amendment No. 257

RCS PIV Leakage 3.4.14 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.14 RCS Pressure Isolation Valve (PIV) Leakage LCO 3.4.14 Leakage from each RCS PIV shall be within limit. APPLICABILITY: MODES 1, 2, and 3, MODE 4, except valves in the residual heat removal (RHR) 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.

2. Enter applicable Conditions and Required Actions for systems made inoperable by an inoperable PIV.

CONDITION REQUIRED ACTION COMPLETIONTIME A. One or more flow paths ----------------- NOTE----------------- with leakage from one or Each valve used to satisfy more RCS PIVs not Required Action A.1 and within limit. Required 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) Point Beach 3.4.14-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

RCS PIV Leakage 3.4.14 CONDITION REQUIRED ACTION COMPLETIONTIME A. (continued) A.1 Isolate the high 4 hours0.167 days 0.0238 weeks 0.00548 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 Isolate the high 72 hours3 days 0.429 weeks 0.0986 months pressure portion of the affected system from the low pressure portion by use of a second closed manual, deactivated automatic, or check valve. B. Required Action and B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time for Condition A AND not met. B.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months Point Beach 3.4.14-2 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.14.1 --------------------------N()TES------------------------

1. Not required to be performed in M()DES 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 within the In accordance limits contained in the RCS PIV Leakage with the Program. INSERVICE TESTING PR()GRAM, and 18 months Prior to entering M()DE 2 whenever the unit has been in M()DE 5 for 7 days or more, if leakage testing has not been performed in the previous 9 months continued) Point Beach 3.4.14-3 Unit 1 - Amendment No. 259 Unit 2 - Amendment No. 263

RCS PIV Leakage 3.4.14 SURVEILLANCE FREQUENCY SR 3.4.14.1 (continued) Within 24 hours1 days 0.143 weeks 0.0329 months following valve actuation due to automatic or manual action or flow through the valve Point Beach 3.4.14-4 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

RCS Leakage Detection Instrumentation 3.4.15 3.4 REACTOR COOLANT SYSTEM (RCS) K) 3.4.15 RCS Leakage Detection Instrumentation LCO 3.4.15 The following RCS leakage detection instrumentation shall be OPERABLE:

a. One containment sump level alarm; and

b. One containment atmosphere radioactivity monitor (gaseous or particulate).

APPLICABILITY: MODES 1, 2, 3, and 4. ACTI ONS . CONDITION REQUIRED ACTION COMPLEI1ONTIME I A. Required containment ---------- NOTE ---------- sump level alarm Not required until inoperable. 12 hours0.5 days 0.0714 weeks 0.0164 months after establishment of steady state operation. A.1 Perform SR 3.4.13.1. Once per 24 hours1 days 0.143 weeks 0.0329 months AND A.2 Restore required 30 days containment sump monitor to OPERABLE status. (continued) Point Beach 3.4.15-1 Unit 1 - Amendment No. 21 5 Unit 2 - Amendment No. 220

RCS Leakage Detection Instrumentation 3.4.15 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION11ME I B. Required containment B.1.1 Analyze grab samples Once per atmosphere radioactivity of the containment 24 hours1 days 0.143 weeks 0.0329 months monitor inoperable. atmosphere. OR

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

Not required until 12 hours0.5 days 0.0714 weeks 0.0164 months after establishment of steady state operation. B.1.2 Perform SR 3.4.13.1. Once per 24 hours1 days 0.143 weeks 0.0329 months AND B.2 Restore required 30 days containment atmosphere radioactivity monitor to OPERABLE status. C. Required Action and C.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND C.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months D. All required monitors D.1 Enter LCO 3.0.3. Immediately and level alarm inoperable. Point Beach 3.4.15-2 Unit 1 - Amendment No.21 Unit 2 - Amendment No.22

RCS Leakage Detection Instrumentation 3.4.15 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.15.1 Perform CHANNEL CHECK of the required In accordance containment atmosphere radioactivity monitor. with the Surveillance Frequency Control Program SR 3.4.15.2 Perform CHANNEL CALIBRATION of the In accordance required containment sump level alarm. with the Surveillance Frequency Control Program SR 3.4.15.3 Perform CHANNEL CALIBRATION of the In accordance required containment atmosphere radioactivity with the monitor. Surveillance Frequency Control Program Point Beach 3.4.15-3 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

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 1-131 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 EQUIVALENT ------------- Note ---------- 1-131 not within limit. LCO 3.0.4.c is applicable. A.1 Verify DOSE Once per 4 hours0.167 days 0.0238 weeks 0.00548 months EQUIVALENT 1-131

                                           <50 pCi/gm.

AND A.2 Restore DOSE 48 hours2 days 0.286 weeks 0.0658 months EQUIVALENT 1-131 to within limit. B. DOSE EQUIVALENT ------------- Note ------------- 48 hours2 days 0.286 weeks 0.0658 months Xe-133 not within limit. LCO 3.0.4.c is applicable. B. 1 Restore DOSE EQUIVALENT Xe-133 to within limit. (continued) Point Beach 3.4.16-1 Unit 1 - Amendment No. 233 Unit 2 - Amendment No. 238

RCS Specific Activity 3.4.16 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time of Condition A or B AND not met. C.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months OR DOSE EQUIVALENT 1-131 >50 µCi/gm. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1 ---------------------------NOTE-------------------------- In accordance Only required to be performed in MODE 1. with the

                 -------------------------------------------------------------   Surveillance Frequency Verify reactor coolant DOSE EQUIVALENT                         Control Program Xe-133 Specific Activity~ 300 µCi/gm.

SR 3.4.16.2 ---------------------------NOTE-------------------------- Only required to be performed in MODE 1.

                 -------------------------------------------------------------   In accordance with the Verify reactor coolant DOSE EQUIVALENT                          Surveillance 1-131 specific activity$: 0.5 µCi/gm.                           Frequency Control Program AND Between 2 and 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> after a THERMAL POWER change of~ 15% RTP within a 1 hour period Point Beach                                   3.4.16-2                 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

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

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

Separate 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 B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time of Condition A not AND met. B.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months OR SG tube integrity not maintained. Point Beach 3.4.17-1 Unit 1 - Amendment No. 254 Unit 2 - Amendment No. 258

SG Tube Integrity 3.4.17 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.17.1 Verify SG tube integrity in accordance with the In accordance Steam Generator Program. with 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 Point Beach 3.4.17-2 Unit 1 - Amendment No. 254 Unit 2 - Amendment No. 258

Accumulators 3.5.1 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.1 Accumulators LCO 3.5.1 Two Safety Injection Accumulators shall be OPERABLE. APPLICABILITY: MODES I and 2, MODE 3 with RCS pressure > 1000 psig. ACTIONS CONDITION REQUIRED ACTION COMPLETIONTIME A. One accumulator A.1 Restore boron 72 hours3 days 0.429 weeks 0.0986 months inoperable due to boron concentration to within concentration not within limits. limits. B. One accumulator B.1 Restore accumulator to 24 hours1 days 0.143 weeks 0.0329 months inoperable for reasons OPERABLE status. other than Condition A. C. Required Action and C.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time of Condition A or B AND not met. C.2 Reduce RCS pressure 12 hours0.5 days 0.0714 weeks 0.0164 months to s 1000 psig. D. Two accumulators D.1 Enter LCO 3.0.3. Immediately Inoperable. Point Beach 3.5.1-1 Unit 1 - Amendment No. 217 Unit 2 - Amendment No. 222

Accumulators 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify each accumulator isolation valve is fully In accordance open. with the Surveillance Frequency Control Program SR 3.5.1.2 Verify borated water volume in each In accordance accumulator is 2 1100 ft3 and :<:;; 1136 ft3. with the Surveillance Frequency Control Program SR 3.5.1.3 Verify nitrogen cover pressure in each In accordance accumulator is 2 700 psig and :<:;; 800 psig. with the Surveillance Frequency Control Program (continued) Point Beach 3.5.1-2 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

Accumulators 3.5.1 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.5.1.4 Verify boron concentration in each accumulator In accordance is;:::: 2700 ppm and :<;;; 3100 ppm. with the Surveillance Frequency Control Program AND

                                                               ------N 0 TE------

Only required to be performed for affected accumulators

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

Once within 24 hours1 days 0.143 weeks 0.0329 months after each solution volume increase of:::: 5% of indicated level that is not the result of addition from the refueling water storage tank with boron concentration

                                                               ;:::: 2700 ppm and

<;;; 3100 ppm SR 3.5.1.5 Verify power is removed from each accumulator In accordance isolation valve operator when RCS pressure is with the

            > 1000 psig.                                       Surveillance Frequency Control Program Point Beach                               3.5.1-3     Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

ECCS - Operating 3.5.2 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.2 ECCS - Operating LCO 3.5.2 Two ECCS trains shall be OPERABLE.

                   -------------------------------------- N 0 TE----------------------------------------

1n MODE 3, both safety injection (SI) pump flow paths may be isolated by closing the isolation valves for up to 2 hours0.0833 days 0.0119 weeks 0.00274 months to perform pressure isolation valve testing per SR 3.4.14.1. APPLICABILITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One ECCS train A.1 Restore train to 72 hours3 days 0.429 weeks 0.0986 months inoperable. OPERABLE status. B. Required Action and B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND B.2 Be in MODE 4. 12 hours0.5 days 0.0714 weeks 0.0164 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 -------------------------N 0 TE------------------------- N ot required to be met for system vent flow paths opened under administrative controls. In accordance Verify each ECCS manual, power operated, and with the automatic valve in the flow path, that is not Surveillance locked, sealed, or otherwise secured in position, Frequency is in the correct position. Control Program (continued) Point Beach 3.5.2-1 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

ECCS - Operating 3.5.2 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.5.2.2 Verify ECCS locations susceptible to gas In accordance accumulation are sufficiently filled with water. with the Surveillance Frequency Control Program SR 3.5.2.3 Verify each ECCS pump's developed head at the In accordance test flow point is greater than or equal to the with the required developed head. INSERVICE TESTING PROGRAM SR 3.5.2.4 Verify each ECCS automatic valve in the flow In accordance path that is not locked, sealed, or otherwise with the secured in position, actuates to the correct Surveillance position on an actual or simulated actuation Frequency signal. Control Program SR 3.5.2.5 Verify each ECCS pump starts automatically on In accordance an actual or simulated actuation signal. with the Surveillance Frequency Control Program SR 3.5.2.6 Verify, by visual inspection, each ECCS train In accordance containment sump suction inlet is not restricted with the by debris and the suction inlet debris screens Surveillance show no evidence of structural distress or Frequency abnormal corrosion. Control Program Point Beach 3.5.2-2 Unit 1 - Amendment No. 259 Unit 2 - Amendment No. 263

ECCS - Shutdown 3.5.3 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.3 ECCS-Shutdown LCO 3.5.3 One ECCS train shall be OPERABLE.

                    --------------------------------------- NOTE -------------------.

An RHR train 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 _ntr~l L. I M LCO 3.0.4.b is not applicable to ECCS high head subsystem. CONDITION REQUIRED ACTION COMPLETIONTIME A. Required ECCS residual A.1 Initiate action to restore Immediately heat removal (RHR) required ECCS RHR subsystem inoperable. subsystem to OPERABLE status. B. Required ECCS Si B.1 Restore required ECCS 1 hour subsystem inoperable. Si subsystem to OPERABLE status. C. Required Action and C.1 Be In MODE 5. 24 hours1 days 0.143 weeks 0.0329 months associated Completion Time of Condition B not met. Point Beach 3.5.3-1 Unit 1 - Amendment No. 215 Unit 2 - Amendment No. 220

ECCS - Shutdown 3.5.3 SURVEILLANCE REQUIREMENTS 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 3.5.2.1 SR 3.5.2.4 SR 3.5.2.2 SR 3.5.2.5 SR 3.5.2.3 SR 3.5.2.6 Point Beach 3.5.3-2 Unit I -Amendment No. 206, 209 Unit 2 - Amendment No. Bel, 214

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 shall be OPERABLE. APPLICABILITY: MODES 1, 2, 3, and 4. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RWST boron A.1 Restore RWST to 8 hours0.333 days 0.0476 weeks 0.011 months concentration not within OPERABLE status. limits. OR RWST borated water temperature not within limits. B. RWST inoperable for B.1 Restore RWST to 1 hour reasons other than OPERABLE status. Condition A. C. Required Action and C.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND C.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months Point Beach 3.5.4-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

RWST 3.5.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.4.1 Verify RWST borated water temperature is In accordance

2': 42.5°F and~ 97.5°F. with the Surveillance Frequency Control Program SR 3.5.4.2 Verify RWST borated water volume is In accordance

2': 275,000 gallons. with the Surveillance Frequency Control Program SR 3.5.4.3 Verify RWST boron concentration is :2': 2800 ppm In accordance and ~ 3200 ppm. with the Surveillance Frequency Control Program Point Beach 3.5.4-2 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

Containment 3.6.1 3.6 CONTAINMENT SYSTEMS 3.6.1 Containment LCO 3.6.1 Containment shall be OPERABLE. APPLICABILITY: MODES 1, 2, 3, and 4. ACTI ONS __ CONDITION REQUIRED ACTION COMPLETIONTIME A. Containment inoperable. A.1 Restore containment to 1 hour OPERABLE status. B. Required Action and B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.1 Perform required visual examinations and In accordance leakage rate testing except for containment air with the lock testing, in accordance with the Containment Containment Leakage Rate Testing Program. Leakage Rate Testing Program SR 3.6.1.2 Verify containment structural integrity in In accordance accordance with the Containment Tendon with the Surveillance Program. Containment Tendon Surveillance Program Point Beach 3.6.1-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

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: MODES 1,2,3, and 4. ACTIONS

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 exceeding the overall containment leakage rate. CONDITION REQUIRED ACTION COMPLETION TIME A. One or more ---------------- NOTES---------------- containment air locks 1. Required Actions A.1, A.2, with one bulkhead and A.3 are not applicable if inoperable. both bulkheads 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) Point Beach 3.6.2-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Containment Air Locks 3.6.2 ACTIONS CONDITION REQUIRED ACTION j COMPLETION TIME A. (continued) A.1 Verify the bulkhead 1 hour door and equalizing valve are closed on the OPERABLE bulkhead in the affected air lock. AND A.2 Lock the bulkhead door l 24 hours1 days 0.143 weeks 0.0329 months and equalizing valve closed on the OPERABLE bulkhead in the affected air lock. AND A.3 ------- NOTE----------- Bulkhead doors and equalizing valves in high radiation areas may be verified locked closed by administrative means. Verify the bulkhead Once per 31 days door and equalizing valve on the OPERABLE bulkhead in the affected air lock are locked closed. ___________________________________ I A (continued) Point Beach 3.6.2-2 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Containment Air Locks 3.6.2 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME B. One or more ----------------- NOTES--------------- containment air locks 1. Required Actions B.1, B.2, with containment air lock and B.3 are not applicable if interlock mechanism both bulkheads in the same inoperable. air lock are inoperable and Condition C is entered.

2. Entry and exit of containment is permissible under the control of a dedicated individual.

B.1 Verify the bulkhead 1 hour door and equalizing valve are closed on an OPERABLE bulkhead in the affected air lock. AND B.2 Lock the bulkhead door 24 hours1 days 0.143 weeks 0.0329 months and equalizing valve closed on an OPERABLE bulkhead in the affected air lock. AND (continued) Point Beach 3.6.2-3 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Containment Air Locks 3.6.2 ACTIONS CONDITIONS REQUIRED ACTION COMPLETION TIME B. (continued) B.3 - NOTE----------- Bulkhead doors and equalizing valves in high radiation areas may be verified locked closed by administrative means. Verify the bulkhead Once per 31 days door and equalizing valve on an OPERABLE bulkhead in the affected airlock are locked closed. C. One or more C.1 Initiate action to Immediately containment air locks evaluate overall inoperable for reasons containment leakage other than Condition A rate per LCO 3.6.1. or B. AND C.2 Verify a bulkhead door 1 hour and associated equalizing valve are closed in the affected air lock. AND C.3 Restore air lock to 36 hours1.5 days 0.214 weeks 0.0493 months OPERABLE status. D. Required Action and D.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND D.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months Point Beach 3.6.2-4 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Containment Air Locks 3.6.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.1 -------------------------N 0 TES--------------------------

1. An inoperable air lock bulkhead does not invalidate the previous successful performance of the overall air lock leakage test.

2. Results shall be evaluated against acceptance criteria applicable to SR 3.6.1.1.

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

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 bulkhead door and its associated In accordance equalizing valve in the air lock can be opened at with the a time. Surveillance Frequency Control Program Point Beach 3.6.2-5 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

Containment Isolation Valves 3.6.3 3.6 CONTAINMENT SYSTEMS 3.6.3 Containment Isolation Valves LCO 3.6.3 Each containment isolation valve shall be OPERABLE. APPLICABILITY: MODES 1,2, 3, and 4. ACTIONS

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

1. Penetration flow path(s) except for the purge supply and exhaust 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 isolation valve leakage results in exceeding the overall containment leakage rate acceptance criteria. CONDITION REQUIRED ACTION COMPLETIONTIME A. ----------- NOTE----------- A.1 Isolate the affected 4 hours0.167 days 0.0238 weeks 0.00548 months Only applicable to penetration flow path by penetration flow paths use of at least one with two containment closed and de-activated isolation valves. automatic valve, closed manual valve, blind flange, or check valve One or more penetration with flow through the flow paths with one valve secured. containment isolation valve inoperable. AND (continued) Point Beach 3.6.3-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Containment Isolation Valves 3.6.3 ACTIONS CONDITION REQUIRED ACTION COMPLEIONTIME A. (continued) A.2 ---------- NOTES----------

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

2. Isolation devices that are locked, sealed or otherwise secured may be verified by use of administrative means.

Verify the affected Once per 31 days penetration flow path is for isolation isolated. devices outside containment AND Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days for isolation devices inside containment B. ----------- NOTE----------- B.1 Isolate the affected 1 hour Only applicable to penetration flow path by penetration flow paths use of at least one with two containment closed and de-activated isolation valves. automatic valve, closed manual valve, or blind flange. One or more penetration flow paths with two containment isolation valves inoperable. (continued) Point Beach 3.6.3-2 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Containment Isolation Valves 3.6.3 ACTIONS (continued) CONDITION I REQUIRED ACTION ICOMPLETION TIME C. ----------- NOTE----------- C.1 Isolate the affected 72 hours3 days 0.429 weeks 0.0986 months Only applicable to penetration flow path by penetration flow paths use of at least one with only one closed and de-activated containment isolation automatic valve, closed valve and a closed manual valve, or blind system. flange. AND One or more penetration flow paths with one C.2 ----------- NOTES---------- containment isolation 1. Isolation devices in high valve inoperable. radiation areas may be verified by use of administrative means.

2. Isolation devices that are locked, sealed, or otherwise secured may be verified by use of administrative means.

Verify the affected Once per 31 days penetration flow path for isolation is isolated. devices outside containment AND Prior to entering Mode 4 from Mode 5 if not performed within the previous 92 days for isolation devices inside containment _________________________________J I (continued) Point Beach 3.6.3-3 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Containment Isolation Valves 3.6.3 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND D.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.1 Deleted SR 3.6.3.2 ---------------------------NOTE-------------------------- Valves and blind flanges in high radiation areas may be verified by use of administrative controls. In accordance Verify each containment isolation manual valve with the and blind flange that is located outside Surveillance containment and not locked, sealed, or Frequency otherwise secured and required to be closed Control Program during accident conditions is closed, except for containment isolation valves that are open under administrative controls. (continued) Point Beach 3.6.3-4 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.6.3.3 ---------------------------N()TE-------------------------- 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 M()DE 4 from containment and not locked, sealed, or M()DE 5 if not otherwise secured and required to be closed performed within during accident conditions is closed, except for the previous containment isolation valves that are open under 92 days administrative controls. SR 3.6.3.4 Verify the isolation time of each automatic power In accordance operated containment isolation valve is within with the INSERVICE TESTING PR()GRAM limits. INSERVICE TESTING PR()GRAM SR 3.6.3.5 Verify each automatic containment isolation In accordance valve that is not locked, sealed or otherwise with the secured in position, actuates to the isolation Surveillance position on an actual or simulated actuation Frequency signal. Control Program Point Beach 3.6.3-5 Unit 1 - Amendment No. 259 Unit 2 - Amendment No. 263

Containment Pressure 3.6.4 3.6 CONTAINMENT SYSTEMS 3.6.4 Containment Pressure LCO 3.6.4 Containment pressure shall be::::: -1.0 psig and s; +1.0 psig. APPLICABILITY: MODES 1, 2, 3, and 4. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment pressure A.1 Restore containment 1 hour not within limits. pressure to within limits. B. Required Action and B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1 Verify containment pressure is within limits. In accordance with the Surveillance Frequency Control Program Point Beach 3.6.4-1 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

Containment Air Temperature 3.6.5 3.6 CONTAINMENT SYSTEMS 3.6.5 Containment Air Temperature LCO 3.6.5 Containment average air temperature shall be:

a. s 116.3°F based on three averaged temperature channels,

b. s 115. 7°F based on two averaged temperature channels, or

c. s 112.5°F based on a single temperature channel.

APPLICABILITY: MODES 1, 2, 3, and 4. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment average air A.1 Restore containment 8 hours0.333 days 0.0476 weeks 0.011 months temperature not within average air temperature limit. to within limit. B. Required Action and B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1 Verify containment average air temperature is In accordance within limit. with the Surveillance Frequency Control Program Point Beach 3.6.5-1 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

Containment Spray and Cooling Systems 3.6.6 3.6 CONTAINMENT SYSTEMS 3.6.6 Containment Spray and Cooling Systems LCO 3.6.6 Two containment spray trains and four accident fan cooler units shall be OPERABLE. APPLICABILITY: MODES 1,2, 3, and 4. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One containment spray A.1 Restore containment 72 hours3 days 0.429 weeks 0.0986 months train inoperable. spray train to OPERABLE status. AND 144 hours6 days 0.857 weeks 0.197 months from discovery of failure to meet the LCO B. Required Action and B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time of Condition A not AND met. B.2 Be in MODE 5. 84 hours3.5 days 0.5 weeks 0.115 months C. One or two accident fan C.1 Restore accident fan 72 hours3 days 0.429 weeks 0.0986 months cooler unit(s) cooler unit(s) to inoperable. OPERABLE status. AND 144 hours6 days 0.857 weeks 0.197 months from discovery of failure to meet the LCO (continued) Point Beach 3.6.6-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Containment Spray and Cooling Systems 3.6.6 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME D. One required accident D.1 Restore required 72 hours3 days 0.429 weeks 0.0986 months fan cooler unit service accident fan cooler unit water outlet valve outlet valve to AND inoperable. OPERABLE status. 144 hours6 days 0.857 weeks 0.197 months from discovery of failure to meet the LCO E. Required Action and E.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time of Condition C AND or D not met. E.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.1 -------------------------N 0 TE------------------------- In accordance Not required to be met for system vent flow with the paths opened under administrative controls. Surveillance Frequency Control Program Verify each containment spray manual, power operated, and automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position. SR 3.6.6.2 Operate each containment cooling accident fan. In accordance with the Surveillance Frequency Control Program (continued) Point Beach 3.6.6-2 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

Containment Spray and Cooling Systems 3.6.6 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.6.6.3 Verify each containment fan cooler unit can In accordance achieve a cooling water flow rate within design with the limits with a fan cooler service water outlet valve Surveillance Frequency open. Control Program SR 3.6.6.4 Verify each containment spray pump's In accordance developed head at the flow test point is greater with the than or equal to the required developed head. INSERVICE TESTING PROGRAM SR 3.6.6.5 Verify each automatic containment spray and In accordance containment fan cooler unit service water outlet with the valve in the flow path that is not locked, sealed, Surveillance or otherwise secured in position, actuates to the Frequency correct position on an actual or simulated Control Program actuation signal. SR 3.6.6.6 Verify each containment spray pump starts In accordance automatically on an actual or simulated with the actuation signal. Surveillance Frequency Control Program SR 3.6.6.7 Verify each containment fan cooler unit accident In accordance fan starts automatically on an actual or with the simulated actuation signal. Surveillance Frequency Control Program SR 3.6.6.8 Verify proper operation of the accident fan In accordance cooler unit backdraft dampers. with the Surveillance Frequency Control Program (continued) Point Beach 3.6.6-3 Unit 1 - Amendment No. 259 Unit 2 - Amendment No. 263

Containment Spray and Cooling Systems 3.6.6 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.6.6.9 Verify each spray nozzle is unobstructed. In accordance with the Surveillance Frequency Control Program SR 3.6.6.10 Verify containment spray locations susceptible In accordance to gas accumulation are sufficiently filled with with the water. Surveillance Frequency Control Proqram Point Beach 3.6.6-4 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

Spray Additive System 3.6.7 3.6 CONTAINMENT SYSTEMS 3.6.7 Spray Additive System LCO 3.6.7 The Spray Additive System shall be OPERABLE. APPLICABILITY: MODES 1, 2, 3, and 4. ACTIONS CONDITION REQUIRED ACTION COMPLEllON TIME A. One Spray Additive A.1 Restore Spray Additive 72 hours3 days 0.429 weeks 0.0986 months System flowpath System flowpath to inoperable. OPERABLE status. B. Spray Additive System B.1 Restore at least one 1 hour inoperable for any Spray Additive System reason other than flowpath to OPERABLE Condition A. status. C. Required Action and C.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time of Condition A or B AND not met. C.2 Be in MODE 5. 84 hours3.5 days 0.5 weeks 0.115 months Point Beach 3.6.7-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Spray Additive System 3.6.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.7.1 Verify each spray additive manual, power In accordance operated, and automatic valve in the flow path with the that is not locked, sealed, or otherwise secured Surveillance in position is in the correct position. Frequency Control Program SR 3.6.7.2 Verify spray additive tank solution volume is In accordance

            ~ 43%.                                                with the Surveillance Frequency Control Program SR 3.6.7.3  Verify spray additive tank NaOH solution              In accordance concentration is ~ 30% and ::::: 33% by weight.       with the Surveillance Frequency Control Program SR 3.6.7.4  Verify each spray additive automatic valve in the     In accordance flow path that is not locked, sealed, or otherwise    with the secured in position, actuates to the correct          Surveillance position on an actual or simulated actuation          Frequency signal.                                               Control Program Point Beach                           3.6.7-2            Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

MSSVs 3.7.1 3.7 PLANT SYSTEMS 3.7.1 Main Steam Safety Valves (MSSVs) LCO 3.7.1 Four MSSVs per steam generator shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3. ACTIONS

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

Separate Condition entry is allowed for each MSSV. CONDITION REQUIRED ACTION COMPLEllONTIME A. One or more Steam A.1 Reduce THERMAL 4 hours0.167 days 0.0238 weeks 0.00548 months Generators with one POWER to less than or MSSV inoperable and equal to the Maximum Moderator Temperature Allowable % RTP Coefficient (MTC) zero specified in or negative at all power Table 3.7.1-1 for the levels. number of OPERABLE MSSVs. B. One or more Steam B.1 Reduce THERMAL 4 hours0.167 days 0.0238 weeks 0.00548 months Generators with two POWER to less than or MSSVs inoperable. equal to the Maximum Allowable % RTP OR specified in Table 3.7.1-1 for the One or more Steam number of OPERABLE Generators with one MSSVs. MSSV inoperable and Moderator Temperature AND Coefficient (MTC) positive at any power level. (continued) Point Beach 3.7.1-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

MSSVs 3.7.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) -----------N 0 TE----------- Only required in MODE 1.

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

B.2 Reduce the Power Range 36 hours1.5 days 0.214 weeks 0.0493 months Neutron Flux - High reactor trip setpoint to less than or equal to the Maximum Allowable

                                               % RTP specified in Table 3.7.1-1 for the number of OPERABLE MSSVs.

C. Required Action and C.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND OR C.2 Be in MODE 4. 12 hours0.5 days 0.0714 weeks 0.0164 months One or more steam generators with three or more MSSVs inoperable. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1.1 ---------------------------NOTE------------------------- Only required to be performed in MODES 1 and 2. Verify each required MSSV lift setpoint per In accordance Table 3.7.1-2 in accordance with the with the INSERVICE TESTING PROGRAM. Following INSERVICE testing, lift setting shall be within +/-1 %. TESTING PROGRAM Point Beach 3.7.1-2 Unit 1 - Amendment No. 259 Unit 2 - Amendment No. 263

MSSVs 3.7.1 Table 3.7.1-1 (page 1 of 1) OPERABLE Main Steam Safety Valves versus Maximum Allowable Power NUMBER OF OPERABLE MSSVs MAXIMUM ALLOWABLE POWER PER STEAM GENERATOR (% RTP) 3 ~ 39 2 ~ 22 Point Beach 3.7.1-3 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

MSSVs 3.7.1 Table 3.7.1-2 (page 1 of 1) Main Steam Safety Valve Lift Settings VALVE NUMBER LIFT SETTING STEAM GENERATOR (psig +/- 3%) A B MS 2010 MS 2005 1085 MS 2011 MS 2006 1100 MS 2012 MS 2007 1105 MS 2013 MS 2008 1105 Point Beach 3.7.1-4 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

- - MSIVs and Non-Return Check Valves 3.7.2 3.7 PLANT SYSTEMS 3.7.2 Main Steam Isolation Valves (MSIVs) and Non-Return Check Valves LCO 3.7.2 Two MSIVs and two non-return check valves shall be OPERABLE. APPLICABILITY: MODES 1, 2 and 3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One Steam Generator A.1 Restore valve to 8 hours0.333 days 0.0476 weeks 0.011 months flowpath with one or OPERABLE status. more inoperable valves in MODE 1. B. Required Action and B.1 Be in MODE 2. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time of Condition A not met. C. -----------NOTE----------- NOTE---- Separate Condition entry An inoperable flowpath may be is allowed for each opened under administrative Steam Generator flowpath. controls to allow cool down of the affected unit. One or both MSIVs C.1 Close and de-activate 8 hours0.333 days 0.0476 weeks 0.011 months inoperable in MODE 2 the MSIV in the affected or 3. fTowpath. OR AND One or both non-return C.2 Close non-return 8 hours0.333 days 0.0476 weeks 0.011 months check valves inoperable check valve in the in MODE 2 or 3. affected flowpath. AND (continued) Point Beach 3.7.2-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

MSIVs and Non-Return Check Valves 3.7.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.3 Verify MSIV and non- Once per 7 days return check valve in the affected flowpath a re closed and the MSIV is de-activated. D. Required Action and D.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time of Condition C not AND met. D.2 Be in MODE 4. 12 hours0.5 days 0.0714 weeks 0.0164 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1 --------------------------NOTE------------------------- Only required to be performed in MODE 1. Verify closure time of each MSIV is within limits. In accordance with the INSERVICE TESTING PROGRAM SR 3.7.2.2 --------------------------NOTE------------------------- Only required to be performed in MODE 1. In accordance Verify each MSIV actuates to the isolation with the position on an actual or simulated actuation Surveillance signal. Frequency Control Program SR 3.7.2.3 Verify each main steam non-return check valve In accordance can close. with the INSERVICE TESTING PROGRAM Point Beach 3.7.2-2 Unit 1 - Amendment No. 2591 Unit 2 - Amendment No. 263

MFIVs, MFRVs, and MFRV Bypass Valves 3.7.3 3.7 PLANT SYSTEMS 3.7.3 Main Feedwater Isolation Valves (MFIVs), Main Feedwater Regulating Valves (MFRVs) and MFRV Bypass Valves LCO 3.7.3 Main Feedwater Isolation shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3. ACTIONS

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

Separate Condition entry is allowed for each valve. CONDITION REQUIRED ACTION COMPLETION TIME A. One or more MFIVs A. 1 Close or isolate MFIV. 72 hours3 days 0.429 weeks 0.0986 months inoperable. AND A.2 Verify' MFIV is closed or Once per isolated. 7 days B. One or more MFRVs B.1 Close or isolate MFRV. 72 hours3 days 0.429 weeks 0.0986 months inoperable. AND B.2 Verify MFRV is closed Once per or isolated. 7 days C. One or more MFRV C.1 Close or isolate MFRV 72 hours3 days 0.429 weeks 0.0986 months Bypass Valves Bypass Valve inoperable. AND C.2 Verify MFRV Bypass Once per 7 days Valve is closed or isolated Point Beach 3.7.3-1 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

MFIVs, MFRVs, and MFRV Bypass Valves 3.7.3 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME D. Two valves in the same D.1 Isolate affected flow 8 hours0.333 days 0.0476 weeks 0.011 months flowpath inoperable. path E. Required Action and E.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND E.2 Be in MODE 4. 12 hours0.5 days 0.0714 weeks 0.0164 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 Verify each MFIV, MFRV, and MFRV bypass In accordance valve, actuate to the isolation position on an with the actual or simulated actuation signal. Surveillance Frequency Control Program SR 3.7.3.2 Verify each MFIV, MFRV, and MFRV Bypass In accordance Valve isolation time is within limits. with the INSERVICE TESTING PROGRAM Point Beach 3.7.3-2 Unit 1 - Amendment No. 259 Unit 2 - Amendment No. 263

ADV Flowpaths 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Atmospheric Dump Valve (ADV) Flowpaths LCO 3.7.4 Two ADV flowpaths shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3, MODE 4 when steam generator is relied upon for heat removal. ACTIONS CONDITION REQUIRED ACTION COMPLETIONTIME A. One required ADV A.1 Restore required ADV 7 days I flowpath inoperable. flowpath to OPERABLE status. B. Two required ADV B.1 Restore one ADV 1 hour flowpaths Inoperable. flowpath to OPERABLE status. C. Required Action and C.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND C.2 Be In MODE 4 without 18 hours0.75 days 0.107 weeks 0.0247 months reliance upon steam generator for heat removal. Point Beach 3.7.4-1 Unit I - Amendment No. 21 5 Unit 2 - Amendment No. 2 20

ADV Flowpaths 3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify one complete manual cycle of each ADV. In accordance with the Surveillance Frequency Control Program SR 3.7.4.2 Verify one complete manual cycle of each In accordance ADV block valve. with the Surveillance Frequency Control Program Point Beach 3.7.4-2 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

AFW System 3.7.5 3.7 PLANT SYSTEMS 3.7.5 Auxiliary Feedwater (AFW) LC03.7.5 The AFW System shall be OPERABLE with; one turbine driven AFW pump system and one motor driven AFW pump system:

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

Only the motor driven AFW pump system 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. Turbine driven AFW A.1 Restore affected 7 days pump system inoperable equipment to due to one inoperable OPERABLE status. steam supply. 10 days from OR discovery of failure to meet the

       -----------NOTE-----------                                                   LCO Only applicable if MODE 2 has not been entered following refueling.

Turbine driven AFW pump system inoperable in MODE 3 following refueling. (continued) Point Beach 3.7.5-1 Unit 1 - Amendment No. 238 Unit 2 - Amendment No. 242

AFW System 3.7.5 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME B. One AFW pump system B.1 Restore AFW pump 72 hours3 days 0.429 weeks 0.0986 months inoperable in MODE 1, 2 system to OPERABLE or 3 for reasons other status. AND than Condition A. 10 days from discovery of failure to meet the LCO C. Turbine driven AFW C.1 Restore the steam 24 hours1 days 0.143 weeks 0.0329 months pump system inoperable supply to the turbine due to one inoperable driven pump system to steam supply. OPERABLE status. AND OR OR Motor driven AFW pump system inoperable. C.2 Restore the motor driven 48 hours2 days 0.286 weeks 0.0658 months if motor AFW pump system to driven AFW pump OPERABLE status. system is available from the opposite unit. (continued) Point Beach 3.7.5-2 Unit 1 - Amendment No. 238 . Unit 2 - Amendment No. 242

AFW System 3.7.5 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time of Condition A, B, AND or C not met. 18 hours0.75 days 0.107 weeks 0.0247 months D.2 Be in MODE 4. E. Two AFW pump systems E.1 -----------NOTE----------- inoperable in MODE 1, 2, LCO 3.0.3 and all other or 3. LCO Required Actions requiring MODE changes are suspended until one AFW pump system is restored to OPERABLE status.

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

Initiate action to restore Immediately one AFW pump system to OPERABLE status. F. Motor driven AFW pump F.1 Initiate action to restore Immediately system inoperable in motor driven AFW pump MODE 4. system to OPERABLE status. Point Beach 3.7.5-3 Unit 1 - Amendment No. 238 Unit 2 - Amendment No. 242

AFW System 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 ---------------------------N()TE--------------------------- AFW pump system(s) may be considered ()PERABLE during alignment and operation for steam generator level control, if it is capable of being manually realigned to the AFW mode of operation. In accordance with the Verify each AFW manual, power operated, and Surveillance automatic valve in each water flow path, and in Frequency both steam supply flow paths to the steam Control turbine driven pump, that is not locked, sealed, or Program otherwise secured in position, is in the correct position. SR 3.7.5.2 ----------------------------N()TE--------------------------- Not required to be performed for the turbine driven AFW pump until 24 hours1 days 0.143 weeks 0.0329 months after THERMAL P()WER exceeds 2% RTP. Verify the developed head of each required AFW In accordance pump at the flow test point is greater than or with the equal to the required developed head. INSERVICE TESTING PR()GRAM SR 3.7.5.3 ----------------------------N()TE-------------------------- AFW pump system(s) may be considered ()PERABLE during alignment and operation for steam generator level control, if it is capable of being manually realigned to the AFW mode of operation. In accordance with the Verify each AFW automatic valve that is not Surveillance locked, sealed, or otherwise secured in position, Frequency actuates to the correct position on an actual or Control simulated actuation signal. Program Point Beach 3.7.5-4 Unit 1 - Amendment No. 259 Unit 2 - Amendment No. 263

AFW System 3.7.5 SURVEILLANCE REQUIREMENTS (continued) SR 3.7.5.4 ---------------------------N 0 TES-------------------------

1. Not required to be performed for the turbine driven AFW pump until 24 hours1 days 0.143 weeks 0.0329 months after

1000 psig in the steam generator.

2. AFW pump system(s) may be considered OPERABLE during alignment and operation for steam generator level control, if it is capable of being manually realigned to the AFW mode of operation.

In accordance with the Verify each AFW pump starts automatically on an Surveillance actual or simulated actuation signal. Frequency Control Program SR 3.7.5.5 Verify proper alignment of the required AFW flow Prior to paths by verifying flow from the condensate THERMAL storage tank to each steam generator supplied by POWER the respective AFW pump system. exceeding 2% RTP whenever unit has been in MODE 5, MODE 6, or defueled for a cumulative period of

                                                                            > 30 days Point Beach                                3.7.5-5                  Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

CST 3.7.6

3. 7 PLANT SYSTEMS 3.7.6 Condensate Storage Tank (CST)

LCO 3.7.6 The CST 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. CST inoperable. A.1 Restore CST to 7 days OPERABLE status. B. Required Action and B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND B.2 Be in MODE 4, without 18 hours0.75 days 0.107 weeks 0.0247 months reliance on steam generator for heat removal. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1.A Verify the CST level is ~ 21, 150 gallons. In accordance with (2 CSTs either cross-tied or individually aligned) the Surveillance Frequency Control OR Program SR 3.7.6.1.B Verify the CST level is ~ 35,837 gallons. (1 CST supplying two units) OR SR 3.7.6.1.C Verify the CST level is~ 14,100 gallons. (2 CSTs supplying one unit) Point Beach 3.7.6-1 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

CC System 3.7.7 3.7 PLANT SYSTEMS 3.7.7 Component Cooling Water (CC) System LCO 3.7.7 The CC System shall be OPERABLE with; two CC pumps, and two required CC heat exchangers. APPLICABILITY: MODES 1, 2, 3, and 4. ACTIONS

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

Enter applicable Conditions and Required Actions of LCO 3.4.6, "RCS Loops-MODE 4," for residual heat removal loops made inoperable by CC.

          -CONDITION                              REQUIRED ACTION                   COMPLETION TIME A. One CC pump                        A.1         Restore CC pump to             72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> inoperable.                                    OPERABLE status.

AND 144 hours6 days 0.857 weeks 0.197 months from discovery of failure to meet the LCO B. One required CC heat B.1 Restore required CC 72 hours3 days 0.429 weeks 0.0986 months exchanger inoperable. heat exchanger to OPERABLE status. AND 144 hours6 days 0.857 weeks 0.197 months from discovery of failure to meet the LCO C. Required Action and C.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND C.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months Point Beach 3.7.7-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

CC System 3.7.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1 --------------------------N()TE------------------------- lsolation of CC flow to individual components does not render the CC System inoperable. In accordance with the Verify each CC manual, power operated, and Surveillance automatic valve in the flow path servicing Frequency safety related equipment, that is not locked, Control Program sealed, or otherwise secured in position, is in the correct position. Point Beach 3.7.7-2 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

SW System 3.7.8 3.7 PLANT SYSTEMS 3.7.8 Service Water (SW) System LCO 3.7.8 The SW System shall be OPERABLE with:

a. Six OPERABLE SW pumps;

b. SW ring header continuous flowpath not interrupted;

c. Required automatic non-essential-SW-load isolation valves OPERABLE or affected non-essential flowpath isolated; and

d. Opposite unit containment accident fan cooler unit SW outlet motor operated valves closed or SW flowpath isolated.

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

Only five SW pumps are required to be OPERABLE with one unit in MODE 5 or 6, or defueled, and the SW System capable of providing required cooling water flow to required equipment.

                                            ---- ----
                                                  --- --- ------  --- --- --- ---- --- ---  ---  --- ----  ---  ---  --- ---  --.

APPLICABILITY: MODES 1, 2, 3, and 4. ACTIONS

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

Enter applicable Conditions and Required Actions for systems made inoperable by SW System. CONDITION REQUIRED ACTION COMPLET1ONTIME A. One SW pump A.1 Restore SW pump to 7 days inoperable. OPERABLE status. AND AND 14 days from Both units in MODES 1, discovery of 2, 3, or 4. failure to meet the LCO (continued) Point Beach 3.7.8-1 Unit 1 - Amendment No. Aim, 205 Unit 2 - Amendment No. -26, 210 AUG 2 9 202

- -

SW System 3.7.8 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETIONTIME B. Two or three SW pumps B.1 Restore SW pump(s) to 72 hours3 days 0.429 weeks 0.0986 months inoperable. OPERABLE status. C. SW ring header C.1 Verify SW System 1 hour continuous flowpath capable of providing interrupted. required cooling water flow to required equipment. AND C.2 Restore the SW ring 7 days header continuous flowpath. AND 14 days from discovery of failure to meet the LCO D. ----- NOTE--------- D.1 ----------- NOTE---------- Separate Condition Not required to be met entry is allowed for if in Condition E. each non-essential-SW-load flowpath. Verify required redundant 1 hour automatic isolation valve One or more in the affected non-non-essential-SW- essential flowpath(s) load flowpath(s) with OPERABLE. one required automatic isolation AND valve inoperable. D.2 Isolate the affected non- 72 hours3 days 0.429 weeks 0.0986 months AND essential flowpath(s). AND Affected non-essential flowpath(s) 14 days from not isolated. discovery of failure to meet the LCO (continued) Point Beach 3.7.8-2 Unit 1 - Amendment No. 20i, 205 Unit 2 - Amendment No. , 0 AIJU? 2 i

SW System 3.7.8 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLEl1ONTIME E. One or more E.1 Isolate the affected non- 1 hour non-essential-SW-load essential flowpath(s). flowpath(s) with two required automatic isolation valves inoperable. AND Affected non-essential flowpath(s) not isolated. F. One or more opposite F.1 Verify SW System 1 hour unit containment capable of providing accident fan cooler unit required cooling water SW outlet motor flow to required operated valves open. equipment. AND AND Opposite unit F.2 Isolate the opposite unit 72 hours3 days 0.429 weeks 0.0986 months containment accident fan containment accident fan cooler unit SW flowpath cooler unit SW flowpath. AND not isolated. 14 days from discovery of failure to meet the LCO G. Four or more SW pumps G.1 Restore SW pump(s) to 1 hour inoperable. OPERABLE status. (continued) Point Beach 3.7.8-3 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

SW System 3.7.8 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME H. Required Action and H.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND H.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.8.1 ---------------------------NOTE--------------------------- 1solation of SW flow to individual components does not render the SW System inoperable. In accordance with the Verify each SW manual, power operated, and Surveillance automatic valve in the flow path servicing safety Frequency related equipment, that is not locked, sealed, or Control Program otherwise secured in position, is in the correct position. SR 3.7.8.2 Verify each required SW automatic non-essential- In accordance SW-load isolation valve that is not locked, with the sealed, or otherwise secured in the closed Surveillance position, actuates to the closed position on an Frequency actual or simulated actuation signal. Control Program SR 3.7.8.3 Verify each SW pump starts automatically on an In accordance actual or simulated actuation signal. with the Surveillance Frequency Control Program Point Beach 3.7.8-4 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

CREFS 3.7.9 3.7 PLANT SYSTEMS 3.7.9 Control Room Emergency Filtration System (CREFS) LCO 3.7.9 CREFS shall be OPERABLE with:

a. Two control room recirculation fans,

b. Two control room emergency fans,

c. One filter train,

d. Two control room emergency fan control dampers, and

e. Two isolation dampers in the kitchen area exhaust duct.

                    -----------------------------------------No-rE---------------------------------------

The control room envelope (CRE) boundary may be opened intermittently under administrative controls. APPLICABILITY: MODES 1, 2, 3, 4, During movement of irradiated fuel assemblies ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. -----------NOTE---------- A.1 Restore inoperable fan 7 days Separate Condition or damper to entry is allowed for each OPERABLE status. component. One control room recirculation fan inoperable. One control room emergency fan inoperable. One control room emergency fan control damper inoperable. Point Beach 3.7.9-1 Unit 1 - Amendment No. 240 Unit 2 - Amendment No. 244

CREFS 3.7.9 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME B. One isolation damper in B.1 Restore isolation 7 days the kitchen area exhaust damper to OPERABLE duct inoperable. status. OR B.2 Place and maintain the 7 days other isolation damper in the same duct in the closed position. C. -----------NOTE---------- C.1 Initiate actions to Immediately Separate Condition implement mitigating entry is allowed for each actions. component.

     ----------------------~-~--------- AND Two control room                   C.2       Suspend movement of            Immediately recirculation fans                           irradiated fuel inoperable.                                  assemblies.

OR AND Two control room C.3 Verify mitigating actions 24 hours1 days 0.143 weeks 0.0329 months emergency fans ensure CRE occupant inoperable. radiological exposures will not exceed limits. OR AND Two control room emergency fan control C.4 Restore inoperable 7 days dampers inoperable. fans, dampers or filter train to OPERABLE OR status. Filter train inoperable for reasons other than Condition D. Point Beach 3.7.9-2 Unit 1 Amendment No. 240 Unit 2 - Amendment No. 244

CREFS 3.7.9 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME D. -----------N 0 TE ---------- 0.1 Initiate actions to Immediately Separate Condition implement mitigating entry is allowed for each actions. component.

     --------------------------------- AND Filter train inoperable            0.2       Suspend movement of          Immediately due to an inoperable                         irradiated fuel CRE boundary                                 assemblies.

OR AND Two isolation dampers 0.3 Verify mitigating actions 24 hours1 days 0.143 weeks 0.0329 months in the kitchen exhaust ensure CRE occupant duct inoperable. radiological and chemical exposures will not exceed limits, and CRE occupants are protected from smoke hazards. AND 0.4 Restore CRE boundary 90 days to OPERABLE status. E. Required Action and E.1 Suspend movement of Immediately associated Completion irradiated fuel Time of Condition A, B, C, assemblies. or 0 not met in MODE 1, 2, 3, or 4 or not met during AND movement of irradiated fuel assemblies. E.2 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months AND E.3 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months * Point Beach 3.7.9-3 Unit 1 - Amendment No. 240 Unit 2 - Amendment No. 244

CREFS 3.7.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.9.1 Operate the CREFS for 2 15 minutes. In accordance with the Surveillance Frequency Control Program SR 3.7.9.2 Perform required CREFS filter testing in In accordance accordance with the Ventilation Filter Testing with the VFTP Program (VFTP). SR 3.7.9.3 Verify each CREFS emergency and recirculation In accordance fan actuates on an actual or simulated actuation with the signal. Surveillance Frequency Control Program SR 3.7.9.4 Verify each CREFS automatic damper in the In accordance emergency mode flow path actuates to the with the correct position on an actual or simulated Surveillance actuation signal. Frequency Control Program SR 3.7.9.5 Verify CREFS manual start capability and In accordance alignment. with the Surveillance Frequency Control Program SR 3.7.9.6 Perform required CRE unfiltered air inleakage In accordance testing in accordance with the Control Room with the Control Envelope Habitability Program. Room Envelope Habitability Program Point Beach 3.7.9-4 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

Fuel Storage Pool Water Level 3.7.10 3.7 PLANT SYSTEMS 3.7.10 Fuel Storage Pool Water Level LCO 3. 7 .10 The fuel storage pool 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 fuel storage pool. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel storage pool water A.1 ----------NOTE----------- level not within limit. LCO 3.0.3 is not applicable. Suspend movement of Immediately irradiated fuel assemblies in the fuel storage pool. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.10.1 Verify the fuel storage pool water level is ~ 23 ft In accordance above the top of the irradiated fuel assemblies with the seated in the storage racks. Surveillance Frequency Control Program Point Beach 3.7.10-1 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

Fuel Storage Pool Boron Concentration 3.7.11 3.7 PLANT SYSTEMS 3.7.11 Fuel Storage Pool Boron Concentration LCO 3.7.11 The fuel storage pool boron concentration shall be ~ 2100 ppm. APPLICABILITY: When fuel assemblies are stored in the spent fuel storage pool. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel storage pool boron -----------------N 0 TE----------------- concentration not within L CO 3.0.3 is not applicable. limit. A.1 Suspend movement of Immediately fuel assemblies in the fuel storage pool. A.2 Initiate action to restore Immediately fuel storage pool boron concentration to within limit. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.11.1 Verify the fuel storage pool boron concentration In accordance is within limit. with the Surveillance Frequency Control Program Point Beach 3.7.11-1 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

3.7 PLANT SYSTEMS 3.7.12 Spent Fuel Pool Storage LCO 3.7.12 The combination of initial enrichment, burnup and decay time of each fuel assembly stored in the spent fuel pool shall be within the Acceptable range of Figure 3.7.12-1 or in accordance with Specification 4.3.1.1. APPLICABILITY: Whenever any fuel assembly is stored in the spent fuel storage pool. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the -------------------NOTE---------------------- LCO not met. LCO 3.0.3 is not applicable. A.1 Restore the spent fuel pool Immediately within fuel storage limits. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.12.1 Verify by administrative means each fuel Prior to storing assembly meets fuel storage limits. the fuel assemblies in the spent fuel storage pool Point Beach 3.7.12.1 Unit 1 - Amendment No. 236 Unit 2 - Amendment No. 240

Spent Fuel Pool Storage 3.7.12 30,000

                     -_._.                       -   I--   -- --                        - f-- -_.-
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                     -      .                                                                               --                                - --
                                                                                                                                               'J D      o yr decay 5 yr decay 25,000 J        V. 10 yr decay I / / ~

15 yr decay I-- .

IACCEPTABLE

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                                                                                                                                         ~~

20 yr decay _.- J

0 ~V

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II' j J 20,000

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a

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       .ilE 15,000 V
        >.

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       <<                                                                                                                  I IUNACCEPTABLE I Qj                                  ._-                                                             .. -                                 ---~
                                                                            ~

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                     -----                               -                        f--. .                                          --

10,000 h

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                                                                                                                       -- ---

J -- -- 1--- --I-- o .i 2.0 2.5 3.0 3.5 4.0 4.5 5.0 Nominal Initial U-235 Enrichment (w/o) o yr decay = 71.56e 3 1166. 6ge 2 + 15059.1ge 27474.43 5 yr decay = -11.14e 3 287.32e 2 + 11630.42e 23361. 60 10 yr decay= -16.28e 3 308.68e 2 + 11655.01e 23267.42 15 yr decay= -85.22e 3 + 436.68e 2 + 8884.52e 20081.62 20 yr decay= -113.81e 3 + 669.67e 2 + 8161.13e 19321. 65 Figure 3.7.12-1 Fuel Assembly Burnup Requirement of "Ali-Ceil" Storage Configuration Point Beach 3.7.12.2 Unit 1 - Amendment No. 236 Unit 2 - Amendment No. 240

Secondary Specific Activity 3.7.13 3.7 PLANT SYSTEMS

3. 7 .13 Secondary S pacific Activity LCO 3.7.13 The specific activity of the secondary coolant shall be ~ 0.1 µCi/gm DOSE EQUIVALENT 1-131.

APPLICABILITY: MODES 1, 2, 3, and 4. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Specific activity not A.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months within limit. AND A.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.13.1 Verify the specific activity of the secondary In accordance coolant is~ 0.1 µCi/gm DOSE EQUIVALENT with the 1-131. Surveillance Frequency Control Program Point Beach 3. 7.13-1 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

AC Sources-Operating 3.8.1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 AC Sources-Operating LCO 3.8.1 The following AC electrical power sources shall be OPERABLE:

a. One circuit between the offsite transmission network and the associated unit's 4.16 kV Class IE safeguards buses, A05 and A06, utilizing the associated unit's 345/13.8 kV (X03) transformer or the opposite unit's 345/13.8 kV (X03) transformer with the gas turbine in operation, and the associated unit's 13.8/4.16 kV (X04) transformer;

b. One circuit between the offslte transmission network and the opposite unit's 4.16 kV Class IE safeguards buses, A05 and A06; and

c. One standby emergency power source capable of supplying each 4.16 kV/480 V Class I E safeguards bus.

APPLICABILITY: MODES 1, 2, 3, and 4. ACTIONS

3. i NE p b---------------------- s-------------------------------

LCO 3.0.4.b is not applicable to standby emergency power sources.

      --- - --- - - - - -- -  - - -   -- - - -  --.- - -  - -.- - - - - - - - - -  - - -  - - - -  - - - - -  - -

CONDITION REQUIRED ACTION COMPLEn1QN11ME A. Associated unit A.1 Verify one circuit 24 hours1 days 0.143 weeks 0.0329 months 345/13.8 kV (X03) between the offsite transformer Inoperable. transmission network and the associated unit's DR 4.16 kV Class 1E safeguards buses, Gas turbine not In A05 and A06, utilizing operation when utilizing the opposite unit's opposite unit's 345/13.8 kV (X03) 345113.8 kV (X03) transformer. transformer. ANa (continued) Point Beach 3.8.1-1 Unit I - Amendment No. 21 5 Unit 2 - Amendment No.2 2 0

AC Sources-Operating 3.8.1 ACTIONS CONDITION REQUIRED ACTION COMPLElMNTOxME A. (continued) A.2 Verify gas turbine in 24 hours1 days 0.143 weeks 0.0329 months I operation. B. Associated unit's B.1 Restore associated 24 hours1 days 0.143 weeks 0.0329 months 13.8/4.16 kV (X04) unit's 13.8/4.16 kV (X04) transformer inoperable. transformer to OPERABLE status. C. Associated unit's C.1 Restore required offsile 24 hours1 days 0.143 weeks 0.0329 months required offsite power power source(s) to source to buses OPERABLE status. A05 and A06 inoperable. OR Required offsite power source to buses 1A05 and 2A06 inoperable. D. One or more required D.1 Declare required 12 hours0.5 days 0.0714 weeks 0.0164 months from offsite power source(s) to feature(s) supported by discovery of one or more required the inoperable required Condition D Class IE 4.16 kV bus(es) offsite power source concurrent with Inoperable. inoperable when its Inoperabillty of required redundant redundant feature(s) is inoperable. required feature(s) AND D.2 Restore required offsite 7 days power source(s) to OPERABLE status. AND 14 days from discovery of failure to meet LCO (continued) Point Beach 3.8.1-2 Unit I - Amendment No. 215 Unit 2 - Amendment No. 2 2 0

AC Sources-Operating 3.8.1 ACTIONS (continued) CONDITION I REQUIRED ACTION ICOMPLETION TIME

          ------------ NOTE------------    E.1      Declare required                4 hours0.167 days <br />0.0238 weeks <br />0.00548 months <br /> from Separate Condition entry                  feature(s) supported by         discovery of is allowed for each                       the inoperable standby          Condition E inoperable standby                        emergency power                 concurrent with emergency power                           source inoperable when          inoperability of source.                                   its required redundant          redundant feature(s) is inoperable.       required feature(s)

E. One or more required AND standby emergency power source(s) E.2.1 Determine other 24 hours1 days 0.143 weeks 0.0329 months inoperable. required standby emergency power source(s) is not inoperable due to common cause failure. OR E.2.2 Perform SR 3.8.1.2 for 24 hours1 days 0.143 weeks 0.0329 months other required standby emergency power source(s). OR E.2.3 Declare other required 24 hours1 days 0.143 weeks 0.0329 months standby emergency power source(s) inoperable. AND E.3 Restore required 7 days standby emergency power source(s) to AND OPERABLE status. 14 days from discovery of failure to meet LCO ________________________ A. I _______________ (continued) Point Beach 3.8.1-3 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

AC Sources-Operating 3.8.1 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME F. One or more required -------------- NOTE------------------- offsite power source to Enter applicable Conditions and one or more Class 1E Required Actions of LCO 3.8.9, 4.16 kV safeguards Distribution Systems-Operating,* bus(es) inoperable. when Condition F is entered with no AC power to any train. AND Standby emergency F.1 Restore required offsite 12 hours0.5 days 0.0714 weeks 0.0164 months power inoperable to circuit to OPERABLE redundant equipment. status. OR F.2 Restore required 12 hours0.5 days 0.0714 weeks 0.0164 months standby emergency power source to OPERABLE status. G. Standby emergency G.1 Restore one required 2 hours0.0833 days 0.0119 weeks 0.00274 months power to buses standby emergency 1A05/1B03 and power source to 1A06/1B04 inoperable. OPERABLE status. OR Standby emergency power to buses 2A05/2B03 and 2A06/2B04 inoperable. OR Standby emergency power to buses 1A05/1 B03 and 2A06/2B04 inoperable. (continued) Point Beach 3.8.1-4 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

AC Sources-Operating 3.8.1 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME H. Required Action and H.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND H.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated In accordance with power availability for each required offsite circuit. the Surveillance Frequency Control Program SR 3.8.1.2 ---------------------------NOTES--------------------------

1. All standby emergency power source starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.

2. A modified standby emergency power source start involving idling and gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer.

In accordance with Verify each standby emergency power source the Surveillance starts from standby conditions and achieves Frequency Control rated voltage and frequency. Program (continued) Point Beach 3.8.1-5 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.8.1.3 --------------------------NOTES--------------------------

1. Standby emergency power source loadings may include gradual loading.

2. Momentary transients outside the load range do not invalidate this test.

3. This SR shall be preceded by and immediately follow without shutdown a successful performance of SR 3.8.1.2.

In accordance with Verify each standby emergency power source is the Surveillance synchronized and loaded and operates for Frequency Control

             ~ 60 minutes at a load ~ 2500 kW and                          Program

2850 kW.

SR 3.8.1.4 Verify the fuel oil transfer system operates to In accordance with automatically transfer fuel oil from storage tank to the Surveillance the day tank. Frequency Control Program (continued) Point Beach 3.8.1-6 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.8.1.5 -------------------------NOTE----------------------------- This surveillance shall not normally be performed with the associated unit in MODE 1, 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 on an actual or simulated loss of offsite In accordance with power signal in conjunction with an actual or the Surveillance simulated ESF actuation signal: Frequency Control Program

a. De-energization of emergency buses;

b. Load shedding from emergency buses; and

c. Standby emergency power source auto-starts from standby condition and:

1. energizes permanently connected loads,

2. energizes auto-connected emergency loads through load logic and sequencer,

3. achieves steady state voltage within limits,

4. achieves steady state frequency within limits, and

5. supplies permanently connected and auto-connected emergency loads for 2 5 minutes.

(continued) Point Beach 3.8.1-7 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.8.1.6 Verify each standby emergency power source: In accordance with the Surveillance

a. Synchronizes with offsite power source Frequency Control while loaded with emergency loads upon a Program simulated restoration of offsite power;

b. Transfers loads to offsite power source; and

c. Returns to ready-to-load operation.

SR 3.8.1.7 -----------------------N 0 TES------------------------------- 1 . Momentary transients outside the load and power factor ranges do not invalidate this test.

2. This Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

3. If performed with the standby emergency power source synchronized with offsite power, it shall be performed at a power factor~ 0.87. 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.

In accordance with Verify each standby emergency power source the Surveillance operates for~ 24 hours1 days 0.143 weeks 0.0329 months at~ 2850 kW (G01/G02), Frequency Control

             ~ 2848 kW (G03/04).                                                    Program Point Beach                                 3.8.1-8                        Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

AC Sources-Shutdown 3.8.2 3.8 ELECTRICAL POWER SYSTEMS 3.8.2 AC Sources-Shutdown LCO 3.8.2 The following AC electrical power sources shall be OPERABLE:

a. One circuit between the offsite transmission network and the 480 V Class 1E safeguards bus(es) B03 and 804, required by LCO 3.8.10, Distribution Systems-Shutdown"; and

b. One standby emergency power source capable of supplying one of the associated unit's 480 V Class 1E safeguards bus(es)

B03 or B04, required by LCO 3.8.10. APPLICABILITY: MODES 5 and 6. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required offsite A.1 Declare affected Immediately circuit inoperable. required feature(s) with no offsite power available inoperable. AND A.2 Initiate action to restore Immediately required offsite power circuit to OPERABLE status. (continued) Point Beach 3.8.2-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

AC Sources-Shutdown 3.8.2 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME B. One required standby B.1 Declare affected Immediately emergency power source required feature(s) with inoperable. no standby emergency power source available inoperable. B.2 Initiate action to restore Immediately required standby emergency power source to OPERABLE status. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.2.1 Verify correct breaker alignment and indicated In accordance with power availability for each required offsite circuit. the Surveillance Frequency Control Program SR 3.8.2.2 ---------------------------N 0 TE--------------------------- A II standby emergency power source starts may be preceded by an engine prelube period and followed by a warmup period prior to loading. In accordance with Verify each required standby emergency power the Surveillance source starts from standby conditions and Frequency Control achieves rated voltage and frequency. Program SR 3.8.2.3 Verify the fuel oil transfer system operates to In accordance with automatically transfer fuel oil from storage tank to the Surveillance the day tank. Frequency Control Program (continued) Point Beach 3.8.2-2 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

AC Sources-Shutdown 3.8.2 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.8.2.4 ---------------------------N()TE--------------------------- The following SR is not required to be performed if it is not met solely due to an expired frequency. Verify on an actual or simulated loss of offsite In accordance with power signal: the Surveillance Frequency Control

1. De-energization of the safeguards buses; Program

2. Load shedding of the 480 V safeguards bus;

3. Standby emergency power source auto-starts from standby condition and energizes the safeguards buses, and

4. supplies bus loads for ~ 5 minutes.

SR 3.8.2.5 ---------------------------N()TE--------------------------- The following SR is not required to be performed if it is not met solely due to an expired frequency. Verify each standby emergency power source In accordance with synchronizes with offsite power source upon a the Surveillance simulated restoration of offsite power and returns Frequency Control to ready-to-load operation. Program Point Beach 3.8.2-3 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

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 Stored diesel fuel oil shall be within limits and starting air subsystem shall be OPERABLE for each required standby emergency power source. APPLICABILITY: When associated standby emergency power source is required to be OPERABLE. ACTIONS

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

Separate Condition entry is allowed for each standby emergency power source. CONDITION REQUIRED ACTION COMPLETION TIME A. One or more standby A.1 Restore fuel oil level to 48 hours2 days 0.286 weeks 0.0658 months emergency power within limits. sources with fuel fevel

       < 86.2% and> 71.3% in storage tank.

B. One or more standby B.1 Restore fuel oil total 7 days emergency power particulates within limit sources with stored fuel oil total particulates not within limit. C. One or more standby C.1 Restore stored fuel oil 30 days emergency power properties to within sources with new fuel oil limits. properties not within limits. (continued) Point Beach 3.8.3-1 Unit 1 - Amendment No. 244 Unit 2 - Amendment No. 248

Diesel Fuel Oil and Starting Air 3.8.3 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME D. One or more standby D.1 Declare associated Immediately emergency power sources standby emergency with inoperable starting air power source{s) system(s). inoperable. E. Required Action and E.1 Declare associated Immediately associated Completion standby emergency Time not met. power source(s) inoperable. OR One or more standby emergency power sources' diesel fuel oil not within limits for reasons other than Condition A, B or C. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify each fuel oil storage tank contains ?: 86.2% of In accordance with fuel. the Surveillance Frequency Control ProQram SR 3.8.3.2 Verify fuel oil properties of new and stored fuel oil are In accordance with tested in accordance with, and maintained within the the Diesel Fuel Oil limits of, the Diesel Fuel Oil Testing Program. Testing Program SR 3.8.3.3 Verify each standby emergency power source air start In accordance with bottle bank pressure is ?: 165 psig. the Surveillance Frequency Control Program SR 3.8.3.4 Check for and remove accumulated water from In accordance with each fuel oil storage tank. the Surveillance Frequency Control Program Point Beach 3.8.3-2 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

Diesel Fuel Oil and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.8.3.4 Check for and remove accumulated water from 92 days each fuel oil storage tank. Point Beach 3.8.3-3 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

DC Sources-Operating 3.8.4 3.8 ELECTRICAL POWER SYSTEMS 3.8.4 DC Sources-Operating LCO 3.8.4 The D-01, D-02, D-03, and D-04 DC electrical power subsystems shall be OPERABLE. APPLICABILITY: MODES 1, 2, 3, and 4. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One DC electrical power -----------------N 0 TE---------------- subsystem inoperable. Enter applicable Conditions and Required Actions of LCO 3.8.9, "Distribution Systems-Operating," when any DC bus is de-energized.

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

A.1 Restore DC electrical 2 hours0.0833 days 0.0119 weeks 0.00274 months power subsystem to OPERABLE status. B. Required Action and B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months Associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify correct battery terminal voltage is within In accordance limits on float charge. with the Surveillance Frequency Control Program (continued) Point Beach 3.8.4-1 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.8.4.2 Verify no visible corrosion at battery terminals In accordance and connectors. with the Surveillance Frequency Control Program Verify battery connection resistance is within limits. SR 3.8.4.3 Verify battery cells, cell plates, and racks show In accordance no visual indication of physical damage or with the abnormal deterioration that could degrade Surveillance battery performance. Frequency Control Program SR 3.8.4.4 Remove visible terminal corrosion, and verify In accordance battery cell to cell and terminal connections are with the coated with anti-corrosion material. Surveillance Frequency Control Program SR 3.8.4.5 Verify battery connection resistance is within In accordance limits. with the Surveillance Frequency Control Program (continued) Point Beach 3.8.4-2 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.8.4.6 Verify battery chargers D-07, D-08, and D-09, while In accordance operating at the current limit setting, each supply with the

320 amps at greater than or equal to the minimum Surveillance established float voltage for

;::: 8 hours0.333 days 0.0476 weeks 0.011 months , and battery Frequency chargers 0-107, D-108, and D-109, while operating Control Program at the current limit setting, each supply:;::: 420 amps at greater than or equal to the minimum established float voltage for :;: : 8 hours0.333 days 0.0476 weeks 0.011 months .

Verify each battery charger can recharge the battery to the fully charged state within 24 hours1 days 0.143 weeks 0.0329 months while supplying the largest combined demands of the various continuous steady-state loads, after a battery discharge to the bounding design basis event discharge state. SR 3.8.4.7 -------------------------N 0 TES------------------------- T he modified performance discharge test in SR 3.8.4.8 may be performed in lieu of SR 3.8.4.7. In accordance Verify battery capacity is adequate to supply, with the and maintain in OPERABLE status, the required Surveillance emergency loads for the design duty cycle when Frequency subjected to a battery service test. Control Program (continued) Point Beach 3.8.4-3 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.8.4.8 Verify battery capacity is ::::: 80% of the In accordance manufacturer's rating when subjected to a with the performance discharge test or a modified Surveillance performance discharge test. Frequency Control Program 12 months when battery shows degradation or has reached 85% of expected life with capacity

                                                                  < 100% of manufacturer's rating 24 months when battery has reached 85% of the expected life with capacity 2100%of manufacturer's ratina Point Beach                         3.8.4-4              Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

DC Sources-Shutdown 3.8.5 3.8 ELECTRICAL POWER SYSTEMS 3.8.5 DC Sources-Shutdown LCO 3.8.5 DC electrical power subsystem shall be OPERABLE to support the DC electrical power distribution subsystem(s) required by LCO 3.8.10, Distribution Systems-Shutdown." APPLICABILITY: MODES 5 and 6. ACTIONS CONDITION REQUIRED ACTION COMPLETlONTIME A. One or more required A.1 Declare affected required Immediately DC electrical power feature(s) inoperable. subsystems inoperable. AND A.2 Initiate action to restore Immediately required DC electrical power subsystems to OPERABLE status. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.5.1 For DC sources required to be OPERABLE, the In accordance with following SRs are applicable: applicable SRs SR 3.8.4.1 SR 3.8.4.4 SR 3.8.4.7 SR 3.8.4.2 SR 3.8.4.5 SR 3.8.4.8. SR 3.8.4.3 SR 3.8.4.6 Point Beach 3.8.5-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

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 safety related batteries shall be within limits. APPLICABILITY: When associated DC electrical power subsystems are required to be OPERABLE. ACTIONS

            ----
              --- ----------- ---    --- ---- --- ----   --- --   N-1M      c- - - - - -  -  - - - - -  - --  - - - - -  - - - - - - -

Separate Condition entry is allowed for each battery.

  - - - - - --
  --             - - - - - - --          - - - - - --   - - - - - - --  - - - - - - --   - - - - - --  - - - - - --.-     - - - - -

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more batteries A.1 Verify pilot cell(s) 1 hour with one or more battery electrolyte level and cell parameters not float voltage meet within Table 3.8.6-1 Table 3.8.6-1 Category A or B limits. Category C limits. AND A.2 Verify battery cell 24 hours1 days 0.143 weeks 0.0329 months parameters meet Table 3.8.6-1 AND Category C limits. Once per 7 days thereafter AND A.3 Restore battery cell 31 days parameters to Table 3.8.6-1 Category A and B limits. (continued) Point Beach 3.8.6-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Battery Cell Parameters 3.8.6 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Declare associated Immediately associated Completion battery inoperable. Time of Condition A not met. One or more batteries with average electrolyte temperature of the representative cells< 60°F. One or more batteries with one or more battery cell parameters not within Table 3.8.6-1 Category C values. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 Verify battery cell parameters meet Table 3.8.6-1 In accordance with Category A limits. the Surveillance Frequency Control Program (continued) Point Beach 3.8.6-2 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

Battery Cell Parameters 3.8.6 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.8.6.2 Verify battery cell parameters meet Table 3.8.6-1 In accordance with Category B limits. the Surveillance Frequency Control Program Once within 24 hours1 days 0.143 weeks 0.0329 months after a battery discharge

                                                                   < 105 v Once within 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> after a battery overcharge
                                                                   > 142.8 v SR 3.8.6.3  Verify average electrolyte temperature of              In accordance with representative cells is ~ 60°F.                       the Surveillance Frequency Control Program Point Beach                          3.8.6-3              Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

Battery Cell Parameters 3.8.6 Table 3.8.6-1 (page 1 of 1) Battery Cell Parameters Requirements PARAMETER CATEGORY A: CATEGORY B: CATEGORY C: LIMITS FOR EACH LIMITS FOR EACH ALLOWABLE DESIGNATED CONNECTED LIMITS FOR EACH PILOT CELL CELL CONNECTED CELL Electrolyte Level > Minimum level > Minimum level Above top of plates, indication mark, indication mark, and not overflowing and < 1/4 inch above and < %A inch above maximum level maximum level indication mark (a) indication mark (a) Float Voltage 2 2.13 V 2 2.13 V > 2.07 V Specific Gravity 2 1.200 2 1.195 Not more than (b)(c) 0.020 below AND average of all connected cells Average of all connected cells AND

                                                   > 1.205 Average of all connected cells 2 1.195 (a)     It is acceptable for the electrolyte level to temporarily increase above the specified maximum during equalizing charges provided it is not overflowing.

(b) Corrected for electrolyte temperature and level. Level correction is not required, however, when battery charging is < 2 amps when on float charge. (c) 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. Point Beach 3.8.6-4 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Inverters-Operating 3.8.7 3.8 ELECTRICAL POWER SYSTEMS 3.8.7 Inverters-Operating LCO 3.8.7 Four inverters shall be OPERABLE. APPLICABILITY: MODES 1, 2, 3, and 4. ACTI ONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required inverter A.1 ----------- NOTE------------ inoperable. Enter applicable Conditions and Required Actions of LCO 3.8.9, Distribution Systems - Operating with any vital bus de-energized. Restore inverter to 8 hours0.333 days 0.0476 weeks 0.011 months OPERABLE status. B. Required Action and B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months Point Beach 3.8.7-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Inverters-Operating 3.8.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct inverter voltage, and alignment to In accordance required AC vital instrument buses. with the Surveillance Frequency Control Program Point Beach 3.8.7-2 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

Inverters-Shutdown 3.8.8 3.8 ELECTRICAL POWER SYSTEMS 3.8.8 Inverters-Shutdown LCO 3.8.8 Inverters shall be OPERABLE to support the onsite Class 1 E AC vital instrument bus electrical power distribution subsystem(s) required by LCO 3.8.10, "Distribution Systems-Shutdown." APPLICABILITY: MODES 5 and 6. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Declare affected Immediately inverters inoperable. required feature(s) inoperable. A.2 Initiate action to restore Immediately required inverters to OPERABLE status. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct inverter voltage and alignments to In accordance required AC vital instrument buses. with the Surveillance Frequency Control Program Point Beach 3.8.8-1 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

- -

Distribution Systems-Operating 3.8.9 3.8 ELECTRICAL POWER SYSTEMS 3.8.9 Distribution Systems-Operating LCO 3.8.9 The following electrical distribution buses shall be OPERABLE:

a. The 4.16 kV Class 1E safeguards buses lA05, 1A06, 2A05, and 2A06;

b. The 480 V Class 1E safeguards buses 1 B03, 1B04, 2B03, and 2B04;

c. The associated unit's 120 VAC Vital Instrument Buses Y01, Y02, Y03, Y04, Y101, Y102, Y103, and Y104;

d. DC distribution buses D01, D02, D03 and D04.

e. Motor Control Centers 1B30/2B30, 1B32/2B32, 1B40/2B40 and 1B42/2B42.

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

1. The opposite unit's 480 V Class 1E safeguards buses B03 and B04, may be cross-tied for < 8 hours0.333 days 0.0476 weeks 0.011 months providing;

a. The opposite unit is in MODE 5, or 6, or defueled;

b. All required redundant shared features for the unit in MODE 1, 2, 3, or 4 are OPERABLE; and

c. All AC electrical power sources required by LCO 3.8.1 for the required redundant shared features for the unit in MODE 1, 2, 3, or 4 are OPERABLE.

2. The opposite units 480 V Class 1E safeguards buses B03 and B04, may be cross-tied for > 8 hours0.333 days 0.0476 weeks 0.011 months and < 7 days providing;

a. The opposite unit is defueled;

b. All required redundant shared features for the unit in MODE 1, 2, 3, or 4 are OPERABLE;

c. All AC electrical power sources required by LCO 3.8.1 for the required redundant shared features for the unit in MODE 1, 2, 3, or 4 are OPERABLE; and

d. Loads on the cross-tied buses are limited to preclude overloading of their standby emergency power source.

                                                          ...........---.-.---.---.--.----..---............-------------..------------........

APPLICABILITY: MODES 1, 2, 3, and 4. Point Beach 3.8.9-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Distribution Systems-Operating 3.8.9 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more electrical A.1 Declare associated Immediately power distribution supported required subsystem inoperable. feature(s) inoperable. B. Required Action and B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.9.1 Verify correct breaker alignments and power In accordance available for required AC, DC, and AC vital with the instrument bus electrical power distribution Surveillance subsystems. Frequency Control Program Point Beach 3.8.9-2 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

Distribution Systems-Shutdown 3.8.10 3.8 ELECTRICAL POWER SYSTEMS 3.8.10 Distribution Systems-Shutdown LCO 3.8.1 0 The necessary portion of AC, DC, and AC vital instrument bus electrical power distribution subsystems shall be OPERABLE to support equipment required to be OPERABLE.

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

The unit specific 480 V Class 1E safeguards buses B03 and B04, may be cross-tied for

8 hours0.333 days 0.0476 weeks 0.011 months providing;

1. Two residual heat removal loops are OPERABLE when the unit is in MODE 5 or MODE 6 with reactor cavity water level < 23 ft above the top of reactor vessel flange; or

2. One residual heat removal loop is OPERABLE when the unit is in MODE 6 with reactor cavity water level 2 23 ft above the top of reactor vessel flange.

APPLICABILITY: MODES 5 and 6. ACTIONS CONDITION REQUIRED ACTION COMPLETlONTIME A. One or more required A.1 Declare associated Immediately electrical power supported required distribution subsystems feature(s) inoperable. inoperable. AND A.2 Initiate actions to Immediately restore required AC, DC, and AC vital instrument bus electrical power distribution subsystems to OPERABLE status. Point Beach 3.8.10-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Distribution Systems-Shutdown 3.8.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.10.1 Verify correct breaker alignments and power In accordance available for required AC, DC, and AC vital with the instrument bus electrical power distribution Surveillance subsystems. Frequency Control Program Point Beach 3.8.10-2 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

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, the refueling canal, and the refueling cavity shall be maintained within the limit specified in the COLR. APPLICABILITY: MODE 6. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Boron concentration not A.1 Suspend positive Immediately within limit. reactivity additions. A.2 Initiate action to restore Immediately boron concentration to within limit. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Verify boron concentration is within the limit In accordance specified in the COLR. with the Surveillance Frequency Control Program Point Beach 3.9.1-1 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

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. AND One source range audible count rate circuit shall be OPERABLE. APPLICABILITY: MODE 6. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required source A.1 Suspend positive Immediately range neutron flux reactivity additions. monitor inoperable. B. Two required source B.1 Initiate action to restore Immediately range neutron flux one source range monitors inoperable, neutron flux monitor to OPERABLE status. AND B.2 Perform SR 3.9.1.1. Once per 12 hours0.5 days 0.0714 weeks 0.0164 months C. Required source range C.1 Initiate action to isolate Immediately audible count rate circuit unborated water inoperable, sources. Point Beach 3.9.2-1 Unit 1 - Amendment No. 224 Unit 2 - Amendment No. 230

Nuclear Instrumentation 3.9.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.9.2.2 ---------------------------N()TE-------------------------- Neutron detectors are excluded from CHANNEL CALIBRATl()N. In accordance Perform CHANNEL CALIBRATl()N. with the Surveillance Frequency Control Program Point Beach 3.9.2-2 Unit 1 - Amendment No. 253 Unit 2 Amendment No. 257

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 with all bolts;

b. One door in each air lock is capable of being closed; and

c. Each Containment Purge and Exhaust System penetration either:

1. closed by a manual or automatic isolation valve, blind flange, or equivalent, or

2. capable of being closed by an OPERABLE Containment Purge and Exhaust Isolation System.

APPLICABILITY: During movement of recently irradiated fuel assemblies within I containment. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Suspend movement of Immediately containment recently irradiated fuel penetrations not in assemblies within required status. containment. Point Beach 3.9.3-1 Unit 1 - Amendment No. 213 Unit 2 - Amendment No. 218

Containment Penetrations 3.9.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Verify each required containment penetration is In accordance in the required status. with the Surveillance Frequency Control Program SR 3.9.3.2 ---------------------------N()TE------------------------- Not applicable to containment purge and exhaust valve(s) in penetrations closed to comply with LC() 3.9.3.c.1. In accordance with the Verify each required containment purge and Surveillance exhaust valve actuates to the isolation position Frequency on an actual or simulated actuation signal. Control Program Point Beach 3.9.3-2 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

RHR and Coolant Circulation-High Water Level 3.9.4 3.9 REFUELING OPERATIONS 3.9.4 Residual Heat Removal (RHR) and Coolant Circulation-High Water Level LCO 3.9.4 One RHR loop shall be OPERABLE and in operation.

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

The required RHR loop may be not in operation for S 1 hour per 8 hour period, provided no operations are permitted that would cause reduction of the Reactor Coolant System boron concentration. APPLICABILITY: MODE 6 with the water level 2 23 ft above the top of reactor vessel flange. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RHR loop requirements A.1 Suspend operations Immediately not met. involving a reduction in reactor coolant boron concentration. AND A.2 Suspend loading Immediately irradiated fuel assemblies in the core. AND A.3 Initiate action to satisfy Immediately RHR loop requirements. Point Beach 3.9.4-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

RHR and Coolant Circulation-High Water Level 3.9.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.4.1 Verify one RHR loop is in operation. In accordance with the Surveillance Frequency Control Program SR 3.9.4.2 Verify required RHR loop locations susceptible In accordance to gas accumulation are sufficiently filled with with the water. Surveillance Frequency Control Program Point Beach 3.9.4-2 Unit 1 - Amendment No.253 Unit 2 - Amendment No.257

RHR and Coolant Circulation-Low Water Level 3.9.5 3.9 REFUELING OPERATIONS 3.9.5 Residual Heat Removal (RHR) 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 restore Immediately number of RHR loops required RHR loops to OPERABLE. OPERABLE status. OR A.2 Initiate action to Immediately establish 2 23 ft of water above the top of reactor vessel flange. B. No RHR loop in B.1 Suspend operations Immediately operation. involving a reduction in reactor coolant boron concentration. AND B.2 Initiate action to restore Immediately one RHR loop to operation. Point Beach 3.9.5-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

RHR and Coolant Circulation-Low Water Level 3.9.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify one RHR loop is in operation. In accordance with the Surveillance Frequency Control Program SR 3.9.5.2 Verify correct breaker alignment and indicated In accordance power available to the required RHR pump that with the is not in operation. Surveillance Frequency Control Program SR 3.9.5.3 Verify RHR loop locations susceptible to gas In accordance accumulation are sufficiently filled with water. with the Surveillance Frequency Control Proqram Point Beach 3.9.5-2 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

Refueling Cavity Water Level 3.9.6 3.9 REFUELING OPERATIONS 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 movement of irradiated fuel assemblies within containment. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refueling cavity water A.1 Suspend movement of Immediately level not within limit. irradiated fuel assemblies within containment. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify refueling cavity water level is :;::: 23 ft In accordance above the top of reactor vessel flange. with the Surveillance Frequency Control Program Point Beach 3.9.6-1 Unit 1 - Amendment No. 253 Unit 2 - Amendment No. 257

Design Features 4.0 4.0 DESIGN FEATURES 4.1 Site Location The Point Beach Nuclear Plant is located on property owned by NextEra Energy Point Beach at a site on the shore of Lake Michigan , approximately 30 miles southeast of the city of Green Bay . The minimum distance from the reactor containment center line to the site exclusion boundary as defined in 10 CFR 100.3 is 1200 meters. 4.2 Reactor Core 4.2.1 Fuel Assemblies The reactor shall contain 121 fuel assemblies. Each assembly shall consist of a matrix of Zircaloy-4, ZIRLO, or Optim ized ZIRLO ' fuel rods with an initial composition of natural or slightly enriched uranium dioxide (U02) as fuel material. Limited substitutions of zircon ium alloy or stainless steel filler rods or vacancies for fuel rods, in accordance with approved applications of fuel rod 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 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 Rod Cluster Control (RCC) Assemblies The reactor core shall contain 33 RCC assemblies. The control material shall be silver indium cadmium alloy clad with stainless steel as approved by the NRC . Point Beach 4.0-1 Unit 1 - Amendment No. 249 Un it 2 -Amendment No. 253

Design Features 4.0 4.0 DESIGN FEATURES 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. kef! < 1.0 if fully flooded with unborated water, which includes an allowance for uncertainties as described in Reference 1;

c. kef! S 0.95 if fully flooded with water borated to 402 ppm, which includes an allowance for uncertainties as described in Reference 1;

d. A nominal 9.825 inch center to center distance between fuel assemblies placed in the fuel storage racks;

e. New or spent fuel assemblies with a combination of discharge burnup, initial enrichment and decay time in the "Acceptable" range of Figure 3.7.12-1 may be allowed unrestricted storage in the fuel storage racks; and

f. New or spent fuel assemblies with a combination of discharge burnup, initial enrichment and decay time in the "Unacceptable" range of Figure 3.7.12-1 will be stored in compliance with Figures 4.3.1-1 through 4.3.1-8.

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. kef! S 0.95 if fully flooded with unborated water, which includes an allowance for uncertainties as described in Section 9.4 of the FSAR;

c. kef! S 0.98 under optimum moderator density conditions, which includes an allowance for uncertainties as described in Section 9.4 of the FSAR; and

d. A nominal 20 inch center to center distance between fuel assemblies placed in the storage racks.

Point Beach 4.0-2 Unit 1 - Amendment No. -236 Unit 2 - Amendment No. 240

Design Features 4.0 4.0 DESIGN FEATURES L1 H1 L1 L1 H1: Fresh fuel assembly with maximum 5.0 wlo U-235. No restriction on burnup. L1: Spent fuel assemblies in the "Acceptable" range of Figure 4.3.1-6. Figure 4.3.1-1 1-0ut-of-4 for 5 wlo with no IFBA Storage Configuration Point Beach 4.0-4 Unit 1 - Amendment No. 236 Unit 2 - Amendment No. 240

Design Features 4.0 4.0 DESIGN FEATURES L2 H2 L2 L2 H2: Fresh fuel assembly with maximum 4.0 wlo U-235 with no IFBA or maximum 5.0 wlo U-235 with IFBA in the "Acceptable" range of Figure 4.3.1-8. No restriction on burnup. L2: Spent fuel assemblies in the "Acceptable" range of Figure 4.3.1-7. Figure 4.3.1-2 1-0ut-of-4 for 4 wlo with IFBA Storage Configuration Point Beach 4.0-5 Unit 1 - Amendment No. 236 Unit 2 - Amendment No. 240

Design Features 4.0 4.0 DESIGN FEATURES A A A A A A A I A A A A A A A A A A A A A A Qj s: L1 L1 L1 L1 A A A UI 1Il e u.. << o j H1 L1 H1 L1 A A A II)

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I H1 L1 H1 L1 A I A A A: Fuel assembly in "Acceptable" range of Figure 3.7.12-1. H1 : Fresh fuel assembly with maximum 5.0 wlo U-235. No restriction on burnup. L1: Spent fuel assemblies in the "Acceptable" range of Figure 4.3.1-6. Figure 4.3.1-3 1-0ut-of-4 for 5 wlo with no IFBA I "All Cell" Interface Point Beach 4.0-6 Unit 1 - Amendment No. 236 Unit 2 - Amendment No. 240

Design Features 4.0 4.0 DESIGN FEATURES A A A A A A A A A A A A A A

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o I H2 L2 H2 L2 A A A or-I A: Fuel assembly in "Acceptable" range of Figure 3.7.12-1. H2: Fresh fuel assembly with maximum 4.0 wlo U-235 with no IFBA or maximum 5.0 wlo U-235 with IFBA in the "Acceptable" range of Figure 4.3.1-8. No restriction on burn up. L2: Spent fuel assemblies in the "Acceptable" range of Figure 4.3.1-7. Figure 4.3.1-4 1-0ut-of-4 for 4 wlo with IFBA I "All Cell" Interface Point Beach 4.0-7 Unit 1 - Amendment No. 236 Unit 2 - Amendment No. 240

Design Features 4.0 4.0 DESIGN FEATURES L1 L1 L1 L1 L1 L1 L1 L1 H1 L1 H1 L1 H1 L1

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I I H2 L2 H2 L2 L1 L1 L1 H1: Fresh fuel assembly with maximum 5.0 wlo U-235. No restriction on burnup. L1: Spent fuel assemblies in the "Acceptable" range of Figure 4.3.1-6. H2: Fresh fuel assembly with maximum 4.0 wlo U-235 with no IFBA or maximum 5.0 wlo U-235 with IFBA in the "Acceptable" range of Figure 4.3.1-8. No restriction on burnup. L2: Spent fuel assemblies in the "Acceptable" range of Figure 4.3.1-7. Figure 4.3.1-5 1-0ut-of-4 for 4 wlo with IFBA I 1-0ut-of-4 for 5 wlo with no IFBA Point Beach 4.0-8 Unit 1 - Amendment No. 236 Unit 2 - Amendment No. 240

Design Features 4.0 4.0 DESIGN FEATURES 55,000 a yr decay 1"1 I I II

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I' I a v ! I I I I 1.0 1.5 2.0 2.5 3.0 35 4.0 4.5 5.0 Nominal Initial U-235 Enrichment (w/o) o yr decay = 428.92e 3 - 5757.04e 2 + 36677.22e - 39606.18 5 yr decay = 354.71e 3 - 4760.55e 2 + 31941.4ge - 34895.75 10 yr decay= 346.35e 3 - 4566.17e 2 + 30296.34e - 33031.86 15 yr decay= 321.26e 3 - 4212.08e 2 + 28522.05e - 31239.39 20 yr decay= 326.36e 3 - 4138.31e 2 + 27551.88e - 30091.55 Figure 4.3.1-6 Spent Fuel Assembly Burnup Requirements for 1-0ut-of-4 for 5.0 w/o with no IFBA Point Beach 4.0-9 Unit 1 - Amendment No. 236 Unit 2 - Amendment No. 240

Design Features 4.0 4.0 DESIGN FEATURES 45,000 1 I I

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I I I l o II I I I 1 I II 15 2.0 2.5 30 3? 40 45 5.0 Nominal Initial U-235 Enrichment (w/o) o yr decay = 212.05e 3 - 3290.58e 2 + 26798.27e - 35321.90 5 yr decay = 461.10e 3 - 5538.1ge 2 + 32070.67e - 39023.97 10 yr decay= 290.71e 3 - 3744.4ge 2 + 25822.24e - 32920.44 15 yr decay= 316.33e 3 - 3898.92e 2 + 25546.37e - 32188.62 20 yr decay= 286.15e 3 - 3716.74e 2 + 25117.81e - 31845.90 Figure 4.3.1-7 Spent Fuel Assembly Burnup Requirements for 1-0ut-of-4 for 4.0 wlo with IFBA Point Beach 4.0-10 Unit 1 - Amendment No. 236 Unit 2 - Amendment No. 240

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o V 4.0 4.2 4.4 4.6 48 5.0 Nominal U-235 Initial Enrichment (w/o) I Number of IFBA pins = 2e2 + 21e - 116 Figure 4.3.1-8 Fresh FuellFBA Requirements Point Beach 4.0-11 Unit 1 - Amendment No. 236 Unit 2 - Amendment No. 240

Responsibility 5.1 5.0 ADMINISTRATIVE CONTROLS 5.1 Responsibility 5.1.1 The Plant Manager shall be responsible for overall facility 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 Duty Shift Superintendent (DSS) shall be responsible for the control room command function. During any absence of the DSS from the control room while either unit is in MODE 1, 2, 3, or 4, an individual with an active Senior Reactor Operator (SRO) license shall be designated to assume the control room command function. During any absence of the DSS from the control room while both units are in MODE 5 or 6, an individual with an active SRO license or Reactor Operator license shall be designated to assume the control room command function. Point Beach 5.1-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

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 communication 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;

b. The Plant Manager shall be responsible for overall safe operation of the plant and shall have control over those onsite activities necessary for safe operation and maintenance of the plant;

c. A specified corporate officer 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.

Point Beach 5.2-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Organization 5.2 5.2 Organization 5.2.2 Facility Staff The facility 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 when either 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.e for a period of time not to exceed 2 hours0.0833 days 0.0119 weeks 0.00274 months in order to accommodate unexpected absence of on-duty shift crew members provided immediate 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 either reactor. The position may be vacant for not more than 2 hours0.0833 days 0.0119 weeks 0.00274 months , in order to provide for unexpected absence, provided immediate action is taken to fill the required position.

d. The Operations Manager or Assistant Operations Manager shall hold an SRO License at Point Beach.

e. An individual shall provide advisory technical support to the operations shift crew in the areas of thermal hydraulics, reactor engineering, and plant analysis with regard to the safe operation of the facility. This individual shall meet the qualifications specified by the Commission Policy Statement on Engineering Expertise on Shift.

Point Beach 5.2-2 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Unit Staff Qualifications 5.3 5.0 ADMINISTRATIVE CONTROLS 5.3 Facility Staff Qualifications 5.3.1 Each member of the facility staff shall meet or exceed the minimum qualifications of ANSI N18.1-1971, as supplemented by Regulatory Guide 1.8, Revision 1, September 1975, for comparable positions, except: a) The education and experience eligibility requirements for license applicants, and changes thereto, shall be those previously reviewed by the NRC, specifically those referenced in NRC Safety Evaluation letter dated October 24, 2003. b) The Operations Manager shall meet one of the following: i) Hold a Senior Operator's license, or ii) Have held a Senior Operator's license on a similar unit (PWR), or iii) Have been certified for equivalent Senior Operator knowledge. 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). 5.3.3 In the event the position of Health Physicist is vacated and the proposed replacement does not meet all the qualifications of TS 5.3.1, but is determined to be otherwise well qualified, the concurrence of NRC shall be sought in approving the qualification of that individual. Point Beach 5.3-1 Unit 1 - Amendment No. 248 Unit 2 - Amendment No. 252

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. Normal sequences of startup, operation and shutdown of components, systems and overall plant;

b. Refueling;

c. Specific and foreseen potential malfunctions of systems or components including abnormal reactivity changes;

d. Security Plan Implementation;

e. 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;

f. Nuclear core testing;

g. Surveillance and Testing of safety related equipment;

h. (Deleted)

i. Quality Assurance for effluent and environmental monitoring;

j. All programs specified in Specification 5.5.

Point Beach 5.4-1 Unit 1 - Amendment No. 256 Unit 2 - Amendment No. 260

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 (ODCM)

a. The ODCM 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 O)DCM shall also contain the radioactive effluent controls and radiolcgical environmental monitoring activities, and descriptions of the information that should be included in the Annual Monitoring Report required by Specification 5.6.2.

c. Licensee initiated changes to the ODCM:

1. Shall be documented and records of reviews performed shall be retained. This documentation shall contain:

i. sufficient information to support the change(s) together with the appropriate analyses or evaluations justifying the change(s), and ii. 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 ODCM as a part of or concurrent with the Annual Monitoring Report for the period of the report in which any change in the ODCM 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.

Point Beach 5.5-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Programs and Manuals 5.5 5.5 Programs and Manuals 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 Containment Spray, Safety Injection (High Head) and Safety Injection (Low Head) systems. 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.

5.5.3 Post Accident Sampling This program provides controls that ensure the capability to obtain and analyze reactor coolant, radioactive gases, and particulates in plant gaseous effluents and containment atmosphere samples under accident conditions. The program shall include the following:

a. Training of personnel;

b. Procedures for sampling and analysis; and

c. Provisions for maintenance of sampling and analysis equipment.

Point Beach 5.5-2 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.4 Radioactive Effluent Controls Program This program conforms to 10 CFR 50.36a for the control of radioactive effluents and for maintaining the doses to members of the public from radioactive effluents as low as reasonably achievable. The program shall be contained in the ODCM, shall be implemented by procedures, and shall include remedial actions to be taken whenever the program limits are exceeded. The program shall include the following elements:

a. Limitations on the functional capability of radioactive liquid and gaseous monitoring instrumentation including surveillance tests and setpoint determination in accordance with the methodology in the ODCM;

b. Limitations on the concentrations of radioactive material released in liquid effluents to unrestricted areas, conforming to ten times the concentration values in Appendix B, Table 2, Column 2 to 10 CFR 20.1001-20.2402;

c. Monitoring, sampling, and analysis of radioactive liquid and gaseous effluents in accordance with 10 CFR 20.1302 and with the methodology and parameters in the ODCM;

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 1;

e. Determination of cumulative and projected 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;

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 l; Point Beach 5.5-3 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.4 Radioactive Effluent Controls Program (continued)

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 in accordance with the following:

1. For noble gases: a dose rate

500mrem/yr to the whole body and a dose rate
3000 mrem/yr to the skin, and

2. For iodine-131, iodine-133, tritium, and all radionuclides in particulate form with half-lives greater than 8 days: a dose rate

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 l;

i. Limitations on the annual and quarterly doses to a member of the public from iodine-131, iodine-133, 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 l; 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 Effluent Controls Program surveillance frequency. Point Beach 5.5-4 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Programs and Manuals 5.5 5.5 Programs and Manuals. 5.5.5 Component Cyclic or Transient Limit This program provides controls to-track the FSAR, Section 4.1, cyclic and transient occurrences to ensure that components are maintained within the design limits. 5.5.6 Reactor Coolant Pump Flywheel Inspection Proaram This program shall provide for the inspection of each reactor coolant pump flywheel per the recommendations of Regulatory Position c.4.b of Regulatory Guide 1.14, Revision 1, August 1975. In lieu of Position c.4.b(1)and c.4.b(2), a qualified in-place UT examination over the volume from the Inner bore of the flywheel to the circle one-half of the outer radius or a surface examination (MT andlor PT) of exposed surfaces of the removed flywheels may be conducted at 20 year intervals. I Point Beach 5.5-5 Unit 1 -Amendment No. ZL8 Unit 2 -Amendment No. 2Z3

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 DELETED Point Beach 5.5-6 Unit 1 - Amendment No. 2591 Unit 2 - Amendment No. 263

Programs and Manuals 5.5 5.5 Programs and Manuals 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), and 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 leakage rate assumed in the accident analysis in terms of total leakage rate Point Beach 5.5-7 Unit 1 - Amendment No. 254 Unit 2 - Amendment No. 258

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.8 Steam Generator (SG) Program (continued) for all SGs and leakage rate for an individual SG. Leakage is not to exceed 500 gallons per day per SG.

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.

The following alternate tube plugging criteria shall be applied as an alternative to the 40% depth based criteria: For Unit 1 only, tubes with service-induced flaws located greater than 20.6 inches below the top of the tubesheet do not require plugging. Tubes with service-induced flaws located in the portion of the tube from the top of the tubesheet to 20.6 inches below the top of the tubesheet shall be plugged upon detection. This alternate tube plugging criteria is not applicable to the tube at row 38 column 69 in the A steam generator, which is not expanded in the hot leg the full length of the tubesheet. This tube has been removed from service by plugging (during U1 R31 ).

d. Provisions for SG tube inspections. Periodic SG tube inspections shall be performed. For Unit 1, 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 20.6 inches below the top of the tubesheet on the hot leg side to 20.6 inches below the top of the tubesheet on the cold leg side and that may satisfy the applicable tube plugging criteria. For Unit 2, 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.

Point Beach 5.5-8 Unit 1 - Amendment No. 260 Unit 2 - Amendment No. 258

Programs and Manuals 5.5 5.5 Programs and Manuals For Unit 1 and Unit 2: 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 location.

1. Inspect 100% of the tubes in each SG during the first refueling outage following SG installation.

2. i. Unit 1 (alloy 600 Thermally Treated tubes): After the first refueling outage following SG installation, inspect each SG at least every 48 effective full power months or at least every other 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, and c 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 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 120 effective full power months. This constitutes the first inspection period; b) During the next 96 effective full power months, inspect 100% of the tubes. This constitutes the second inspection period; and Point Beach 5.5-8a Unit 1 - Amendment No. 260 Unit 2 - Amendment No. 258

Programs and Manuals 5.5 5.5 Programs and Manuals c) During the remaining life of the SGs, inspect 100% of the tubes every 72 effective full power months. This constitutes the third and subsequent inspection periods. ii. Unit 2 (alloy 690 Thermally Treated tubes): 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 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. Point Beach 5.5-9 Unit 1 - Amendment No. 260 Unit 2 - Amendment No. 258

Programs and Manuals 5.5 5.5 Programs and Manuals

3. For Unit 1, if crack indications are found in any SG tube from 20.6 inches below the top of the tubesheet on the hot leg side to 20.6 inches below the top of the tubesheet on the cold leg side, 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-like indication is not associated with a crack(s}, then the indication need not be treated as a crack.

For Unit 2, 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-like 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.

Point Beach 5.5-10 Unit 1 - Amendment No. 260 Unit 2 - Amendment No. 258

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 discharge of the condensate pumps 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.

5.5.10 Ventilation Filter Testing Program (VFTP) A program shall be established to implement the following required testing of the Control Room Emergency Filtration System (F-16) at the frequencies specified in Regulatory Guide 1.52, Revision 2, and in accordance with ASTM D3803-1989 and the methodology of ANSI N510-1980, as prescribed below.

a. Demonstrate for the Control Room Emergency Filtration System (F-16) that an in place test of the high efficiency particulate air (HEPA) filters shows a penetration and system bypass ~1.0% when tested in accordance with the methodology of ANSI N510-1980, Section 10, excluding subsection 10.3, at a system flowrate of 4950 cfm +/- 10%.

b. Demonstrate for the Control Room Emergency Filtration System (F-16) that an in place test of the charcoal adsorber shows a penetration and system bypass~ 1.0% when tested in accordance with the methodology of ANSI N510-1980, Section 12, excluding subsection 12.3, at a system flowrate of 4950 cfm +/- 10%.

Point Beach 5.5-11 Unit 1 - Amendment No. 260 Unit 2 - Amendment No. 206

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.10 Ventilation Filter Testing Program (VFTP) (continued)

c. Demonstrate for the Control Room Emergency Filtration System (F-16) that a laboratory test of a sample of the charcoal adsorber, when obtained in accordance with the methodology of ANSI N510-1980, Section 13, excluding subsection 12.3, shows the methyl iodide penetration~ 2.5%, when tested in accordance with ASTM D3803-1989 at a temperature of 30°C and a relative humidity of 95%, applying the tolerances of ASTM D3803-1989.

d. Demonstrate for the Control Room Emergency Filtration System (F-16) that the pressure drop across the combined HEPA filters and the charcoal adsorbers is less than 6 inches of water when tested in accordance with the methodology of ANSI N510-1980, Sections 10 and 12, excluding subsections 10.3 and 12.3, at a system flowrate of 4950 cfm +/- 10%.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the VFTP test frequencies. 5.5.11 Explosive Gas Monitoring Program This program provides controls for potentially explosive gas mixtures contained in the on-service Gas Decay Tank. The program shall include a limit for oxygen concentration in the on-service Gas Decay Tank and a surveillance program to ensure the limit is maintained. This limit shall be appropriate to the system's design criteria (i.e., whether or not the system is designed to withstand a hydrogen explosion). The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Explosive Gas Monitoring Program surveillance frequencies. Point Beach 5.5-12 Unit 1 - Amendment No. 260 Unit 2 - Amendment No. 262

Programs and Manuals 5.5 5.5 Programs and Manuals 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. The program shall include sampling and testing requirements, and acceptance criteria, all in accordance with applicable ASTM Standards. The purpose of the program is to establish the following:

a. Acceptability of new fuel oil for use prior to addition to storage tanks by determining that the fuel oil has:

1. an API gravity or an absolute specific gravity within limits,

2. a flash point and kinematic viscosity within limits for ASTM 2D fuel oil, and

3. a clear and bright appearance with proper color;

b. Within 31 days of addition of the new fuel oil to storage tanks verify that the properties of the new fuel oil, other than those addressed in

a. above, are within limits for ASTM 2D fuel oil; and

c. Total particulate concentration of the fuel oil is~ 1O mg/I when tested every 92 days in accordance with the applicable ASTM standard.

d. The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Diesel Fuel Oil Testing Program test frequencies.

5.5.13 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 NRC approval pursuant to 10 CFR 50.59.

Point Beach 5.5-13 Unit 1 - Amendment No. 260 Unit 2 - Amendment No. 206

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.13 Technical Specifications (TS) Bases Control Program (continued)

c. The Bases Control Program shall contain provisions to ensure that the Bases are maintained consistent with the FSAR.

d. Proposed changes that meet the criteria of Specification 5.5.13b 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 NRC on a frequency consistent with 10 CFR 50. 71 (e).

5.5.14 Safety Function Determination Program (SFDP) 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:

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 result of multiple support system inoperabilities; and

d. Other appropriate limitations and remedial or compensatory actions.

Point Beach 5.5-14 Unit 1 - Amendment No. 260 Unit 2 - Amendment No. 237

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.14 Safety Function Determination Program (SFDP) (continued) A loss of safety function exists when, assuming no concurrent single failure, and assuming no concurrent loss of offsite power or loss of onsite diesel generator(s), 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 system(s) for the supported systems (a) and (b) 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. When a loss of safety function is caused by the inoperability of a single Technical Specification support system, the appropriate Conditions and Required Actions to enter are those of the support system. 5.5.15 Containment Leakage Rate Testing Program

a. 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 Nuclear Energy Institute (NEI) 94-01, Revision 3-A, "Industry Guidance for Implementing Performance Based Option of 10 CFR 50, Appendix J," and the conditions and limitations specified in NEI 94-01, Revision 2-A.

Point Beach 5.5-15 Unit 1 - Amendment No. 265 Unit 2 -Amendment No. 268

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.15 Containment Leakage Rate Testing Program (continued)

b. The peak design containment internal accident pressure, Pa. is 60 psig.

c. The maximum allowable containment leakage rate, La at Pa. shall be 0.2% of containment air weight per day.

d. Leakage rate acceptance criteria are:

1. Containment leakage rate acceptance criterion is~ 1.0 La.

2. During the first unit startup following testing in accordance with this program, the leakage rate acceptance are~ 0.6 La for the combined Type Band Type C tests and~ 0.75 La for the Type A tests.

3. Air lock testing acceptance criteria are:

i. Overall air lock leakage rate is~ 0.05 La when tested at ~

Pa. ii. For each door seal, leakage rate is equivalent to~ 0.02 La at~ Pa when tested at a differential pressure of~ to 10 inches of Hg_

e. The provisions of SR 3.0.2 do not apply to the test frequencies in the Containment Leakage Rate Testing Program.

f. The provisions of SR 3.0.3 are applicable to the Containment Leakage Rate Testing Program.

Point Beach 5.5-16 Unit 1 - Amendment No. 260 Unit 2 - Amendment No. 244

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.16 Reactor Coolant System (RCS) Pressure Isolation Valve (PIV) Leakage Program A program shall be established to verify the leakage from each RCS PIV is within the limits specified below, in accordance with the Event V Order, issued April 20, 1981.

a. Minimum differential test pressure shall not be less than 150 psid.

b. Leakage rate acceptance criteria are:

1. Leakage rates less than or equal to 1.0 gpm are considered acceptable.

2. Leakage rates greater than 1.0 gpm but less than or equal to 5.0 gpm are considered acceptable if the latest measured rate has not exceeded the rate determined by the previous test by an amount that reduces the margin between measured leakage rate and the maximum permissible rate of 5.0 gpm by 50% or greater.

3. Leakage rates greater than 1.0 gpm but less than or equal to 5.0 gpm are considered unacceptable if the latest measured rate exceeded the rate determined by the previous test by an amount that reduces the margin between measured leakage rate and the maximum permissible rate of 5.0 gpm by 50% or greater.

4. Leakage rates greater than 5.0 gpm are considered unacceptable.

5.5.17 Pre-Stressed Concrete Containment Tendon Surveillance Program This program provides controls for monitoring any tendon degradation in pre-stressed concrete containments, including effectiveness of its corrosion protection medium, to ensure containment structural integrity. The program shall include baseline measurements prior to initial operations. The Tendon Surveillance Program, inspection frequencies, and acceptance criteria shall be in accordance with Regulatory Guide 1.35, Revision 3, 1990. The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Tendon Surveillance Program inspection frequencies. Point Beach 5.5-17 Unit 1 - Amendment No. 260 Unit 2 - Amendment No. 206

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.18 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 Emergency Filtration System (CREFS), CRE occupants can control the reactor safely under normal conditions and maintain it in a safe condition following a radiological event. The program shall ensure that adequate radiation protection is provided to permit access and occupancy of the CRE under design basis accident (DBA) conditions without personnel receiving radiation exposures in excess of 5 rem total effective dose equivalent (TEDE) for the duration of the accident. Additionally, separate from the CREFS, the program shall ensure CRE occupants can maintain the reactor in a safe condition following a hazardous chemical release or smoke challenge. The program shall include the following elements:

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.1 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.1 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 technical specification emergency mode of operation by the CREFS, operating at the flow rate required by the VFTP, at a Frequency of 18 months. The results shall be trended at a frequency of 18 months and used as part of the periodic 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 analyses of DBA consequences.

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.

Point Beach 5.5-18 Unit 1 - Amendment No. 260 Unit 2 - Amendment No. 244

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.18 Control Room Envelope Habitability Program (continued)

g. An adequate supply of self contained breathing apparatus (SCBA) units in the CRE to protect CRE occupants from a hazardous chemical release.

h. Portable smoke ejection equipment per the Fire Protection Evaluation Report and Safe Shutdown Analysis Report to address a potential smoke challenge.

5.5.19 Surveillance Frequency Control Program This program provides controls for Surveillance Frequencies. The program shall ensure that Surveillance Requirements specified in the Technical Specifications are performed at intervals sufficient to assure the associated Limiting Conditions for Operations are met:

a. The Surveillance Frequency Control Program shall contain a list of frequencies of those Surveillance Requirements for which the frequency is controlled by the program.

b. Changes to the frequencies listed in the Surveillance Frequency Control Program shall be made in accordance with NEI 04-10, "Risk-Informed Method for Control of Surveillance Frequencies," Revision 1.

c. The provisions of Surveillance Requirements 3.0.2 and 3.0.3 are applicable to the frequencies established in the Surveillance Frequency Control Program.

Point Beach 5.5-19 Unit 1 - Amendment No. 260 Unit 2 - Amendment No.257

- - Reporting Requirements 5.6 5.0 ADMINISTRATIVE CONTROLS 5.6 Reporting Requirements The following reports shall be submitted in accordance with 10 CFR 50.4. 5.6.1 Deleted 5.6.2 Annual Monitoring Report

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

A single submittal may be made that combines sections common to Units 1 and 2. The Annual Monitoring Report covering the operation of the units during the previous calendar year shall be submitted by April 30 of each year. The report shall include summaries, 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. Point Beach 5.6-1 Unit I - Amendment No. 216 Unit 2 - Amendment No. 221 "Revised by letter dated April 1, 2005"

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.2 Annual Monitoring Report (continued) The Annual Monitoring Report shall include the results of analyses of all radiological environmental samples and of all environmental radiation measurements taken during the period pursuant to the locations specified in the table and figures in the ODCM, as well as summarized and tabulated results of these analyses and measurements. In the event that some individual results are not available for inclusion with the report, the report shall be submitted noting and explaining the reasons for the missing results. The missing data shall be submitted in a supplementary report as soon as possible. The Annual Monitoring Report shall also include The Radioactive Effluent Release Report covering the operation of the units in the previous year and submitted in accordance with 10 CFR 50.36a. 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 report shall include a summary of the quantities of radioactive liquid and gaseous effluents and solid waste released from the units. The material provided shall be consistent with the objectives outlined in the ODCM and Process Control Program and in conformance with 10 CFR 50.36a and 10 CFR 50, Appendix I, Section IV.B.1. 5.6.3 Deleted 5.6.4 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:

(1) LCO 2.1.1, 'Safety Limits (SLs)" (2) LCO 3.1.1, 'Shutdown Margin (SDM)" (3) LCO 3.1.3, "Moderator Temperature Coefficient (MTC)" (4) LCO 3.1.5, "Shutdown Bank Insertion Limits" (5) LCO 3.1.6, MControl Bank Insertion Limits' (6) LCO 3.2.1, uHeat Flux Hot Channel Factor (FO(Z))" (7) LCO 3.2.2, 'Nuclear Enthalpy Rise Hot Channel Factor(F NiH)" Point Beach 5.6-2 Unit 1 - Amendment No. 216 Unit 2 - Amendment No. 221 "Revised by letter dated April 1, 2005"

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.4 CORE OPERATING LIMITS REPORT (COLR) (continued) (8) LCO 3.2.3, "Axial Flux Difference (AFD)" (9) LCO 3.3.1, "Reactor Protection System (RPS) Instrumentation - Overtemperature AT" (10) LCO 3.3.1, uReactor Protection System (RPS) Instrumentation - Overpower ArT (11) LCO 3.4.1, ARCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits" (12) LCO 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. When an initial assumed power level of 102 percent of the original rated thermal power is specified in a previously approved method, 100.6 percent of uprated rated thermal power may be used only when the main feedwater flow measurement (used as the input for reactor thermal output) is provided by the Caldon leading edge flowmeter (LEFM) as described in reports 11 and 12 listed below. When main feedwater flow measurements from the LEFM are unavailable, a power measurement uncertainty consistent with the instruments used shall be applied.

Future revisions of approved analytical methods listed in this Technical Specification that currently reference the original Appendix K uncertainty of 102 percent of the original rated thermal power should include the condition given above allowing use of 100.6 percent of uprated rated thermal power in the safety analysis methodology when the LEFM is used for main feedwater flow measurement. The approved analytical methods are described in the following documents: (1) WCAP-14449-P-A, "Application of Best Estimate Large Break LOCA Methodology to Westinghouse PWR's with Upper Plenum Injection," Revision 1, October 1999. (cores containing 422VW fuel) (2) WCAP-9272-P-A, "Westinghouse Reload Safety Evaluation Methodology," July 1985. (3) WCAP-11397-P-A, "Revised Thermal Design Procedure," April 1989. Point Beach 5.6-3 Unit 1 -Amendment No. 291, 207 Unit 2 - Amendment No. 206, 212

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.4 CORE OPERATING LIMITS REPORT (COLR) (continued) (4) WCAP-14787 , Rev 3, "Westinghouse Revised Thermal Design Procedure Instrument Uncertainty Methodology for Point Beach Units 1 & 2 Power Uprate (1775 MWt Core Power with Feedwater Venturis, or 1800 MWt Core Power with LEFM on Feedwater Header)" (5) WCAP-10054-P-A, "Westinghouse Small Break ECCS Evaluation Model Using The NOTRUMP Code," August 1985. (6) WCAP-1 0054-P-A, "Addendum to the Westinghouse Small Break ECCS Evaluation Model Using the NOTRUMP Code: Safety Injection into the Broken Loop and COSI Condensation Model," Addendum 2, Revision 1, July 1997. (7) WCAP-87 45-P-A, "Design Bases for the Thermal Overpower

                          ~T and Thermal Overtemperature ~T Trip Functions,"

September 1986. (8) DELETED (9) WCAP-1 0924-P-A, "Large Break LOCA Best Estimate Methodology, Volume 2: Application to Two-Loop PWRs Equipped with Upper Plenum Injection," and Addenda, December 1988. (cores not containing 422 V+ fuel) (10) WCAP-10924-P-A, "LBLOCA Best Estimate Methodology: Model Description and Validation : Model Revisions, " Volume 1, Addendum 4, August 1990. (cores not containing 422 V+ fuel) (11) Caldon, Inc., Engineering Report-BOP, "TOPICAL REPORT: Improving Thermal Power Accuracy and Plant Safety While Increasing Operating Power Level Using the LEFM,/ System," Revision 0, March 1997. (12) Caldon, Inc. , Engineering Report-160P, "Supplement to Topical Report R-80P: Basis for a Power Uprate With the LEFM,(rMSystem, " Revision 0, May 2000. ( 13) WCAP-16009-P-A, "Realistic Large-Break LOCA Evaluation Methodology Using the Automated Statistical Treatment of Uncertainty Method (ASTRUM)," January 2005. (14) WCAP-16259-P-A, "Westinghouse Methodology for Application of 3-D Transient Neutronics to Non-LOCA Accident Analysis," August 2006. (15) WCAP-8403 (nonproprietary), "Power Distribution Control and Load Following Procedures, "Westinghouse Electric Corporation," September 1974. (16) NS-TMA-2198, Westinghouse to NRC Letter, Attachment "Operation and Safety Analysis Aspects of Improved Load Follow Package," January 31 , 1980. (17) NS-CE-687, Westinghouse to NRC Letter, "Power Distribution Control Analysis," July 16, 1975. Point Beach 5.6-4 Unit 1 - Amendment No. 249 Unit 2 - Amendment No. 253

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.4 CORE OPERATING LIMITS REPORT (COLR) (continued) (18) WCAP-12610-P-A, "VANTAGE+ Fuel Assembly Reference Core Report," April 1995. (19) WCAP-1261 0-P-A & CENPD-404-P-A, Addendum 1-A, "Optimized ZIRLO'," July 2006.

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 upon issuance for each reload cycle to the NRC.

5.6.5 Reactor Coolant System (RCS) PRESSURE AND TEMPERATURE LIMITS REPORT (PTLR)

a. RCS pressure and temperature limits for heat up, cooldown, low temperature operation, criticality, hydrostatic testing, LTOP enabling, and PORV lift settings as well as heatup and cooldown rates shall be established and documented in the PTLR for the following:

(1) LCO 3.4.3, "RCS Pressure and Temperature (PIT) Limits" (2) LCO 3.4.6, "RCS Loops-MODE 4" (3) LCO 3.4.7, "RCS Loops-MODE 5, Loops Filled" (4) LCO 3.4.1 0, "Pressurizer Safety Valves" (5) LCO 3.4.12, "Low Temperature Overpressure Protection (L TOP)"

b. The analytical methods used to determine the RCS pressure and temperature limits shall be those previously reviewed and approved by the NRC, specifically those described in the NRC Letters dated October 6, 2000, July 23, 2001, and October 18, 2007, and June 30, 2014.

c. The PTLR shall be provided to the NRC upon issuance for each reactor vessel fluence period and for any revision or supplement thereto.

Point Beach 5.6-5 Unit 1 -Amendment No. 250 Unit 2 -Amendment No. 254 Revised by correction letter dated August 14, 2014

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.6 PAM Report When a report is required by Condition B or F of LCO 3.3.3, "Post Accident Monitoring (PAM) Instrumentation," a report shall be submitted within the following 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. 5.6.7 Tendon Surveillance Report Abnormal conditions observed during testing will be evaluated to determine the effect of such conditions on containment structural integrity. This evaluation should be completed within 30 days of the identification of the condition. Any condition which is determined in this evaluation to have a significant adverse effect on containment structural integrity will be considered an abnormal degradation of the containment structure. Any abnormal degradation of the containment structure identified during the engineering evaluation of abnormal conditions shall be reported to the Nuclear Regulatory Commission pursuant to the requirements of 10 CFR 50.4 within thirty days of that determination. Other conditions that indicate possible effects on the integrity of two or more tendons shall be reportable in the same manner. Such reports shall include a description of the tendon condition, the condition of the concrete (especially at tendon anchorages), the inspection procedure and the corrective action taken. 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, Point Beach 5.6-6 Unit 1 - Amendment No. 254 Unit 2 - Amendment No. 258

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.8 Steam Generator Tube Inspection Report (continued)

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 steam generator,

g. The results of condition monitoring, including the results of tube pulls and in-situ testing.

h. For Unit 1 only, the primary to secondary leakage rate observed in each SG (if it is not practical to assign the leakage to an individual SG, the entire primary to secondary leakage should be conservatively assumed to be from one SG) during the cycle preceding the inspection which is the subject of the report,

i. For Unit 1 only, the calculated accident induced leakage rate from the portion of the tubes below 20.6 inches from the top of the tubesheet for the most limiting accident in the most limiting SG. In addition, if the calculated accident induced leakage rate from the most limiting accident is less than 5.22 times the maximum operational primary to secondary leakage rate, the report should describe how it was determined, and

j. For Unit 1 only, the results of monitoring for tube axial displacement (slippage). If slippage is discovered, the implications of the discovery and corrective action shall be provided.

Point Beach 5.6-7 Unit 1 - Amendment No. 260 Unit 2 - Amendment No. 258

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 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 Point Beach 5.7-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

High Radiation Area 5.7 5.7 High Radiation Area (continued) 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 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 individuals in the area who are covered by such surveillance.

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 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.

Point Beach 5.7-2 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

High Radiation Area 5.7 5.7 High Radiation Area (continued) 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 shall remain locked 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 shall 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 personnel radiation exposure within the area with the means to communicate with and control every individual in the area, or Point Beach 5.7-3 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

High Radiation Area 5.7 5.7 High Radiation Area (continued) 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 option (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.

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 shall be activated at the area as a warning device.

Point Beach 5.7-4 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

APPENDIX B TO FACILITY OPERATING LICENSE DPR-24 AND FACILITY OPERATING LICENSE DPR-27 FOR POINT BEACH NUCLEAR PLANT UNIT NOS. 1 AND 2 NEXTERA ENERGY POINT BEACH, LLC DOCKET NOS. 50-266 AND 50-301 Unit 1 - Amendment No. 237 Unit 2 - Amendment No. 241

TARLE OF CONTENTS sect:--. Initle Page 16 NONRADIOLOGICAL TECiLNICAL SPECIFICATIONS 16.1-1

16. . Definitions 16.1-1 16.2 Limiting Conditicns for Operation 16.1-2 16.3 Environmental Monitoring 16.1-2 16.4 Record Keeping and Monitoring Program for Nonradiological Parameters 16.1-2 16.5 Reporting Requirements 16.1-3 Unit 1 - Amendment No. 69

. Unit 2 - Amendment No. 74 16-i

16. NOI\JRADIOLOGICAL TECHNICAL SPECIFICATIONS 16.1 Definitions The definitions for terms used in these Nonradiological Technical Specifications for Unit 1 and 2 are stated below.

WPDES Permit The WPDES permit is the Wisconsin Pollutant Discharge Elimination System Permit No. WI-0000957 issued by the State of Wisconsin Department of Natural Resources for the NextEra Energy Point Beach, LLC, Point Beach Nuclear Plant, and as subsequently amended. 16.1-1 Unit 1 - Amendment No. 237 Unit 2 - Amendment No. 241

C L2it'. Conditicns fcr Ooeration None required.* 16.3 Environmental Ycnitoring None required.* 16.4 Recordkeeping and Monitoring Program for Nonradiological Parameters None required.*

In consideration of the provisions of the Clear Water Act (33 USC & 1251, et seq.) and in the interest of avoiding duplication of effort, the conditions and monitoring and recording requirements related to water quality and aquatic biota are specified in the WPDES Permit. As a matter of law, the NRC acknowledges the applicability of the WPDES Permit limitations for protection of the aquatic enfironment due to nonradiological effluents.

Unit 1 - Amendment No. 69 Unit 2 - Amendment No. 74 16.1-2

KJ 16.5 Reporting Requirements S~caification

1. As part of the Annual Monitoring Report, described in Section 5.6.2 of Appendix A, the following shall be reported: I

a. All scheduled and unscheduled chemical discharge to the condenser cooling water.

b. A description of circulating water system operation for each unit which includes ambient temperature, intake temperature, discharge temperature, and circulating water system flow.

16.1-3 Amendment No. 26, 69, 409, 462, 201 Amendment No. 34, I4, 1-2, 466, 206 AUG 0 5 2001

APPENDIX C ADDITIONAL CONDITIONS OPERATING LICENSE DPR-24 NextEra Energy Point Beach, LLC shall comply with the following conditions and the schedules noted below: Amendment Implementation Number Additional Conditions Date 414 Deleted 174 This amendment is authorized contingent on compliance with commitments Immediately provided by the licensee to operate Point Beach Nuclear Plant in accordance with its service water system analyses and approved procedures. Specifically, each unit will utilize only one component cooling water heat exchanger until such time as analyses are completed and the service water system reconfigured as necessary to allow operation of one or both units with two heat exchangers in service. If two component cooling water heat exchangers are required in one or both units for maintaining acceptable component cooling water temperature prior to completion of necessary analyses to allow operation in the required configuration, the service water system will be considered in an unanalyzed condition, declared inoperable, and action taken as specified by TS LCO 3.0.3 except for short periods of time as necessary to effect procedurally controlled changes in system lineups and unit operating conditions.

   ~         Deleted
   ~         Deleted 228       At the time of the closing of the transfer of the licenses from Wisconsin Electric     Immediately Power Company (WEPCO) to FPLE Point Beach 1 , WEPCO shall transfer to FPLE Point Beach* WEPCO's decommissioning funds in an aggregate minimum value of $200.8 million for Point Beach Unit 1. FPLE Point Beach*

shall deposit such funds in an external decommissioning trust fund established by FPLE Point Beach* for Point Beach Units 1 and 2. The trust agreement shall be in a form acceptable to the NRC. NextEra Energy Point Beach shall take no actions to cause FPL Group Immediately Capital, or its successors and assigns, to void, cancel, or modify its $70 million Support Agreement (Agreement) to NextEra Energy Point Beach, as presented in its application dated January 26, 2007, or cause it to fail to perform or impair its performance under the Agreement, without the prior written consent from the NRC. The Agreement may not be amended or modified without 30 days prior written notice to the Director of Nuclear Reactor Regulation or his designee. An executed copy of the Agreement shall be submitted to the NRC no later than 30 days after the completion of the license transfers. Also, NextEra Energy Point Beach shall inform the NRC in writing anytime it draws upon the $70 million Agreement.

   ~         Deleted
   ~         Deleted 240       Deleted 1

On April 16, 2009, the name "FPLE Point Beach, LLC" was changed to "NextEra Energy Point Beach, LLC." Point Beach Unit 1 C-1 Amendment No. 258 I

APPENDIX C ADDITIONAL CONDITIONS OPERATING LICENSE DPR-24 NextEra Energy Point Beach, LLC shall comply with the following conditions and the schedules noted below: Amendment Implementation Number AddllionalCondllions Date 24-0 Deleted 24-0 Deleted 24-0 Deleted 24-0 Deleted 24-0 Deleted 24-0 Deleted 24-0 Deleted 24+ Deleted 24+ Deleted Point Beach Unit 1 C-2 Amendment No. 258 I}}

ML053110031

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