Text

Current Facility Operating License DPR-44, Tech Specs, Revised 01/24/2020
	ML052720266
Person / Time
Site:	Peach Bottom
Issue date:	05/07/2003
From:	Collins S; Office of Nuclear Reactor Regulation
To:	; Exelon Generation Co
	Boska J, NRR/DORL, 301-415-2901
References
	Download: ML052720266 (397)
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EXELON GENERATION COMPANY, LLC PSEG NUCLEAR, LLC DOCKET NO. 50-277 PEACH BOTTOM ATOMIC POWER STATION, UNIT 2 SUBSEQUENT RENEWED FACILITY OPERATING LICENSE Subsequent Renewed License No. DPR-44

1. The U.S. Nuclear Regulatory Commission (the Commission) having previously made the findings set forth in Renewed License No. DPR-44 issued May 7, 2003, has now found that:

A. The application for Subsequent Renewed Facility Operating License No. DPR-44 filed by Exelon Generation Company LLC (Exelon Generation Company) and PSEG Nuclear LLC (PSEG Nuclear) (the licensees) complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations set forth in 10 CFR Chapter I, and all required notifications to other agencies or bodies have been duly made; B. Actions have been identified and have been or will be taken with respect to managing the effects of aging during the subsequent 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 this subsequent renewed facility operating license will continue to be conducted in accordance with the current licensing basis, as defined in 10 CFR 54.3, for Peach Bottom Atomic Power Station, Unit No. 2, and that any changes made to the plant's current licensing basis in order to comply with 10 CFR 54.29(a) are in accord with the Act and the Commission's regulations; C. The facility will operate in conformity with the application, as amended, the provisions of the Act, and the rules and regulations of the Commission; D. There is reasonable assurance: (1) that the activities authorized by this subsequent renewed 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 rules and regulations of the Commission; Page 1 Subsequent Renewed License No. DPR-44

E. Exelon Generation Company is technically qualified, and the licensees are financially qualified to engage in the activities authorized by this subsequent renewed license in accordance with the rules and regulations of the Commission; F. The licensees have satisfied the applicable provisions of 10 CFR Part 140, Financial Protection Requirements and indemnity Agreements, of the Commissions regulations; G. The issuance of this subsequent renewed license will not be inimical to the common defense and security or to the health and safety of the public; H. After weighing the environmental, economic, technical, and other benefits of the facility against environmental costs and considering available alternatives, the Commission concludes that the issuance of the Subsequent Renewed Facility Operating License No. DPR-44 is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied; and I. The receipt, possession, and use of source, byproduct, and special nuclear material as authorized by the subsequent renewed license will be in accordance with the Commission's regulations in 10 CFR Parts 30, 40, and 70, including 10 CFR Sections 30.33, 40.32, 70.23 and 70.31.

2. On the basis of the foregoing findings regarding this facility, Renewed Facility Operating License No. DPR-44, issued May 7, 2003, is superseded by Subsequent Renewed Facility Operating License No. DPR-44, which is hereby issued to the Exelon Generation Company and PSEG Nuclear, licensees, to read as follows:

A. This subsequent renewed facility operating license applies to the Peach Bottom Atomic Power Station, Unit 2, a single-cycle, forced-circulation boiling water nuclear reactor and associated equipment (the facility), owned by the licensees and operated by Exelon Generation Company. The facility is located partly in Peach Bottom Township, York County, partly in Drumore Township, Lancaster County, and partly in Fulton Township, Lancaster County in southeastern Pennsylvania and is described in the Final Safety Analysis Report as supplemented and amended and the Environmental Report as supplemented and amended.

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

(1) Exelon Generation Company, pursuant to Section 104b of the Act and 10 CFR Part 50, Licensing of Production and Utilization Facilities, to possess, use, and operate the facility and PSEG Nuclear to possess the facility at the designated location in Peach Bottom, York County, Pennsylvania in accordance with the procedures and limitations set forth in this license; Page 2 Subsequent Renewed License No. DPR-44

(2) Exelon Generation Company, pursuant to the Act and 10 CFR Part 70, 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 the Final Safety Analysis Report, as supplemented and amended; (3) Exelon Generation Company, pursuant to the Act and 10 CFR Parts 30, 40, and 70, to receive, possess, and use at any time any byproduct, source, and special nuclear material as sealed neutron sources for reactor startup, sealed sources for reactor instrumentation and radiation monitoring equipment calibration, and as fission detectors in amounts as required; (4) Exelon Generation Company, pursuant to the Act and 10 CFR Parts 30, 40 and 70, to receive, possess, and use in amounts as required any byproduct, source, or special nuclear material without restriction to chemical or physical form for sample analysis or instrument calibration or when associated with radioactive apparatus or components; (5) Exelon Generation Company, pursuant to the Act and 10 CFR Parts 30 and 70, to possess, but not to separate, such byproduct and special nuclear material as may be produced by operation of the facility, and such Class B and Class C low-level radioactive waste as may be produced by the operation of Limerick Generating Station, Units 1 and 2.

C. This subsequent renewed license shall be deemed to contain and is subject to the conditions specified in the following Commission regulations in 10 CFR Chapter I: Part 20, Section 30.34 of Part 30, Section 40.41 of Part 40, Section 50.54 of Part 50, and Section 70.32 of Part 70; all applicable provisions of the Act and the rules, regulations, and orders of the Commission now or hereafter in effect; and is subject to the additional conditions specified below:

(1) Maximum Power Level Exelon Generation Company is authorized to operate the Peach Bottom Atomic Power Station, Unit 2, at steady state reactor core power levels not in excess of 4016 megawatts thermal.

(2) Technical Specifications The Technical Specifications contained in Appendices A and B, as revised through Amendment No. 330, are hereby incorporated in the license.

Exelon Generation Company shall operate the facility in accordance with the Technical Specifications.

(3) Physical Protection Exelon Generation Company 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 Page 3 Subsequent Renewed License No. DPR-44

27822), and the authority of 10 CFR 50.90 and 10 CFR 50.54(p). The combined set of plans1, submitted by letter dated May 17, 2006, is entitled:

"Peach Bottom Atomic Power Station Security Plan, Training and Qualification Plan, Safeguards Contingency Plan, and Independent Spent Fuel Storage Installation Security Program, Revision 3." The set contains Safeguards Information protected under 10 CFR 73.21.

Exelon Generation Company shall fully implement and maintain in effect all provisions of the Commission-approved cyber security plan (CSP),

including changes made pursuant to the authority of 10 CFR 50.90 and 10 CFR 50.54(p). The Exelon Generation Company CSP was approved by License Amendment No. 281 and modified by Amendment No. 301.

(4) Fire Protection The Exelon Generation Company shall implement and maintain in effect all provisions of the approved fire protection program as described in the Updated Final Safety Analysis Report for the facility, and as approved in the NRC Safety Evaluation Report (SER) dated May 23, 1979, and Supplements dated August 14, September 15, October 10 and November 24, 1980, and in the NRC SERs dated September 16, 1993, and August 24, 1994, subject to the following provision:

The Exelon Generation Company may make changes to the approved fire protection program without prior approval of the Commission only if those changes would not adversely affect the ability to achieve and maintain safe shutdown in the event of a fire.

(5) Public Service Electric & Gas Company (PSE&G) to PSEG Nuclear License Transfer Conditions (a) PSEG Nuclear shall take all necessary steps to ensure that the decommissioning trust is maintained in accordance with the application, the requirements of the Order Approving Transfer of License and Conforming Amendment, dated August 21, 2000, and the related Safety Evaluation dated February 16, 2000.

(b) The decommissioning trust agreement shall provide that:

1) The use of assets in both the qualified and nonqualified funds shall be limited to expenses related to decommissioning of the unit as defined by the NRC in its regulations and issuances, and as provided in the unit's license and any amendments thereto. However, upon completion of decommissioning, as defined above, the assets may be used for any purpose authorized by law.

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

Page 4 Subsequent Renewed License No. DPR-44

2) Investments in the securities or other obligations of PSE&G or affiliates thereof, or their successors or assigns, shall be prohibited. In addition, except for investments tied to market indexes or other non-nuclear-sector mutual funds, investments in any entity owning one or more nuclear power plants shall be prohibited.

3) No disbursements or payments from the trust shall be made by the trustee until the trustee has first given the NRC 30 days notice of the payment. In addition, no disbursements or payments from the trust shall be made if the trustee receives prior written notice of objection from the Director, Office of Nuclear Reactor Regulation.

4) The trust agreement shall not be modified in any material respect without prior written notification to the Director, Office of Nuclear Reactor Regulation.

5) The trustee, investment advisor, or anyone else directing the investments made in the trust shall adhere to a "prudent investor" standard, as specified in 18 CFR 35.32(3) of the Federal Energy Regulatory Commission's regulations.

(c) PSEG Nuclear shall not take any action that would cause PSEG Power LLC or its parent companies to void, cancel, or diminish the commitment to fund an extended plant shutdown as represented in the application for approval of the transfer of this license from PSE&G to PSEG Nuclear.

(6) Exelon Generation Company shall provide to the Director of the Office of Nuclear Reactor Regulation a copy of any application, at the time it is filed, to transfer (excluding grants of security interests or liens) from Exelon Generation Company to its direct or indirect parent, or to any other affiliated company, facilities for the production, transmission, or distribution of electric energy having a depreciated book value exceeding ten percent (10%) of Exelon Generation Company's consolidated net utility plant, as recorded on Exelon Generation Company's books of account.

(7) Exelon Generation Company shall have decommissioning trust funds for Peach Bottom, Unit 2, in the following minimum amount, when Peach Bottom, Unit 2, is transferred to Exelon Generation Company:

Peach Bottom, Unit 2 $71,250,231 (8) The decommissioning trust agreement for Peach Bottom, Unit 2, at the time the transfer of the unit to Exelon Generation Company is effected and thereafter, is subject to the following:

(a) The decommissioning trust agreement must be in a form acceptable to the NRC.

Page 5 Subsequent Renewed License No. DPR-44

(b) With respect to the decommissioning trust fund, investments in the securities or other obligations of Exelon Corporation or affiliates thereof, or their successors or assigns shall be prohibited. Except for investments tied to market indexes or other non-nuclear-sector mutual funds, investments in any entity owning one or more nuclear power plants shall be prohibited.

(c) The decommissioning trust agreement for Peach Bottom, Unit 2, must provide that no disbursements or payments from the trust shall be made by the trustee unless the trustee has first given the Director, Office of Nuclear Reactor Regulation, 30 days prior written notice of payment. The decommissioning trust agreement shall further contain a provision that no disbursements or payments from the trust shall be made if the trustee receives prior written notice of objection from the NRC.

(d) The decommissioning trust agreement must provide that the agreement cannot be amended in any material respect without 30 days prior written notification to the Director of the Office of Nuclear Reactor Regulation.

(e) The appropriate section of the decommissioning trust agreement shall state that the trustee, investment advisor, or anyone else directing the investments made in the trust shall adhere to a prudent investor standard, as specified in 18 CFR 35.32(a)(3) of the Federal Energy Regulatory Commissions regulations.

(9) Exelon Generation Company shall take all necessary steps to ensure that the decommissioning trust is maintained in accordance with the application for approval of the transfer of the Peach Bottom, Unit 2, license and the requirements of the Order approving the transfer, and consistent with the safety evaluation supporting the Order.

(10) Additional Conditions of the Renewed License (a) Updated Final Safety Analysis Report The Updated Final Safety Analysis Report supplement, as revised on January 31, 2003, shall be included in the next scheduled update to the Updated Final Safety Analysis Report required by 10 CFR 50.71(e)(4) following the issuance of the renewed license. Until that update is complete, the Exelon Generation Company may make changes to the programs described in the supplement without prior Commission approval, provided that the Exelon Generation Company evaluates each such change pursuant to the criteria set forth in 10 CFR 50.59 and otherwise complies with the requirements in that section.

Page 6 Subsequent Renewed License No. DPR-44

(b) Future Inspection Activities The Exelon Generation Company Updated Final Safety Analysis Report supplement submitted pursuant to 10 CFR 54.21(d), as revised on January 31, 2003, describes certain future inspection activities to be completed before the period of extended operation.

The Exelon Generation Company shall complete these activities no later than August 8, 2013, and shall notify the NRC in writing when implementation of these activities is complete and can be verified by NRC inspection.

(c) Integrated Surveillance Program The Exelon Generation Company shall implement an NRC staff-approved reactor vessel integrated surveillance program for the extended period of operation which satisfies the requirements of 10 CFR Part 54. Such a program will be implemented through a staff-approved Boiling Water Reactor Vessel and Internals Project program or through a staff-approved plant-specific program. Before August 8, 2013, the licensee will notify the NRC of its decision to implement the integrated surveillance program or a plant-specific program, and provide the appropriate revisions to the Updated Final Safety Analysis Report Supplement summary descriptions of the vessel surveillance material testing program.

(d) Core Shroud Inspection and Evaluation Guidelines Program The Exelon Generation Company shall implement an NRC staff-approved core shroud inspection and evaluation guidelines program for the extended period of operation which satisfies the requirements of 10 CFR Part 54. Such a program will be implemented through a staff- approved Boiling Water Reactor Vessel and Internals Project program or through a staff-approved plant-specific program. Before August 8, 2013, the licensee will notify the NRC of its decision to implement the core shroud inspection and evaluation guidelines program or a plant-specific program and provide the appropriate revisions to the Updated Final Safety Analysis Report Supplement summary descriptions of the core shroud inspection and evaluation guidelines program.

(11) Mitigation Strategy License Condition Develop and maintain strategies for addressing large fires and explosions and that include the following key areas:

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

1. Pre-defined coordinated fire response strategy and guidance

2. Assessment of mutual aid fire fighting assets

3. Designated staging areas for equipment and materials

4. Command and control

5. Training of response personnel Page 7 Subsequent Renewed License No. DPR-44

(b) Operations to mitigate fuel damage considering the following:

1. Protection and use of personnel assets

2. Communications

3. Minimizing fire spread

4. Procedures for implementing integrated fire response strategy

5. Identification of readily-available pre-staged equipment

6. Training on integrated fire response strategy

7. Spent fuel pool mitigation measures (c) Actions to minimize release to include consideration of:

1. Water spray scrubbing

2. Dose to onsite responders (12) The licensee shall implement and maintain all Actions required by Attachment 2 to NRC Order EA-06-137, issued June 20, 2006, except the last action that requires incorporation of the strategies into the site security plan, contingency plan, emergency plan and/or guard training and qualification plan, as appropriate.

(13) Deleted (14) Spent Fuel Pool Criticality Considerations (a) Use of spent fuel pool storage cells without NETCO-SNAP-IN rack inserts shall be restricted as follows:

1) Minimum panel Boron-10 areal density of a storage cell shall be greater than or equal to 0.014 grams per square centimeter to store fuel assemblies with the maximum in-core cold k-infinity of up to 1.235. The minimum panel Boron-10 areal density shall be evaluated by assuming that the panel areal density was initially equal to a value of 0.0235 grams per square centimeter.

2) A storage cell shall not contain any fuel assembly if the minimum panel Boron-10 areal density of a storage cell is less than 0.014 grams per square centimeter. The minimum panel Boron-10 areal density shall be evaluated by assuming that the panel areal density was initially equal to a value of 0.0235 grams per square centimeter.

(b) Until the installation of NETCO-SNAP-IN rack inserts are completed in the Peach Bottom Unit 2 spent fuel pool, Boraflex degradation shall be monitored analytically every 6 months.

(c) Boraflex degradation shall be monitored by in-situ testing in the Peach Bottom Unit 2 spent fuel pool no later than December 31, 2014, unless installation of the NETCO-SNAP-IN rack inserts for Unit 2 have been completed prior to this date.

Page 8 Subsequent Renewed License No. DPR-44

(d) Installation of NETCO-SNAP-IN rack inserts shall be completed by December 31, 2016.

(15) Potential Adverse Flow Effects In conjunction with the license amendment to revise paragraph 2.C(1) of Renewed Facility Operating License No. DPR-44, for Peach Bottom Unit 2, to reflect the new maximum licensed reactor core power level of 3951 megawatts thermal (MWt), the license is also amended to add the following license condition. This license condition provides for monitoring, evaluating, and taking prompt action in response to potential adverse flow effects as a result of power uprate operation on plant structures, systems, and components (including verifying the continued structural integrity of the steam dryer). This license condition is applicable to the initial power ascension from 3514 MWt to the extended power uprate (EPU) power level of 3951 MWt:

(a) The following requirements are placed on the initial operation of the facility, above the thermal power level of 3514 MWt, for the power ascension to 3951 MWt. These conditions are applicable until the first time full EPU conditions (3951 MWt) are achieved. If the number of active main steam line (MSL) strain gauges is less than two strain gauges (180 degrees apart) at any of the eight MSL locations, Exelon Generation Company will stop power ascension and repair/replace the damaged strain gauges and only then resume power ascension.

In addition, sufficient on-dryer strain gauges must remain in working order to monitor all dryer peak stress locations with a minimum alternating stress ratio (MASR) less than 1.5. In the event there are no working on-dryer strain gauges, with coherence of greater than 0.5 with any peak stress location, Exelon Generation Company will:

(1) stop power ascension; (2) evaluate the dryer MASR at the current power level and at the projected EPU power level; and (3) provide the results to the NRC Project Manager via e-mail. Exelon Generation Company shall not resume power ascension for at least 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after the NRC Project Manager confirms receipt of the MASR results unless, prior to the expiration of the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period, the NRC Project Manager advises that the NRC staff has no objections to the continuation of power ascension. Furthermore, power ascension may only resume if Exelon Generation Company determines that the dryer MASR will remain greater than 1.0.

1. Exelon Generation Company shall provide a brief stress summary report for the replacement steam dryer (RSD) based on MSL strain gauge and on-dryer instrument data collected at or near 3514 MWt for NRC review before increasing power above 3514 MWt. Exelon Generation Company shall also provide a brief vibration summary report for piping and valve vibration data collected at or near 3514 MWt for NRC review before increasing power above 3514 MWt. Both summary reports shall be provided by e-mail to the NRC Project Manager. Exelon Generation Company shall not increase Page 9 Subsequent Renewed License No. DPR-44

power above 3514 MWt for at least 240 hours0.00278 days 0.0667 hours 3.968254e-4 weeks 9.132e-5 months after the NRC Project Manager confirms receipt of the reports unless, prior to expiration of the 240 hour0.00278 days 0.0667 hours 3.968254e-4 weeks 9.132e-5 months period, the NRC Project Manager advises that the NRC staff has no objections to the continuation of power ascension. The stress summary report shall include the information in items a through f, and the vibration summary report shall include the information in items g through i, as follows:

a. A comparison of predicted and measured pressure spectra plots on the RSD.

b. A comparison of predicted and measured root mean square (RMS) strains and spectra plots on the RSD.

c. End-to-end bias errors and uncertainties (B/Us) for RSD strains, along with a demonstration that the application of these B/Us leads to RSD strain simulations that bound the measured spectra at dominant frequencies and RMS strains at all active strain gauge locations.

d. RSD strain gauge limits based on benchmarking performed near 3514 MWt. This will include the predicted RSD strains at each measured location and the corresponding updated MASR near 3514 MWt.

e. Predicted (extrapolated) strains at the active RSD strain gauge locations at 104% of 3514 MWt and an evaluation against acceptance limits.

f. Predicted RSD stresses and MASRs at EPU.

g. Vibration data for piping and valve locations deemed prone to vibration and vibration monitoring locations identified in Attachment 13 to the EPU application dated September 28, 2012, and Supplement 16 dated December 20, 2013, including the following locations: MSLs (including those in the drywell, turbine building and in the steam tunnel), Feedwater Lines (including those in the drywell and turbine building), Safety Relief Valves (SRVs) and Main Steam Isolation Valves in the drywell.

h. An evaluation of the measured vibration data collected in item 1.g above compared against acceptance limits.

i. Predicted vibration values and associated acceptance limits at approximately 104 percent, 108 percent, and 112.4 percent of 3514 MWt using the data collected in item 1.g above.

Page 10 Subsequent Renewed License No. DPR-44

2. Exelon Generation Company shall monitor the RSD strain gauges during power ascension above 3514 MWt for increasing strain fluctuations. Upon the initial increase of power above 3514 MWt until reaching 3951 MWt, Exelon Generation Company shall collect data from the RSD strain gauges at nominal 2 percent thermal power increments and evaluate steam dryer stress ratios based on these data.

Summaries of the results shall be provided via e-mail to the NRC Project Manager at approximately 104 percent and 108 percent of 3514 MWt.

3. Exelon Generation Company shall monitor the MSL strain gauges during power ascension above 3514 MWt for increasing pressure fluctuations in the main steam lines. Upon the initial increase of power above 3514 MWt until reaching 3951 MWt, Exelon Generation Company shall collect data from the MSL strain gauges and on-dryer instruments at nominal 2 percent thermal power increments.

4. Exelon Generation Company shall hold the facility at approximately 104 percent and 108 percent of 3514 MWt to perform the following:

a. Collect strain data from the MSL strain gauges and collect data from on-dryer instruments (accelerometers, strain gauges, and pressure transducers).

b. Collect vibration data for the locations included in the vibration summary report discussed above.

c. Evaluate steam dryer performance based on RSD strain gauge data.

d. Evaluate the measured vibration data (collected in item 4.b above) at that power level, data projected to EPU conditions, trends, and comparison with the acceptance limits.

e. Provide the steam dryer evaluation and the vibration evaluation, including the data collected, via e-mail to the NRC Project Manager, upon completion of the evaluation for each of the two hold points.

f. Exelon Generation Company shall submit a comparison of predicted and measured pressures and strains (RMS and spectra) on the RSD at 104% of 3514 MWt and 108% of 3514 MWt during power ascension.

g. Exelon Generation Company shall not increase power above each hold point until 96 hours0.00111 days 0.0267 hours 1.587302e-4 weeks 3.6528e-5 months after the NRC Project Manager confirms receipt of the evaluations Page 11 Subsequent Renewed License No. DPR-44

unless, prior to the expiration of the 96 hour0.00111 days 0.0267 hours 1.587302e-4 weeks 3.6528e-5 months period, the NRC Project Manager advises that the NRC staff has no objections to the continuation of power ascension.

5. If any RMS level measured by the active RSD strain gauges exceeds allowable Level 1 limits, Exelon Generation Company shall return the facility to a power level at which the limit(s) is not exceeded. Exelon Generation Company shall resolve the discrepancy, evaluate and document the continued structural integrity of the steam dryer, and provide that documentation to the NRC Project Manager via e-mail prior to further increases in reactor power. If a revised stress analysis is performed and new RSD strain limits are developed, then Exelon Generation Company shall not further increase power above each hold point until 96 hours0.00111 days 0.0267 hours 1.587302e-4 weeks 3.6528e-5 months after the NRC Project Manager confirms receipt of the documentation or until the NRC Project Manager advises that the NRC staff has no objections to the continuation of power ascension, whichever comes first. Additional detail is provided in paragraph (b)1 below.

(b) Exelon Generation Company shall implement the following actions for the initial power ascension from 3514 MWt to 3951 MWt condition:

1. In the event that RMS strain levels for active RSD strain gauges are identified to exceed the allowable Level 1 limits during power ascension above 3514 MWt, Exelon Generation Company shall re-evaluate dryer loads and stresses, and re-establish updated MASRs and RSD strain gauge RMS limits. In the event that stress analyses are re-performed based on new strain gauge data to address paragraph (a)5 above, the revised load definition, stress analysis, and limits shall include:

a. Determination of end-to-end B/Us and their application in determining maximum alternating stress intensities.

b. Use of bump-up factors associated with all of the SRV acoustic resonances, as determined from the scale model test results or in-plant data acquired during power ascension.

2. After reaching 3951 MWt, Exelon Generation Company shall obtain measurements from the MSL strain gauges and establish the steam dryer flow-induced vibration load fatigue margin for the facility, update the dryer stress report, and re-establish the RSD strain gauge limits based on the updated load definition. These data will be provided to the NRC staff as described below in paragraph (e).

Page 12 Subsequent Renewed License No. DPR-44

(c) Exelon Generation Company shall prepare the EPU power ascension test procedure to include:

1. The stress limits and the corresponding RSD strain limits to be applied for evaluating steam dryer performance.

2. Specific hold points and their durations during EPU power ascension.

3. Activities to be accomplished during the hold points.

4. Plant parameters to be monitored.

5. Inspections and walkdowns to be conducted for steam, feedwater, and condensate systems and components during the hold points.

6. Methods to be used to trend plant parameters.

7. Acceptance criteria for monitoring and trending plant parameters, and conducting the walkdowns and inspections.

8. Actions to be taken if acceptance criteria are not satisfied.

9. Verification of the completion of commitments and planned actions specified in the application and all supplements to the application in support of the EPU license amendment request pertaining to the steam dryer prior to power increase above 3514 MWt. Exelon Generation Company shall provide the related EPU startup test procedure sections to the NRC Project Manager via e-mail prior to increasing power above 3514 MWt.

(d) The following key attributes of the program for verifying the continued structural integrity of the steam dryer shall not be made less restrictive without prior NRC approval:

1. During initial power ascension testing above 3514 MWt, each of the two hold points shall be at increments of 4 percent of 3514 MWt.

2. Level 1 performance criteria.

3. The methodology for establishing the RSD strain limits used for the Level 1 and Level 2 performance.

(e) The results of the power ascension testing to verify the continued structural integrity of the steam dryer shall be submitted to the NRC staff in a report in accordance with 10 CFR 50.4. The report shall include a final load definition and stress report of the steam dryer, including the results of a complete re-analysis using the end-to-end B/Us determined at EPU conditions and a comparison of predicted Page 13 Subsequent Renewed License No. DPR-44

and measured pressures and strains (RMS levels and spectra) on the RSD. The report shall be submitted within 90 days of the completion of EPU power ascension testing for Peach Bottom Unit 2.

(f) During the first two scheduled refueling outages after reaching EPU conditions, a visual inspection shall be conducted of the steam dryer as described in the inspection guidelines contained in WCAP-17635-P.

(g) The results of the visual inspections of the steam dryer shall be submitted to the NRC staff in a report in accordance with 10 CFR 50.4. The report shall be submitted within 90 days following startup from each of the first two respective refueling outages.

(h) Within 6 months following completion of the second refueling outage, after the implementation of the EPU, the licensee shall submit a long-term steam dryer inspection plan based on industry operating experience along with the baseline inspection results.

The license condition described above shall expire: (1) upon satisfaction of the requirements in paragraphs (f) and (g), provided that a visual inspection of the steam dryer does not reveal any new unacceptable flaw(s) or unacceptable flaw growth that is due to fatigue, and; (2) upon satisfaction of the requirements specified in paragraph (h).

(16) Maximum Extended Load Line Limit Analysis Plus (MELLLA+) Special Consideration The licensee shall not operate the facility within the MELLLA+ operating domain with a feedwater heater out of service resulting in more than a 10°F reduction in feedwater temperature below the design feedwater temperature.

(17) Adoption of 10 CFR 50.69, "Risk-informed Categorization and Treatment of Structures, Systems, and Components for Nuclear Power Plants" In support of implementing License Amendment No. 321 permitting the adoption of the provisions of 10 CFR 50.69 for Renewed Facility Operating License No. DPR-44 for Peach Bottom Unit 2, the license is amended to add the following license condition:

(a) Exelon 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 (ANO-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 Page 14 Subsequent Renewed License No. DPR-44

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 Unit 2 License Amendment No. 321 dated October 25, 2018.

Exelon will complete the implementation items listed in Attachment 2 of Exelon's letter to the NRC dated June 6, 2018, prior to implementation of 10 CFR 50.69. All issues identified in the attachment will be addressed and any associated changes will be made, focused-scope peer reviews will be performed on changes that are PRA upgrades as defined in the PRA standard (ASME/ANS RA-Sa-2009, as endorsed by RG 1.200, Revision 2), and any findings will be resolved and reflected in the PRA of record prior to implementation of the 10 CFR 50.69 categorization process.

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).

(18) This subsequent renewed license is subject to the following conditions for the protection of the environment:

(a) To the extent matters related to thermal discharges are treated therein, operation of Peach Bottom Atomic Power Station Unit No. 2 will be governed by NPDES Permit No. PA 0009733, as now in effect and as hereafter amended. Questions pertaining to conformance thereto shall be referred to and shall be determined by the NPDES Permit issuing or enforcement authority, as appropriate.

(b) In the event of any modification of the NPDES Permit related to thermal discharges or the establishment (or amendment) of alternative effluent limitations established pursuant to Section 316 of the Federal Water Pollution Control Act, the Exelon Generation Company shall inform the NRC and analyze any associated changes in or to the Station, its components, its operation or in the discharge of effluents therefrom. If such change would entail any modification to this license, or any Technical Specifications which are part of this license, or require NRC approval pursuant to 10 CFR 50.59 or involve an environmental impact different than analyzed in the Final Environmental Statement, the Exelon Generation Company shall file with the NRC, as applicable, an appropriate analysis of any such change on facility safety, and/or an analysis of any such change on the environmental impacts and on the overall cost-benefit balance for facility operation set forth in the Final Environmental Statement and a request for an amendment to the operating license, if required by the Commission's regulations. As used in this Condition (18)(b), Final Environmental Statement (FES) means the NRC Staff Final Environmental Statement related to Operation of Peach Bottom Page 15 Subsequent Renewed License No. DPR-44

Atomic Power Station Units Nos. 2 and 3 dated April 1973, as modified by (1) the Initial Decision of the Atomic Safety and Licensing Board dated September 14, 1973, (2) the Supplemental Initial Decision of the Atomic Safety and Licensing Board dated June 14, 1974, (3) the Decision of the Atomic Safety and Licensing Appeal Board dated July 5, 1974, (4) the Memorandum and Order of the Commission dated August 8, 1974, (5) any further modification resulting from further review by the Appeal Board and by the Commission, if any, and (6) any Environmental Impact Appraisal which has been or may be issued by the NRC since the FES was published in April 1973.

(19) Subsequent Renewed License Conditions.

(a) The information in the Updated Final Safety Analysis Report (UFSAR) supplement submitted pursuant to 10 CFR 54.21(d), as revised during the subsequent license renewal application review process, and Exelon Generation Company commitments as listed in Appendix A of the Safety Evaluation Report Related to the Subsequent License Renewal of Peach Bottom Atomic Power Station, Units 2 and 3, dated February 2020, are collectively the Subsequent License Renewal UFSAR Supplement. This Supplement is henceforth part of the UFSAR, which will be updated in accordance with 10 CFR 50.71(e). As such, Exelon Generation Company may make changes to the programs, activities, and commitments described in the Subsequent License Renewal UFSAR Supplement, provided Exelon Generation Company evaluates such changes pursuant to the criteria set forth in 10 CFR 50.59, Changes, Tests, and Experiments, and otherwise complies with the requirements in that section.

(b) The Subsequent License Renewal UFSAR Supplement, as defined in subsequent renewed license condition (19)(a) above, describes programs to be implemented and activities to be completed prior to the subsequent period of extended operation, which is the period following the August 8, 2033, expiration of the initial renewed license.

1. Exelon Generation Company shall implement those new programs and enhancements to existing programs no later than 6 months before the subsequent period of extended operation.

2. Exelon Generation Company shall complete those activities by the 6-month date prior to the subsequent period of extended operation or by the end of the last refueling outage before the subsequent period of extended operation, whichever occurs later.

3. Exelon Generation Company shall notify the NRC in writing within 30 days after having accomplished item (b)1 above and include the status of those activities that have been or remain to be completed in item (b)2 above.

Page 16 Subsequent Renewed License No. DPR-44

3. This subsequent renewed license is effective as of the date of issuance and shall expire at midnight on August 8, 2053.

FOR THE UNITED STATES NUCLEAR REGULATORY COMMISSION

/RA/

Ho K. Nieh, Director Office of Nuclear Reactor Regulation Attachments:

Appendix A - Technical Specifications Peach Bottom Atomic Power Station Unit 2 Appendix B - Environmental Protection Plan Date of Issuance: March 5, 2020 Page 17 Subsequent Renewed License No. DPR-44

APPENDIX A TECHNICAL SPECIFICATIONS FOR PEACH BOTTOM ATOMIC POWER STATION UNIT 2

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.

AVERAGE PLANAR LINEAR The APLHGR shall be applicable to a specific HEAT GENERATION RATE planar height and is equal to the sum of the (APLHGR) heat generation rate per unit length of fuel rod for all the fuel rods in the specified bundle at the specified height divided by the number of fuel rods in the fuel bundle at the height.

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 the entire channel, including the required sensor, alarm, display, and trip functions, and shall include the CHANNEL FUNCTIONAL TEST. 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 so that the entire channel is calibrated.

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

(continued)

PBAPS UNIT 2 1 .1-1 Amendment No. 210

Definitions 1.1 1.1 Definitions (continued)

CHANNEL FUNCTIONAL TEST A CHANNEL FUNCTIONAL TEST shall be the injection of a simulated or actual signal into the channel as close to the sensor as practicable to verify OPERABILITY, including required alarm, interlock, display, and trip functions, and channel failure trips. The CHANNEL FUNCTIONAL TEST may be performed by means of any series of sequential, overlapping, or total channel steps so that the entire channel is tested.

CORE ALTERATION COR E ALTERATI0N s hal 1 bet hem 0 vem ent 0 fan y f ue1 ,

sources, or reactivity control components within the reactor vessel with the vessel head removed and fuel in the vessel. The f ol l owi ng exceptions are not considered to be CORE ALTERATIONS:

a. Movement of wide range neutron monitors, local power range monitors, traversing incore probes, or special movable detectors (including undervessel replacement); and

b. Control rod movement, provided there are no fuel assemblies in the associated core cell.

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

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

DOSE EQUIVALENT 1-131 DOSE EQUIVALENT 1-131 shall be that concentration of 1-131 (microcuries/gram) that alone would produce the same dose as the quantity and isotopic mixture of 1-131, 1-132, 1-133, 1-134, and 1-135 actually present. The dose conversion factors used for this calculation shall be those listed in Table III of TID-14844, AEC, 1962, "Calculation of Distance Factors for Power and Test Reactor Sites,"

or Federal Guidance Report 11, "Limiting Values of Radionuclide Intake and Air Concentration and Dose Conversion Factors for Inhalation, Submersion, and Ingestion," 1989.

(continued)

PBAPS LIN IT 2 1.1-2 Amendment No.269

Definitions 1.1 1.1 Definitions (continued)

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

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

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

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

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

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

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

(continued)

PBAPS UNIT 2 1.1-3 Amendment No. 317

Definitions 1.1 1.1 Definitions (continued)

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

INSERVICE TESTING PROGRAM The INSERVICE TESTING PROGRAM is the licensee program that fulfills the requirements of 10 CFR 50.SSa(f).

LEAKAGE LEAKAGE shall be:

a. Identified LEAKAGE

1. LEAKAGE into the drywell, such as that from pump seals or valve packing, that is captured and conducted to a sump or collecting tank; or

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

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

c. Total LEAKAGE Sum of the identified and unidentified LEAKAGE;

d. Pressure Boundary LEAKAGE LEAKAGE through a nonisolable fault in a Reactor Coolant System (RCS) component body, pipe wall, or vessel wall.

LINEAR HEAT GENERATION The LHGR shall be the heat generation rate per RATE (LHGR) unit length of fuel rod. It is the integral of the heat flux over the heat transfer area associated with the unit length.

(continued)

PBAPS UNIT 2 1.1-3a Amendment No. 317

Definitions 1.1 1.1 Definitions (continued)

LOGIC SYSTEM FUNCTIONAL A LOGIC SYSTEM FUNCTIONAL TEST shall be a test TEST of all required logic components (i.e., all required relays and contacts, trip units, solid state logic elements, etc.) of a logic circuit, from as close to the sensor as practicable up to, but not including, the actuated device, to verify OPERABILITY. The LOGIC SYSTEM FUNCTIONAL TEST may be performed by means of any series of sequential, overlapping, or total system steps so that the entire logic system is tested.

MINIMUM CRITICAL POWER The MCPR shall be the smallest critical power RATIO (MCPR) ratio (CPR) that exists in the core. The CPR is that power in the assembly that is calculated by application of the appropriate correlation(s) to cause some point in the assembly to experience boiling transition, divided by the actual assembly operating power.

MODE A MODE shall correspond to any one inclusive combination of mode switch position, average reactor coolant temperature, and reactor vessel head closure bolt tensioning specified in Table 1.1-1 with fuel in the reactor vessel.

OPERABLE-OPERABILITY A system, subsystem, division, component, or device shall be OPERABLE or have OPERABILITY when it is capable of performing its specified safety function(s) and when all necessary attendant instrumentation, controls, normal or emergency electrical power, cooling and seal water, lubrication, and other auxiliary equipment that are required for the system, subsystem, division, component, or device to perform its specified safety function(s) are also capable of performing their related support function(s).

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

These tests are:

a. Described in Section 13.5, Startup and Power Test Program of the UFSAR; (continued)

PBAPS UNIT 2 1.1-4 Amendment No. 210

Definitions 1.1 1.1 Definitions PHYSICS TESTS b. Authorized under the provisions of (continued) 10 CFR 50.59; or

c. Otherwise approved by the Nuclear Regulatory Commission.

PRESSURE AND TEMPERATURE The PTLR is the unit-specific document that LIMITS REPORT (PTLR) provides the reactor vessel pressure and temperature limits, including heatup and cooldown rates, for the current reactor vessel fluence period. These pressure and temperature limits shall be determined for each fluence period in accordance with Specification 5.6.7.

RATED THERMAL POWER RTP shall be a total reactor core heat transfer (ITT~ rate to the reactor coolant of 4016 MWt.

REACTOR PROTECTION SYSTEM The RPS RESPONSE TIME shall be that time interval (RPS) RESPONSE TIME from the opening of the sensor contact up to and including the opening of the trip actuator contacts.

RECENTLY IRRADIATED RECENTLY IRRADIATED FUEL is fuel that has occupied FUEL part of a critical reactor core within the previous 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

SHUTDOWN MARGIN (SDM) SDM shall be the amount of reactivity by which the reactor is subcritical or would be subcritical throughout the operating cycle assuming that:

a. The reactor is xenon free;

b. The moderator temperature is~ 68'F, corresponding to the most reactive state; and

c. All control rods are fully inserted except for the single control rod of highest reactivity worth, which is assumed to be fully withdrawn.

With control rods not capable of being fully inserted, the reactivity worth of these control rods must be accounted for in the determination of SDM.

(continued)

PBAPS UNIT 2 1.1-5 Amendment No. 316

Def; nit ions 1.1 1.1 Definitions (continued)

STAGGERED TEST BASIS A STAGGERED TEST BASIS shall consist of the testing of one of the systems, subsystems, channels, or other designated components during the interval specified by the Surveillance Frequency. so that all systems, subsystems, channels, or other designated components are tested during n Surveillance Frequency intervals, where n is the total number of systems, subsystems, channels, or other designated components in the associated function.

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

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

a. The time from initial movement of the main turbine stop valve or control valve until 80%

of the turbine bypass capacity is established; and

b. The time from initial movement of the main turbine stop valve or control valve until initial movement of the turbine bypass valve.

The response time may be measured by means of any seri es of sequent i a1. overl appi ng, or tota 1 steps so that the entire response time is measured.

PBAPS UNIT 2 1.1-6 Amendment No. 286

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

MODES REACTOR MODE AVERAGE REACTOR MODE TITLE SWITCH POSITION COOLANT TEMPERATURE (0F) 1 Power Operation Run NA 2 Startup Refuel(a) or Startup/Hot NA Standby 3 Hot Shutdown(a) Shutdown > 212 4 Cold Shutdown(a) Shutdown S 212 5 Refueling(b) Shutdown or Refuel NA (a) All reactor vessel head closure bolts fully tensioned.

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

PBAPS UNIT 2 1.1-7 Amendment No. 210

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 indentions of the logical connectors.

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

EXAMPLES The following examples illustrate the use of logical connectors.

(continued)

PBAPS UNIT 2 1 .2-1 Amendment No. 210

Logical Connectors 1.2 1.2 Logical Connectors EXAMPLES EXAMPLE 1.2-1 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LCO not met. A.1 Verify . . .

AND A.2 Restore . . .

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

(continued)

PBAPS UNIT 2 1.2-2 Amendment No. 210

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

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 . . .

3R 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 QE 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 QE indicates that A.2.2.1 and A.2.2.2 are alternative choices, only one of which must be performed.

PBAPS UNIT 2 1.2-3 Amendment No. 210

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 m1n1mum 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 Times(s).

DESCRIPTION The Completion Time is the amount of time allowed for completing a Required Action. It is referenced to the 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. Unless otherwise specified, the Completion Time begins when a senior licensed operator on the operating shift crew with responsibility for plant operations makes the determination that an LCO is not met and an ACTIONS Condition is entered. The "otherwise specified" exceptions are varied, such as a Required Action Note or Surveillance Requirement Note that provides an alternative time to perform specific tasks, such as testing, without starting the Completion Time. While utilizing the Note, should a Condition-be applicable for any reason not addressed by the Note, the Completion Time begins. Should the time allowance in the Note be exceeded, the Completion Time begins at that point. The exceptions may also be incorporated into the Completion Time. For example, LCO 3.8.1, "AC Sources - Operating," Required Action B.3, requires declaring required feature(s) supported by an inoperable diesel generator, inoperable when the redundant required feature(s) are inoperable. The Completion Time states, "4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from discovery of Condition B concurrent with inoperability of redundant required feature(s)." In this case the Completion Time does not begin until the conditions in the Completion Time are satisfied. 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.

(continued)

PBAPS UNIT 2 1. 3-1 Amendment No.314

Completion Times 1.3 1.3 Completion Times DESCRIPTION If situations are discovered that require entry into more (continued) 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 discovery of the situation that required entry into the Condition, unless otherwise specified.

Once a Condition has been entered, subsequent divisions, 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, unless otherwise specified.

(continued)

PBAPS UNIT 2 1.3-la Amendment No.314

Completion Times 1.3 1.3 Completion Times OESCRI PTION However, when a subsequent division, subsystem, component, (continued) 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 iiLi1 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 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ; or

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

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

The above Completion Time extension does not apply to a Completion Time with a modified "time zero." This modified "time zero" may be expressed as a repetitive time (i .e.,

"once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ," where the Completion Time is referenced from a previous completion of the Required Action versus the time of Condition entry) or as a time modified by the phrase "from discovery . . . "

(continued)

PBAPS UNIT 2 1. 3 - 2 Amendment No. 277

Completion Times 1.3 1.3 Completion Times (continued)

EXAMPLES The following examples illustrate the use of Completion Times with different types of Conditions and changing Conditions.

EXAMPLE 1.3-1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. Required B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Action and associated AND Completion Time not B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months met.

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 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND in MODE 4 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . A total of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is allowed for reaching MODE 3 and a total of 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (not 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months ) is allowed for reaching MODE 4 from the time that Condition B was entered. If MODE 3 is reached within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , the time allowed for reaching MODE 4 is the next 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months because the total time allowed for reaching MODE 4 is 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

If Condition B is entered while in MODE 3, the time allowed for reaching MODE 4 is the next 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

(continued)

PBAPS UNIT 2 1.3-3 Amendment No. 210

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

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

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

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.

(continued)

PBAPS UNIT 2 1.3-4 Amendment No. 210

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

While in LCO 3.0.3, if one of the inoperable pumps is restored to OPERABLE status and the Completion Time for Condition A has expired, LCO 3.0.3 may be exited and operation continued in accordance with Condition B. The Completion Time for Condition 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 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months extension to the stated 7 days is allowed, provided this does not result in the second pump being inoperable for

> 7 days.

(continued)

PBAPS UNIT 2 1.3-5 Amendment No. 210

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

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

B. One B. 1 Restore 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Function Y Function Y subsystem subsystem to inoperable. OPERABLE status.

C. One C.1 Restore 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Function X Function X subsystem subsystem to inoperable. OPERABLE status.

MQ Q.R One C.2 Restore 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Function Y Function Y subsystem subsystem to inoperable. OPERABLE status.

(continued)

PBAPS UNIT 2 1 .3 - 6 Amendment No.277

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

When one Function X subsystem and one Function Y subsystem are inoperable, Condition A and Condition B are concurrently applicable. The Completion Times for Condition A and Condition B are tracked separately for each subsystem, starting from the time each subsystem was declared inoperable and the Condition was entered. A separate Completion Time is established for Condition C and tracked from the time the second subsystem was declared inoperable (i .e., the time the situation described in Condition C was di scovered).

If Required Action C.2 is completed within the specified Completion Time, Conditions Band C are exited. If the Completion Time for Required Action A.l 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 subsystem was declared inoperable (i.e., initial entry into Condition A).

It is 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. However, doing so would be inconsistent with the basis of the Completion Times. Therefore, there shall be administrative controls to limit the maximum time allowed for any combination of Conditions that result in a single contiguous occurrence of failing to meet the LCO. These administrative controls shall ensure that the Completion Times for those Conditions are not inappropriately extended.

(contjnued)

PBAPS UNIT 2 1. 3 - 7 Amendment No.2??

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-4 (continued)

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

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

A single Completion Time is used for any number of valves inoperable at the same time. The Completion Time associated with Condition A is based on the initial entry into Condition A and is not tracked on a per valve basis.

Declaring subsequent valves inoperable, while Condition A is still in effect, does not trigger the tracking of separate Completion Times.

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

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

(continued)

PBAPS UNIT 2 1.3-8 Amendment No. 210

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

ACTIONS

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

Separate Condition entry is allowed for each inoperable valve.

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

inoperable.

B. Required B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Action and associated AMD Completion Time not B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months met.

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

The Note allows Condition A to be entered separately for each inoperable valve, and Completion Times tracked on a per valve basis. When a valve is declared inoperable, Condition A is entered and its Completion Time starts. If subsequent valves are declared inoperable, Condition A is entered for each valve and separate Completion Times start and are tracked for each valve.

(continued)

PBAPS UNIT 2 1 .3-9 Amendment No. 210

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

If the Completion Time associated with a valve in Condition A expires, Condition B is entered for that valve.

If the Completion Times associated with subsequent valves in Condition A expire, 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.

EXAMPLE 1.3-6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One channel A.1 Perform Once per inoperable. SR 3.x.x.x. 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months OR A.2 Place channel in 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months trip.

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

(continued)

PBAPS UNIT 2 1 .3-10 Amendment No. 210

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

Entry into Condition A offers a choice between Required Action A.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 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months interval of Required Action A.1 begins when Condition A is entered and the initial performance of Required Action A.1 must be complete within the first 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months interval. If Required Action A.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 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 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.

(continued)

PBAPS UNIT 2 1 .3-11 Amendment No. 210

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One A.1 Verify affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months subsystem subsystem inoperable. isolated. AD Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND A.2 Restore subsystem 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months to OPERABLE status.

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

Required Action A.1 has two Completion Times. The 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Completion Time begins at the time the Condition is entered and each Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter' interval begins upon performance of Required Action A.1.

If after Condition A is entered, Required Action A.1 is not met within either the initial 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or any subsequent 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months interval from the previous performance (plus the extension allowed by SR 3.0.2), Condition 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 (continued)

PBAPS UNIT 2 1.3-12 Amendment No. 210

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

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

PBAPS UNIT 2 1.3-13 Amendment No. 210

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 Limiting Condition for Operation (LCO). An understanding of the correct application of the specified Frequency is necessary for compliance with the SR.

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

Sometimes special situations dictate when the requirements of a Surveillance are to be met. They are 'otherwise stated" conditions allowed by SR 3.0.1. They may be stated as clarifying Notes in the Surveillance, as part of the Surveillance, or both. Example 1.4-4 discusses these special situations.

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.

The use of 'met' or "performed" in these instances conveys specific meanings. A Surveillance is 'met' only when the acceptance criteria are satisfied. Known failure of the requirements of a Surveillance, even without a Surveillance specifically being "performed,' constitutes a Surveillance not 'met." 'Performance" refers only to the requirement to specifically determine the ability to meet the acceptance (continued)

PBAPS UNIT 2 1 .4-1 Amendment No. 210

Frequency 1.4 1.4 Frequency DESCRIPTION criteria. SR 3.0.4 restrictions would not apply if both the (continued) following conditions are satisfied:

a. The Surveillance is not required to be performed; and

b. The Surveillance is not required to be met or, even if required to be met, is not known to be failed.

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. The examples do not reflect the potential application of LCO 3.0.4.b. I EXAMPLE 1.4-1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Example 1.4-1 contains the type of SR most often encountered in the Technical Specifications (TS). The Frequency specifies an interval (12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ) during which the associated Surveillance must be performed at least one time.

Performance of the Surveillance initiates the subsequent interval. Although the Frequency is stated as 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , an extension of the time interval to 1.25 times the interval specified in the Frequency is allowed by SR 3.0.2 for operational flexibility. The measurement of this interval continues at all times, even when the SR is not required to be met per SR 3.0.1 (such as when the equipment is inoperable, a variable is outside specified limits, or the unit is outside the Applicability of the LCO). If the interval specified by SR 3.0.2 is exceeded while the unit is in a MODE or other specified condition in the Applicability of the LCO, and the performance of the Surveillance is not otherwise modified (refer to Examples 1.4-3 and 1.4-4), then SR 3.0.3 becomes applicable.

(continued)

PBAPS UNIT 2 1.4 -2 Amendment No. 252

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

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

EXAMPLE 1.4-2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Verify flow is within limits. Once withi n 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after

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

25% RTP. the Surveillance must be performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

The use of "once" indicates a single performance will satisfy the specified Frequency (assuming no other Frequencies are connected by "AND"). This type of Frequency does not qualify for the extension allowed by SR 3.0.2.

(continued)

PBAPS UN IT 2 1. 4 - 3 Amendment N0'273

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

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

EXAMPLE 1.4-3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

- - - - - - - - - - - - - - - - - - NOT E- - - - - - - - - - - - - - - - -

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

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

< 25% RTP between performances.

As the Note modifies the required performance of the Survei 11 ance, it is const rued to be pa rt of the "speci fi ed Frequency." Shoul d the 7 day i nterv*a 1 be exceeded whi 1e operation is < 25% RTP, this Note allows 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after power reaches ~ 25% RTP to perform the Surveillance. The Surveillance is still considered to be within th~ "specified Frequency. " Therefore, if the Survei 11 ance were not performed within the 7 day interval (plus the extension allowed by SR 3.0.2), 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 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (plus the extension allowed by SR 3.0.2) with power ~ 25% RTP.

(contjnued)

PBAPS UNIT 2 1. 4-4 Amendment No.272

Frequency 1.4 1.4 Frequency EXAMP LES EXAMPLE 1.4-3 (continued)

Once the unit reaches 25% RTP, 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months would be allowed for completing the Surveillance. If the Surveillance were not performed within this 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months interval (plus the extension allowed by SR 3.0.2), there would then be a failure to perform a Surveillance within the specified Frequency, and the provisions of SR 3.0.3 would apply.

EXAMPLE 1. 4-4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

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

Only required to be met in MODE 1.

Verify leakage rates are within limits. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Example 1.4-4 specifies that the requirements of this Surveillance do not have to be met until the unit is in MODE 1. The interval measurement for the Frequency of this Surveillance continues at all times, as described in Example 1.4-1. However, the Note constitutes an "otherwise stated" exception to the Applicability of this Surveillance.

Therefore, if the Surveillance were not performed within the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months interval (plus the extension allowed by SR 3.0.2),

but the unit was not in MODE 1, there would be no failure of the SR nor failure to meet the LCO. Therefore, no violation of SR 3.0.4 occurs when changing MODES, even with the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency exceeded, provided the MODE change was not made into MODE 1. Prior to entering MODE 1 (assuming again that the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency were not met), SR 3.0.4 would require satisfying the SR.

PBAPS UN IT 2 1. 4 - 5 Amendment No.272

SLs 2.0 2.0 SAFETY LIMITS (SLs) 2.1 SLs 2.1.1 Reactor Core SLs 2.1.1.1 With the reactor steam dome pressure< 700 psia or core flow< 10% rated core flow:

THERMAL POWER shall be~ 22.6% RTP.

2.1.1.2 With the reactor steam dome pressure~ 700 psia and core flow~ 10% rated core flow:

MCPR shall be~ 1.07.

2.1.1.3 Reactor vessel water level shall be greater than the top of active irradiated fuel.

2.1.2 Reactor Coolant System Pressure SL Reactor steam dome pressure shall be~ 1340 psig.

2.2 SL Violations With any SL violation, the following actions shall be completed within 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months s:

2.2.1 Restore compliance with all Sls; and 2.2.2 Insert all insertable control rods.

PBAPS UNIT 2 2.0-1 Amendment No. 326

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, LCO 3.0.7 and LCO 3.0.8.

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

If the LCO is met or is no longer applicable prior to expiration of the specified 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 in which the LCO is not applicable. Action shall be initiated within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to place the unit, as applicable, in:

a. MODE 2 within 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months ;

b. MODE 3 within 13 hours1.50463e-4 days 0.00361 hours 2.149471e-5 weeks 4.9465e-6 months ; and

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

Exceptions to this Specification are stated in the individual Specifications.

Where corrective 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 ~pplicable in MODES 1, 2, and 3.

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

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

b. After performance of a risk assessment addressing inoperable systems and components, consideration of the results, determination of the acceptability of (continued)

PBAPS UNIT 2 3.0-1 Amendment No. 285

LCO Applicability 3.0 3.0 LCO APPLICABILITY LCO 3.0.4 entering the MODE or other specified condition in the (continued) Applicability, and establishment of risk management actions, if appropriate (exceptions to this Specification are stated in the individual Specifications); or

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

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

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

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, additional evaluations and limitations may be required in accordance with Specification 5.5.11, "Safety Function Determination Program (SFDP)." If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered.

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

(continued)

PBAPS UNIT 2 3.0-2 Amendment No.314

LCO Applicability 3.0 3.0 LCO APPLICABILITY (continued)

LCO 3.0.7 Special Operations LCOs in Section 3.10 allow specified Technical Specifications (TS) requirements to be changed to permit performance of special tests and operations. Unless otherwise specified, all other TS requirements remain unchanged. Compliance with Special Operations LCOs is optional. When a Special Operations LCO is desired to be met but is not met, the ACTIONS of the Special Operations LCO shall be met. When a Special Operations LCO is not desired to be met, entry into a MODE or other specified condition in the Applicability shall only be made in accordance with the other applicable Specifications.

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

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

b. the snubbers not able to perform their associated support function(s) are associated with more than one train or subsystem of a multiple train or subsystem supported system and are able to perform their associated support function within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

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

PBAPS UNIT 2 3.0-3 Amendment No. 285

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 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or up to the limit of the specified Frequency, whichever is greater. This delay period is permitted to allow performance of the Surveillance. The delay period is only applicable when there is a reasonable expectation the surveillance will be met when performed. A risk evaluation shall be performed for any Surveillance delayed greater than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and the risk impact shall be managed.

If the Surveillance is not performed within the delay period, the LCO must 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.

(continued)

PBAPS UNIT 2 3.0-4 Amendment No.314

SR Applicability 3.0 3.0 SR APPLICABILITY (continued)

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

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

PBAPS UNIT 2 3.0- 5 Amendment No. god, 252

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

LCO 3.1.1 SDM shall be:

a. ; 0.38% Ak/k, with the highest worth control rod analytically determined; or

b. > 0.28% Ak/k, with the highest worth control rod determined by test.

APPLICABILITY: MODES 1, 2, 3, 4, and 5.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SDM not within limits A.1 Restore SDM to within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months in MODE 1 or 2. limits.

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

C. SDM not within limits C.1 Initiate action to Immediately in MODE 3. fully insert all insertable control rods.

D. SDM not within limits D.1 Initiate action to Immediately in MODE 4. fully insert all insertable control rods.

AND (continued)

PBAPS UNIT 2 3.1-1 Amendment No. 210

SDM 3.1.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. (continued) D.2 Initiate action to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore secondary containment to OPERABLE status.

AND D.3 Initiate action to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore one standby gas treatment (SGT) subsystem for Unit 2 to OPERABLE status.

AND D.4 Initiate action to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore isolation capability in each required secondary containment penetration flow path not isolated.

E. SDM not within limits E.1 Suspend CORE Immediately in MODE 5. ALTERATIONS except for control rod insertion and fuel assembly removal.

AND E.2 Initiate action to Immediately fully insert all insertable control rods in core cells containing one or more fuel assemblies.

(continued)

PBAPS UNIT 2 3.1-2 Amendment No. 210

SDM 3.1.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. (continued) E.3 Initiate action to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore secondary containment to OPERABLE status.

AND E.4 Initiate action to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore one SGT subsystem for Unit 2 to OPERABLE status.

AND E.5 Initiate action to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore isolation capability in each required secondary containment penetration flow path not isolated.

PBAPS UNIT 2 3.1-3 Amendment No. 210

SDM 3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.1.1 Verify SDM is: Prior to each in vessel fuel

a. 2 0.38% Ak/k with the highest worth movement during control rod analytically determined; fuel loading or sequence

b. ; 0.28% Ak/k with the highest worth AND control rod determined by test.

Once within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after criticality following fuel movement within the reactor pressure vessel or control rod replacement PBAPS UNIT 2 3.1-4 Amendment No. 210

Reactivity Anomalies 3.1.2 3.1 REACTIVITY CONTROL SYSTEMS 3.1.2 Reactivity Anomalies LCO 3.1.2 The reactivity difference between the monitored core kMf and the predi cted core keff sha 11 be wi thi n +/- 1% ak/k.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Core reactivity A.1 Restore core 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months difference not within reactivity difference 1imit. to within limit.

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

PBAPS UNIT 2 3.1-5 Amendment No. 284

Reactivity Anomalies 3.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.2.1 Verify core reactivity difference between Once within the monitored core keff and the predicted 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after core keff ; 5 within +/- U Ak/k. reaching equilibrium conditions following startup after fuel movement withi n the reactor pressure vessel or control rod replacement

.8RIl 1000 MWD/T thereafter during operations in MODE 1 PBAPS UN IT 2 3.1-6 Amendment No.284

Control Rod OPERABILITY 3.1.3 3.1 REACTIVITY CONTROL SYSTEMS 3.1.3 Control Rod OPERABILITY LCO 3.1.3 Each control rod shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS

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

Separate Condition entry is allowed for each control rod.

CONDITION REQUIRED ACTION COMPLETION TIME A. One withdrawn control ------------ NOTE-------------

rod stuck. Rod worth minimizer (RWM) may be bypassed as allowed by LCO 3.3.2.1, Control Rod Block Instrumentation," if required, to allow continued operation.

A.1 Verify stuck control Immediately rod separation criteria are met.

AND A.2 Disarm the associated 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months control rod drive (CRD).

AND (continued)

PBAPS UNIT 2 3.1-7 Amendment No. 210

Control Rod OPERABILITY 3.1. 3 ACTIONS CONDITION REqu I RED ACTION COMPLETION TIME A. (continued) A.3 Perform SR 3.1.3.3 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months from for each withdrawn discovery of OP ERAB LE cont ro 1 rod. Cond it i on A concurrent with THERMAL POWER greater than the low power setpoint (LPSP) of the RWM A.4 Perform SR 3.1.1.1.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months B. Two or more wi thd rawn B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months control rods stuck.

C. One or more control C.1 - - - .. - - . NOTE - - - - - -'

rods inoperable for RWM may be bypassed reasons other than as allowed by Condition A or B. LCO 3.3.2.1, if required, to allow insertion of inoperable control rod and continued operation.

Fully insert 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months inoperable control rod.

C.2 Disarm the associated 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months CRD.

(continued)

PBAPS UNIT 2 3.1-8 Amendment No.272

Control Rod OPERABILITY 3.1.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. ---------- NOTE--------- D.1 Restore compliance 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Not applicable when with the analyzed rod THERMAL POWER position sequence.

> 10% RTP.

- --- --- --- -- OR Two or more inoperable D.2 Restore control rod 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months control rods not in to OPERABLE status.

compliance with the analyzed rod position sequence and not separated by two or more OPERABLE control rods.

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

OR Nine or more control rods inoperable.

PBAPS UNIT 2 3.1-9 Amendment No.260

Control Rod OPERABILITY 3.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.1.3.5 Verify each withdrawn control rod does not Each time the go to the withdrawn overtravel position. control rod is withdrawn to "full out" position ANDl Prior to declaring control rod OPERABLE after work on control rod or CRD System that could affect coupling PBAPS UNIT 2 3. 1-11 Amendment No. 210

Control Rod Scram Times 3.1.4 3.1 REACTIVITY CONTROL SYSTEMS 3.1.4 Control Rod Scram Times LCO 3.1.4 a. No more than 13 OPERABLE control rods shall be "slow,"

in accordance with Table 3.1.4-1; and

b. No more than 2 OPERABLE control rods that are "slow" shall occupy adjacent locations.

APPLICABILITY: MODES I and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the A.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months LCO not met.

SURVEILLANCE REQUIREMENTS

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

During single control rod scram time Surveillances, the control rod drive (CRD) pumps shall be isolated from the associated scram accumulator.

SURVEILLANCE FREQUENCY SR 3.1.4.1 Verify each control rod scram time is Prior to I

within the limits of Table 3.1.4-1 with exceeding reactor steam dome pressure 2 800 psig. 40% RTP after each reactor shutdown 2 120 days (continued)

PBAPS UNIT 2 3.1- 12 Amendment No. 259

Control Rod Scram Times 3.1.4 Table 3.1.4-1 (page 1 of 1)

Control Rod Scram Times

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

1. OPERABLE control rods with scram times not within the limits of this Table are considered "slow."

2. Enter applicable Conditions and Required Actions of LCO 3.1.3, "Control Rod OPERABILITY," for control rods with scram times > 7 seconds to notch position 06. These control rods are inoperable, in accordance with SR 3.1.3.4, and are not considered 'slow."

SCRAM TIMES WHEN REACTOR STEAM DTE)PRESSURE 2: 800 psig(aJ )

NOTCH POSITION (seconds) 46 0.44 36 1.08 26 1.83 06 3.35 (a) Maximum scram time from fully withdrawn position, based on de-energization of scram pilot valve solenoids at time zero.

(b) When reactor steam dome pressure is < 800 psig, established scram time limits apply.

PBAPS UNIT 2 3.1-14 Amendment No. 210

Control Rod Scram Accumulators 3.1.5 3.1 REACTIVITY CONTROL SYSTEMS 3.1.5 Control Rod Scram Accumulators LCO 3.1.5 Each control rod scram accumulator shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS

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

Separate Condition entry is allowed for each control rod scram accumulator.

CONDITION REQUIRED ACTION COMPLETION TIME A. One control rod scram A.1 -------- NOTE---------

accumulator inoperable Only applicable if with reactor steam the associated dome pressure control rod scram 2 900 psig. time was within the limits of Table 3.1.4-1 during the last scram time Surveillance.

Declare the 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months associated control rod scram time

,slow."

OR A.2 Declare the 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months associated control rod inoperable.

(continued)

PBAPS UNIT 2 3.1-15 Amendment No. 210

I Control Rod Scram Accumulators 3.1.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Two or more control B.1 Restore charging 20 minutes from rod scram accumulators water header pressure discovery of inoperable with reactor steam dome to > 940 psig. Condition B concurrent with I

pressure 2 900 psig. charging water header pressure

< 940 psig AND B.2.1 --------NOTE---------

Only applicable if the associated control rod scram time was within the limits of Table 3.1.4-1 during the last scram time Surveillance.

Declare the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated control rod scram time oslow..

B.2.2 Declare the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated control rod inoperable.

(continued)

PBAPS UNIT 2 3.1-16 Amendment No. i10, 211 4's: '

Rod Pattern Control 3.1.6 3.1 REACTIVITY CONTROL SYSTEMS 3.1.6 Rod Pattern Control LCO 3.1.6 OPERABLE control rods shall comply with the requirements of the analyzed rod position sequence.

APPLICABILITY: MODES 1 and 2 with THERMAL POWER

10% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more OPERABLE A.1 ---------

NOTE--------

control rods not in Rod worth minimizer compliance with the (RWM) may be bypassed analyzed rod position as allowed by sequence. LCO 3.3.2.1, "Control Rod Block Instrumentation."

Move associated 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months control rod(s) to correct position.

OR A.2 Declare associated 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months inoperable.

(continued)

PBAPS UNIT 2 3.1-18 Amendment No 260

SLC System 3.1.7 3.1 REACTIVITY CONTROL SYSTEMS 3.1.7 Standby Liquid Control (SLC) System LCO 3.1.7 Two SLC subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REOUIRED ACTION COMPLETION TIME A. Concentration of boron A.1 Verify the 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months in solution> 9.82% concentration and weight. temperature of boron in solution and pump suction piping Once per temperature are 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months within the limits of thereafter Figure 3.1.7-1.

A.2 Restore concentration 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months of boron in solution to ~ 9.82% weight.

B. One SLC subsystem B.1 Restore SLC subsystem 7 days inoperable for reasons to OPERABLE status.

other than Condition A.

(cont i nued)

PBAPS UNIT 2 3.1-20 Amendment No. 277

SLC System 3 .1. 7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

c. Two SLC subsystems c.1 Restore one SLC 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months inoperable for reasons subsystem to OPERABLE other than status.

Condition A.

D. Required Action and D.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AND D.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.1 Verify level of sodium pentaborate solution In accordance in the SLC tank is~ 52%. with the Surveillance Frequency Control Program.

SR 3.1.7.2 Verify temperature of sodiu~ pentaborate In accordance solution is~ 53°F. with the Surveillance Frequency Control Program.

SR 3.1.7.3 Verify temperature of pump suction piping In accordance is~ 53°F.

with the Surveillance Frequency Control Program.

(continued)

PBAPS UN IT 2 3.1-21 Amendment No. 293

SLC System 3 .1. 7 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.1.7.4 Verify continuity of explosive charge. In accordance with the Surveillance Frequency Control Program.

SR 3.1.7.5 Verify the concentration of boron in In accordance solution is~ 8.32% weight and~ 9.82% with the weight. Surveillance Frequency Control Program.

Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after water or boron is added to solution Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after solution temperature is restored within limits SR 3.1.7.6 Verify each SLC subsystem manual and power In accordance operated valve in the flow path that is not with the locked, sealed, or otherwise secured in Surveillance position is in the correct position, or can Frequency be aligned to the correct position. Control Program.

(continued)

PBAPS UN IT 2 3.1-22 Amendment No. 293

SLC System 3 .1. 7 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3 .1. 7. 7 Deleted SR 3.1.7.8 Verify each pump develops a flow rate In accordance

~ 49.1 gpm at a discharge pressure with the

~ 1275 psig. INSERVICE TESTING PROGRAM SR 3.1.7.9 Verify flow through one SLC subsystem from In accordance pump into reactor pressure vessel. with the Surveillance Frequency Control Program.

SR 3.1.7.10 Verify sodium pentaborate enrichment is Prior to

~ 92.0 atom percent B-10. addition to SLC tank PBAPS UNIT 2 3 .1-23 Amendment No. 313

SLC System 3 .1. 7 THIS PAGE INTENTIONALLY LEFT BLANK The contents of this page have been deleted.

PBAPS UN IT 2 3.1-24 Amendment No. 2 93

SLC System 3 .1. 7 110.0 .,----,---,-------,-,--,----,---,--,---,--,----,---,---,-,--------,---,-----,-----,.--,---;,

1(8.32% 11o') 1 ( 4.0%, 1 1 0 ; /

105.o +---+-+--++--+--+-+--+-+---+---+--+----+--+-----,---+----+--+-v~~---~

1 100.0 f--------------------t--------------------*,,*------------*tvL_

./

_LL 95.0 +--+--+--+--t----+---------1--+---+---+-____;.---+----+---!--f--L-'~"--t---t--+-~-

~ 90.0 Acc~:-prA LE

~ --------- V: . _ __

1

~ 85.0 +---+"C"CNcccO:=t-----+-t--+--------1--+----+----+----+-+v~'l------+!----'---+---t--t--1---~

~ 80.0 Aft-g~:r ~~g - ******************** .......... -- . T : ;

LLJ 75.o -t--+---+-+-+-----+-----t--+---+------t------;v---.~/-+----+---+---'---'-+------t----1---t-~:

~

~ 70 .0 ......................................................... I ********************************** /

7

/ I ~.OT ACCEP ABLE 65.o +---+--+---+i-t--+--------1--+---/-hv~+-----r-- :-+-+--t-*--+----"---+---t--+-----+----

6o.o-+ -+***************f************* i r ******--******t/_ * -** * * * * * * --- ********* ------------ --------

55*0 ---j-(8-:-:.3""'2,.-%T:53-~

'--+--'I 5.0 6.0 7.0 8.0 9.0 10.0 11.0 12.0 13.0 14.0 15.0 16.0 17.0 18.0 19.0 20.0 21.0 22.0 23.0 24.0 CONCENTRATION (Weight Percent Pentaborate in Solution)

Figure 3.1.7-1 (page 1 of 1)

Sodium Pentaborate Solution Temperature Versus Concentration Requirements PBAPS UN IT 2 3.1-25 Amendment No. 293

SDV Vent and Drain Valves 3.1.8 3.1 REACTIVITY CONTROL SYSTEMS 3.1.8 Scram Discharge Volume (SDV) Vent and Drain Valves LCO 3.1.8 Each SDV vent and drain valve shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS

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

1. Separate Condition entry is allowed for each SDV vent and drain line. I

2. An isolated line may be unisolated under administrative control to allow draining and venting of the SDV. I CONDITION REQUIRED ACTION COMPLETION TIME A. One or more SDV vent A.1 Isolate the 7 days or drain lines with one valve inoperable.

associated line. I B. One or more SDV vent B.1 Isolate the 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or drain lines with associated line.

both valves inoperable.

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

PBAPS UNIT 2 3.1- 26 Amendment No.259

APLHGR 3.2.1 3.2 POWER DISTRIBUTION LIMITS 3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR)

LCO 3.2.1 All APLHGRs shall be less than or equal to the limits specified in the COLR.

APPLICABILilY: THERMAL POWER 2 22.6% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Any APLHGR not within A.1 Restore APLHGR(s) to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months limits. within limits.

B. Required Action and B.1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion to < 22 . 6% RTP.

Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3. 2 .1.1 Verify all APLHGRs are less than or equal Once within to the limits specified in the COLR. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after 2 22.6% RTP In accordance with the Surveillance Frequency Control Program.

PBAPS UNIT 2 3.2-1 Amendment No. 316

MCPR 3.2.2 3.2 POWER DISTRIBUTION LIMITS 3.2.2 MINIMUM CRITICAL POWER RATIO (MCPR)

LCO 3.2.2 All MCPRs shall be greater than or equal to the MCPR operating limits specified in the COLR.

APPLICABILITY: THERMAL POWER z 22.6% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Any MCPR not within A.1 Restore MCPR(s) to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months limits. within limits.

B. Required Action and B.1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion to < 22 . 6% RTP.

Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify all MCPRs are greater than or equal Once within to the limits specified in the COLR. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after 2 22.6% RTP In accordance with the Surveillance Frequency Control Program.

(continued)

PBAPS UNIT 2 3.2-2 Amendment No. 316

MCPR 3.2.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.2.2.2 Determine the MCPR limits. Once within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after each completion of SR 3.1.4.1 AND Once within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after each completion of SR 3.1.4.2 AND Once within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after each completion of SR 3.1.4.4 PBAPS UNIT 2 3.2 -3 Amendment No.259

LHGR 3.2.3 3.2 POWER DISTRIBUTION LIMITS 3.2.3 LINEAR HEAT GENERATION RATE (LHGR)

LCO 3.2.3 All LHGRs shall be less than or equal to the limits specified in the COLR.

APPLICABILITY: THERMAL POWER~ 22.6% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Any LHGR not within A.1 Restore LHGR(s) to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months limits. within limits.

B. Required Action and B.1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion to< 22.6% RTP.

Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 Verify all LHGRs are less than or equal to Once within the limits specified in the COLR. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after

~ 22. 6% RTP In accordance with the Surveillance Frequency Control Program.

PBAPS UNIT 2 3.2-4 Amendment No. 316

RPS Instrumentation 3.3.1.1 3.3 INSTRUMENTATION 3.3.1.1 Reactor Protection System (RPS) Instrumentation LCO 3.3.1.1 The RPS instrumentation for each Function in Table 3.3.1.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.1.1-1.

ACTIONS

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

1. Separate Condition entry is allowed for each channel.

2. When Functions 2.b and 2.c channels are inoperable due to the calculated power exceeding the APRM output by more than 2% RTP while operating at

~ 22.6% RTP, entry into associated Conditions and Required Actions may be delayed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

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

A.2 --------NOTE--------- 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Not applicable for Functions 2.a, 2.b, 2.c, 2.d, or 2.f.

Place associated trip system in trip.

(continued)

PBAPS UN IT 2 3.3-1 Amendment No. 322

RPS Instrumentation 3.3.1.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. --------NOTE--------- B.l Pl ace channel in one 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Not applicable for trip system in trip.

Functions 2.a, 2.b, 2.c, 2.d, or 2.f.

One or more Functions B.2 Place one trip system 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months with one or more in trip.

required channels inoperable in both trip systems.

C. One or more automatic C.l Restore RPS trip 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Functions with RPS capability.

trip capability not maintained.

Two or more manual Functions with RPS trip capability not maintained.

D. Required Action and D.l Enter the Condition Immediately associated Completion referenced in Time of Condition A, Table 3.3.1.1-1 for B, or C not met. the channel.

E. As required by E. 1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Required Action D.l to< 26.3% RTP.

and referenced in Table 3.3.1.1-1.

(continued)

PBAPS UN IT 2 3.3-2 Amendment No. 322

RPS Instrumentation 3.3.1.1 ACTIONS (Continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. As required by F. 1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Required Action D.1 and referenced in Table 3.3.1.1-1.

G. As required by G.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Required Action D.1 and referenced in Table 3.3.1.1-1.

H. As required by H.1 Initiate action to Immediately Required Action D.1 fully insert all and referenced in insertable control Table 3.3.1.1-1. rods in core cells containing one or more fuel assemblies.

I. As required by I.1 Initiate action to Immediately Required Action D.1 implement the Manual and referenced in Backup Stability Table 3.3.1.1-1. Protection (BSP)

Regions defined in the COLR.

AND I. 2 Implement the 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Automated BSP Scram Region using the modified APRM Simulated Thermal Power-High scram setpoints defined in the COLR.

AND I.3 Initiate action to Immediately submit an OPRM report in accordance with Specification 5.6.8.

(continued)

PBAPS UN IT 2 3.3-3 Amendment No. 322

RPS Instrumentation 3.3.1.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME J. Required Action and J. 1 Initiate action to Immediately associated Completion implement the Manual Time of Condition I BSP Regions defined in not met. the COLR.

AND J.2 Reduce operation to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months below the BSP Boundary defined in the COLR.

AND J.3 -------- NOTE--------

LCO 3.0.4 is not applicable.

Restore required 120 days channel to OPERABLE.

K. Required Action and K.1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion to< 17.6% RTP.

Time of Condition J not met.

PBAPS UN IT 2 3.3-3a Amendment No. 322

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS

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

1. Refer to Table 3.3.1.1-1 to determine which SRs apply for each RPS Function.

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

SURVEILLANCE FREQUENCY SR 3.3.1.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program.

SR 3.3.1.1.2 - - - - - - - - - - - - - - - - - - NOTE - - - - - - - - - - - - - - - - - - -

Not required to be performed unti 1 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER~ 22.6% RTP.

Verify the calculated power does not In accordance exceed the average power range monitor with the (APRM) channels by greater than 2% RTP Surveillance while operating at~ 22.6% RTP. Frequency Control Program.

(continued)

PBAPS UN IT 2 3.3-3b Amendment No. 322

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.9 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program.

SR 3.3.1.1.10 Deleted.

SR 3.3.1.1.11 - - - - - - - - - - - - - - - - - -NOTES- - - - - - - - - - - - - - - - - -

1. For Function 2.a, not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2.

2. For Functions 2.b and 2.f, the CHANNEL FUNCTIONAL TEST includes the recirculation flow input processing, excluding the flow transmitters.

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program.

(continued)

PBAPS UN IT 2 3.3-5 Amendment No. 299

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3 . 3 . 1. 1. 12 ------------------NOTES------------------

1. Neutron detectors are excluded.

2. For Function 1, not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2.

3. For Functions 2.b and 2.f, the recirculation flow transmitters that feed the APRMs are included.

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

SR 3.3.1.1.13 Verify Turbine Stop Valve-Closure and In accordance Turbine Control Valve Fast Closure, Trip with the Oil Pressure- Low Functions are not Surveillance bypassed when THERMAL POWER is Frequency

~ 26.3% RTP. Control Program.

SR 3.3.1.1.14 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program.

SR 3.3.1.1.15 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program.

(continued)

PBAPS UNIT 2 3.3-6 Amendment No. 316

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.16 Deleted SR 3.3.1.1.17 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program.

SR 3.3.1.1.18 Verify the RPS RESPONSE TIME is within In accordance limits. with the Surveillance Frequency Control Program.

SR 3.3.1.1.19 Deleted PBAPS UN IT 2 3.3-6a Amendment No. 305

RPS Instrumentation 3.3.1.1 Table 3.3.1.1-1 (page 1 of 3)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.l REQUIREMENTS VALUE

1. Wide Range Neutron Monitors

a. Period-Short 2 G SR 3.3.1.1.1 ;, 13 seconds SR 3.3.1.1.5 SR 3.3.1.1.12 SR 3. 3 .1.1.17 SR 3.3.1.1.18 (a) 5 H SR 3.3.1.1.1 ;, 13 seconds SR 3.3.1.1.6 SR 3. 3. 1.1.12 SR 3. 3 .1.1.17 SR 3.3.1.1.18

b. Inop G SR 3.3.1.1.5 NA SR 3. 3 .1.1.17 Cal 5 H SR 3.3.1.1.6 NA SR 3. 3 .1.1.17

2. Average Power Range Monitors

a. Neutron Flux-High G SR 3.3.1.1.1 ,; 15.0% RTP (Setdown) SR 3.3.1.1.8 SR 3.3.1.1.11 SR 3.3.1.1.12

b. Simulated Thermal 1 F SR 3.3.1.1.1 ,; 0.60 W Power-High SR 3.3.1.1.2 + 65. 9% RTPcblc,,

SR 3.3.1.1.8 and ,; 118.0%

SR 3.3.1.1.11 RTP SR 3. 3 .1.1.12*"'

c. Neutron Flux-High 1 F SR 3.3.1.1.1 ,; 119.7% RTP SR 3.3.1.1.2 SR 3.3.1.1.8 SR 3.3.1.1.11 SR 3.3.1.1.12

d. Inop 1,2 G SR 3.3.1.1.11 NA

e. 2-0ut-Of-4 Voter 1,2 2 G SR 3.3.1.1.1 NA SR 3.3.1.1.11 SR 3. 3 .1.1.17 SR 3.3.1.1.18

f. OPRM Upscale ;, 17. 6%'h) SR 3.3.1.1.1 NA RTP SR 3.3.1.1.8 SR 3.3.1.1.11 SR 3.3.1.1.12 (continued)

(a) With any control rod withdrawn from a core cell containing one or more fuel assemblies.

(b) 0.54 (W - t,.W) + 60.3% RTP when reset for single loop operation per LCO 3.4.1, "Recirculation Loops Operating."!

(c) Each APRM channel provides inputs to both trip systems.

(d) De 1 eted (e) 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.

(f) The instrument channel set point shall be reset to a value that is within the Leave Alone Zone (LAZ) 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 the as-found tolerance and LAZ apply to the actual setpoint implemented in the Surveillance procedures to confirm channel performance. The NTSP methodologies used to determine the as-found tolerance and the LAZ are specified in the Bases associated with the specified function.

PBAPS UNIT 2 3.3-7 Amendment No. 316

RPS Instrumentation 3.3.1.l Table 3.3.1.1-1 Cpage la of 3)

Reactor Protection System Instrumentation Cg) With OPRM Upscale (Function 2.f) inoperable, the Automated BSP Scram Region setpoints are implemented in accordance with Action I of this Specification.

(h) Following Detect and Suppress Solution-Confirmation Density CDSS-CD) implementation, DSS-CD is not required to be armed while in the DSS-CD Armed Region during the first reactor startup and during the first controlled shutdown that passes completely through the DSS-CD Armed Region. However, DSS-CD is considered OPERABLE and shall be maintained OPERABLE and capable of automatically arming for operation at recirculation drive flow rates above the DSS-CD Armed Region.

PBAPS UNIT 2 3.3-7a Amendment No. 305

RPS Instrumentation 3.3.1.1 Table 3.3.1.1-1 (page 2 of 3)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D. l REQUIREMENTS VALUE

3. Reactor Pressure -High 1, 2 2 G SR 3.3.1.1.1 ,; 1085.0 psig SR 3.3.1.1.9 SR 3. 3 .1.1.15 SR 3. 3 .1.1.17 SR 3.3.1.1.18

4. Reactor Vessel Water 1,2 2 G SR 3.3.1.1.1 :,. 1. 0 inches Level-Low (Level 3) SR 3.3.1.1.9 SR 3. 3. 1.1.15 SR 3. 3 .1.1.17 SR 3.3.1.1.18

5. Main Steam Isolation 1 8 F SR 3.3.1.1.9 ,; 10% closed Valve -Closure SR 3. 3 .1.1.15 SR 3. 3 .1.1.17 SR 3. 3 .1.1.18

6. Drywell Pressure - High 1,2 2 G SR 3.3.1.1.1 ,; 2.0 psig SR 3.3.1.1.9 SR 3. 3 .1.1.15 SR 3. 3 .1.1.17 SR 3. 3 .1.1.18

7. Scram Discharge Volume 1, 2 2 G SR 3.3.1.1.9 ,; 50.0 gallons Water Level -High SR 3. 3. 1.1.15 SR 3. 3 .1.1.17 SR 3.3.1.1.18 5(a) 2 H SR 3.3.1.1.9 ,; 50.0 gallons SR 3. 3 .1.1.15 SR 3. 3 .1.1.17

8. Turbine Stop :,. 26. 3% RTP 4 E SR 3.3.1.1.9 ,; 10% closed Valve -Closure SR 3.3.1.1.13 SR 3. 3 .1.1.15 SR 3. 3 .1.1.17 SR 3. 3. 1.1.18

9. Turbine Control Valve :,. 26.3% RTP 2 E SR 3.3.1.1.9 :,. 500.0 psig Fast Closure, Trip Oil SR 3.3.1.1.13 Pressure -Low SR 3. 3 .1.1.15 SR 3. 3 .1.1.17 SR 3. 3 .1.1.18

10. Turbine Condenser -Low 1 2 F SR 3.3.1.1.1 ;, 21. 5 inches Vacuum SR 3.3.1.1.9 Hg vacuum SR 3. 3. 1.1.15 SR 3. 3 .1.1.17 SR 3.3.1.1.18

11. Deleted

12. Reactor Mode Switch - 1,2 1 G SR 3. 3 .1.1.14 NA Shutdown Position SR 3. 3 .1.1.17 5(a) 1 H SR 3. 3 .1.1.14 NA SR 3. 3 .1.1.17 (continued)

(a) With any control rod withdrawn from a core cell containing one or more fuel assemblies.

PBAPS UNIT 2 3.3-8 Amendment No. 316

RPS Instrumentation 3.3.1.1 Table 3.3.1.1-1 (page 3 of 3)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

13. Manual Scram 1,2 1 G SR 3.3.1.1.9 NA SR 3.3.1.1.17 5'a) 1 H SR 3.3.1.1.9 NA SR 3.3.1.1.17

14. RPS ChanneL Test Switch 1,2 2 a SR 3.3.1.1.4 NA SR 3.3.1.1.17 5(a) 2 H SR 3.3.1.1.4 NA SR 3.3.1.1.17 (a) With any control rod withdrawn from a core cell containing one or more fuel assembtlies.

PBAPS UNIT 2 3.3-9 Amendment No. 210

WRNM Instrumentation 3.3.1.2 3.3 INSTRUMENTATION l 3.3.1.2 Wide Range Neutron Monitor (WRNM) Instrumentation I LCO 3.3.1.2 The WRNM instrumentation in Table 3.3.1.2-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.1.2-1.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Restore required 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months WRNMs inoperable in WRNMs to OPERABLE MODE 2. status.

B. Three required WRNMs B.1 Suspend control rod Immediately I inoperable in MODE 2. withdrawal.

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

(continued)

PBAPS UNIT 2 3.3-10 Amendment No. i10,222 AUG 2 4 1998

I WRNM Instrumentation 3.3.1.2 Table 3.3.1.2-1 (page 1 of 1)

I Wide Range Neutron Monitor Instrumentation APPLICABLE MODES OR OTHER REQUIRED SURVEILLANCE FUNCTION SPECIFIED CONDITIONS CHANNELS REQUIREMENTS

1. Wide Range Neutron Monitor 2 (a) 3 (d) SR 3.3.1.2.1 SR 3.3.1.2.4 SR 3.3.1.2.5 SR 3.3.1.2.6 3,4 2 SR 3.3.1.2.3 SR 3.3.1.2.4 SR 3.3.1.2.5 SR 3.3.1.2.6 5 2 (b)(c) SR 3.3.1.2.1 SR 3.3.1.2.2 SR 3.3.1.2.4 SR 3.3.1.2.5 SR 3.3.1.2.6 I (a) With WRNMs reading 125E-5 X power or below.

(b) Only one WRNM charnel is required to be OPERABLE during spiral offload or reload when the fueled region I includes only that WRNN detector.

I (c) Special movable detectors may be used in place of WRNMs if connected to normal WRNM circuits.

I (d) Channels must be in3 of 4 core quadrants.

PBAPS UNIT 2 3.3-14 Amendment No. i%0,222 AUG 2 4 1998

I WRNM Instrumentation 3.3.1.2 3.0 -

2.9 -

2.8 -

2.7 2.6 2.5 2.4 2.3 at 2.2 C.

4t 2.1 S

X 2.0

_ 1.9 0 1.8 1.7 z 1.6 1.5 1.4 1.3 1.2 1.1 1.0 0.9 0.8 0.7 2 6 10 14 18 22 26 30 Slgnal-to-Noise RaUo Figure 3.3.1.2-1 (page 1 of 1)

I Minimum WRNM Count Rate Versus Signal to Noise Ratio PBAPS UNIT 2 3.3-15 Amendment No. i10,222 AUG 2 4 1398

Control Rod Block Instrumentation 3.3.2.1 3.3 INSTRUMENTATION 3.3.2.1 Control Rod Block Instrumentation LCO 3.3.2.1 The control rod block instrumentation for each Function in Table 3.3.2.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.2.1-1.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One rod block monitor A.1 Restore RBM channel 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (RBM) channel to OPERABLE status.

inoperable.

B. Required Action and B.1 Place one RBM channel 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated Completion in trip.

Time of Condition A not met.

OR Two RBM channels inoperable.

C. Rod worth minimizer C.1 Suspend control rod Immediately (RWM) inoperable movement except by during reactor scram.

startup.

OR (continued)

PBAPS UNIT 2 3.3-16 Amendment No. 210

Control Rod Block Instrumentation 3.3.2.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.2.1.1 Verify _>12 rods Immediately wi thdrawn.

OR C.2.1.2 Verify by Immediately administrative methods that startup with RWM inoperable has not been performed in the last calendar year.

AND C.2.2 Verify movement of During control control rods is in rod movement compliance with the analyzed rod position

.sequence by a second licensed operator or other qualified member of the technical staff.

D. RWM inoperable during D.1 Verify movement of During control reactor shutdown. control rods is in rod movement

-acco-rdance--wi-t-h -the-- -- -,---- - - - I---- -

analyzed rod position sequence by a second licensed operator or other qualified member of the technical staff..

(continued)

PBAPS UNIT 2 3 .I3-17 Amendment No.260

Control Rod Block Instrumentation 3.3.2.1 Table 3.3.2.1-1 (page 1 of 1)

Control Rod Block Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS REQUIREMENTS VALUE

1. Rod Block Monitor

a. Low Power Range-Upscale (a) 2 SR 3.3.2.1.1 (h)

SR 3.3.2.1.4 SR 3.3.2.1.5

b. Intermediate Power (b) 2 SR 3.3.2.1.1 (h)

Range - UpscaLe SR 3.3.2.1.4 SR 3.3.2.1.5 I c. High Power Range-Upscale (c) 2 SR 3.3.2.1.1 (h)

SR 3.3.2.1.4 SR 3.3.2.1.5

d. Inop (a) 2 SR 3.3.2.1.1 NA I

2. Rod Worth Minimizer 1 (f), 2 (f) 1 SR 3.3.2.1.2 NA SR 3.3.2.1.3 SR 3.3.2.1.6 SR 3.3.2.1.8

3. Reactor Mode Switch-Shutdown (g) 2 SR 3.3.2.1.7 NA Position I (a) THERMAL POWER 2 28.4X R7P and MCPR less than the limit specified in the COLR.

I (b) THERMAL POWER > 63.4X RTP and MCPR less than the limit specified in the COLR.

I (c) THERMAL POWER a 83.4X and MCPR less than the limit specified in the COLR.

I (d) Deleted.

I (e) Deleted.

(f) With THERMAL POWER 5 10X RTP.

(g) Reactor mode switch in the shutdown position.

(h) Less than or equal to the Allowable Value specified in the COLR.

I PBAPS UNIT 2 3.3-21 Amendment No.24l,232 AUG 0 1 2080

Feedwater and Main Turbine High Water Level Trip Instrumentation 3.3.2.2 3.3 INSTRUMENTATION 3.3.2.2 Feedwater and Main Turbine High Water Level Trip Instrumentation LCO 3.3.2.2 Two channels per trip system of the Digital Feedwater Control System (DFCS) high water level trip instrumentation Function shall be OPERABLE.

APPLICABILITY: THERMAL POWER~ 22.6% RTP.

ACTIONS

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more DFCS high A.l Place channel in 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months water level trip trip.

channels inoperable.

B. DFCS high water level B.l Restore DFCS high 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months trip capability not water level trip maintained. capability.

C. Required Action and C.l --------NOTE--------

associated Completion Only applicable if Time not met. inoperable channel is the result of inoperable feedwater pump turbine or main turbine stop valve.

Remove affected 4 hours feedwater pump(s) and main turbine valve(s) from service.

OR C. 2 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months to< 22.6% RTP.

PBAPS UNIT 2 3. 3-22 Amendment No. 316

PAM Instrumentation 3.3.3.1 3.3 INSTRUMENTATION 3.3.3.1 Post Accident Monitoring (PAM) Instrumentation LCO 3.3.3.1 The PAM instrumentation for each Function in Table 3.3.3.1-1 shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS

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

Separate Condition entry is allowed for each Function. I CONDITION REQUIRED ACTION COMPLETION TIME 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 Specification 5.6.6.

not met.

C. One or more Functions C.1 Restore one required 7 days with two required channel to OPERABLE channels inoperable. status.

(continued)

PBAPS UNIT 2 3.3 -24 Amendment No. 2i9, 252

PAM Instrumentation 3.3.3.1 Table 3.3.3.1-1 (page I of I)

Post Accident Monitoring Instrumentation CONDITIONS REFERENC ED REQUIRED FROM REQUIREO FUNCTION CHANNELS ACTION 0.1

1. Reactor Pressure 2

2. Reactor Vessel Water Le Ye 1 (Wide Range) 2

3. Reactor Vessel Water Le ve 1 (Fuel Zone) 2

4. Suppression Chamber Water Level (Wide Rangel

5. Orywell Pressure (Wide Range)

6. Orywe II Pressure (Subatmospheric Range) 2

7. Orywell High Range Radiation

8. Penetration Flow Path PCIV Position per penetration flow path (a)(b)

9. Oeleted

10. Oeleted II. Suppression Chamber Water Temperature (al Not required for isolation valves whose associated penetration flow path is isolated by at least one closed and deactiYated automatic valve. closed manual Yalve, blind flange, or check yalye with flow through the valve secured, (bJ Only one position indication channel is required for penetration flow paths with only one installed control room indication channel.

(c) Each channel requires 10 resistance temperature detectors (RTOs) to be OPERABLE with no two adjacent RTOs inoperable.

PBAPS UNIT 2 3.3-26 Amendment No.273

ATWS-RPT Instrumentation 3.3.4.1 3.3 INSTRUMENTATION 3.3.4.1 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) Instrumentation LCO 3.3.4.1 Two channels per trip system for each ATWS-RPT instrumentation Function listed below shall be OPERABLE:

a. Reactor Vessel Water Level -Low Low (Level 2); and

b. Reactor Pressure-High.

APPLICABILITY: MODE 1.

ACTIONS

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Restore channel to 14 days inoperable. OPERABLE status.

OR A.2 -------- NOTE---------

Not applicable if inoperable channel is the result of an inoperable breaker.

Place channel in 14 days trip.

(continued)

PBAPS UNIT 2 3.3-29 Amendment No. 210

EOC-RPT Instrumentation 3.3.4.2 3.3 INSTRUMENTATION 3.3.4.2 End of Cycle Recirculation Pump Trip (EOC-RPT) Instrumentation LCO 3.3.4.2 a. Two channels per trip system for each EOC-RPT instrumentation Function listed below shall be OPERABLE:

1. Turbine Stop Valve (TSV)-Closure; and

2. Turbine Control Valve (TCV) Fast Closure, Trip Oil Pressure-Low.

OR

b. The following limits are made applicable:

1. LCO 3.2.1, "AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR)," limits for inoperable EOC-RPT as specified in the COLR;

2. LCO 3. 2. 2, "MINIMUM CRITICAL POWER RATIO (MCPR),"

limits for inoperable EOC-RPT as specified in the COLR; and

3. LCO 3.2.3, "LINEAR HEAT GENERATION RATE (LHGR),"

limits for inoperable EOC-RPT as specified in the COLR.

APPLICABILITY: THERMAL POWER~ 26.3% RTP.

ACTIONS

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Restore channel to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months channels inoperable. OPERABLE status.

OR A.2 --------NOTE---------

Not applicable if inoperable channel is the result of an inoperable breaker.

Place channel in 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months trip.

(continued)

PBAPS UNIT 2 3.3-31a Amendment No. 316

EOC-RPT Instrumentation 3.3.4.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more Functions B.1 Restore EOC-RPT trip 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months with EOC-RPT trip capability.

capability not maintained.

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

associated Completion Only applicable if Time not met. inoperable channel is the result of an inoperable RPT breaker.

Remove the affected 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months recirculation pump from service.

OR C. 2 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months to< 26.3% RTP.

SURVEILLANCE REQUIREMENTS

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

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

SURVEILLANCE FREQUENCY SR 3.3.4.2.1 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program.

(continued)

PBAPS UNIT 2 3.3-31b Amendment No. 316

EOC-RPT Instrumentation 3.3.4.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.4.2.2 Perform CHANNEL CALIBRATION. The In accordance Allowable Values shall be: with the Surveillance TSV-Closure: ~ 10% closed; and Frequency Control TCV Fast Closure, Trip Oil Pressure-Low: Program.

500 psig.

SR 3.3.4.2.3 Perform LOGIC SYSTEM FUNCTIONAL TEST In accordance including breaker actuation. with the Surveillance Frequency Control Program.

SR 3.3.4.2.4 Verify TSV-Closure and TCV Fast Closure, In accordance Trip Oi 1 Pressure- Low Functions are not with the bypassed when THERMAL POWER is Surveillance Frequency

26. 3% RTP. Control Program.

SR 3.3.4.2.5 ------------------NOTE-------------------

Breaker interruption time may be assumed from the most recent performance of SR 3.3.4.2.6.

Verify the EOC-RPT SYSTEM RESPONSE TIME In accordance is within limits. with the Surveillance Frequency Control Program.

SR 3.3.4.2.6 Determine RPT breaker interruption time. In accordance with the Surveillance Frequency Control Program.

PBAPS UNIT 2 3.3-31c Amendment No. 316

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

APPLICABILITY: According to Table 3.3.5.1-1.

ACTIONS

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

Separate Condition entry is allowed for each channel.

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

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

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

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

PBAPS UNIT 2 3.3-32 Amendment No. 317

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

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

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

C. As required by C.1 --------NOTE---------

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

2. f.

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

(continued)

PBAPS UNIT 2 3.3-33 Amendment No. 317

ECCS Instrumentation 3.3.5.1 ACTIONS (continued) _

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

Required Action A.1 Only applicable if and referenced in HPCI pump suction is Table 3.3.5.1-1. not aligned to the suppression pool.

Declare HPCI System 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from inoperable. discovery of loss of HPCI initiation capability AND D.2.1 Place channel in 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months trip.

OR D.2.2 Align the HPCI pump 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months suction to the suppression pool.

(continued)

PBAPS UNIT 2 3.3-34 Amendment No. 210

ECCS Instrumentation 3.3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. As required by E.l --------NOTE---------

Required Action A.l 1. Only applicable and referenced in to Functions l.d Table 3.3.5.1-1. and 2.g.

Declare supported 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from feature(s) inoperable discovery of when its redundant loss of feature ECCS subsystem initiation capability initiation is inoperable. capability in both subsystems E.2 Restore channel to 7 days OPERABLE status.

(continued)

PBAPS UNIT 2 3.3-35 Amendment No. 317

ECCS Instrumentation 3.3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. As required by F.1 Declare Automatic 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Required Action A.1 Depressurization discovery of and referenced in System (ADS) valves loss of ADS Table 3.3.5.1-1. inoperable. initiation capability in both trip systems AND F.2 Place channel in 96 hours0.00111 days 0.0267 hours 1.587302e-4 weeks 3.6528e-5 months from trip. discovery of inoperable channel concurrent with HPCI or reactor core isolation cooling (RCIC) inoperable 8 days (continued)

PBAPS UNIT 2 3.3-36 Amendment No. 210

ECCS Instrumentation 3.3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME G. As required by G.1 Declare ADS valves 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Required Action A.1 inoperable. discovery of and referenced in loss of ADS Table 3.3.5.1-1. initiation capability in both trip systems G.2 Restore channel to 96 hours0.00111 days 0.0267 hours 1.587302e-4 weeks 3.6528e-5 months from OPERABLE status. discovery of inoperable channel concurrent with HPCI or RCIC inoperable AND 8 days H. Required Action and H.1 Declare associated Immediately associated Completion supported feature(s)

Time of Condition B, inoperable.

C, D, E, F, or G not met.

PBAPS UNIT 2 3.3-37 Amendment No. 210

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

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIDNS MODES REQUIRED REFERENCED DR OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTIDN CONDITIONS FUNCTION ACTION A.l REQUIREMENTS VALUE

1. Core Spray System

a. Reactor Vessel Water 1,2,3 4 Cb) B SR 3.3.5.1.1 ;, -160.0 Level -Low Low Low SR 3.3. 5.1.2 inches (Level 1) SR 3.3.5.1.4 SR 3.3.5.1.5 b, Drywell 1,2,3 4 Cb) B SR 3.3. 5.1.1 s 2.0 psig Pressure -High SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.5 C. Reactor Pressure - Low l,2,3 4 C SR 3.3.5.l.1 ;, 425.0 psig (Injection Permissive) SR 3.3.5.l,2 and SR 3.3.5.1.4 s 475.0 psig SR 3.3.5.1.5

d. Core Spray Pump 1,2,3 4 E SR 3.3.5.1.2 ;, 319.0 psid Discharge Flow -Low (1 per SR 3.3.5.1.4 and (Bypass) pump) s 351.0 psi d

e. Core Spray Pump Start- 1,2,3 4 C SR 3.3.5.1.4 ;, 5. 0 seconds Time Delay Relay (loss (1 per SR 3.3.5.1.5 and of offsite power) pump) s 7.0 seconds

f. Core Spray Pump Start-Time Delay Relay (offsite power avail ab 1 e)

Pumps A,C 1,2,3 2 C SR 3.3.5.1.4 ;, 12.1 Cl per SR 3,3.5.l.5 seconds and pump) s 13.9 seconds Pumps B,D 1,2,3 2 ( SR 3.3.5.1.4 ;, 21.4 (1 per SR 3.3.5.1.S seconds and pump) s 24.6 seconds (continued)

(a) Deleted (b) Also required to initiate the associated diesel generator (DG).

PBAPS UNIT 2 3.3-39 Amendment No. 317

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

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

2. Low Pressure Coolant Injection (LPCI) System

a. Reactor Vessel Water 1. 2, 3 4 B SR 3.3.5.1.1 i! -160 inches Level -Low Low Low SR 3.3.5.1.2 (Level 1) SR 3.3.5.1.4 SR 3.3.5.1.5

b. Drywell 1,2,3 4 B SR 3.3.5.1.1 s 2.0 psig Pressure -High SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.5 C Reactor Pressure -Low 1.2.3 4 C SR 3.3.5.1.1 i! 425.0 psig (Injection Permissive) SR 3.3.5.1.2 and SR 3.3. 5.1.4 s 475.0 psig SR 3.3.5.1.5

d. Reactor Pressure -Low 1 lCJ ,2lCJ, 4 C SR 3.3.5.1.1 i! 211.0 psig Low (Recirculation SR 3.3.5.1.2 Discharge Valve 3 cc) SR 3.3.5.1.4 Permissive) SR 3.3.5.1.5

e. Reactor Vessel Shroud 1, 2, 3 2 B SR 3.3.5.1.1 i! -226 .0 Level -Level 0 SR 3.3.5.1.2 inches SR 3.3.5.1.4 SR 3.3.5.1.5

f. Low Pressure Coolant 1.2,3 8 C SR 3.3.5.1.4 Injection Pump (2 per SR 3.3.5.1.5 Start -Time Delay pump)

Relay (offsite power available)

Pumps A,B c 1.9 seconds ands 2.1 seconds Pumps C.D c 7.5 seconds and,; 8.5 seconds

g. Low Pressure Coolant 1,2,3 4 E SR 3.3.5.1.2 "299.0 psid Injection Pump (1 per SR 3.3.5.1.4 and Discharge Flow -Low pump) SR 3.3.5.1.5 ,; 331. O psi d (Bypass)

(continued)

(a) Deleted

( c) With associated recirculation pump discharge valve open.

PBAPS UNIT 2 3.3-40 Amendment No. 317

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

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

3. High Pressure Coolant Injection ( HPC I) System

a. Reactor Vessel Water 1, SR 3.3.5.1.1 <: -48.0 Level -Low Low SR 3.3.5.1.2 inches (Level 2) 2 cdJ 3(d) SR 3.3.5.1.4 SR 3.3.5.1.5

b. Drywell 1, 4 SR 3.3.5.1.1 ,; 2.0 psig Pressure -High SR 3.3.5.1.2 2 (d)' 3 (d) SR 3. 3. 5. 1. 4 SR 3. 3. 5. 1. 5

c. Reactor Vessel Water 1, c SR 3.3.5.1.1 ,; 46.0 inches Level -High (Level 8) SR 3. 3. 5.1. 2 2 (d) 3(d) SR 3. 3. 5. 1. 4 SR 3. 3. 5. 1. 5

d. Condensate Storage 1' SR 3.3.5.1.2 ;, 5.25 ft Tank Level -Low SR 3.3.5.1.4 above tank 2 (d)' 3 (d) SR 3. 3. 5. 1. 5 bottom

e. Suppression Pool Water 1, 0 SR 3. 3. 5. 1. 2 ,; 16 ft Level -High SR 3. 3. 5. 1. 4 inches 2 (d) 3 (d) SR 3.3.5.1.5

f. High Pressure Coolant 1' SR 3.3.5.1.2 ;, 3.5 in-we Injection Pump SR 3.3.5.1.4 and ,; 19.0 Discharge Flow -Low 2 (d)' 3(d) SR 3.3.5.1.5 in -we (Bypass)

4. Automatic Depressurization System CADS) Trip System A

a. Reactor Vessel Water Level -Low Low Low 1, SR SR

3. 3. 5. 1. 1

3. 3. 5. 1. 2 "inches

-160.0 (Level 1) 2 (e), 3 (e) SR 3. 3. 5. 1. 4 SR 3.3.5.1.5

b. Drywell 1' SR 3. 3. 5. 1. 1 ,; 2.0 psig Pressure -High SR 3.3.5.1.2 2 (e) 3 (e) SR 3.3.5.1.4 SR 3.3.5.1.5

c. Automatic 1' G SR 3.3.5.1.4 :;; 115.0 Depressurization SR 3.3.5.1.5 seconds System Initiation 2 (e) 3 (e)

Timer (continued)

(d) With reactor steam dome pressure > 150 psi g.

(e) With reactor steam dome pressure > 100 psi g.

PBAPS UN IT 2 3.3-41 Amendment No. 293

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

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

4. ADS Trip System A (continued)

d. Reactor Vessel Water 1, 2 F SR 3.3.5.1.1 2 -160.0 Level-Low Low Low SR 3.3.5.1.2 inches (Level 1), 2"' 3 "e) SR 3.3.5.1.4 (Permissive) SR 3.3.5.1.5

e. Reactor Vessel Water 1, I F SR 3.3.5.1.1 X 6.0 Inches Confirmatory SR 3.3.5.1.2 Level -Low (Level 4) 2 (e)" 3 (e) SR 3.3.5.1.4 SR 3.3.5.1.5

f. Core Spray Pump 1, G SR 3.3.5.1.3 2 175.0 psig Discharge SR 3.3.5.1.5 and Pressure -High 2 (e)Z 3 (e) S 195.0 psig

g. Low Pressure Coolant 1, e G SR 3.3.5.1.3 t 40.0 psig Injection Pump SR 3.3.5.1.5 and Discharge 2 "c) 3 (e) S 60.0 psig Pressure -High

h. Automatic 1, 2 G SR 3.3.5.1.4 S 9.5 minutes Depressurization SR 3.3.5.1.5 System Low Water Level 2 (e) 3 (e)

Actuation Timer

5. ADS Trip System B

a. Reactor Vessel Water 1, 2 F SR 3.3.S.1.1 ? -160.0 Level -Low Low Low SR 3.3.5.1.2 inches (Level 1) 2"' 3 (e) SR 3.3.5.1.4 SR 3.3.5.1.5

b. DrywelL 1, 2 F SR 3.3.5.1.1 S 2.0 psig Pressure -High SR 3.3.5.1.2 2 (e), 3 (e) SR 3.3.5.1.4 SR 3.3.5.1.5

c. Automatic 1, 1 G SR 3.3.5.1.4 S 115.0 Depressuri zat ion SR 3.3.5.1.5 seconds System Initiation 2 "e), 3 (e)

Timer

d. Reactor Vessel Water 1, 2 F SR 3.3.5.1.1 k -160.0 Level-Low Low Low SR 3.3.5.1.2 inches (Level 1), 2 "c)*3 "e) SR 3.3.5.1.4 (Permissive) SR 3.3.5.1.5 (continued) te) With reactor steam dome pressure > 100 psig.

PBAPS UNIT 2 3 .3-42 Amendment No. 210

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

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

5. ADS Trip System B (continued)

e. Reactor Vessel Water 1, 1 F SR 3.3.5.1.1 2 6.0 inches Confirmatory SR 3.3.5.1.2 Level -Low (Level 4) 2 "e) 3 "e) SR 3.3.5.1.4 SR 3.3.5.1.5

f. Core Spray Pump 1 4 G SR 3.3.5.1.3 k 175.0 psig Discharge SR 3.3.5.1.5 and Pressure -High 2(e)" 3C") S 195.0 psig

g. Low Pressure Coolant 1. 8 G SR 3.3.5.1.3 2 40.0 psig Injection Pump SR 3.3.5.1.5 and Discharge 2 "e), 3 "5 e) 60.0 psig Pressure -High

h. Automatic 1, 2 G SR 3.3.5.1.4 S 9.5 minutes Depressurization SR 3.3.5.1.5 System Low Water Level 2 (e), 3 (e)

Actuation Timer (e) With reactor steam dome pressure > 100 psig.

PBAPS UNIT 2 3.3-43 Amendment No. 210

RCIC System Instrumentation 3.3.5.2 3.3 INSTRUMENTATION 3.3.5.2 Reactor Core Isolation Cooling (RCIC) System Instrumentation LCO 3.3.5.2 The RCIC System instrumentation for each Function in Table 3.3.5.2-1 shall be OPERABLE.

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

ACTIONS

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

Separate Condition entry is allowed for each channel.

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

B. As required by B.1 Declare RCIC System 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Required Action A.1 inoperable. discovery of and referenced in loss of RCIC Table 3.3.5.2-1. initiation capability ALD 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 8.2 Place channel in trip.

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

and referenced in Table 3.3.5.2-1.

(continued)

PBAPS UNIT 2 3.3-44 Amendment No. 210

RCIC System Instrumentation 3.3.5.2 ACTIONS (continued)

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

Required Action A.1 Only applicable if and referenced in RCIC pump suction is Table 3.3.5.2-1. not aligned to the suppression pool.

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

OR D.2.2 Align RCIC pump 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months suction to the suppression pool.

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

Time of Condition B, C, or D not met.

PBAPS UNIT 2 3.3-45 Amendment No. 210

RCIC System Instrumentation 3.3.5.2 Table 3.3.5.2-1 (page 1 of 1)

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

1. Reactor Vessel Water 4 E SR 3.3.5.2.1 2 -48.0 riches Level -Low Low (Level 2) SR 3.3.5.2.2 SR 3.3.5.2.3 SR 3.3.5.2.4

2. Reactor Vessel Water 2 C SR 3.3.5.2.1 S 46.0 Inches Level -High (Level 8) SR 3.3.5.2.2 SR 3.3.5.2.3 SR 3.3.5.2.4

3. Condensate Storage Tank 2 D SR 3.3.5.2.1 2 5.25 ft above Level -Low SR 3.3.5.2.2 tank bottom SR 3.3.5.2.3 SR 3.3.5.2.4 PBAPS UNIT 2 3.3-47 Amendment No. 210

Not Used 3.3.5.3 3.3 INSTRUMENTATION 3.3.5.3 Not Used PBAPS UNIT 2 3.3-47a Amendment No. 317

RPV Water Inventory Control Instrumentation 3.3.5.4 3.3 INSTRUMENTATION 3.3.5.4 Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation LCO 3.3.5.4 The RPV Water Inventory Control instrumentation for each Function in Table 3.3.5.4-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.5.4-1.

ACTIONS

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.l Enter the Condition Immediately inoperable. referenced in Table 3.3.5.4-1 for the channel.

B. As required by B.l Declare associated Immediately Required Action A.l penetration flow and referenced in path(s) incapable of Table 3.3.5.4-1. automatic isolation.

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

and referenced in Table 3.3.5.4-1.

D. As required by D.l Restore channel to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Required Action A.l OPERABLE status and referenced in Tab l e 3 . 3 . 5 . 4-1.

(continued)

PBAPS UNIT 2 3.3-47b Amendment No. 317

RPV Water Inventory Control Instrumentation 3.3.5.4 ACTIONS (continued)

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

SURVEILLANCE REQUIREMENTS

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

1. Refer to Table 3.3.5.4-1 to determine which SRs apply for each ECCS Function.

SURVEILLANCE FREQUENCY SR 3.3.5.4.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program.

SR 3.3.5.4.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program.

SR 3.3.5.4.3 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program.

(continued)

PBAPS UNIT 2 3.3-47c Amendment No. 317

RPV Water Inventory Control Instrumentation 3.3.5.4 Table 3.3.5.4-1 (page 1 of 1)

RPV Water Inventory Control Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED OR OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNQION CONDITIONS fllN(TION ACTION A.l REQUIREMENTS VALUE

1. Core Spray System

a. Reactor Pressure~Low 4,5 C SR 3.3.5.4.1 ~ 425.0 psig (Injection Permissive) SR 3.3.5.4.2 and s 475 .0 psig

b. Core Spray Pump 4,5 1 per pump D SR 3.3.5.4.1 ~ 319.0 psid Discharge Flow--Low Ca) SR 3.3. 5.4.2 and s 351.0 (Bypass) psid

c. Manual Initiation 4,5 1 per D SR 3.3.5.4.3 NA subsystem Ca)

2. Low Pressure Coolant Injection (LPCI) System

a. Reactor Pressure-Low 4,5 C SR 3.3.5.4.1 ~ 425.0 psig (Injection Permissive) SR 3.3.5.4.2 ands 475.0 psig

b. Low Pressure Coolant 4,5 1 per pump D SR 3.3.5.4.1 ~ 299.0 psid Injection Pump Ca) , Cc) SR 3.3.5.4.2 and < 331.0 Discharge Flow - Low psid-(Bypass)

c. Manual Initiation 4,5 1 per D SR 3.3.5.4.3 NA subsystem Ca)

3. RHR System Isolation

a. Reactor Vessel Cb) B SR 3.3.5.4.1 ,:. 1.0 inches Water Level - Low, SR 3.3. 5.4.2 Level 3

4. Reactor Water Cleanup (RWCU) System Isolation

a. Reactor Vessel (b) B SR 3.3.5.4.1 ,:. 1.0 inches Water Level - Low, SR 3.3.5.4.2 Level 3 (a) Associated with an ECCS subsystem required to be OPERABLE by LCD 3.5.4, "Reactor Pressure Vessel Water Inventory Control."

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

Cc) Function not required to be OPERABLE while associated pump is operating in decay heat removal when minimum flow valve is closed and deactivated.

PBAPS UNIT 2 3.3-47d Amendment No.317

Primary Containment Isolation Instrumentation 3.3.6.1 3.3 INSTRUMENTATION 3.3.6.1 Primary Containment Isolation Instrumentation LCO 3.3.6.1 The primary containment isolation instrumentation for each Function in Table 3.3.6.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.6.1-1.

ACTIONS

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

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

2. Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.l Pl ace channel in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for channels inoperable. trip. Functions 2.a, 2.b, 8.a, and 8.b 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for Functions other than Functions 2.a, 2.b, 8.a, and 8.b

8. One or more Functions 8.1 Restore isolation 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with i sol at ion capability.

capability not maintained.

C. Required Action and C.l Enter the Condition Immediately associated Completion referenced in Time of Condition A or Table 3.3.6.1-1 for 8 not met. the channel.

(continued)

PBAPS UN IT 2 3.3-48 Amendment No. 299

Primary Containment Isolation Instrumentation 3.3.6.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. As required by D.1 Isolate associated 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Required Action C.1 main steam line and referenced in (MSL).

Table 3.3.6.1-1.

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

D.2.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E. As required by E.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Required Action C.1 and referenced in Table 3.3.6.1-1.

F. As required by F.1 Isolate the affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Required Action C.1 penetration flow and referenced in path(s).

Table 3.3.6.1-1.

G. As required by G.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Required Action C.1 and referenced in ADE Table 3.3.6.1-1.

G.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months DE Required Action and associated Completion Time of Condition F or J not met. I (continued)

PBAPS UNIT 2 3.3 -49 Amendment No. 259

Primary Containment Isolation Instrumentation 3.3.6.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME H. As required by H.l Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Required Action C.1 standby 1 i quid and referenced in control (SLC)

Tab 1e 3 . 3 . 6 . 1-1. subsystem inoperable.

OR H.2 Isolate the Reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Water Cleanup System.

I. As required by I. l Initiate action to Immediately Required Action C.1 restore channel to and referenced in OPERABLE status.

Table 3.3.6.1-1.

J. As required by J.1 Isolate the affected 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Required Action C.1 penetration flow and referenced in path(s).

Table 3.3.6.1-1.

PBAPS UNIT 2 3.3-50 Amendment No. 317

Primary Containment Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS

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

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

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

SURVEILLANCE FREQUENCY SR 3.3.6.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program.

SR 3.3.6.1.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.3 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.4 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program (continued)

PBAPS UN IT 2 3.3-51 Amendment No. 299

Primary Containment Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS (continued)

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

SR 3.3.6.1.6 Deleted.

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

PBAPS UN IT 2 3.3-51a Amendment No. 299

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 1 of 3)

Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIREO REFERENCEO OTHER CHANNELS FROM SPECIFIEO PER TRIP REQUIREO SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C .1 REQUIREMENTS VALUE

1. Main Steam Line !sol at ion

a. Reactor Vessel Water 1. 2. 3 SR 3.3.6.1.1 ;;, -160.0 Level - Low LOw Low SR 3.3.6.1.2 inches (Level 1) SR 3.3.6.1.5 SR 3.3.6.1.7

b. Main Steam Line SR 3.3.6.1.3 ;;, 825.0 psig Pressure - Low SR 3.3.6.1.7

c. Main Steam Line 1. 2. 3 2 per SR 3.3.6.1.1 ,; 173.8 psid Flow-High MSL SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.7

d. Deleted

e. Turbine Building Main 1. 2. 3 0 SR 3.3.6.1.1 ,; 200.0°F Steam Tunnel SR 3.3.6.1.2 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.7

f. Reactor Building Main 1. 2. 3 SR 3.3.6.1.1 ,; 230.0°F Steam Tunnel SR 3.3.6.1.2 Temperature-High SR 3.3.6.1.5 SR 3.3.6.1.7

2. Primary Containment Isolation

a. Reactor Vessel Water 1. 2. 3 G SR 3.3.6.1.1 ;;, 1. 0 inches Level - Low (Level 3) SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.7

b. Drywell Pressure - High 1. 2. 3 G SR 3.3.6.1.l ,; 2.0 psig SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.7

c. Main Stack Monitor 1. 2. 3 SR 3.3.6.1.l ,; 2 x 10" Radiation-High SR 3.3.6.1.2 µCi/cc SR 3.3.6.1.4 SR 3.3.6.1.7

d. Reactor Building 1. 2. 3 G SR 3. 3. 6. 1. 1 ,; 16.0 mR/hr Ventilation Exhaust SR 3.3.6.1.3 Radiation -High SR 3. 3. 6. 1. 7

e. Refueling Fl oar 1' 2' 3 SR 3.3.6.1.l ,; 16.0 mR/hr Ventilation Exhaust SR 3.3.6.1.3 Radiation-High SR 3.3.6.1.7 (continued)

PBAPS UN IT 2 3.3-52 Amendment No. 299

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 2 of 3)

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

3. High Pressure Coolant Injection (HPCI) System Isolation

a. HPCI Steam Line 1,2,3 1 F SR 3.3.6.1.3 S 225.0 in-wc Flow -High SR 3.3.6.1.7

b. HPCI Steam Line 1,2,3 1 F SR 3.3.6.1.5 1 10.0 seconds Flow -Time Delay SR 3.3.6.1.7 Relays

c. HPCI Steam Supply Line 1,2,3 2 F SR 3.3.6.1.3 2 60.0 psig Pressure -Low SR 3.3.6.1.7

d. Orywell Pressure -High 1,2.3 2 F SR 3.3.6.1.1 S 2.0 psig (Vacuum Breakers) SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.7

e. HPCI Compartment and 1,2,3 8 F SR 3.3.6.1.1 5 200.09F Steam Line Area SR 3.3.6.1.2 Temperature -High SR 3.3.6.1.5 SR 3.3.6.1.7

4. Reactor Core Isolation Cooling (RCIC) System Isolation

a. RCIC Steam Line 1,2,3 1 F SR 3.3.6.1.3 S 450.0 In-wc Flow -High SR 3.3.6.1.7

b. RCIC Steam Line 1,2,3 1 F SR 3.3.6.1.5 S 10.0 seconds Flow -Time Delay SR 3.3.6.1.7 Relays

c. RCIC Steam Supply Line 1,2,3 2 F SR 3.3.6.1.3 2 60.0 psig Pressure -Low SR 3.3.6.1.7

d. Drywell Pressure -High 1,2,3 2 F SR 3.3.6.1.1 5 2.0 psig (Vacuum Breakers) SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.7

e. RCIC Compartment and 1,2,3 8 F SR 3.3.6.1.1 S 200.0F Steam Line Area SR 3.3.6.1.2 Temperature -High SR 3.3.6.1.5 SR 3.3.6.1.7 (continued)

PBAPS UNIT 2 3.3-53 Amendment No. 210

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 3 of 3)

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

s. Reactor Water Cleanup (RWCU) System Isolation

a. RWCU Flow-High 1,2,3 1 F SR 3.3.6.1.1 '"125% rated SR 3.3.6.1.3 flow (23.0 SR 3.3.6.1.7 i n-wc)

b. SLC System Initiation 1, 2, 3 l H SR 3.3.6.1.7 NA C. Reactor Vessel Water 1,2,3 2 F SR 3.3.6.1.l " 1.0 inches Level-Low (Level 3) SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.7

5. RHR Shutdown Cooling System Isolation

a. Reactor Pressure-High 1,2,3 1 F SR 3.3.6.1.3 s 70.0 psig SR 3.3.6.1.7

b. Reactor Vessel Water 3 2 I SR 3.3.6.1.1 " 1.0 inches Level-Low (Level 3) SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.7

7. Feedwater Recirculation Isolation

a. Reactor Pressure-High 1,2,3 2 F SR 3.3.6.1.1 s 600 psig SR 3.3.6.1.2 SR 3.3.6.1.S SR 3.3.6.1.7

8. Traversing Incore Probe Isolation

a. Reactor Vessel Water 1,2,3 SR 3.3.6.1.1 inches Level-Low (Level 3) SR 3.3.6.1.2 " 1. 0 SR 3.3.6.1.S SR 3.3.6.1.7

b. Drywel 1 Pressure-High l,2,3 2 J SR 3.3.6.1.1 s 2.0 psig SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.7 (a) Deleted PBAPS UNIT 2 3.3-54 Amendment No.317

Secondary Containment Isolation Instrumentation 3.3.6.2 3.3 INSTRUMENTATION 3.3.6.2 Secondary Containment Isolation Instrumentation LCO 3.3.6.2 The secondary containment isolation instrumentation for each Function in Table 3.3.6.2-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.6.2-1.

ACTIONS

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Place channel in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for inoperable. trip. Functions 1 and 2

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for Functions other than Functions 1

-and 2 B. One or more Functions B.1 Restore isolation 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with isolation capability.

capability not maintained.

(continued)

PBAPS UNIT 2 3.3-55 Amendment No. 210

Secondary Containment Isolation Instrumentation 3.3.6.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1.1 Isolate the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated Completion associated secondary Time of Condition A or containment B not met. penetration flow path(s).

OR C.1.2 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months secondary containment isolation valves inoperable.

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

OR C.2.2 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SGT subsystem(s) inoperable.

PBAPS UNIT 2 3.3-56 Amendment No. 210

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

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

1. Reactor Vessel Water 1. 2, 3 2 SR 3.3.6.2.1 ?: 1. O inches Level -Low (Level 3) SR 3.3.6.2.2 SR 3.3.6.2.4 SR 3.3.6.2.5

2. Drywel l Pressure -High 1,2,3 2 SR 3.3.6.2.l s 2.0 psig SR 3.3.6.2.2 SR 3.3.6.2.4 SR 3.3.6.2.5

3. Reactor Building 1,2,3, 2 SR 3.3.6.2.1 $ 16.0 mR/hr Ventilation Exhaust (b) SR 3.3.6.2.3 Radiation-High SR 3.3.6.2.5

4. Refueling Floor 1, 2, 3, 2 SR 3.3.6.2.1 $ 16.0 mR/hr Ventilation Exhaust Cb) SR 3.3.6.2.3 Radiation -High SR 3.3.6.2.5 (a) Deleted (b) During movement of RECENTLY IRRADIATED FUEL assemblies in secondary containment.

PBAPS UNIT 2 3.3-58 Amendment No. 317

MCREV System Instrumentation 3.3.7.1 3.3 INSTRUMENTATION 3.3.7.1 Main Control Room Emergency Ventilation (MCREV) System Instrumentation LCO 3.3.7.1 Two channels per trip system of the Control Room Air Intake Radiation-High Function shall be OPERABLE.

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

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.l Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from channels inoperable. MCREV subsystems discovery of inoperable. loss of MCREV System initiation capability A.2 Place channel in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months trip.

(continued)

PBAPS UNIT 2 3. 3.. 59 Amendment No. 317

LOP Instrumentation 3.3.8.1 3.3 INSTRUMENTATION 3.3.8.1 Loss of Power (LOP) Instrumentation LCO 3.3.8.1 The Unit 2 LOP instrumentation for each Function in Table 3.3.8.1-1 shall be OPERABLE.

AND The Unit 3 LOP instrumentation for Functions 1, 2, 3, and 5 in Unit 3 Table 3.3.8.1-1 shall be OPERABLE.

APPLICABILITY: When the associated diesel generator and offsite circuit are required to be OPERABLE by LCO 3.8.1, 'AC Sources-Operating," or LCO 3.8.2, "AC Sources-Shutdown."

ACTIONS

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One 4 kV emergency bus A.1 --------NOTE---------

with one or two Enter applicable required Function 3 Conditions and channels inoperable. Required Actions of LCO 3.8.1 for offsite OR circuits made inoperable by LOP One 4 kY emergency bus instrumentation.

with one or two required Function 5 channels inoperable. Place channel in 14 days trip.

(continued)

PBAPS UNIT 2 3.3-61 Amendment No. 210

LOP Instrumentation 3.3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Two 4 kV emergency B.1 --------NOTE---------

buses with one Enter applicable required Function 3 Conditions and channel inoperable. Required Actions of LCO 3.8.1 for offsite OR circuits made inoperable by LOP Two 4 kV emergency instrumentation.

buses with one required Function 5 channel inoperable. Place the channel in 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months trip.

OR One 4 kV emergency bus with one required Function 3 channel inoperable and a different 4 kV emergency bus with one required Function 5 channel inoperable.

(continued)

PBAPS UNIT 2 3.3-62 Amendment No. 210

LOP Instrumentation 3.3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more 4 kV C.1 -NOTE---------

emergency buses with Enter applicable one or more required Conditions and Function 1, 2, or 4 Required Actions of channels inoperable. LCO 3.8.1 for offsite circuits made OR inoperable by LOP instrumentation.

One 4 kV emergency bus with one required Function 3 channel and Place the channel in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months one required Function trip.

5 channel inoperable.

OR Any combination of three or more required Function 3 and Function 5 channels inoperable.

D. Required Action and D.1 Declare associated Immediately associated Completion diesel generator (DG)

Time not met. inoperable.

PBAPS UNIT 2 3.3-63 Amendment No. 210

LOP Instrumentation 3.3.8.1 Table 3.3.8.1-1 (page 1 of 1)

Loss of Power Instrumentation REQUIRED CHANNELS SURVEI LLANCE ALLOWABLE FUNCTI ON PER BUS REQUIREMENTS VALUE

1. 4 kV Emergency Bus Undervoltage (Loss of Voltage)

a. Bus Undervoltage SR 3.3.8.1.3 NA SR 3.3.8.1.4

2. 4 kV Emergency Bus Undervoltage (Degraded Voltage Low Setting)

a. Bus Undervoltage 2 SR 3.3.8.1.1 ~ 2286 V and s 2706 V (1 per SR 3.3.8.1.2 source) SR 3.3.8.1.4

b. Time Delay 2 SR 3.3.8.1.1 ~ 1.5 seconds and (1 per SR 3.3.8.1.2 S 2.1 seconds source) SR 3.3.8.1.4

3. 4 kV Emergency Bus Undervoltage (Degraded Voltage High Setting)

a. Bus Undervoltage 2 SR 3.3.8.1.1 ~ 3409 V and s 3829 V (1 per SR 3.3.8.1.2 source) SR 3.3.8.1.4

b. Time Delay 2 SR 3.3.8.1.1 ~ 23.0 seconds and (1 per SR 3.3.8.1.2 S 37.0 seconds source) SR 3.3.8.1.4

4. 4 kV Emergency Bus Undervoltage (Degraded Voltage LOCA)

a. Bus Undervoltage 2 SR 3.3.8.1.1 ~ 3766 V and S 3836 V (1 per SR 3.3.8.1.2 source) SR 3.3.8.1.4

b. Time Delay 2 SR 3.3.8.1.1 ~ 9.2 seconds and (1 per SR 3.3.8.1.2 s Hl.8 seconds source) SR 3.3.8.1.4

5. 4 kV Emergency Bus Undervoltage (Degraded Voltage non-LOCAl

a. Bus Undervoltage 2 SR 3.3.8.1.1 ~ 4116 V and S 4186 V (1 per SR 3.3.8.1.2 source) SR 3.3.8.1.4

b. Time Delay 2 SR 3.3.8.1.1 ~ 57.8 seconds and S 64.2 (1 per SR 3.3.8.1.2 seconds source) SR 3.3.8.1.4 PBAPS UN IT 2 3.3-65 Amendment No.273

RPS Electric Power Monitoring 3.3.8.2 3.3 INSTRUMENTATION 3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring LCO 3.3.8.2 Two RPS electric power monitoring assemblies shall be OPERABLE for each inservice RPS motor generator set or alternate power supply.

APPLICABILITY: MODES 1 and 2, MODES 3, 4, and 5 with any control rod withdrawn from a core cell containing one or more fuel assemblies.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or both inservice A.1 Remove associated 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months power supplies with inservice power one electric power supply(s) from monitoring assembly service.

inoperable.

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

inoperable.

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

(continued)

PBAPS UNIT 2 3.3-66 Amendment No. 210

Recirculation Loops Operating 3.4.1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 Recirculation Loops Operating LCO 3.4.1 Two recirculation loops with matched flows shall be in operation.

OR

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

Single recirculation loop operation is prohibited in the MELLLA+ domain.

One recirculation loop shall be in operation with the following limits applied when the associated LCO is applicable:

a. LCO 3.2.1, "AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR)," single loop operation limits specified in the COLR;

b. LCO 3.2.2, "MINIMUM CRITICAL POWER RATIO (MCPR)," single loop operation limits specified in the COLR;

c. LCO 3.2.3, <<LINEAR HEAT GENERATION RATE (LHGR)," single loop operation limits specified in the COLR; and

d. LCO 3.3.1.1, "Reactor Protection System (RPS)

Instrumentation," Function 2.b (Average Power Range Monitors Simulated Thermal Power-High), Allowable Value of Table 3.3.1.1-1 is reset for single loop operation.

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

Required limit modifications for single recirculation loop operation may be delayed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after transition from two recirculation loop operation to single recirculation loop operation.

APPLICABILITY: MODES 1 and 2.

PBAPS UN IT 2 3.4-1 Amendment No. 305

Recirculation Loops Operating 3.4.1 ACTIONS THIS PAGE LEFT BLANK INTENTIONALLY (The contents of this page have been deleted)

PBAPS UNIT 2 3.4-2 Amendment No. 2+1, 251

Recirculation Loops Operating 3.4.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the A. 1 Satisfy the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months LCO not met. requirements of the LCO.

B. Operation in the B.l Initiate action to Immediately MELLLA+ domain with a exit the MELLLA+

single recirculation domain.

loop in operation.

C. No recirculation C.l Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months loops in operation.

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

PBAPS UN IT 2 3.4-3 Amendment No. 305

Recirculation Loops Operating 3.4.1 THIS PAGE LEFT BLANK INTENTIONALLY (The contents of this page have been deleted)

PBAPS UNIT 2 3.4-5 Amendment No.216, 244, 251

Jet Pumps 3.4.2 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.2 Jet Pumps LCO 3.4.2 All jet pumps shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more jet pumps A.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months inoperable.

PBAPS UNIT 2 3.4-6 Amendment No. 210

Jet Pumps 3.4.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.2.1 -------------------NOTES-------------------

1. Not required to be performed until 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after associated recirculation loop is in operation.

2. Not required to be performed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after> 22.6% RTP.

Verify at least one of the following In accordance criteria (a, b, or c) is satisfied for each with the operating recirculation loop: Surveillance Frequency

a. Recirculation pump flow to speed ratio Control differs bys 5% from established Program.

patterns, and jet pump loop flow to recirculation pump speed ratio differs bys 5% from established patterns.

b. Each jet pump diffuser to lower plenum differential pressure differs bys 20%

from established patterns.

c. Each jet pump flow differs bys 10%

from established patterns.

PBAPS UNIT 2 3.4-7 Amendment No. 316

SRVs and SVs 3.4.3 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.3 Safety Relief Valves (SRVs) and Safety Valves (SVs)

LCO 3.4.3 The safety function of 12 valves (any combination of SRVs and and SVs) sha 11 be OPERABLE. .

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

The safety function of 12 valves (any combination of SRVs and SVs) are required to be OPERABLE~ 3358 MWt during operating cycle 22.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.l Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SRVs or SVs inoperable.

A.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months PBAPS UNIT 2 3.4-8 Amendment No. 323

SRVs and SVs 3.4.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.3.1 Verify the safety function lift setpoints In accordance of the required SRVs and SVs are as with the follows: IN SERVICE TESTING PROGRAM Number of Setpoint SRVs Cpsig) 4 1135 +/- 34.1 4 1145 +/- 34.4 3 1155 +/- 34.7 Number of Setpoint SVs Cpsig) 3 1260 +/- 37.8 Following testing, lift settings shall be within +/- 1%.

SR 3.4.3.2 Verify each required SRV actuator strokes In accordance when manually actuated in the with the depressurization mode. Surveillance Frequency Control Program.

PBAPS UNIT 2 3.4-9 Amendment No. 313

RCS Operational LEAKAGE 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.4 RCS Operational LEAKAGE LCO 3.4.4 RCS operational LEAKAGE shall be limited to:

a. No pressure boundary LEAKAGE;

b. 5 5 gpm unidentified LEAKAGE;

c. s 25 gpm total LEAKAGE averaged over the previous 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period; and

d. s 2 gpm increase in unidentified LEAKAGE within the previous 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period in MODE 1.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Unidentified LEAKAGE A.1 Reduce LEAKAGE to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months not within limit. within limits.

OR Total LEAKAGE not within limit.

B. Unidentified LEAKAGE B.1 Reduce LEAKAGE 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months increase not within increase to within limit. limits.

(continued)

PBAPS UNIT 2 3.4-10 Amendment No. 210

RCS leakage Detection Instrumentation 3.4.5 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.5 RCS leakage Detection Instrumentation lCO 3.4.5 The following RCS leakage detection instrumentation shall be OPERABLE:

a. Drywell sump monitoring system; and

b. One channel of primary containm ent atmospheric gaseous monitoring system.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Drywell sump A.1 Analyze grab samples Once per monitoring system of the primary 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months inoperable. containment atmosphere.

AND A.2 Monitor ReS lEAKAGE Once per by administrative 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months means.

AND A.3 Restore drywell sump 7 days monitoring system to OPERABLE status.

B. Required primary B.1 Analyze grab samples Once per containment of primary 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months atmospheriC monitoring containment system inoperable. atmosphere.

At::LD.

B.2 Restore required 30 days primary containment atmospheriC monitoring system to OPERABLE status.

(continued)

PBAPS UNIT 2 3.4-12 Amendment No. 2B3

RCS Specific Activity 3.4.6 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.6 RCS Specific Activity LCO 3.4.6 The specific activity of the reactor coolant shall be limited to DOSE EQUIVALENT I-131 specific activity

0.2 pCi/gm.

APPLICABILITY: MODE 1, MODES 2 and 3 with any main steam line not isolated.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME

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

A. Reactor coolant LCO 3.0.4.c is applicable. I specific activity

> 0.2 pCi/gm and

4.0 pCi/gm DOSE EQUIVALENT I-131. A.1 Determine DOSE Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months EQUIVALENT I-131.

AED A.2 Restore DOSE 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months EQUIVALENT I-131 to within limits.

B. Required Action and B.1 Determine DOSE Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion EQUIVALENT 1-131.

Time of Condition A not met. AND OR B.2.1 Isolate all main 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months steam lines.

Reactor coolant specific activity DR

> 4.0 pCi/gm DOSE EQUIVALENT 1-131.

(continued)

PBAPS UNIT 2 3.4-14 Amendment No. Z*q, 252

RHR Shutdown Cooling System-Hot Shutdown 3;4.7 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.7 Residual Heat Removal (RHR) Shutdown Cooling System-Hot Shutdown LCO 3.4.7 Two RHR shutdown cooling subsystems shall be OPERABLE, and, with no recirculation pump in operation, at least one RHR shutdown cooling subsystem shall be in operation.

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

1. Both required RHR shutdown cooling subsystems and recirculation pumps may be removed from operation for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period.

2. One required RHR shutdown cooling subsystem may be inoperable for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for performance of Surveillances.

APPLICABILITY: MODE 3, with reactor steam dome pressure less than the RHR shutdown cooling isolation pressure.

ACTIONS

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

Separate Condition entry is allowed for each RHR shutdown cooling subsystem. I CONDITION- REQUIRED ACTION COMPLETION TIME A. One or two required A.1 Initiate action to Immediately RHR shutdown cooling restore required RHR subsystems inoperable. shutdown cooling subsystem(s) to OPERABLE status.

(continued)

PBAPS UNIT 2 3.4-16 Amendment No. ad, 252

RHR Shutdown Cooling System-Hot Shutdown 3.4.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 Verify an alternate 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months method of decay heat removal is available for each required inoperable RHR shutdown cooling subsystem.

A.3 Be in MODE 4. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months B. No RHR shutdown B.1 Initiate action to Immediately cooling subsystem in restore one RHR operation. shutdown cooling subsystem or one AND recirculation pump to operation.

No recirculation pump in operation. AND B.2 Verify reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from coolant circulation discovery of no by an alternate reactor coolant method. circulation AND Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter B.3 Monitor reactor Once per hour coolant temperature and pressure.

PBAPS UNIT 2 3.4-17 Amendment No. 210

RHR Shutdown Cooling System-Hot Shutdown 3.4.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 - - - - - - - - - - - - - - - - - - - NOTE - - - - - - - - - - - - - - - - - - - -

Not required to be met until 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after reactor steam dome pressure is less than the RHR shutdown cooling isolation pressure.

Verify one required RHR shutdown cooling In accordance subsystem or recirculation pump is with the operating. Surveillance Frequency Control Program.

SR 3.4.7.2 - - - - - - - - - - - - - - - - - - - NOTE - - - - - - - - - - - - - - - - - - - -

1. Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam dome pressure is less than the RHR shutdown cooling isolation pressure.

2. HPSW system related components are excluded.

Verify required RHR shutdown cooling In accordance subsystem locations susceptible to gas with the accumulation are sufficiently filled with Surveillance water. Frequency Control Program.

PBAPS UN IT 2 3.4-18 Amendment No. 297

RHR Shutdown Cooling System-Cold Shutdown 3.4.8 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.8 Residual Heat Removal (RHR) Shutdown Cooling System-Cold Shutdown LCO 3.4.8 Two RHR shutdown cooling subsystems shall be OPERABLE, and, with no recirculation pump in operation, at least one RHR shutdown cooling subsystem shall be in operation.

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

1. Both required RHR shutdown cooling subsystems and recirculation pumps may be removed from operation for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period.

2. One required RHR shutdown cooling subsystem may be inoperable for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for performance of Surveillances.

APPLICABILITY: MODE 4.

ACTIONS

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

Separate Condition entry is allowed for each RHR shutdown cooling subsystem.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or two required A.1 Verify an alternate 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months RHR shutdown cooling method of decay heat subsystems inoperable. removal is available AND for each inoperable required RHR shutdown Once per cooling subsystem. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter (continued)

PBAPS UNIT 2 3.4-19 Amendment No. 210

RHR Shutdown Cooling System-Cold Shutdown 3.4.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. No RHR shutdown B.l Verify reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from cooling subsystem in coolant circulating discovery of no operation. by an alternate reactor coolant method. circulation AND No recirculation pump in operation. Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter AND B.2 Monitor reactor Once per hour coolant temperature and pressure.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one required RHR shutdown cooling In accordance subsystem or recirculation pump is with the operating. Surveillance Frequency Control Program.

SR 3.4.8.2 - - - - - - - - - - - - - - - - - - - NOTE - - - - - - - - - - - - - - - - - - - -

HPSW system related components are excluded.

Verify required RHR shutdown cooling In accordance subsystem locations susceptible to gas with the accumulation are sufficiently filled with Surveillance water. Frequency Control Program.

PBAPS UN IT 2 3.4-20 Amendment No. 297

RCS PIT Limits 3.4.9 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.9 RCS Pressure and Temperature (PIT) Limits LCO 3.4.9 RCS pressure, RCS temperature, RCS heatup and cool down rates, and the recirculation pump starting temperature requirements shall be maintained within the limits specif1ed in the PTLR.

APPLICABILITY: At all times.

ACTIONS CONDITION REOU IRED ACTI ON COMPLETION TIME A. - -------NOTE---- -. A.1 Restore parameter(s) 30 minutes Required Action A.2 to within limits.

shall be compl eted if this Condition is AND entered.

A.2 Determine RCS is 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months acceptable for Requirements of the continued operation.

LCO not met in MODE 1,

2. or 3.

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

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

PBAPS UNIT 2 3.4-21 Amendment No. 286

RCS PIT Limits 3.4.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. ---------NOTE-------- C.1 Initiate action to Immediately Required Action C.2 restore parameter(s) shall be compl eted i f to within limits.

this Condition is entered. AliD.

C.2 Determine RCS is Prior to Requirements of the acceptable for entering MODE 2 LCO not met in other operation. or 3.

than MODES I, 2, and 3.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 - - - - - - - - - - - - - - - - - - -NOT E- - - - - - - - - - - - - - - - - - -

Only required to be performed during RCS heat up and cooldown operations and RCS inservice leak and hydrostatic testing.

Verify: In accordance with the

a. RCS pressure and RCS temperature are Surveillance within the limits specified in the Frequency PTLR; and Control Program.

b. RCS heatup and cool down rates are within the limits specified in the PTLR.

(continued)

PBAPS UN IT 2 3.4-22 Amendment No. 286

RCS PIT Limits 3.4.9 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.9.2 Verify RCS pressure and RCS temperature are Once withi n within the criticality limits specified in 15 minutes the PLTR. prior to control rod withdrawal for the purpose of achieving criticality SR 3.4.9.3 - - - - - - - - - - - - - - - - - - - - NOT E- - - - - - - - - - - - - - - - -

Only required to be met in MODES 1, 2, 3, and 4 during recirculation pump start.

Verify the difference between the bottom Once within head coolant temperature and the reactor 15 minutes pressure vessel (RPV) coolant temperature prior to each is within the limits specified in the PTLR. startup of a recirculation pump SR 3.4.9.4 - - - - - - - - - - - - - - - - - - - NOT E- - - - - - - - - - - - - - - - -

Only required to be met in MODES 1, 2, 3, and 4 during recirculation pump start.

Verify the difference between the reactor Once within coolant temperature in the recirculation 15 minutes loop to be started and the RPV coolant prior to each temperature is within the limits specified startup of a in the PTLR. recirculation pump (continued)

PBAPS UN IT 2 3.4-23 Amendment No. 286

RCS PIT Limits 3.4.9 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.9.5 - - - - - - - - - - - - - - - - - -NOT E- - - - - - - - - - - - - - - - - -

Only required to be performed when tensioning the reactor vessel head bolting studs.

Verify reactor vessel flange and head In accordance flange temperatures are within the limits with the specified in the PTLR. Surveillance Frequency Control Program.

SR 3.4.9.6 - - -- -- ------NOTE ------ -- --

Not required to be performed until 30 minutes after RCS temperature s BO°F in MODE 4.

Verify reactor vessel flange and head In accordance flange temperatures are within the limits with the specified in the PTLR. Surveillance Frequency Control Program.

SR 3.4.9.7 - ------- - -- -NOTE----------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after RCS temperature s 100°F in MODE 4.

Verify reactor vessel flange and head In accordance flange temperatures are within the limits with the specified in the PTLR! Surveillance Frequency Control Program.

PBAPS UNIT 2 3.4-24 Amendment No. 286

THE INFORMATION ON THIS PAGE HAS BEEN DELETED.

INTENTIONALLY LEFT BLANK.

PBAPS UN IT 2 3.4-25 Amendment No. 286

THE INFORMATION ON THIS PAGE HAS BEEN DELETED.

INTENTIONALLY LEFT BLANK.

PBAPS UNIT 2 3.4-26 Amendment No. 286

THE INFORMATION ON THIS PAGE HAS BEEN DELETED.

INTENTIONALLY LEFT BLANK.

PBAPS UNIT 2 3.4-27 Amendment No. 286

ECCS-Operati ng 3.5.1 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY CONTROL (WIC),

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

APPLICABILITY: MODE 1, MODES 2 and 3, except high pressure coolant injection (HPCI) is not required to be OPERABLE with reactor steam dome pressures 150 psig and ADS valves are not required to be OPERABLE with reactor steam dome pressures 100 psig.

ACTIONS

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

LCO 3.0.4.b is not applicable to HPCI.

CONDITION REQUIRED ACTION COMPLETION TIME A. One low pressure ECCS A.1 Restore low pressure 7 days injection/spray ECCS injection/spray subsystem inoperable. subsystem(s) to OPERABLE status.

OR One low pressure coolant injection (LPCI) pump in each subsystem inoperable.

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

(continued)

PBAPS UNIT 2 3.5-1 Amendment No. 317

ECCS-Operating 3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. HPCI System C.1 Verify by Immediately inoperable, administrative means RCIC System is OPERABLE.

AND C.2 Restore HPCI System 14 days to OPERABLE status.

D. HPCI System D.1 Restore HPCI System 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable, to OPERABLE status.

AND OR One low pressure ECCS D.2 Restore low pressure 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months injection/spray ECCS injection/spray subsystem is subsystem to OPERABLE inoperable, status.

E. One ADS valve E.1 Restore ADS valve to 14 days inoperable. OPERABLE status.

(continued)

PBAPS UNIT 2 3.5-2 Amendment No.261

ECCS-Operating 3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. One ADS valve F.1 Restore ADS valve to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. OPERABLE status.

AND OR One low pressure ECCS F.2 Restore low pressure 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months injection/spray ECCS injection/spray subsystem inoperable, subsystem to OPERABLE status.

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

H. Two or more ADS valves H.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months inoperable.

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

< 100 psig.

I. Two or more low f.1 Enter LCO 3.0.3. Immediately pressure ECCS injection/spray subsystems inoperable for reasons other than Condition A.

OR HPCI System and one or more ADS valves inoperable.

PBAPS UNIT 2 3.5-3 Amendment No 261

ECCS-Operating

3. 5 .1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify, for each ECCS injection/spray In accordance subsystem, locations susceptible to gas with the accumulation are sufficiently filled with Surveillance water. Frequency Control Program.

SR 3.5.1.2 - - - - - - - - - - - - - - - - - - - NOTE- - - - - - - - - - - - - - - - - - - -

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

Verify each ECCS injection/spray subsystem In accordance manual, power operated, and automatic valve with the in the flow path, that is not locked, Surveillance sealed, or otherwise secured in position, Frequency is in the correct position. Control Program.

SR 3.5.1.3 Verify ADS nitrogen supply header pressure In accordance is ~ 85 psig. with the Surveillance Frequency Control Program.

SR 3. 5 .1. 4 Verify the LPCI cross tie valve In accordance is closed and power is removed from the with the valve operator. Surveillance Frequency Control Program.

(continued)

PBAPS UN IT 2 3.5-4 Amendment No. 297

ECCS-Operati ng 3.5.l SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3. 5 .1. 5 Verify each recirculation pump discharge In accordance valve cycles through one complete cycle of with the full travel or is de-energized in the IN SERVICE closed position. TESTING PROGRAM.

SR 3. 5 .1. 6 Verify automatic transfer of the power In accordance supply from the normal source to the with the alternate source for each LPCI subsystem Surveillance inboard injection valve and each Frequency recirculation pump discharge valve. Control Program.

SR 3. 5 .1. 7 -------------------NOTE--------------------

For the core spray pumps, SR 3.5.1.7 may be met using equivalent values for flow rate and test pressure determined using pump curves.

Verify the following ECCS pumps develop the In accordance specified flow rate against a system head with the corresponding to the specified reactor Surveillance pressure. Frequency SYSTEM HEAD Control NO. CORRESPONDING Program.

OF TO A REACTOR SYSTEM FLOW RATE PUMPS PRESSURE OF Core Spray ;::: 3,125 gpm 1 ;::: 105 psig LPCI <! 8,600 gpm 1 <! 20 psig (continued)

PBAPS UNIT 2 3.5-5 Amendment No. 313

ECCS -Operating 3.5.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3. 5 .1. 8 -------------------NOTE--------------------

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

Verify, with reactor pressure~ 1053 and In accordance

~ 910 psig, the HPCI pump can develop a with the flow rate~ 5000 gpm against a system head Surveillance corresponding to reactor pressure. Frequency Control Program.

SR 3. 5 .1. 9 -------------------NOTE--------------------

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

Verify, with reactor pressure~ 175 psig, In accordance the HPCI pump can develop a flow rate with the

~ 5000 gpm against a system head Surveillance corresponding to reactor pressure. Frequency Control Program.

SR 3. 5 .1.10 -------------------NOTE--------------------

Vessel injection/spray may be excluded.

Verify each ECCS injection/spray subsystem In accordance actuates on an actual or simulated with the automatic initiation signal. Surveillance Frequency Control Program.

(continued)

PBAPS UNIT 2 3.5-6 Amendment No. 316

ECCS - Shutdown 3.5.2 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY CONTROL (WIC),

AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM Deleted PBAPS UNIT 2 3.5-8 Amendment No. 317

THE INFORMATION ON THIS PAGE HAS BEEN DELETED.

INTENTIONALLY LEFT BLANK.

PBAPS UNIT 2 3.5-9 Amendment No. 317

THE INFORMATION ON THIS PAGE HAS BEEN DELETED.

INTENTIONALLY LEFT BLANK.

PBAPS UNIT 2 3. 5-10 Amendment No. 317

THE INFORMATION ON THIS PAGE HAS BEEN DELETED.

INTENTIONALLY LEFT BLANK.

PBAPS UNIT 2 3.5-11 Amendment No. 317

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

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

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

ACTIONS

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

LCO 3.0.4.b is not applicable to RCIC.

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

AND A.2 Restore RCIC System 14 days to OPERABLE status.

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

PBAPS UNIT 2 3. 5-12 Amendment No. 317

RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 Verify the RCIC System locations In accordance susceptible to gas accumulation are with the sufficiently filled with water. Surveillance Frequency Control Program.

SR 3.5.3.2 -------------------NOTE--------------------

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

Verify each RCIC System manual, power In accordance operated, and automatic valve in the flow with the path, that is not locked, sealed, or Surveillance otherwise secured in position, is in the Frequency correct position. Control Program.

SR 3.5.3.3 -------------------NOTE--------------------

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

Verify, with reactor pressure~ 1053 psig In accordance and~ 910 psig, the RCIC pump can develop a with the flow rate~ 600 gpm against a system head Surveillance corresponding to reactor pressure. Frequency Control Program.

SR 3.5.3.4 -------------------NOTE--------------------

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

Verify, with reactor pressure~ 175 psig, In accordance the RCIC pump can develop a flow rate with the

~ 600 gpm against a system head Surveillance corresponding to reactor pressure. Frequency Control Program.

(continued)

PBAPS UNIT 2 3.5-13 Amendment No. 316

RPV Water Inventory Control 3.5.4 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY CONTROL (WIC),

AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.4 Reactor Pressure Vessel (RPV) Water Inventory Control LCO 3.5.4 DRAIN TIME of RPV water inventory to the top of active fuel (TAF) shall be~ 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

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

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

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

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

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

C. DRAIN TIME < 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months C.l Verify secondary 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and ~ 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . containment boundary is capable of being established in less than the DRAIN TIME.

AND (continued)

PBAPS UNIT 2 3.5-15 Amendment No. 317

RPV Water Inventory Control 3.5.4 ACTIONS (continued)

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

AND C. 3 Verify one standby 4 hours gas treatment subsystem is capable of being placed in operation in less than DRAIN TIME.

D. DRAIN TIME< 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . D.1 -------NOTE-----------

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

Initiate action to Immediately establish an additional method of water injection with water sources capable of maintaining RPV water level> TAF for

~ 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

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

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

AND (continued)

PBAPS UNIT 2 3.5-16 Amendment No. 317

RPV Water Inventory Control 3.5.4 ACTIONS (continued)

D. (continued) D.4 Initiate action to verify Immediately one Standby Gas Treatment subsystem is capable of being placed into operation.

E. Required Action and E.1 Initiate action to Immediately associated Completion restore DRAIN TIME to~

Time of Condition C or 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

D not met.

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

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.4.1 Verify DRAIN TIME~ 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . In accordance with the Surveillance Frequency Control Program.

SR 3.5.4.2 Verify, for a required low pressure coolant In accordance injection (LPCI) subsystem, the suppression with the pool water level is~ 11.0 ft. Surveillance Frequency Control Program.

SR 3.5.4.3 Verify, for a required Core Spray (CS) In accordance subsystem, the: with the Surveillance

a. Suppression pool water level is~ Frequency Control 11.0 ft. or Program.

b. Condensate storage tank water level is~

17.3 ft.

(continued)

PBAPS UNIT 2 3.5-17 Amendment No. 317

RPV Water Inventory Control 3.5.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.4.4 Verify, for the required ECCS In accordance injection/spray subsystem, locations with the susceptible to gas accumulation are Surveillance sufficiently filled with water. Frequency Control Prooram.

SR 3.5.4.5 ----------------NOTE------------------

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

Verify for the required ECCS In accordance injection/spray subsystem manual, power with the operated, and automatic valve in the flow Surveillance path, that is not locked, sealed, or Frequency otherwise secured in position, is in the Control correct position. Program.

SR 3.5.4.6 Operate the required ECCS injection/spray In accordance subsystem through the recirculation line with the for~ 10 minutes. Surveillance Frequency Control Program.

SR 3.5.4.7 Verify each valve credited for In accordance automatically isolating a penetration flow with the path actuates to the isolation position on Surveillance an actual or simulated isolation signal. Frequency Control Program.

SR 3.5.4.8 -------------------NOTE----------------

Vessel injection/spray may be excluded.

Verify the required ECCS injection/spray In accordance subsystem can be manually actuated. with the Surveillance Frequency Control Program.

PBAPS UNIT 2 3.5-18 Amendment No. 317

Primary Containment 3.6.1.1 3.6 CONTAINMENT SYSTEMS 3.6.1.1 Primary Containment LCO 3.6.1.1 Primary containment shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Primary containment A.1 Restore primary 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable, containment to OPERABLE status.

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

PBAPS UNIT 2 3.6-1 Amendment No. 261

Primary Containment Air Lock 3.6.1.2 3.6 CONTAINMENT SYSTEMS 3.6.1.2 Primary Containment Air Lock LCO 3.6.1.2 The primary containment air lock shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

-_-------------------------NOTES------------------------------------

1. Entry and exit is permissible to perform repairs of the air lock components.

2. Enter applicable Conditions and Required Actions of LCO 3.6.1.1, "Primary Containment," when air lock leakage results in exceeding overall containment leakage rate acceptance criteria.

CONDITION REQUIRED ACTION COMPLETION TIME A. One primary ------------ NOTES------------

containment air lock 1. Required Actions A.1, door inoperable. A.2, and A.3 are not applicable if both doors in the air lock are inoperable and Condition C is entered.

2. Entry and exit is permissible for 7 days under administrative controls.

A.1 Verify the OPERABLE 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months door is closed.

AND (continued)

PBAPS UNIT 2 3.6-3 Amendment No. 210

Primary Containment Air Lock 3.6.1.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 Lock the OPERABLE 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months door closed.

AND A.3 -------- NOTE---------

Air lock doors in high radiation areas or areas with limited access due to inerting may be verified locked closed by administrative means.

Verify the OPERABLE Once per 31 days door is locked closed.

B. Primary containment ------------NOTES------------

air lock interlock 1. Required Actions B.1, mechanism inoperable. B.2, and B.3 are not applicable if both doors in the air lock are inoperable and Condition C is entered.

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

B.1 Verify an OPERABLE 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months door is closed.

(continued)

PBAPS UNIT 2 3.6-4 Amendment No. 210

Primary Containment Air Lock 3.6.1.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2 Lock an OPERABLE door 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months closed.

AND B.3 --------NOTE---------

Air lock doors in high radiation areas or areas with limited access due to inerting may be verified locked closed by administrative means.

Verify an OPERABLE Once per 31 days door is locked closed.

C. Primary containment C.1 Initiate action to Immediately air lock inoperable evaluate primary for reasons other than containment overall Condition A or B. leakage rate per LCO 3.6.1.1, using current air lock test results.

C.2 Verify a door is 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months closed.

C.3 Restore air lock to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE status.

(continued)

PBAPS UNIT 2 3.6-5 Amendment No. 210

Primary Containment Air Lock 3.6.1.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AND D.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.2.1 ------------------NOTES---------------

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

2. Results shall be evaluated against acceptance criteria applicable to SR 3.6.1.1.1.

Perform required primary containment air In accordance lock leakage rate testing in accordance with the with the Primary Containment Leakage Rate Primary Testing Program. Containment Leakage Rate Testing Program (continued)

PBAPS UNIT 2 3.6-6 Amendment No. 'I>,Q214 JUN 1 8 1996

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

LCO 3.6.1.3 Each PCIV, except reactor building-to-suppression chamber vacuum breakers and scram discharge volume vent and drain valves, shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, When associated instrumentation is required to be OPERABLE per LCO 3.3.6.1, RPrimary Containment Isolation Instrumentation."

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

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

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

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

4. Enter applicable Conditions and Required Actions of LCO 3.6.1.1, 'Primary Containment," when PCIV leakage results in exceeding overall containment leakage rate acceptance criteria.

CONDITION REQUIRED ACTION COMPLETION TIME A. --------- NOTE--------- A.1 Isolate the affected 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months except Only applicable to penetration flow path for main steam penetration flow paths by use of at least line with two PCIVs. one closed and de-activated AND automatic valve, One or more closed manual valve, 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months for main penetration flow paths blind flange, or steam line with one PCIV check valve with flow inoperable except for through the valve MSIV leakage not secured.

within limit.

(continued)

PBAPS UNIT 2 3 .6-8 Amendment No. 210

PCIVs 3.6.1.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 -------- NOTES--------

1. Isolation devices in high radiation I

areas may be verified by use of administrative means.

2. Isolation devices that are locked, sealed, or other-wise 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 primary containment AU Prior to entering MODE 2 or 3 from MODE 4, if primary containment was de-inerted while in MODE 4, if not performed within the previous 92 days, for isolation devices inside primary containment S I (continued)

PBAPS UNIT 2 3.6- 9 Amendment No. 259

PCIVs 3 .6.1 .3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. ---------NOTE--------- B.1 Isolate the affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Only applicable to penetration flow path penetration flow paths by use of at least with two PCIVs. one closed and de-activated automatic valve, One or more closed manual valve, penetration flow paths or blind flange.

with two PCIVs inoperable except for MSIV leakage not within limit.

C. --------- NOTE--------- C.1 Isolate the affected 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months except Only applicable to penetration flow path for excess flow penetration flow paths by use of at least check valves with only one PCIV. one closed and (EFCVs) and de-activated penetrations automatic valve, with a closed One or more closed manual valve, system penetration flow paths or blind flange.

with one PCIV AND inoperable. AND 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for EFCVs and penetrations with a closed system (continued)

PBAPS UNIT 2 3.6-10 Amendment No. 259

PCIVs 3.6.1.3 ACTIONS (continued)

CONDITION J REQUIRED ACTION COMPLETION TIME C. (continued) C.2 NOTES--------

1. Isolation devices in high radiation I

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 primary containment Afi2 Prior to entering MODE 2 or 3 from MODE 4, if primary containment was de-inerted while in MODE 4, if not performed within the previous 92 days, for isolation devices inside primary containment D. One or more D.1 Restore leakage rate 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months penetration flow paths to within limit.

with one or more MSIVs not within MSIV leakage rate limits.

(continued)

PBAPS UNIT 2 3.6 -11 Amendment No. 259

PCIVs 3.6.1.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Purge/Vent flowpath E.1 Isolate the 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months open for an penetration.

accumulated time greater than 90 hours0.00104 days 0.025 hours 1.488095e-4 weeks 3.4245e-5 months OR for the calendar year while in MODE 1 or 2 E.2 .1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months with Reactor Pressure greater than 100 psig. AND E.2. 2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months F. Required Action and F.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A, AND B, C, or D not met in MODE 1, 2, or 3. F.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months G. Required Action and G.1 Initiate action to Immediately associated Completion restore valve(s) to Time of Condition A, OPERABLE status.

B, C, or D not met for PCIV(s) required to be OPERABLE during MODE 4 or 5.

SURVEILLANCE RE UIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.3.1 Verify nitrogen inventory is equivalent In accordance to~ 22 inches water column in the liquid with the nitrogen storage tank. Su rvei 11 ance Frequency Control Program.

(continued)

PBAPS UNIT 2 3.6-12 Amendment No. 317

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3. 6 .1. 3. 8 Verify the isolation time of each In accordance automatic power operated PCIV, except for with the MSIVs, is within limits. INSERVICE TESTING PROGRAM SR 3. 6 .1. 3. 9 Verify the isolation time of each MSIV is In accordance

~ 3 seconds and ~ 5 seconds. with the INSERVICE TESTING PROGRAM SR 3. 6 .1. 3 .10 Verify each automatic PCIV actuates to In accordance the isolation position on an actual or with the simulated isolation signal. Surveillance Frequency Control Program.

SR 3.6.1.3.11 Verify a representative sample of reactor In accordance instrumentation line EFCVs actuates to with the the isolation position on a simulated Survei 11 ance instrument line break signal. Frequency Control Program.

SR 3. 6 .1. 3 .12 Remove and test the explosive squib from In accordance each shear isolation valve of the TIP with the System. Survei 11 ance Frequency Control Program.

SR 3 . 6 .1. 3. 13 Verify the CAD System supplies nitrogen In accordance to the SGIG System upon loss of the with the normal air supply. Surveillance Frequency Control Program.

(continued)

PBAPS UNIT 2 3.6-15 Amendment No. 313

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.1.3.14 Verify combined MSIV leakage rate for all In accordance four main steam lines is~ 170 scfh, and with the

~ 85 scfh for any one steam line, when Primary tested at ~ 25 psig. Containment Leakage Rate Testing Program SR 3.6.1.3.15 Verify each 6 inch and 18 inch primary In accordance containment purge valve and each 18 inch with the primary containment exhaust valve is Surveillance blocked to restrict opening greater than Frequency the required maximum opening angle. Control Program.

SR 3.6.1.3.16 Replace the inflatable seal of each In accordance 6 inch and 18 inch primary containment with the purge valve and each 18 inch primary Surveillance containment exhaust valve. Frequency Control Program.

PBAPS UN IT 2 3.6-16 Amendment No. 293

Reactor Building-to-Suppression Chamber Vacuum Breakers 3.6.1.5 3.6 CONTAINMENT SYSTEMS 3.6.1.5 Reactor Building-to-Suppression Chamber Vacuum Breakers LCO 3.6.1.5 Each reactor building-to-suppression chamber vacuum breaker shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

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

Separate Condition entry is allowed for each line.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more lines with A.1 Close the open vacuum 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months one reactor building- breaker.

to-suppression chamber vacuum breaker not closed.

B. One or more lines with B.1 Close one open vacuum 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months two reactor building- breaker.

to-suppression chamber vacuum breakers not closed.

C. One line with one or C.1 Restore the vacuum 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months more reactor building- breaker(s) to to-suppression chamber OPERABLE status.

vacuum breakers inoperable for opening.

(continued)

PBAPS UNIT 2 3.6-18 Amendment No. 210

Reactor Building-to-Suppression Chamber Vacuum Breakers 3.6.1.5 ACTIONS (continued)

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

E. Two lines with one or E.1 Restore all vacuum 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months more reactor building- breakers in one line to-suppression chamber to OPERABLE status.

vacuum breakers inoperable for opening.

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

F.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6. 1 . 5. 1 Verify nitrogen inventory is equivalent In accordance to 2 22 inches water column in the liquid with the nitrogen storage tank. Surveillance Frequency Control Program.

SR 3.6.1.5.2 Verify Safety Grade Instrument Gas (SGIG) In accordance System header pressure 2 80 psig. with the Surveillance Frequency Control Program.

(continued)

PBAPS UNIT 2 3.6-19 Amendment No. 282

Suppression Chamber-to-Drywell Vacuum Breakers 3.6.1.6 3.6 CONTAINMENT SYSTEMS 3.6.1.6 Suppression Chamber-to-Drywell Vacuum Breakers LCO 3.6.1.6 Nine suppression chamber-to-drywell vacuum breakers shall be OPERABLE for opening.

AND Twelve suppression chamber-to-drywell vacuum breakers shall be closed, except when performing their intended function.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required A.1 Restore one required 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months suppression chamber- vacuum breaker to to-drywell vacuum OPERABLE status.

breaker inoperable fQr opening.

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

C. One suppression C.1 Close the open vacuum 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months chamber-to-drywell breaker.

vacuum breaker not closed.

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

D.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months PBAPS UNIT 2 3.6-21 Amendment No. 261

Suppression Pool Average Temperature 3.6.2.1 3.6 CONTAINMENT SYSTEMS 3.6.2.1 Suppression Pool Average Temperature LCO 3.6.2.1 Suppression pool average temperature shall be:

a. s 950F when any OPERABLE wide range neutron monitor (WRNM) channel is at 1.00EO % power or above and no testing that adds heat to the suppression pool is being performed;

b. s 105°F when any OPERABLE WRNM channel is at 1.OOEO %

power or above and testing that adds heat to the suppression pool is being performed; and

c.

1100F when all OPERABLE WRNM channels are below 1.00EO

% power.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Suppression pool A.1 Verify suppression Once per hour average temperature pool average

> 950F but s 1100F. temperature s 110'F.

AND AND Any OPERABLE WRNM at A.2 Restore suppression 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 1.00EO % power or pool average above. temperature to s 95F.

AND Not performing testing that adds heat to the suppression pool.

(continued)

PBAPS UNIT 2 3.6-23 Amendment No. Z10,222 AUG 24 1998

Suppression Pool Average Temperature 3.6.2.1 ACTIONS (continued) -

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Reduce THERMAL POWER 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion until all OPERABLE Time of Condition A WRNM channels are not met. below 1.00EO % power.

C. Suppression pool C.1 Suspend all testing Immediately average temperature that adds heat to the

> 105 0F. suppression pool.

AND Any OPERABLE WRNM at I 1.OOEO % power or above.

AND Performing testing that adds heat to the suppression pool.

D. Suppression pool D.1 Place the reactor Immediately average temperature mode switch in the

> 110 0F but i 120 0F. shutdown position.

QAN D.2 Verify suppression Once per pool average 30 minutes temperature s 120'F.

D.3 Be in MODE 4 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued)

Amendment No. fl0,222 PBAPS UNIT 2 3.6-24 AUG 2 4 1998

RHR Suppression Pool Cooling 3.6.2.3 3.6 CONTAINMENT SYSTEMS 3.6.2.3 Residual Heat Removal (RHR) Suppression Pool Cooling LCO 3.6.2.3 Two RHR suppression pool cooling subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR suppression A.1 Restore RHR 7 days*

pool cooling subsystem suppression pool inoperable. cooling subsystem to OPERABLE status.

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

C. Two RHR suppression C.l Restore one RHR 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months pool cooling subsystems suppression pool inoperable. cooling subsystem to OPERABLE status.

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

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

The 7-day Completion Time for one RHR suppression pool cooling subsystem inoperable may be extended to 10 days four (4) times until December 31, 2021

with compensatory measures identified in EGC License Amendment Request letter dated September 28, 2018 established and in effect, to allow for modifications to the HPSW system.

PBAPS UN IT 2 3.6-27 Amendment No. 327

RHR Suppression Pool Cooling 3.6.2.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.3.1 Verify each RHR suppression pool cooling In accordance subsystem manual, power operated, and with the automatic valve in the flow path that is Surveillance not locked, sealed, or otherwise secured Frequency in position is in the correct position or Control can be aligned to the correct position. Program.

SR 3.6.2.3.2 Verify each required RHR pump develops a In accordance flow rate ~ 8,600 gpm through the with the associated heat exchanger while operating INSERVICE in the suppression pool cooling mode. TESTING PROGRAM SR 3.6.2.3.3 Verify manual transfer capability of In accordance power supply for the RHR motor-operated with the flow control valve and the RHR cross-tie Surveillance motor-operated valve from the normal Frequency source to the alternate source. Control Program.

SR 3.6.2.3.4 ------------------NOTE-------------------

HPSW system related components are excluded.

Verify RHR suppression pool cooling In accordance subsystem locations susceptible to gas with the accumulation are sufficiently filled with Surveillance water. Frequency Control Program.

PBAPS UNIT 2 3.6-28 Amendment No. 313

RHR Suppression Pool Spray 3.6.2.4 3.6 CONTAINMENT SYSTEMS 3.6.2.4 Residual Heat Removal (RHR) Suppression Pool Spray LCO 3.6.2.4 Two RHR suppression pool spray subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR suppression A.1 Restore RHR 7 days*

pool spray subsystem suppression pool inoperable. spray subsystem to OPERABLE status.

B. Two RHR suppression B. 1 Restore one RHR 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months pool spray subsystems suppression pool inoperable. spray subsystem to OPERABLE status.

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

The 7-day Completion Time for one RHR suppression pool spray subsystem inoperable may be extended to 10 days four (4) times until December 31, 2021 with compensatory measures identified in EGC License Amendment Request letter dated September 28, 2018 established and in effect, to allow for modifications to the HPSW system.

PBAPS UN IT 2 3.6-29 Amendment No. 327

RHR Suppression Pool Spray 3.6.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.4.l Verify each RHR suppression pool spray In accordance subsystem manual, power operated, and with the automatic valve in the flow path that is Surveillance not locked, sealed, or otherwise secured Frequency in position is in the correct position or Control can be aligned to the correct position. Program.

SR 3.6.2.4.2 Verify each suppression pool spray nozzle In accordance is unobstructed. with the Surveillance Frequency Control Program.

SR 3.6.2.4.3 Deleted SR 3.6.2.4.4 - - - - - - - - - - - - - - - - - - NOTE - - - - - - - - - - - - - - - - - - -

HPSW system related components are excluded.

Verify RHR suppression pool spray In accordance subsystem locations susceptible to gas with the accumulation are sufficiently filled with Survei 11 ance water. Frequency Control Program.

PBAPS UN IT 2 3.6-30 Amendment No. 308

RHR Drywell Spray 3.6.2.5 3.6 CONTAINMENT SYSTEMS 3.6.2.5 Residual Heat Removal (RHR) Drywell Spray LCO 3.6.2.5 Two RHR drywell spray subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR drywel l spray A.l Restore RHR drywell 7 days*

subsystem inoperable. spray subsystem to OPERABLE status.

B. Two RHR drywel l spray B.1 Restore one RHR 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months subsystems inoperable. drywell spray subsystem to OPERABLE status.

C. Required Action and C. 1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Ti me not met. AND C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months

The 7-day Completion Time for one RHR drywell spray subsystem inoperable may be extended to 10 days four (4) times until December 31, 2021 with compensatory measures identified in EGC License Amendment Request letter dated September 28, 2018 established and in effect, to allow for modifications to the HPSW system.

PBAPS UN IT 2 3.6-30a Amendment No. 327

RHR Drywel l Spray 3.6.2.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.5.l Verify each RHR drywell spray subsystem In accordance manual, power operated, and automatic with the valve in the flow path that is not locked, Survei 11 ance sealed, or otherwise secured in position Frequency is in the correct position or can be Control aligned to the correct position. Program.

SR 3.6.2.5.2 Verify each drywell spray nozzle is In accordance unobstructed. with the Survei 11 ance Frequency Control Program.

SR 3.6.2.5.3 Deleted SR 3.6.2.5.4 - - - - - - - - - - - - - - - - - - NOTE - - - - - - - - - - - - - - - - - - -

HPSW system related components are excluded.

Verify RHR drywell spray subsystem In accordance locations susceptible to gas accumulation with the are sufficiently filled with water. Surveillance Frequency Control Program.

PBAPS UN IT 2 3.6-30b Amendment No. 308

CAD System 3.6.3.1 3.6 CONTAINMENT SYSTEMS 3.6.3.1 Deleted PBAPS UNIT 2 3.6-31 Amendment N0.274

The information on this page has been deleted.

Intentionally left blank, PBAPS UNIT 2 3.6-32 Amendment N0'274

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

APPLICABILITY: MODES 1, 2, and 3, During movement of RECENTLY IRRADIATED FUEL assemblies in the secondary containment ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Secondary containment A.1 Restore secondary 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months inoperable in MODE 1, containment to 2, or 3. OPERABLE status.

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

C. Secondary containment C.1 --------NOTE---------

inoperable during LCO 3.0.3 is not movement of RECENTLY applicable.

IRRADIATED FUEL assemblies in the secondary containment. Suspend movement of Immediately RECENTLY IRRADIATED FUEL assemblies in the secondary containment.

PBAPS UNIT 2 3.6-34 Amendment No. 317

Secondary Containment 3.6.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1.1 Verify al 1 secondary containment In accordance equipment hatches are closed and sealed. with the Surveillance Frequency Control Program.

SR 3.6.4.1.2 Verify one secondary containment access In accordance door in each access opening is closed, with the except when the access opening is being Survei11 ance used for entry or exit. Frequency Control Program.

SR 3.6.4.1.3 Verify secondary containment can be drawn In accordance down to~ 0.25 inch of vacuum water gauge with the in~ 180 seconds using one standby gas , Survei 11 ance treatment (SGT) subsystem. Frequency Control Program.

SR 3.6.4.1.4 Verify the secondary containment can be In accordance maintained~ 0.25 inch of vacuum water with the gauge for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months using one SGT subsystem Surveillance at a flow rate~ 10,500 cfm. Frequency Control Program.

PBAPS UNIT 2 3.6-35 Amendment No. 317

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

LCO 3.6.4.2 Each SCIV shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, During movement of RECENTLY IRRADIATED FUEL assemblies in the secondary containment ACTIONS

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

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

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

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

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

(continued)

PBAPS UNIT 2 3.6-36 Amendment No. 317

SCIVs 3.6.4.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 --------NOTES--------

1. Isolation devices in high radiation I

areas may be verified by use of administrative means.

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

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

B. --------- NOTE-------- B.1 Isolate the affected 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Only applicable to penetration flow path penetration flow paths by use of at least with two isolation one closed and valves. de-activated automatic valve, closed manual valve, One or more or blind flange.

penetration flow paths with two SCIVs inoperable.

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

PBAPS UNIT 2 3.6 -37 Amendment No.259

SCIVs 3.6.4.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 --------NOTE---------

associated Completion LCO 3 . 0 . 3 i s not Time of Condition A applicable.

or B not met during movement of RECENTLY IRRADIATED FUEL Suspend movement of Immediately assemblies in the RECENTLY IRRADIATED secondary containment. FUEL assemblies in the secondary containment.

PBAPS UNIT 2 3.6-38 Amendment No. 317

SCI Vs 3.6.4.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.2.1 ------------------NOTES------------------

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

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

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

SR 3.6.4.2.2 Verify the isolation time of each power In accordance operated automatic SCIV is within limits. with the INSERVICE TESTING PROGRAM SR 3.6.4.2.3 Verify each automatic SCIV actuates to In accordance the isolation position on an actual or with the simulated actuation signal. Surveillance Frequency Control Program.

PBAPS UNIT 2 3.6-39 Amendment No. 313

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

APPLICABILITY: MODES 1, 2, and 3, During movement of RECENTLY IRRADIATED FUEL assemblies in the secondary containment ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SGT subsystem A.1 Restore SGT subsystem 7 days inoperable. to OPERABLE status.

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

C. Required Action and ------------NOTE-------------

associated Completion LCO 3.0.3 is not applicable.

Time of Condition A not met during movement of RECENTLY C.1 Place OPERABLE SGT Immediately IRRADIATED FUEL subsystem in assemblies in the operation.

secondary containment.

(continued)

PBAPS UNIT 2 3.6-40 Amendment No. 317

SGT System 3.6.4.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.2 Suspend movement of Immediately RECENTLY IRRADIATED FUEL assemblies in secondary containment.

D. Two SGT subsystems D.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months inoperable in MODE 1, 2, or 3.

E. Two SGT subsystems E.1 --------NOTE---------

inoperable during LCO 3.0.3 is not movement of RECENTLY applicable.

IRRADIATED FUEL ---------------------

assemblies in the secondary containment. Suspend movement of Immediately RECENTLY IRRADIATED FUEL assemblies in secondary containment.

PBAPS UNIT 2 3.6-41 Amendment No. 317

HPSW System 3.7.1 3.7 PLANT SYSTEMS 3.7.1 High Pressure Service Water (HPSW) System LCO 3.7.1 Two HPSW subsystems and the HPSW cross tie shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One HPSW subsystem - - - - - - - - - - - NOTE - - - - - - - - - - - - -

inoperable. Enter applicable Conditions and Required Actions of LC O 3 . 4 . 7 , " Res i d ua l He a t Removal ( RHR) Shutdown Cooling System-Hot Shutdown," for RHR shutdown cooling made inoperable by HPSW System.

A.1 Restore HPSW 7 days*

subsystem to OPERABLE status.

B. HPSW cross tie B. 1 Restore HPSW cross 7 days*

inoperable. tie to OPERABLE status.

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

(continued)

The 7-day Completion Time for one HPSW subsystem inoperable may be extended to 10 days four (4) times until December 31, 2021 and the 7-day Completion Time for the HPSW cross tie inoperable may be extended to 10 days two (2) times until December 31, 2021 with compensatory measures identified in EGC License Amendment Request letter dated September 28, 2018 established and in effect, to allow for modifications to the HPSW system.

PBAPS UN IT 2 3.7-1 Amendment No. 327

HPSW System 3.7.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Both HPSW subsystems -----------NOTE-------------

inoperable. Enter applicable Conditions and Required Actions of LCO 3.4.7 for RHR shutdown cooling made inoperable by HPSW System.

D.1 Restore one HPSW 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months subsystem to OPERABLE status.

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

E.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1.1 Verify each HPSW manual and power operated In accordance valve in the flow path, that is not locked, with the sealed, or otherwise secured in position, Surveillance is in the correct position or can be Frequency aligned to the correct position. Control Program.

SR 3.7.1.2 Verify manual transfer capability of power In accordance supply for the HPSW cross-tie motor- with the operated valve and the RHR heat exchanger Surveillance HPSW outlet valve from the normal source to Frequency the alternate source. Control Program.

PBAPS UNIT 2 3.7-2 Amendment No. 293

ESW System and Normal Heat Sink 3.7.2 3.7 PLANT SYSTEMS 3.7.2 Emergency Service Water (ESWJ System and Normal Heat Sink LCO 3. 7.2 Two ESW subsystems and normal heat sink shall be OPERABLE.

APPLICABILITY: MODES l, 2, and 3.

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

B. Required Action and B. 1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. MJ2

.QR B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Both ESW subsystems inoperable.

OR Normal heat sink inoperable.

PBAPS UN IT 2 3.7-3 Amendment No. 291

ESW System and Normal Heat Sink 3.7.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1 Verify the water level in the pump bays of In accordance the pump structure is ~ 98.5 ft Conowingo with the Datum (COl and ~ 113 ft CD. Surveillance Frequency Control Program.

SR 3.7.2.2 Verify the water temperature of normal heat In accordance sink is~ 92"F. with the Surveillance Frequency Control Program.

Hourly when water temperature of normal heat sink is > 90°F.

SR 3. 7.2.3 ---- *--------------NOTE--------------------

Isolation of flow to individual components does not render ESW System inoperable.

Verify each ESW subsystem manual and power In accordance operated valve in the flow paths servicing with the safety related systems or components, that Surveillance is not locked, sealed, or otherwise secured Frequency in position, is in the correct position. Control Program.

SR 3. 7.2.4 Verify each ESW subsystem actuates on an In accordance actual or simulated initiation signal. with the Surveillance Frequency Control Program.

PBAPS UN IT 2 3.7-4 Amendment No. 291

Emergency Heat Sink 3.7.3 3.7 PLANT SYSTEMS 3.7.3 Emergency Heat Sink LCO 3.7.3 The emergency heat sink shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required emergency A.1 Restore required 14 days cooling tower fan emergency cooling inoperable. tower fan to OPERABLE status.

B. Emergency heat sink B.1 Restore emergency 7 days inoperable for reasons heat sink to OPERABLE other than status.

Condition A.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AND C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months PBAPS UNIT 2 3.7-5 Amendment No. 210

MCREV System 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Main Control Room Emergency Ventilation (MCREV) System LCO 3.7.4 Two MCREV subsystems shall be OPERABLE.

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

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

APPLICABILITY: MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary containment, During CORE ALTERATIONS ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One MCREV subsystem A.1 Restore MCREV 7 days inoperable for reasons subsystem to OPERABLE other than Condition status.

8.

B. One or more MCREV 8.1 Initiate action to Immediately subsystems inoperable implement mitigating due to inoperable CRE actions.

boundary in MODE 1, 2 or 3. AND 8.2 Verify mitigating 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months actions ensure CRE occupant exposures to radiological/chemical hazards will not exceed limits and mitigating actions for smoke hazards are taken as required.

AND 8.3 Restore CRE boundary 90 days to OPERABLE status.

PBAPS UNIT 2 3.7-7 Amendment No. 317

MCREV System 3.7.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A or B not met in MODE 1, 2, or 3.

D. Required Action and ------------NOTE-------------

associated Completion LCO 3.0.3 is not applicable.

Time of Condition A not met during movement of irradiated D.1 Place OPERABLE MCREV Immediately fuel assemblies in the subsystem in secondary containment, operation.

or during CORE ALTERATIONS.

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

D.2.2 Suspend CORE Immediately AL TE RATIONS.

E. Two MCREV subsystems E.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months inoperable in MODE l, 2, or 3 for reasons other than Condition B.

PBAPS UNIT 2 3.7-8 Amendment No. 317

MCREV System 3.7.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME F. Two MCREV subsystems ------------NOTE-------------

inoperable during LCO 3.0.3 is not applicable.

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

One or more MCREV AND subsystems inoperable due to an inoperable F.2 Suspend CORE Immediately CRE Boundary during ALTERATIONS.

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

SURVEILLANCE RE UIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Operate each MCREV subsystem for In accordance

~ 15 minutes. with the Surveil 1ance Frequency Control Program.

SR 3.7.4.2 Perform required MCREV filter testing in In accordance accordance with the Ventilation Filter with the VFTP Testing Program (VFTP).

SR 3.7.4.3 Verify each MCREV subsystem actuates on an In accordance actual or simulated initiation signal. with the Surveillance Frequency Control Program.

SR 3.7.4.4 Perform required CRE unfiltered air In accordance inleakage testing in accordance with the with the Control Room Envelope Habitability Program. Control Room

! Envelope

Habi tabi 1 i ty Program.

PBAPS UNIT 2 3.7-9 Amendment No. 317

Main Condenser Offgas 3.7.5 3.7 PLANT SYSTEMS 3.7.5 Main Condenser Offgas LCO 3.7.5 The gross gamma activity rate of the noble gases measured at the steam jet air ejector (SJAE) discharge at the offgas sample rack shall be

320,000 gCi/second after decay of 30 minutes.

APPLICABILITY: MODE 1, MODES 2 and 3 with any main steam line not isolated and SJAE in operation.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Gross gamma activity A.1 Restore gross gamma 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months rate of the noble activity rate of the gases not within noble gases to within limit. limit.

B. Required Action and B.1 Isolate all main 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion steam lines.

Time not met.

OR B.2 Isolate SJAE. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months OR B.3 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months PBAPS UNIT 2 3.7-10 Amendment No. 261

Main Turbine Bypass System 3.7.6 3.7 PLANT SYSTEMS 3.7.6 Main Turbine Bypass System LCO 3.7.6 The Main Turbine Bypass System shall be OPERABLE.

OR

\

The following limits are made applicable:

a. LCO 3.2.1, "AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR)," limits for an inoperable Main Turbine Bypass System, as specified in the COLR;

b. LCO 3. 2. 2, "MINIMUM CRITICAL POWER RATIO (MCPR)," limits for an inoperable Main Turbine Bypass System, as specified in the COLR; and

c. LCO 3.2.3, "LINEAR HEAT GENERATION RATE (LHGR)," limits for an inoperable Main Turbine Bypass System, as specified in the COLR.

APPLICABILITY: THERMAL POWER~ 22.6% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the A.1 Satisfy the 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months LCO not met. requirements of the LCO.

B. Required Action and B.1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion to < 22 . 6% RTP.

Time not met.

PBAPS UNIT 2 3.7-12 Amendment No. 316

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. Two qualified circuits between the offsite transmission network and the Unit 2 onsite Class IE AC Electrical Power Distribution System;

b. Four diesel generators (DGs) capable of supplying the Unit 2 onsite Class lE AC Electrical Power Distribution System;

c. The qualified circuit(s) between the offsite transmission network and the Unit 3 onsite Class IE AC electrical power distribution subsystem(s) needed to support the Unit 3 powered equipment required to be OPERABLE by LCO 3.6.4.3, "Standby Gas Treatment (SGT)

System," LCO 3.7.3, *Emergency Heat Sink," and LCO 3.8.4, "DC Sources-Operating"; and

d. The DG(s) capable of supplying the Unit 3 onsite Class IE AC electrical power distribution subsystem(s) needed to support the Unit 3 powered equipment required to be OPERABLE by LCO 3.6.4.3, LCO 3.7.3, and LCO 3.8.4.

APPLICABILITY: MODES 1, 2, and 3.

PBAPS UNIT 2 3.8-1 Amendment No. 210

AC Sources-Operating 3.8.1 ACTIONS

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

LCO 3.0.4.b is not applicable to DGs.

CONDITION REQUIRED ACTION COMPLETION TIME A. One offsite circuit A. 1 Perform SR 3.8.1.1 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. for OPERABLE offsite circuits. AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND A.2 Declare required 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months from feature(s) with no discovery of no offsite power offsite power to available inoperable one 4 kV when the redundant emergency bus required feature(s) concurrent with are inoperable. inoperability of redundant required feature(s)

AND A.3 Restore off site 7 days ( *)

circuit to OPERABLE status.

(continued)

(*) Or 21 days, to support installation and testing of new electrical cables routed between the 3EA Emergency Auxiliary Transformer and the J-58 junction box serving the 3SU-E 4.16 kV feed switchgear. The work shall be completed by June 30, 2020.

Prior to entry into the 21-day extended Completion Time, the SBO Line (i.e., 33kV Conowingo AAC source) shall be verified available. During the 21-day Completion Time, the 33kV SBO Line shall be verified available once per shift.

If the SBO Line becomes unavailable after the initial seven (7) days while in the extended 21-day Completion Time period, it shall be made available within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , or the unit shall be brought to MODE 3 within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and MODE 4 within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

PBAPS UN IT 2 3.8-2 Amendment No. 328

AC Sources-Operating 3.8.1 ACTIONS (continued)

CONDITION I REQUIRED ACTION ICOMPLETION TIME B. One DG inoperable. B.1 Verify correct Immediately breaker alignment, required equipment AND available, and indicated power Once per available for the 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Conowingo Tie-Line. thereafter B.2 Perform SR 3.8.1.1 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months for OPERABLE offsite circuits. AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND B.3 Declare required 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from feature(s), supported discovery of by the inoperable DG, Condition B inoperable when the concurrent with redundant required inoperability of feature(s) are redundant inoperable. required feature(s)

AND B.4.1 Determine OPERABLE 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months DG(s) are not inoperable due to common cause failure.

OR B.4.2 Perform SR 3.8.1.2 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for OPERABLE DG(s).

AND (continued)

PBAPS UNIT 2 3.8-3 Amendment No. 210

AC Sources-Operating 3.8.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.5 Restore DG to 14 days from OPERABLE status. discovery of failure to meet LCO 3.8.1.a or b C. Required Action B.1 C.1 Restore DG to 7 days and associated OPERABLE status.

Completion Time not met.

D. Two or more offsite D.1 Declare required 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months from circuits inoperable. feature(s) inoperable discovery of when the redundant Condition D required feature(s) concurrent with are inoperable. inoperability of redundant required feature(s)

AND D.2 Restore all but one 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months offsite circuit to OPERABLE status.

(continued)

PBAPS UNIT 2 3.8-4 Amendment No. 210

AC Sources-Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. One offsite circuit ------------- NOTE-----------

inoperable. Enter applicable Conditions and Required Actions of AND LCO 3.8.7, "Distribution Systems-Operating," when One DG inoperable. Condition E is entered with no AC power source to any 4 kV emergency bus.

E.1 Restore offsite 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months circuit to OPERABLE status.

E.2 Restore DG to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months OPERABLE status.

F. Two or more DGs F.1 Restore all but one 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months inoperable. DG to OPERABLE status.

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

OR Required Action B.2, B.3, B.4.1, B.4.2, or B.5 and associated Completion Time not met.

(continued)

PBAPS UNIT 2 3.8-5 Amendment No. 261

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 qualified circuit between the offsite transmission network and the Unit 2 onsite Class lE AC electrical power distribution subsystem(s) required by LCO 3.8.8, Distribution Systems-Shutdown";

b. Two DGs each capable of supplying one Unit 2 onsite Class 1E AC electrical power distribution subsystem required by LCO 3.8.8;

c. One qualified circuit between the offsite transmission network and the Unit 3 onsite Class IE AC electrical power distribution subsystem(s) needed to support the Unit 3 powered equipment required to be OPERABLE by LCO 3.6.4.3, "Standby Gas Treatment (SGT) System," and LCO 3.8.5, "DC Sources-Shutdown"; and

d. One DG capable of supplying one Unit 3 onsite Class 1E AC electrical power distribution subsystem needed to support the Unit 3 powered equipment required to be OPERABLE by:

1. LCO 3.6.4.3.

OR

2. LCO 3.8.5.

APPLICABILITY: MODES 4 and 5, During movement of irradiated fuel assemblies in the secondary containment.

PBAPS UNIT 2 3.8-20 Amendment No. 210

AC Sources - Shutdown 3.8.2 ACTIONS

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

LCO 3.0.3 is not applicable.

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

offsite circuits Enter applicable Condition inoperable. and Required Actions of LCO 3.8.8, with one or more required 4 kV emergency buses de-energized as a result of Condition A.

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

with no offsite power available inoperable.

A.2.1 Suspend CORE Immediately ALTERATIONS.

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

(continued)

PBAPS UNIT 2 3.8-21 Amendment No. 317

AC Sources - Shutdown 3.8.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.3 Initiate action to Immediately restore required offsite power ci rcui t(s) to OPERABLE status.

B. One required DG B.l Declare affected Immediately inoperable. required feature(s) with no DG available inoperable.

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

AND B.2.3 Initiate action to Immediately restore required DGs to OPERABLE status.

(continued)

PBAPS UNIT 2 3.8-22 Amendment No . 317

AC Sources - Shutdown 3.8.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Two or more required C.1 Suspend CORE Immediately DGs inoperable. ALTERATIONS.

AND C.2 Suspend movement of Immediately irradiated fuel assemblies in secondary containment.

AND C. 3 Initiate action to Immediately restore required OG(s) to OPERABLE status.

PBAPS UNIT 2 3.8-23 Amendment No. 317

AC Sources -Shutdown 3.8.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.2.1 -------------------NOTE--------------------

The following SRs are not required to be performed: SR 3.8.1.3,--SR 3.8.1.9 through SR 3.8.1.11, SR 3.8.1.13 through SR 3.8.1.16, SR 3.8.1.18, and SR 3.8.1.19.

---NOTE ---------------- __

The requirements of SR 3.8.1.12, SR 3.8.1.13, and SR 3.8.1.19 are not required to be met during periods that ECCS are not required.

For required Unit 2 AC sources the SRs of In accordance Specification 3.8.1, except SR 3.8.1.8, with applicable SR 3.8.1.17, and SR 3.8.1.20, are SRs applicable.

SR 3.8.2.2 -------------------NOTE--------------------

When Unit 3 is not in MODE 1, 2, or 3, the Note to Unit 3 SR 3.8.2.1 is applicable.

For required Unit 3 AC sources, the SRs of In accordance Unit 3 Specification 3.8.1, except with applicable SR 3.8.1.8 (when only one Unit 3 offsite SRs circuit is required), SR 3.8.1.12, SR 3.8.1.13, SR 3.8.1.17, SR 3.8.1.18 (ECCS load block requirement only), SR 3.8.1.19, and SR 3.8.1.20, are applicable.

PBAPS UNIT 2 3.8-24 Amendment No.221 OCT 2 : 1997

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 3.8 ELECTRICAL POWER SYSTEMS 3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air LCO 3.8.3 The stored diesel fuel oil, lube oil, and starting air subsystem shall be within limits for each required diesel generator (DG).

APPLICABILITY: When associated DG is required to be OPERABLE.

ACTIONS

- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NOTE Separate Condition entry is allowed for each DG.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more DGs with A.l Restore fuel oil 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months fuel 0 i l level level to within

< 33,000 gal and limits.

> 29,500 gal in storage tank.

B. One or more DGs with B.l Restore lube oil 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months lube oil inventory inventory to within less than a 7 day limits.

supply and greater than a 6 day supply.

c. One or more DGs with C.l Restore fuel 0 i l 7 days stored fuel oil total total particulates to particulates not within limit.

within limit.

(continued)

PBAPS UN IT 2 3.8-25 Amendment No. 310

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 ACTIONS (continued) .

CONDITION REQUIRED ACTION COMPLETION TIME D. One or more DGs with D.1 Restore stored fuel 30 days new fuel oil oil properties to properties not within within limits.

limits.

E. One or more DGs with E.1 Restore required 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months required starting air starting air receiver receiver pressure pressure to

< 225 psig and ; 225 psig.

2 150 psig.

F. Required Action and F.1 Declare associated DG Immediately associated Completion inoperable.

Time of Condition A, B, C, D, or E not met.

OR One or more DGs with diesel fuel oil, lube oil, or starting air subsystem not within limits for reasons other than Condition A, B, C, D, or E.

PBAPS UNIT 2 3.8-26 Amendment No. 210

DC Sources-Operating 3.8.4 3.8 ELECTRICAL POWER SYSTEMS 3.8.4 DC Sources-Operating LCO 3.8.4 The following DC electrical power subsystems shall be OPERABLE:

a. Unit 2 Division I and Division II DC electrical power subsystems; and

b. Unit 3 Division I and Division II DC electrical power subsystems.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One Unit 3 DC - - - - - - - - - - - - -NOTE- - - - - - - - - - - -

electrical power Enter applicable Conditions subsystem inoperable and Required Actions of LCO due to performance of 3.8.7, "Distribution SR 3.8.4.7 or Systems-Operating," when SR 3.8.6.6. Condition A results in de-energization of a Unit 2 4 kV emergency bus or de-energization of a Unit 3 DC bus.

A.l Restore Unit 3 DC 7 days electrical power subsystem to OPERABLE status.

(continued)

PBAPS UNIT 2 3.8-28 Amendment No.~. 3 20

DC Sources-Operating 3.8.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One required Unit 3 B.1 Restore Unit 3 battery 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months battery charger on one terminal voltage to subsystem inoperable. greater than or equal to the minimum established float voltage.

AND B.2 Verify battery float 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months current~ 2 amps.

Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter AND B.3 Restore battery charger 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months to OPERABLE status.

(continued)

PBAPS UN IT 2 3.8-28a Amendment No. 329

DC Sources-Operating 3.8.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One Unit 3 DC - - - - - - - - - - - - - NOTE - - - - - - - - - - - -

electrical power Enter applicable Conditions subsystem inoperable and Required Actions of LCO for reasons other than 3.8.7, "Distribution Condition A or B. Systems-Operating," when Condition C results in de-energization of a Unit 2 4 kV emergency bus.

C.1 Restore Unit 3 DC 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months electrical power subsystem to OPERABLE status.

D. One Unit 2 battery D.l Restore Unit 2 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months charger on one battery terminal subsystem inoperable. voltage to greater than or equal to the m1n1mum established fl oat voltage.

D.2 Verify battery float Once per 12 currents 2 amps. hours D.3 Restore battery 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months charger to OPERABLE status.

(continued)

PBAPS UN IT 2 3.8-29 Amendment No. 329

DC Sources-Operating 3.8.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. One Unit 2 DC E. 1 Restore Unit 2 DC 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months electrical power electrical power subsystem inoperable subsystem to OPERABLE for reasons other than status.

Condition D.

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

F.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months G. Two or more inoperable G.l Enter LCO 3.0.3. Immediately DC electrical power subsystems.

PBAPS UN IT 2 3.8-29a Amendment No. 329

DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS

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

SR 3.8.4.1 through SR 3.8.4.8 are applicable only to the Unit 2 DC electrical power subsystems. SR 3.8.4.9 is applicable only to the Unit 3 DC electrical power subsystems.

SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify battery terminal voltage is greater In accordance than or equal to the minimum established with the float voltage. Surveillance Frequency Control Program.

SR 3.8.4.2 DELETED SR 3.8.4.3 DELETED (continued)

PBAPS UN IT 2 3.8-30 Amendment No.~' 3 20

DC Sources -Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.4.4 DELETED SR 3.8.4.5 DELETED SR 3.8.4.6 Verify each required battery charger In accordance supplies~ 200 amps at greater than or with the equal to the minimum established float Surveillance voltage for~ 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . Frequency Control Program.

Verify each battery charger can recharge the battery to the fully charged state within 20 hours2.314815e-4 days 0.00556 hours 3.306878e-5 weeks 7.61e-6 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.

(continued)

PBAPS UN IT 2 3.8-31 Amendment No.~. 320

DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.4.7 - * - - * - * - - - - - - - - - - * -NOT ES - - - - - - - - - - - - - - * * - - -

1. The modified performance discharge test in SR 3.8.6.6 may be performed in lieu of SR 3.8.4.7.

2. This Surveillance shall not be performed in MODE 1, 2, or 3.

However, credit may be taken for unplanned events that satisfy this SR.

Verify battery capacity is adequate to In accordance supply, and maintain in OPERABLE status, with the the required emergency loads for the design Surveillance duty cycle when subjected to a battery Frequency service test. Control Program.

(continued)

PBAPS UN IT 2 3.8 31a Amendment No. 32D

DC Sources - Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.4.8 DELETED (continued)

PBAPS UNIT 2 3.8-32 Amendment No.~, 320

DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY 4.

SR 3.8.4.9 - ------------- NOTE--------------------

When Unit 3 is in MODE 4 or 5, or moving irradiated fuel assemblies in the secondary containment, the Note to Unit 3 SR 3.8.5.1 is applicable.

For required Unit 3 DC electrical power In accordance subsystems, the SRs of Unit 3 Specification with applicable 3.8.4 are applicable. SRs PBAPS UNIT 2 3.8-33 Amendment No. 210

DC Sources- Shutdown 3.8.5 3.8 ELECTRICAL POWER SYSTEMS 3.8.5 DC Sources-Shutdown LCO 3.8.5 The following DC electrical power subsystems shall be OPERABLE:

a. Unit 2 DC electrical power subsystems needed to support the DC electrical power distribution subsystem(s) required by LCO 3.8.8, "Distribution Systems-Shutdown";

and

b. Unit 3 DC electrical power subsystems needed to support the DC electrical power distribution subsystem(s) required by LCO 3.8.8, "Distribution Systems-Shutdown."

APPLICABILITY: MODES 4 and 5, During movement of irradiated fuel assemblies in the secondary containment.

ACTIONS

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

LCO 3.0.3 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One battery charger on A.l Restore battery 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months one subsystem terminal voltage to inoperable. greater than or equal to the minimum established float voltage.

The redundant subsystem battery and .81iQ chargers OPERABLE.

A.2 Verify battery float Once per 12 current~ 2 amps. hours A.3 Restore battery 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months charger to OPERABLE status.

(continued)

PBAPS UN IT 2 3.8-34 Amendment No.~. 3 20

DC Sources- Shutdown 3.8.5 ACTIONS (continued)

CONDITION REQUIRED ACT! ON COMPLETION TIME B. One or more required B.1 Declare affected Immediately DC electrical power required feature(s) subsystems inoperable inoperable.

for reasons other than Condition A. Q.R B.2.1 Suspend CORE Immediately AL TE RATIONS.

Required actions and associated completion time of Condition A B.2.2 Suspend movement of Immediately not met. irradiated fuel assemblies in the secondary containment.

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

PBAPS UNIT 2 3.8-35 Amendment No.W, 320

DC Sources - Shutdown 3.8.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.5.1 - - - - - - - - - - - - - - - - - - - NOTE- - - - - - - - - - - - - - - - - - - -

The following SRs are not required to be performed: SR 3.8.4.6 and SR 3.8.4.7.

For required Unit 2 DC electrical power In accordance subsystems, the following SRs are with applicable applicable: SRs SR 3.8.4.1 SR 3.8.4.6 SR 3.8.4.7 SR 3.8.5.2 - - - - - - - - - - - - - - - - - - - NOTE - - - - - - - - - - - - - - - - - - - -

When Unit 3 is in MODE 4 or 5, or moving irradiated fuel assemblies in the secondary containment, the Note to Unit 3 SR 3.8.5.1 is applicable.

For required Unit 3 DC electrical power In accordance subsystems, the SRs of Unit 3 Specification with applicable 3.8.4 are applicable. SRs PBAPS UNIT 2 3.8-36 Amendment No. ~ . 3 20

Battery Parameters 3.8.6 3.8 ELECTRICAL POWER SYSTEMS 3.8.6 Battery Parameters LCO 3.8.6 Battery parameters for the station electrical power subsystem batteries shall be within limits.

APPLICABILITY: When associated DC electrical power subsystems are required to be OPERABLE.

ACTIONS

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

Separate Condition entry is allowed for each battery.

CONDIT ION REQUIRED ACTION COMPLETION TIME A. One battery on one A. 1 Perform SR 3.8.4.1 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months subsystem with one or more battery cells float voltage< 2.07.

A.2 Perform SR 3.8.6.l 2 hours A.3 Restore affected cell 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months float voltage~ 2.07 V.

(continued)

PBAPS UN IT 2 3.8-37 Amendment No. &-W, 32 0

Battery Parameters 3.8.6 ACTIONS (continued)

CONDITION REQUIRED ACT ION COMPLETION TIME B. One battery on one 8.1 Perform SR 3.8.4.1. 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months subsystem with float current> 2 amps.

B.2 Restore battery float 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months current to~ 2 amps.

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

Required Action C.2 Required Actions C.l and C.2 sha 11 be completed if are only applicable if electrolyte level was electrolyte level was below below the top of the top of plates.

plates.

C. One battery on one C.l Restore affected cell 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months subsystem with one or electrolyte level to more cells electrolyte above the top of plates.

level less than minimum established design limits.

C.2 Verify no evidence of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months leakage.

C.3 Restore electrolyte level 31 days to greater than or equal to minimum established design limits.

(continued)

PBAPS UN IT 2 3.8-38 Amendment No.~, 320

Battery Parameters 3.8.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One battery with 0.1 Restore battery pi 1ot 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months pilot cell electrolyte cell temperature to temperature less than greater than or equal minimum established to minimum design limits. established design limits.

E. One or more batteries E.1 Restore battery 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months in redundant parameters for subsystems with batteries in one battery parameters system to within not within limits. limits.

F. Required Action and F.1 Declare associated Immediately associated Completion battery inoperable.

Time of Condition A, B, C, D, or E not met.

One battery on one subsystem with one or more battery cells with float voltage

< 2.07 V and float current> 2 amps.

PBAPS UNIT 2 3.8-38a Amendment No. 3 2 0

Battery Parameters 3.8.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 - - - - - - - - - - - - - - - - - - NOTE - - - - - - - - - - - - - - - - - - - -

Not required to be met when battery terminal voltage is less than the minimum established float voltage of SR 3.8.4.1.

Verify each battery float current is s 2 amps. In accordance with the Surveillance Frequency Control Program.

SR 3.8.6.2 Verify each battery pilot cell float In accordance voltage is~ 2.07. with the Surveillance Frequency Control Program.

SR 3.8.6.3 Verify each battery connected cell In accordance electrolyte level is greater than or equal with the to minimum established design limits. Surveillance Frequency Control Program.

(continued)

PBAPS UNIT 2 3.8-39 Amendment No. ~ , 320

Battery Parameters 3.8.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.6.4 Verify each battery pilot cell temperature In accordance is is greater than or equal to minimum with the established design limits. Surveillance Frequency Control Program.

SR 3.8.6.5 Verify each battery cell float voltage is In accordance 2: 2.07 V. with the Surveillance Frequency Control Program.

SR 3.8.6.6 - - - - - - - - - - - - - - - - - -NOTE- - - - - - - - - - - - - - - - - - - -

This Surveillance shall not be performed in MODE 1, 2, or 3. However, credit may be taken for unplanned events that satisfy this SR.

Verify battery capacity is 2: 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 the expected life with capacity< 100%

of manufacturer's rating 24 months when battery has reached 85% of the expected life with capacity 2: 100%

of manufacturer's rating PBAPS UN IT 2 3.8-39a Amendment No. 3 20

Battery Parameters 3.8.6 The information on this page has been deleted.

Intentionally left blank.

PBAPS UNIT 2 3.8-40 Amendment No. 2-+/--G, 320

Di st ri but i on Systems - Ope rat i ng 3.8.7 3.8 ELECTRICAL POWER SYSTEMS 3.8.7 Di st ri but i on Systems - Operat i ng LCD 3.8.7 The following AC and DC electrical power distribution sUbsystems shall be OPERABLE:

a. Unit 2 Division I and Division II AC and DC electrical power distribution subsystems; and

b. Unit 3 AC and DC electrical power distribution subsystems needed to support equipment required to be OPERABLE by LCD 3.4.7, "Residual Heat Removal (RHR) Shutdown Cooling System-Hot Shutdown," LCD 3.5.1, "ECCS-Operating," LCD 3.6.2.3, "RHR Suppression Pool Cooling," LCD 3.6.2.4, "RHR Suppression Pool Spray," LCD 3.6.4.3, "Standby Gas Treatment (SGT) System," LCD 3.7.1, "High Pressure Service Water (HPSW) System," LCD 3.7.2, "Emergency Service Water (ESW) System and Normal Heat Sink," LCD 3.7.3, "Emergency Heat Sink," and LCD 3.8.1, "AC Sources - Operati ng. "

APPLICABI LITY: MODES 1, 2, and 3.

PBAPS UNIT 2 3.8-41 Amendment No. 274

Distribution Systems-Operating 3.8.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required - - - - - - - - - - - - - NOTE - - - - - - - - - - -

Unit 3 AC electrical Enter applicable Conditions power distribution and Required Actions of LCO subsystems inoperable. 3.8.4, "DC Sou rces Ope rat i ng ," when Condition A results in a de-energization of a required Unit 3 125 V battery charger.

A.1 Restore required 7 days Unit 3 AC electrical power distribution subsystem(s) to OPERABLE status.

B. One required Unit 3 DC B.1 Restore Unit 3 DC 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months electrical power electrical power distribution subsystem distribution inoperable. subsystem to OPERABLE status.

C. One Unit 2 AC C.l Restore Unit 2 AC 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months electrical power electrical power distribution subsystem distribution inoperable. subsystem to OPERABLE status.

(continued)

PBAPS UNIT 2 3.8-42 Amendment No. 277

Di stri buti on Systems - Shutdown 3.8.8 3.8 ELECTRICAL POWER SYSTEMS

3. 8. 8 Di stri buti on Systems - Shutdown LCO 3.8.8 The necessary portions of the following AC and DC electrical power distribution subsystems shall be OPERABLE:

a. Unit 2 AC and DC electrical power distribution subsystems needed to support equipment required to be OPERABLE; and

b. Unit 3 AC and DC electrical power distribution subsystems needed to support equipment required to be OPERABLE by LCO 3.4.8, "Residual Heat Removal (RHR)

Shutdown Coo 1i ng System - Co 1d Shutdown," LCO 3. 5. 4, "RPV Water Inventory Control," LCO 3.6.4.3, "Standby Gas Treatment (SGT) System," LCO 3.8.2, "AC Sources-Shutdown," LCO 3.9.7, "RHR-High Water level," and LCO 3.9.8, "RHR-low Water level."

APPLICABILITY: MODES 4 and 5, During movement of irradiated fuel assemblies in the secondary containment.

ACTIONS

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

LCO 3.0.3 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.l Declare associated Immediately AC or DC electrical supported required power distribution feature(s) subsystems inoperable. inoperable.

QB A.2.1 Suspend CORE Immediately ALTERATIONS.

(continued)

PBAPS UNIT 2 3.8-44 Amendment No. 317

Distribution Systems-Shutdown 3.8.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ( continued) A.2.2 Suspend handling of Immediately irradiated fuel assemblies in the secondary containment.

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

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

PBAPS UNIT 2 3, 8-45 Amendment No. 317

Refueling Equipment Interlocks 3.9.1 3.9 REFUELING OPERATIONS 3.9.1 Refueling Equipment Interlocks LCO 3.9.1 The refueling equipment interlocks shall be OPERABLE.

APPLICABILITY: During in-vessel fuel movement with equipment associated with the interlocks.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Suspend in-vessel Immediately refueling equipment fuel movement with interlocks inoperable. equipment associated with the inoperable interlock(s).

PBAPS UNIT 2 3.9-1 Amendment No. 210

Control Rod Position Indication 3.9.4 3.9 REFUELING OPERATIONS 3.9.4 Control Rod Position Indication LCO 3.9.4 The control rod 'full-in' position indication for each control rod shall be OPERABLE.

APPLICABILITY: MODE 5.

ACTIONS

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

Separate Condition entry is allowed for each required position indication.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1.l Suspend in-vessel Immediately control rod position fuel movement.

indications inoperable. AND A.1.2 Suspend control rod Immediately withdrawal.

AND A.1.3 Initiate action to Immediately fully insert all insertable control rods in core cells containing one or more fuel assemblies.

OR (continued)

PBAPS UNIT 2 3.9-6 Amendment No. 210

Control Rod Position Indication 3.9.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.1 Initiate action to Immediately fully insert the control rod associated with the inoperable position indicator.

AND A.2.2 Initiate action to Immediately disarm the control rod drive associated with the fully inserted control rod.

SURVEILLANCE REQUIREMENT SURVEILLANCE FREQUENCY SR 3.9.4.1 Verify the required position indication has Each time the no 'full-in" indication on each control rod control rod is that is not 'full-in." withdrawn from the "full-in" position PBAPS UNIT 2 3.9-7 Amendment No. 210

RHR-High Water Level 3.9.7 3.9 REFUELING OPERATIONS 3.9.7 Residual Heat Removal (RHR) -High Water Level LCO 3.9.7 One RHR shutdown cooling subsystem shall be OPERABLE and in operation.

_ __ ------------ NOTE----------------------------

The required RHR shutdown cooling subsystem may be removed from operation for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period.

APPLICABILITY: MODE 5 with irradiated fuel in the reactor pressure vessel (RPV) and the water level 2 458 inches above RPV instrument zero.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required RHR shutdown A.1 Verify an alternate I hour cooling subsystem method of decay heat inoperable. removal is available. AND Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter B. Required Action and B.1 Suspend loading Immediately associated Completion irradiated fuel Time of Condition A assemblies into the not met. RPV.

AND B.2 Initiate action to Immediately restore secondary containment to OPERABLE status.

AND (continued)

PBAPS UNIT 2 3.9-10 Amendment No. 210

RHR-High Water Level 3.9.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.3 Initiate action to Immediately restore one standby gas treatment subsystem for Unit 2 to OPERABLE status.

B.4 Initiate action to Immediately restore isolation capability in each required secondary containment penetration flow path not isolated.

C. No RHR shutdown C.1 Verify reactor I hour from cooling subsystem in coolant circulation discovery of no operation. by an alternate reactor coolant method. circulation AND Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter C.2 Monitor reactor Once per hour coolant temperature.

PBAPS UNIT 2 3 .9-11 Amendment No. 210

RHR- High Water Level 3.9.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify one RHR shutdown cooling subsystem In accordance is operating. with the Surveillance Frequency Control Program.

SR 3.9.7.2 - - - - - - - - - - - - - - - - - - NOTE- - - - - - - - - - - - - - - - - - -

HPSW system related components are excluded.

Verify required RHR shutdown cooling In accordance subsystem locations susceptible to gas with the accumulation are sufficiently filled with Surveillance water. Frequency Control Program.

PBAPS UN IT 2 3.9-12 Amendment No. 297

RHR-Low Water Level 3.9.8 3.9 REFUELING OPERATIONS 3.9.8 Residual Heat Removal (RHR)-Low Water Level LCO 3.9.8 Two RHR shutdown cooling subsystems shall be OPERABLE, and one RHR shutdown cooling subsystem shall be in operation.

_ _------------ NOTE----------------------------

The required operating shutdown cooling subsystem may be removed from operation for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period.

APPLICABILITY: MODE 5 with irradiated fuel in the reactor pressure vessel (RPV) and the water level < 458 inches above RPV instrument zero.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or two required A.1 Verify an alternate 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months RHR shutdown cooling method of decay heat subsystems inoperable. removal is available AND for each inoperable required RHR shutdown Once per cooling subsystem. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter B. Required Action and B.1 Initiate action to Immediately associated Completion restore secondary Time of Condition A containment to not met. OPERABLE status.

AND (continued)

PBAPS UNIT 2 3.9-13 Amendment No. 210

RHR-Low Water Level 3.9.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2 Initiate action to Immediately restore one standby gas treatment subsystem for Unit 2 to OPERABLE status.

B.3 Initiate action to Immediately restore isolation capability in each required secondary containment penetration flow path not isolated.

C. No RHR shutdown C.1 Verify reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from cooling subsystem in coolant circulation discovery of no operation. by an alternate reactor coolant method. circulation AND Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter AND C.2 Monitor reactor Once per hour coolant temperature.

PBAPS UNIT 2 3.9-14 Amendment No. 210

RHR- Low Water Level 3.9.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.8.1 Verify one RHR shutdown cooling subsystem In accordance is operating. with the Surveillance Frequency Control Program.

SR 3.9.8.2 - - - - - - - - - - - - - - - - - - NOTE- - - - - - - - - - - - - - - - - - -

HPSW system related components are excluded.

Verify required RHR shutdown cooling In accordance subsystem locations susceptible to gas with the accumulation are sufficiently filled with Surveillance water. Frequency Control Program.

PBAPS UN IT 2 3.9-15 Amendment No. 297

Inservice Leak and Hydrostatic Testing Operation 3.10.1 3.10 SPECIAL OPERATIONS 3.10.1 Inservice Leak and Hydrostatic Testing Operation LCO 3.10.1 The average reactor coolant temperature specified in Table 1.1-1 for MODE 4 may be changed to "NA," and operation considered not to be in MODE 3; and the requirements of LCO 3.4.8, "Residual Heat Removal (RHR) Shutdown Cooling System-Cold Shutdown," may be suspended to all ow reactor coolant temperature> 212°F:

For performance of an inservice leak or hydrostatic test, As a consequence of maintaining adequate pressure for an inservice leak or hydrostatic test, or As a consequence of maintaining adequate pressure for control rod scram time testing initiated in conjunction with an inservice leak or hydrostatic test, provided the following MODE 3 LCOs are met:

a. LCO 3.3.6.2, "Secondary Containment Isolation Instrumentation," Functions 1, 3, and 4 of Table 3.3.6.2-1;

b. LCO 3.6.4.1, "Secondary Containment";

c. LCO 3.6.4.2, "Secondary Containment Isolation Valves (SCIVs)"; and

d. LCO 3.6.4.3, "Standby Gas Treatment (SGT) System."

APPLICABILITY: MODE 4 with average reactor coolant temperature> 212°F.

PBAPS UN IT 2 3.10-1 Amendment No. 307

Inservice Leak and Hydrostatic Testing Operation 3.10.1 ACTIONS

_- NOTE-------------------------------------

Separate Condition entry is allowed for each requirement of the LCO.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 -------- NOTE---------

above requirements not Required Actions to met. be in MODE 4 include reducing average reactor coolant temperature to s 212F.

Enter the applicable Immediately Condition of the affected LCO.

OR A.2.1 Suspend activities Immediately that could increase the average reactor coolant temperature or pressure.

AND A.2.2 Reduce average 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months reactor coolant temperature to s 212VF.

PBAPS UNIT 2 3.10-2 Amendment No. 210

Inservice Leak and Hydrostatic Testing Operation 3.10.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.1.1 Perform the applicable SRs for the required According to MODE 3 LCOs. the applicable SRs PBAPS UNIT 2 3.10-3 Amendment No. 210

Reactor Mode Switch Interlock Testing 3.10.2 3.10 SPECIAL OPERATIONS 3.10.2 Reactor Mode Switch Interlock Testing LCO 3.10.2 The reactor mode switch position specified in Table 1.1-1 for MODES 3, 4, and 5 may be changed to include the run, startup/hot standby, and refuel position, and operation considered not to be in MODE 1 or 2, to allow testing of instrumentation associated with the reactor mode switch interlock functions, provided:

a. All control rods remain fully inserted in core cells containing one or more fuel assemblies; and

b. No CORE ALTERATIONS are in progress.

APPLICABILITY: MODES 3 and 4 with the reactor mode switch in the run, startup/hot standby, or refuel position, MODE 5 with the reactor mode switch in the run or startup/hot standby position.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 Suspend CORE Immediately above requirements not ALTERATIONS except met. for control rod insertion.

AND A.2 Fully insert all 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months insertable control rods in core cells containing one or more fuel assemblies.

AND (continued)

PBAPS UNIT 2 3.10-4 Amendment No. 210

Single Control Rod Withdrawal-Hot Shutdown 3.10.3 3.10 SPECIAL OPERATIONS 3.10.3 Single Control Rod Withdrawal -Hot Shutdown LCO 3.10.3 The reactor mode switch position specified in Table 1.1-1 for MODE 3 may be changed to include the refuel position, and operation considered not to be in MODE 2, to allow withdrawal of a single control rod, provided the following requirements are met:

a. LCO 3.9.2, "Refuel Position One-Rod-Out Interlock";

b. LCO 3.9.4, "Control Rod Position Indication";

c. All other control rods are fully inserted; and

d. 1. LCO 3.3.1.1, "Reactor Protection System (RPS)

Instrumentation," MODE 5 requirements for Functions 1.a, 1.b, 7, 12, 13, and 14 of Table 3.3.1.1-1, and LCO 3.9.5, "Control Rod OPERABILITY-Refueling,"

OR

2. All other control rods in a five by five array centered on the control rod being withdrawn are disarmed, at which time LCO 3.1.1, "SHUTDOWN MARGIN (SDM)," MODE 3 requirements, may be changed to allow the single control rod to be withdrawn to be assumed the highest worth control rod.

APPLICABILITY: MODE 3 with the reactor mode switch in the refuel position.

PBAPS UNIT 2 3.10-6 Amendment No. 210

Single Control Rod Withdrawal -Hot Shutdown 3.10.3 ACTIONS

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

Separate Condition entry is allowed for each requirement of the LCO.

CONDITION REQUIRED ACTION I COMPLETION TIME A. One or more of the A.I --------NOTES--------

above requirements not 1. Required Actions met. to fully insert all insertable control rods include placing the reactor mode switch in the shutdown position.

2. Only applicable if the requirement not met is a required LCO.

Enter the applicable Immediately Condition of the affected LCO.

OR A.2.1 Initiate action to Immediately fully insert all insertable control rods.

AND A.2.2 Place the reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months mode switch in the shutdown position.

PBAPS UNIT 2 3.10-7 Amendment No. 210

Single Control Rod Withdrawal -Cold Shutdown 3.10.4 3.10 SPECIAL OPERATIONS 3.10.4 Single Control Rod Withdrawal -Cold Shutdown LCO 3.10.4 The reactor mode switch position specified in Table 1.1-1 for MODE 4 may be changed to include the refuel position, and operation considered not to be in MODE 2, to allow withdrawal of a single control rod, and subsequent removal of the associated control rod drive (CRD) if desired, provided the following requirements are met:

a. All other control rods are fully inserted;

b. 1. LCO 3.9.2, Refuel Position One-Rod-Out Interlock,"

and LCO 3.9.4, "Control Rod Position Indication,"

OR

2. A control rod withdrawal block is inserted;

c. 1. LCO 3.3.1.1, "Reactor Protection System (RPS)

Instrumentation," MODE 5 requirements for Functions 1.a, 1.b, 7, 12, 13, and 14 of Table 3.3.1.1-1, and LCO 3.9.5, "Control Rod OPERABILITY-Refueling,"

OR

2. All other control rods in a five by five array centered on the control rod being withdrawn are disarmed, at which time LCO 3.1.1, "SHUTDOWN MARGIN (SDM)," MODE 4 requirements, may be changed to allow the single control rod to be withdrawn to be assumed the highest worth control rod.

APPLICABILITY: MODE 4 with the reactor mode switch in the refuel position.

PBAPS UNIT 2 3.10-9 Amendment No. 210

Single Control Rod Withdrawal -Cold Shutdown 3.10.4 ACTIONS

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

Separate Condition entry is allowed for each requirement of the LCO.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 -------- NOTES--------

above requirements not 1. Required Actions met with the affected to fully insert control rod all insertable insertable. control rods include placing the reactor mode switch in the shutdown-position.

2. Only applicable if the requirement not met is a required LCO.

Enter the applicable Immediately Condition of the affected LCO.

OR A.2.1 Initiate action to Immediately fully insert all insertable control rods.

AND A.2.2 Place the reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months mode switch in the shutdown position.

(continued)

PBAPS UNIT 2 3. 10-10 Amendment No. 210

Single CRD Removal -Refueling 3.10.5 3.10 SPECIAL OPERATIONS 3.10.5 Single Control Rod Drive (CRD) Removal -Refueling LCO 3.10.5 The requirements of LCO 3.3.1.1, "Reactor Protection System (RPS) Instrumentation'; LCO 3.3.8.2, "Reactor Protection System (RPS) Electric Power Monitoring"; LCO 3.9.1, "Refueling Equipment Interlocks"; LCO 3.9.2, "Refuel Position One Rod Out Interlock"; LCO 3.9.4, "Control Rod Position Indication"; and LCO 3.9.5, "Control Rod OPERABILITY-Refueling," may be suspended in MODE 5 to allow the removal of a single CRD associated with a control rod withdrawn from a core cell containing one or more fuel assemblies, provided the following requirements are met:

a. All other control rods are fully inserted;

b. All other control rods in a five by five array centered on the withdrawn control rod are disarmed;

c. A control rod withdrawal block is inserted and LCO 3.1.1, "SHUTDOWN MARGIN (SDM)," MODE 5 requirements, may be changed to allow the single control rod withdrawn to be assumed to be the highest worth control rod; and

d. No other CORE ALTERATIONS are in progress.

APPLICABILITY: MODE 5 with LCO 3.9.5 not met.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 Suspend removal of Immediately above requirements not the CRD mechanism.

met.

AND (continued)

PBAPS UNIT 2 3.10-13 Amendment No. 210

Multiple Control Rod Withdrawal -Refueling 3.10.6 3.10 SPECIAL OPERATIONS 3.10.6 Multiple Control Rod Withdrawal -Refueling LCO 3.10.6 The requirements of LCO 3.9.3, "Control Rod Position";

LCO 3.9.4, "Control Rod Position Indication"; and LCO 3.9.5,

'Control Rod OPERABILITY-Refueling," may be suspended, and the "full in" position indicators may be bypassed for any number of control rods in MODE 5, to allow withdrawal of these control rods, removal of associated control rod drives (CRDs), or both, provided the following requirements are met:

a. The four fuel assemblies are removed from the core cells associated with each control rod or CRD to be removed;

b. All other control rods in core cells containing one or more fuel assemblies are fully inserted; and

c. Fuel assemblies shall only be loaded in compliance with an approved spiral reload sequence.

APPLICABILITY: MODE 5 with LCO 3.9.3, LCO 3.9.4, or LCO 3.9.5 not met.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 Suspend withdrawal of Immediately above requirements not control rods and met. removal of associated CRDs.

AND A.2 Suspend loading fuel Immediately assemblies.

(continued)

PBAPS UNIT 2 . 3.10-16 Amendment No. 210

Control Rod Testing-Operating 3.10.7 3.10 SPECIAL OPERATIONS 3.10.7 Control Rod Testing-Operating LCO 3.10.7 The requirements of LCO 3.1.6, "Rod Pattern Control," may be suspended to allow performance of SDM demonstrations, control rod scram time testing, control rod friction testing, and the Startup Test Program, provided:

a. The analyzed rod position sequence requirements of SR 3.3.2.1.8 are changed to require the control rod sequence to conform to the specified test sequence.

OR

b. The RWM is bypassed; the requirements of LCO 3.3.2.1, "Control Rod Block Instrumentation," Function 2 are suspended; and conformance to the approved control rod sequence for the specified test is verified by a second licensed operator or other qualified member of the technical staff.

APPLICABILITY: MODES 1 and 2 with LCO 3.1.6 not met.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the A.1 Suspend performance Immediately LC....

Onotmet. of the test and exception to LCO 3.1.6.

PBAPS UNIT 2 3.10-18 Amendment No. 260

Control Rod Testing-Operating 3.10.7 SURVEILLANCE REOUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.7.1 --------------- NOTE--------------------

Not required to be met if SR 3.10.7.2 satisfied.

Verify movement of control rods is in During control compliance with the approved control rod rod movement sequence for the specified test by a second licensed operator or other qualified member of the technical staff.

SR 3.10.7.2 ------------------ NOTE--------------------

Not required to be met if SR 3.10.7.1 satisfied.

Verify control rod sequence input to the Prior to RWM is in conformance with the approved control rod control rod sequence for the specified movement test.

PBAPS UNIT 2 3. 10-19 Amendment No. 210

SDM Test-Refueling 3.10.8 3.10 SPECIAL OPERATIONS 3.10.8 SHUTDOWN MARGIN (SDM) Test-Refueling LCO 3.10.8 The reactor mode switch position specified in Table 1.1-1 for MODE 5 may be changed to include the startup/hot standby position, and operation considered not to be in MODE 2, to allow SDM testing, provided the following requirements are met:

a. LCO 3.3.1.1, "Reactor Protection System Instrumentation," MODE 2 requirements for Functions 2.a, 2.d and 2.e of Table 3.3.1.1-1;

b. 1. LCO 3.3.2.1, "Control Rod Block Instrumentation,"

MODE 2 requirements for Function 2 of Table 3.3.2.1-1, with the analyzed rod position sequence requirements of SR 3.3.2.1.8 changed to require the control rod sequence to conform to the SDM test sequence.,

OR

2. Conformance to the approved control rod sequence for the SDM test is verified by a second licensed operator or other qualified member of the technical staff;

c. Each withdrawn control rod shall be coupled to the associated CRD;

d. All control rod withdrawals during out of sequence control rod moves shall be made in notch out mode;

e. No other CORE ALTERATIONS are in progress; and

f. CRD charging water header pressure _ 940 psig.

APPLICABILITY: MODE 5 with the reactor mode switch in startup/hot standby position.

PBAPS UNIT 2 3.10-20 Amendment No. 260

SDM Test-Refueling 3.10.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. --------NOTE--------- A.1 -------- NOTE---------

Separate Condition Rod worth minimizer entry is allowed for may be bypassed as each control rod. allowed by LCO 3.3.2.1, 'Control Rod Block One or more control Instrumentation," if rods not coupled to required, to allow its associated CRD. insertion of inoperable control rod and continued operation.

Fully insert 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months inoperable control rod.

AND A.2 Disarm the associated 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months CRD.

B. One or more of the B.1 Place the reactor Immediately above requirements not mode switch in the met for reasons other shutdown or refuel than Condition A. position.

PBAPS UNIT 2 3.10-21 Amendment No. 210

Design Features 4.0 4.0 DESIGN FEATURES 4.1 Site 4.1.1 Site and Exclusion Area Boundaries The site and exclusion area boundaries shall be as shown in Figure 4.1-1.

4.1.2 Low Population Zone (LPZ)

The LPZ shall be a 7300 meter radius from the plant stack.

4.2 Reactor Core 4.2.1 Fuel Assemblies The reactor shall contain 764 fuel assemblies. Each assembly shall consist of a matrix of zircaloy or ZIRLO fuel rods with an initial composition of natural or slightly enriched uranium dioxide (UO ) as fuel material. Limited substitutions of zirconium alloy or stainless steel filler rods 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 NRC staff approved codes and methods and have been shown by tests or analyses to comply with all safety design bases. A limited number of lead test assemblies that have not completed representative testing may be placed in nonlimiting core regions.

4.2.2 Control Rod Assemblies The reactor core shall contain 185 cruciform shaped control rod assemblies. The control materials shall be boron carbide and hafnium metal as approved by the NRC.

(continued)

PBAPS UNIT 2 4.0-1 Amendment No. 210

Design Features 4.0 4.0 DESIGN FEATURES (continued) 4.3 Fuel Storage 4.3.1 Criticality 4.3.1.1 The spent fuel storage racks are designed and shall be maintained with:

a. Fuel assemblies having a maximum k infinity of 1.270 in the normal reactor core configuration at cold conditions;

b. keff $ 0.95 if fully flooded with unborated water, which includes an allowance for uncertainties as described in Section 10.3 of the UFSAR;

c. A nominal 6.280 inch center to center distance between fuel assemblies placed in the storage racks; and

d. The installed neutron absorbing rack inserts having a Boron-10 areal density;;:: 0.0102 g/cm2.

4.3.1.2 The new fuel storage racks shall not be used for fuel storage. The new fuel shall be stored in the spent fuel storage racks.

4.3.2 Drainage The spent fuel storage pool is designed and shall be maintained to prevent inadvertent draining of the pool below plant elevation 219 ft.

4.3.3 Capacity The spent fuel storage pool is designed and shall be maintained with a storage capacity limited to no more than 3819 fuel assemblies.

PBAPS UN IT 2 4.0-2 Amendment No. 287

Design Features 4.0 2700 FT.

-- RAO.

UNIT 1 / l'llAININO CENTER

~ ... \

I

\\

Figure 4.1-1 (page 1 of 1)

Site and Exclusion Area Boundaries PBAPS UN IT 2 4.0-3 Amendment No. 296

Responsibility 5.1 5.0 ADMINISTRATIVE CONTROLS 5.1 Responsibility 5.1.1 The plant manager shall be responsible for overall unit operation and shall delegate in writing the succession to this responsibility during his absence.

The plant manager or his designee shall approve, prior to implementation, each proposed test, experiment, or modification to systems or equipment that affect nuclear safety.

5.1.2 The Shift Supervisor shall be responsible for the control room command function. During any absence of the Shift Supervisor from the control room while the unit is in MODE 1, 2, or 3, 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 Shift Supervisor from the control room while the unit is in MODE 4 or 5, an individual with an active SRO license or Reactor Operator license shall be designated to assume the control room command function.

PBAPS UNIT 2 5 .0- 1 Amendment No. 259

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 ch.arts, functional descriptions of departmental responsibili-ties and relationships, and job descriptions for key personnel positions, or in equivalent forms of documentation. These requirements, including the generic titles of those personnel fulfilling the responsibilities of the positions delineated in these Technical Specifications, shall be documented in the QATR; .

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. The specified corporate officer shall have corporate responsibility for overall plant nuclear ýafety and shall take any measures needed to ensure acceptable performance of the staff. in operating, maintaining, and providing technical support to the plantto 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.

5.2.2 Unit Staff The unit staff organization shall also include the following:

(continued)

PBAPS UNIT 2 .O-2ý Amendment No.265

Organization 5.2 5.2 Organization 5.2.2 Unit Staff (continued)

a. A total of five non-licensed Operators shall be assigned for PBAPS Units 2 and 3 at all times.

b. Each on-duty shift crew composition may be less than the minimum requirements of 10 CFR 50.54(m)(2)(i) arid Specification 5.2.2.a and 5.2.2.f for a period of time not to exceed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months in order to 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. An individual qualified in radiation protection procedures shall be on site when fuel is in the reactor. The position may be vacant for not more than 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , in order to provide for unexpected absence, provided immediate action is taken to fill the required position.

d. DELETED (continued)

PBAPS UNIT 2 5.0-3 Amendment No. 2n

Organization 5,2 5.2 Organization 5.2.2 Unit Staff (continued)

e. The senior operations manager or an operations manager shall hold an SRO license.

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

PBAPS UNIT 2 5.0-4 Amendment No. 271

Unit Staff Qualifications 5.3 5.0 ADMINISTRATIVE CONTROLS 5.3 Unit Staff Qualifications 5.3.1 Each member of the unit staff shall meet or exceed the minimum qualifications referenced for comparable positions as specified in the Exelon Quality Assurance Topical Report.

PBAPS ur~IT 2 5.0-5 Amendment No. 319

Procedures 5.4 5.0 ADMINISTRATIVE CONTROLS 5.4 Procedures 5.4.1 Written procedures shall be established, implemented, and maintained covering the following activities:

a. The applicable procedures recommended in Regulatory Guide 1.33, Appendix A, November 1972;

b. The emergency operating procedures required to implement the requirements of NUREG-0737 and NUREG-0737, Supplement 1, as stated in Generic Letter 82-33;

c. Quality assurance for effluent and environmental monitoring;

d. Fire Protection Program implementation; and

e. All programs specified in Specification 5.5.

PBAPS UNIT 2 5.0-6 Amendment No. 210

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 ODCM shall also contain the radioactive effluent controls and radiological environmental monitoring activities, and descriptions of the information that should be included in the Annual Radiological Environmental Operating, and Radioactive Effluent Release reports required by Specification 5.6.2 and Specification 5.6.3.

c. Licensee initiated changes to the ODCM:

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

Sufficient information to support the change(s) together with the appropriate analyses or evaluations justifying the change(s), and 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 review and acceptance by the Plant Operations Review Committee and the approval of the plant manager; and (continued)

PBAPS UNIT 2 5.0- 7 Amendment No. 259

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1 Offsite Dose Calculation Manual (ODCM) (continued)

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 Radioactive Effluent Release 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.

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 Core Spray, High Pressure Coolant Injection, Residual Heat Removal, Reactor Core Isolation Cooling, and Reactor Water Cleanup. The program shall include the following:

a. Preventive maintenance and periodic visual inspection requirements; and

b. System leak test requirements for each system, to the extent permitted by system design and radiological conditions, at least once per 24 months. The provisions of SR 3.0.2 are applicable.

5.5.3 DELETED (continued)

PBAPS UNIT 2 5.0-8 Amendment No. 259

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.4 Radioactjy~ 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 t he program 1 imi [,S are exceeded. The program shall inc'ude 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 10 times the concentration values in Appendix S, 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 aDCM;

d. Limitations on the annual and quarterly doses or dose commitment to a member of the public from radioactive materials in liquid effluents released from each unit to unrestricted areas, conforming to 10 CFR 50, Appendix I;

e. Determination of cumulative dose contributions from radioactive effluents for the current calendar quarter and current calendar year in accordance with the methodology and parameters in the aDCM at least every 31 days. Determination of projected dose contributions from radioactive effluents in accordance with the methodology in the ODCM at least every 31 days;

f. Limitations on the functional capability and use of the liquid effluent treatment systems to ensure that appropriate portions of these systems are used to reduce releases of radioactivity when projected doses averaged over one month would exceed 0.12 mrem to the total body or 0.4 mrem to any organ (combined total from the two reactors at the site);

g. Limitations to ensure gaseous effluents shall be processed, prior to release, through the appropriate gaseous effluent treatment systems as described in the aDCM;

_______ (cont i nued)

PBAPS UI~ IT 2 5.0*9 Amendment No. 270

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

h. 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: less than or equal to a dose rate of 500 mrems/yr to the total body and less than or equal to a dose rate of 3000 mrems/yr to the skin, and

2. For iodine-131, iodine-133, tritium, and for all radionuclides in particulate form with half lives

> 8 days: less than or equal to a dose rate of 1500 mrems/yr to any organ;

i. Limitations on the annual and quarterly air doses resulting from noble gases released in gaseous effluents from each unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I;

j. 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 I; and

k. 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 3.0.3 are applicable to the Radioactive Effluent Controls Program surveillance frequency.

5.5.5 Component Cyclic or Transient Limit This program provides controls to track the UFSAR, Table 4.2.4, cyclic and transient occurrences to ensure that components are maintained within the design limits.

(continued)

PBAPS UNIT 2 5.0-10 Amendment No. 240 AUG s , 2,11

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.6 DELETED 5.5.7 Ventilation Filter Testing Program CVFTP)

The VFTP shall establish the required testing of Engineered Safety Feature (ESF) filter ventilation systems.

Tests described in Specifications 5.5.7.a, 5.5.7.b, and 5.5.7.c shall be performed:

(continued)

PBAPS UNIT 2 5.0-11 Amendment No. 313

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 Ventilation Filter Testing Program (VFTP) (continued)

1) Once per 12 months for standby service or after 720 hours0.00833 days 0.2 hours 0.00119 weeks 2.7396e-4 months of system operation; and,

2) After each complete or partial.replacement of the HEPA filter train or charcoal adsorber filter; after any structural maintenance on the system housing; and, following significant painting, fire, or chemical release in any ventilation zone communicating with the system while it is in operation.

Tests described in Specifications 5.5.7.d and 5.5.7.e shall be performed once per 24 months.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the YFTP test frequencies.

a. Demonstrate for each of the ESF systems that an inplace test of the HEPA filters shows a penetration and system bypass

< 1.0% when tested in accordance with Regulatory Guide 1.52, I Revision 2, Section 5c, and ASME N510-1989, Sections .6 (Standby Gas Treatment (SGT) System only) and 10, at the system flowrate specified below.

ESF Ventilation System FlograteL&ffl SGT System 7200 to 8800 Main Control Room Emergency 2700 to Ventilation (MCREV) System 3300 (continued)

PBAPS UNIT 2 5.0-12 Amendment No.Zl0, air,213 JAN 1 !; 1996

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 Ventilation Filter TestinQ Program (VFTP) (continued)

b. Demonstrate for each of the ESF systems that an inplace test of the charcoal adsorber shows a penetration and system bypass < 1.0% when tested in accordance with Regulatory Guide 1.52, Revision 2, Section 5d, and ASME N510-1989, Sections 6 (SGT System only) and 11, at the system flowrate specified below.

ESF Ventilation System Flowrate (cfm)

SGT System 7200 to 8800 MCREV System 2700 to 3300

c. Demonstrate for each of the ESF systems that a laboratory test of a sample of the charcoal adsorber, when obtained as described in Regulatory Guide 1.52, Revision 2, Section 6b, shows the methyl iodide penetration less than the value specified below when tested in accordance with the laboratory testing criteria of ASTM D3803-1989 at a temperature of 30 degrees C [86 degrees F], face velocity, and the relative humidity specified below.

ESF Ventilation System SGT System MCREV System Penetration 5 5

(%)

Face Velocity 60 57 (FPM)

Relative Humidity: 70 95 (X)

(continued)

PBAPS UNIT 2 5.0-13 Amendment No. A-P, 4'3, 237 IUOV C f 2A9n

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 Ventilation Filter Testing Program (VFTP) (continued)

d. Demonstrate for each of the ESF systems that the pressure drop across the combined HEPA filters, the prefilters (if installed), and the charcoal adsorbers is less than the value specified below when tested at the system flowrate specified below.

ESF Ventilation System Delta P (inches wg) Flowrate (cfm)

SGT System < 3.9 7200 to 8800 MCREV System <8 2700 to 3300

e. Demonstrate that the heaters for the SGT System dissipate 2 40 kw.

5.5.8 ExDlosive Gas Monitoring Program This program provides controls for potentially explosive gas mixtures contained downstream of the off-gas recombiners.

The program shall include:

a. The limit for the concentration of hydrogen downstream of the off-gas recombiners 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.

5.5.9 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:

(continued)

PBAPS UNIT 2 5.0-14 Amendment No. 210

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.9 Diesel Fuel Oil Testing Proaram (continued)

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. kinematic viscosity, when required, and a flash point within limits for ASTM 2-0 fuel oil, and

3. a clear and bright appearance with proper color or a water and sediment content within limits;

b. Within 31 days following 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 20 fuel oil; and

c. Total particulate concentration of the fuel oil is < 10 mg/l when tested every 31 days in accordance with ASTM D2276, Method A, except that the filters specified in the ASTM method may have a nominal pore size of up to three (3) microns.

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

5.5.10 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:

A change in the TS incorporated in the license; or A change to the UFSAR or Bases that requires NRC approval pursuant to 10 CFR 50.59.

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

(continued)

PBAPS UNIT 2 5.0 -15 Amendment No. 259

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.10 Technical Specifications (TS) Bases Control ProQram (continued)

d. Proposed changes that meet the criteria of b. above shall be reviewed and approved by the NRC prior to implementation.

Changes to the Bases implemented without prior NRC approval shall be provided to the NRC on a frequency consistent with 10 CFR 50.71(e).

5.5.11 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 limitations and remedial or compensatory actions may be identified to 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.

a. The SFDP shall contain the following:

1. Provisions for cross division checks to ensure a loss of the capability to perform the safety function assumed in the accident analysis does not go undetected;

2. Provisions for ensuring the plant is maintained in a safe condition if a loss of function condition exists;

3. Provisions to ensure that an inoperable supported system's Completion Time is not inappropriately extended as a result of multiple support system inoperabilities; and

4. Other appropriate limitations and remedial or compensatory actions.

b. A loss of safety function exists when, assuming no concurrent single failure, a safety function assumed in the accident analysis cannot be performed. For the purpose of this program, a loss of safety function may exist when a support system is inoperable, and:

(continued)

PBAPS UNIT 2 5.0-16 Amendment No. 210

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.11 Safety Function Determination Program (SFDP) (continued)

1. A required system redundant to system(s) supported by the inoperable support system is also inoperable; or

2. A required system redundant to system(s) in turn supported by the inoperable supported system is also inoperable; or

3. A required system redundant to support system(s) for the supported systems (b.l) and (b.2) above is also inoperable.

c. 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.

5.5.12 Primary Containment Leakage Rate Testing Program A program shall be established to implement the leakage rate testing of the containment as required by 10 CFR 50.54(0) and 10 CFR 50, Appendix J, Option B, as modified by approved exemptions.

This program shall be in accordance with the guidelines contained in NEI 94-01, "Industry Guideline for Implementing Performance-Based Option of 10 CFR Part 50, Appendix J," Revision 3-A, dated July 2012, and the conditions and limitations specified in NEI 94-01, Revision 2-A, dated October 2008, as modified by the following exception:

a. Section 10.2: MSIV leakage is excluded from the combined total of 0.6 L. for the Type B and C tests.

The peik calculated containment internal pressure for the design basis loss of coolant accident, P., is 49.l psig.

The maximum allowable primary containment leakage rate, L., at P.,

shall be 0.7% of primary containment air weight per day.

Leakage Rate acceptance criteria are:

a. Primary Containment leakage rate acceptance criterion is ~

1.0 L.. During the first unit startup following testing in accordance with this program, the leakage rate acceptance criteria are~ 0.60 La for the Type B and Type C tests and~

0.75 La for Type A tests; continued PBAPS UNIT 2 5.0-17 Amendment No. 302

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.12 Primary Containment Leakage Rate Testing Program (continued)

b. Air lock testing acceptance criteria are:

1) Overall air lock leakage rate is ~ 9000 scc/min when tested at ~ Pa.

c. MSIV leakage acceptance criteria are as specified in SR 3.6.1.3.14.

The provisions of SR 3.0.2 do not apply to the test frequencies specified in the Primary Containment Leakage Rate Testing Program.

The provisions of SR 3.0.3 are applicable to the Primary Containment Leakage Rate Testing Program.

5.5.13 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 Main Control Room Emergency Ventilation (MCREV) System, CRE occupants can control the reactor safely under normal conditions and maintain it in a safe condition following a radiological event, hazardous chemical release as applicable, or a smoke challenge. The program shall ensure that adequate radiation protection is provided to permit access and occupancy of the CRE under design basis accident (DBA) conditions without personnel receiving radiation exposures in excess of 5 rem total effective dose equivalent (TEDE) for the duration of the accident. The program shall include the following elements:

a. The definition of the CRE and the CRE boundary.

b. Requirements for maintaining the eRE boundary in its design condition including configuration control and preventative maintenance.

c. Requirements of (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 Section 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 Section C.1 and C.2 of Regulatory Guide 1.197, Revision O.

(continued)

PBAPS UNIT 2 5.0-18 Amendment No. 269

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.15 Battery Monitoring and Maintenance Program This Program provides controls for battery restoration and maintenance. The program shall be in accordance with IEEE Standard (Std) 450-2002, "IEEE Recommended Practice for Maintenance, Testing, and Replacement of Vented Lead-Acid Batteries for Stationary Applications," as endorsed by Regulatory Guide 1.129, Revision 2 (RG), with RG exceptions and program provisions as identified below:

a. The program allows the following RG 1.129, Revision 2 exceptions:

1. Battery temperature correction may be performed before or after conducting discharge tests.

2. RG 1.129, Regulatory Position 1, Subsection 2, "References," is not applicable to this program.

3. In lieu of RG 1.129, Regulatory Position 2, Subsection 5.2,"Inspections," the following shall be used: "Where reference is made to the pilot cell, pilot cell selection sha 11 be b'ased on the 1 owe st voltage eel l in the battery."

4. In Regulatory Guide 1.129, Regulatory Position 3, Subsection 5.4.l, "State of Charge Indicator," the following statements in paragraph (dl may be omitted:

"When it has been recorded that the charging current has stabilized at the charging voltage for three consecutive hourly measurements, the battery is near full charge. These measurements shall be made after the initially high charging current decreases sharply and the battery voltage rises to approach the charger output voltage."

5. In lieu of RG 1.129, Regulatory Position 7, Subsection 7.6,"Restoration," the following may be used: "Following the test, record the float voltage of each cell of the string."

b. The program shall include the following provisions:

PBAPS UNIT 2 5.0-lBb Amendment No. 320

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.15 Battery Monitoring and Maintenance Program (continued)

l. Actions to restore battery cells with float voltage

< 2.13 V;

2. Actions to determine whether the float voltage of the remaining battery cells is~ 2.13 V when the float voltage of a battery cell has been found to be

< 2.13 V;

3. Actions to equalize and test battery cells that had been discovered with electrolyte level below the top of the plates;

4. Limits on average electrolyte temperature, battery connection resistance, and battery terminal voltage; and

5. A requirement to obtain specific gravity readings of all cells at each discharge test, consistent with manufacturer recommendations.

PBAPS UNIT 2 5.0-18c AmendmentNo.320

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 leted 5.6.2 Annual Radiolooical Environmental Operating Report

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

A single submittal may be made for a multiple unit station. The submittal should combine sections common to all units at the station.

The Annual Radiological Environmental Operating Reoort covering the operation of the unit during the previous calendar year shall be submitted by May 31 of each year. The report shall include summaries, interpretations, and analyses of trends of the results of the radiological environmental monitoring activities 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.8.3, and IV.C.

(continued)

PBAPS UNIT 2 5.C-19 Amendment No. 254

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.2 Annual Radiological Environmental Operating Repo-rt (continued)

The Annual Radiological Environmental Operating 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 format of the table in the Radiological Assessment Branch Technical Position, Revision 1, November 1979. 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.

5.6.3 Radioactive Effluent Release Report

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

A single submittal may be made for a multiple unit station. The submittal shall combine sections common to all units at the station.

The Radioactive Effluent Release Report covering the operation of the unit during the previous year shall be submitted prior to May 1 of each year in accordance with 10 CFR 50.36a. The report shall include a summary of the quantities of radioactive liquid and gaseous effluents and solid waste released from the unit. The material provided shall be consistent with the objectives outlined in the ODCM and Process Control Program and in conformance with 10 CFR 50.36a and 10 CFR Part 50, Appendix I, Section IV.B.1.

5.6.4 Deleted (continued)

PBAPS UNIT 2 5.0-20 Amendment No. 2 59

Reporting Requirements 5.6 5.6 Reporting Requirements (continued) 5.6.5 CORE OPERATING LIMITS REPORT CCOLR)

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. The Average Planar Linear Heat Generation Rate for Specification 3.2.1;

2. The Minimum Critical Power Ratio (MCPR) for Specifications 3.2.2 and 3.3.2.1, and MCPR99.9% for Specification 3.2.2;

3. The Linear Heat Generation Rate for Specification

3. 2. 3;

4. The Control Rod Block Instrumentation for Specification 3.3.2.1; and

5. The Manual Backup Stability Protection (BSP) Scram Region (Region I), the Manual BSP Controlled Entry Region (Region II), the modified APRM Simulated Thermal Power-High scram setpoints used in the Automated BSP Scram Region and the BSP Boundary for Specification 3.3.1.1.

b. The analytical methods used to determine the core operating limits shall be those previously reviewed and approved by the NRC, specifically those described in the following document:

1. NEDE-24011-P-A, "General Electric Standard Application for Reactor Fuel" (latest approved version as specified in the COLR).

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 rev1s1ons or supplements, shall be provided upon issuance for each reload cycle to the NRC.

PBAPS UN IT 2 5.0-21 Amendment No. 326

Reporting Requirements 5.6 5.6 Reporting Requirements (continued) 5.6.6 Post Accident Monitoring (PAM) Instrumentation Report When a report is required by Condition B or F of LCO 3.3.3.1, "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 Reactor Coolant System (RCS) PRESSURE AND TEMPERATURE LIMITS REPORT

( PTLR)

a. RCS pressure and temperature limits for heatup, cooldown, low temperature operation, criticality, and hydrostatic testing as well as heatup and cooldown rates shall be established and documented in the PTLR for the following:

i) Limiting Conditions for Operation Section 3.4.9, "RCS Pressure and Temperature (P/T) Limits" ii) Surveillance Requirements Section 3.4.9, "RCS Pressure and Temperature (P/T) Limits"

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 following document:

i) NEDC-33178P-A, "GE Hitachi Nuclear Energy Methodology for Development of Reactor Pressure Vessel Pressure-Temperature Curves," Revision 1, June 2009

c. The PTLR shall be provided to the NRC upon issuance for each reactor vessel fluence period and for any revision or supplement thereto.

5.6.8 OPRM Report When an 0 PRM report i s re qui red by C0ND IT ION I of LC 0 3 . 3 . 1 . 1 , " RPS Instrumentation," the report shall be submitted within the following 90 days. The report shall outline the preplanned means to provide backup stability protection, the cause of the inoperability, and the plans and schedule for restoring the required instrumentation channels to OPERABLE status.

PBAPS UN IT 2 5.0-22 Amendment No. 305

High Radiation Areas 5.7 5.0 ADMINISTRATIVE CONTROLS 5.7 High Radiation Areas As provided in paragraph 20.1601(c) of 10 CFR Part 20, the following controls shall be applied to high radiation areas in place of the controls required by paragraph 20.1601(a) and (b) of 10 CFR Part 20:

5.7.1 High Radiation Areas with Dose Rates not Exceeding 1.0 rem/hour (at 30 centimeters from the radiation sources 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 a 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 ("radiation monitoring and indicating device"), 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

("alarming dosimeter"), with an appropriate alarm setpoint, or

3. A radiation monitoring device that continuously transmits dose rate and cumulative dose information to a remote receiver monitored by radiation protection personnel responsible for controlling personnel radiation exposure within the area, or (continued)

PBAPS UNIT 2 5.0-23 Amendment No. 240 AUG S 0 2,,,j,1

High Radiation Areas 5.7 5.7 High Radiation Areas 5.7.1 High Radiation Areas with Dose Rates not Exceeding 1.0 rem/hour (at 30 centimeters from the radiation sources or from any surface penetrated by the radiation): (continued)

4. A self-reading dosimeter (e.g., pocket ion 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 radiation 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 shall 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.

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.

(continued)

PBAPS UNIT 2 5.0-24 Amendment No. 240 AUlu, > X

High Radiation Areas 5.7 5.7 High Radiation Areas 5.7.2 HiQh 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 bV the radiation) (continued)

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 (whether alone or in a 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

3. A self-reading dosimeter (e.g., pocket ion 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 continually displays radiation dose rates in the area; who is responsible for controlling personnel exposure within the area, or (continued)

PBAPS UNIT 2 5.0-25 Amendment No. 240 AUGa- Cv23'1

APPENDIX B ENVIRONMENTAL TECHNICAL SPECIFICATIONS FOR PEACH BOTTOM ATOMIC POWER STATION UNIT 2

Appendix B Environmental Technical Specifications Table of Contents 1.1 Responsibility . . . . . . . . . . . . . . . . . . . . . . . . . App. B-i 1.2 Reviews and Audits ....................... App. B-2 1.3 Environmental Deviations ................ ... . App. B-3 1.4 Reporting Requirements .................... . App. B-4 1.5 Record Retention ....................... App. B-6 PBAPS UNIT 2 App. B-i Amendment No. 210

Responsibility 1.1 Appendix B Environmental Technical Specifications 1.1 Responsibility 1.1.1 The Plant Manager is responsible for overall operation of the facility and to assure that the facility operates within the limits, conditions and requirements considered necessary for the protection of the environment.

1.1.2 In all matters pertaining to the operation of the facility and to the Environmental Technical Specifications, the Plant Manager shall report to and consult with the Vice President - Peach Bottom Atomic Power Station (PBAPS).

PBAPS UNIT 2 App. B-1 Amendment No. 210

Reviews and Audits 1.2 Appendix B Environmental Technical Specifications 1.2 Reviews and Audits 1.2.1 Plant Reviews and Audits Reviews and audits of plant operation are described in the Quality Assurance Topical Report (QATR). I PBAPS UNIT 2 App. B-2 Amendment No.21e),

257

Environmental Deviations 1.3 Appendix B Environmental Technical Specifications 1.3 Environmental Deviations 1.3.1 Environmental Deviations shall be reported immediately to the Plant Manager or designee.

Environmental Deviations include exceeding a protection limit or report level or, in the opinion of the Plant Manager, an event involving significant environmental impact. A protection limit is a numerical limit on plant effluent or operating parameter which, when not exceeded, should not result in an unacceptable environmental impact. A report level is the numerical value of an environmental parameter below which the environmental impact is considered reasonable on the basis of available information.

1.3.2 Deleted 1.3.3 Environmental Deviations shall be reported to the NRC as specified in Section 1.4.2.1.

1.3.4 If environmental monitoring programs detect harmful effects or evidence of irreversible damage not considered in the Final Environmental Statement, an analysis of the problem and a plan of action to eliminate or significantly reduce the detrimental effects of the damage shall be prepared and provided to the NRC.

PBAPS UNIT 2 App. B-3 Amendment No. -EO, 25:

Reporting Requirements 1.4 Appendix B Environmental Technical Specifications 1.4 Reporting Requirements 1.4.1 Deleted 1.4.2 Non-Routine Reports 1.4.2.1 Environmental Deviation Reports In the event of an Environmental Deviation as defined in Section 1.3.1, notification shall be made within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months to the NRC. A written report shall follow within 30 days to the NRC in accordance with 10 CFR 50.4.

If an event is reportable under 10 CFR 50.72, then a duplicate immediate report under this subsection is not required. However, a follow-up written report is required.

The written report on an Environmental Deviation, and to the extent possible, the preliminary notification, should:

a. Describe, analyze, and evaluate implications of the Environmental Deviation;

b. Identify the cause of the occurrence; and

c. Indicate the corrective action (including any significant change made In procedures) taken to prevent similar occurrences involving similar components or systems.

(continued)

PBAPS UNIT 2 App. B-4 Amendment No.;2+, 257

Reporting Requirements 1.4 Appendix B Environmental Technical Specifications 1.4 Reporting Requirements (continued) 1.4.2.2 Reporting Changes to the Plant or Permits A written report, Including an evaluation of the environmental impact resulting from a change, shall be forwarded to the NRC in accordance with 10 CFR 50.4 in the event of:

a. Changes to the plant that affect the environmental impact evaluation contained in the Environmental Report or the Environmental Statement.

b. Changes or additions to permits and certificates required by Federal, State, local and regional authorities for the protection of the environment. When submittals of changes are approved by the concerned agency, a copy shall be submitted to the NRC.

c. Requests for changes in Environmental Technical Specifications.

PBAPS UNIT 2 App. B-5 Amendment No.2+0, 257

Record Retention 1.5 Appendix B Environmental Technical Specifications 1.5 Record Retention 1.5.1 Records Retained for 5 Years Records relative to the following items shall be kept in a manner convenient for review and shall be retained for 5 years, unless a longer period is required by applicable regulations.

a. Records of principal maintenance activities of equipment pertaining to environmental impact.

b. Records of Environmental Deviations.

c. Records of periodic checks, inspections and/or calibrations performed to verify that environmental surveillance requirements are being met.

d. Deleted

e. Records of changes made to operating procedures, equipment, permits or certificates.

1.5.2 Records Retained until the date of termination of the operating license.

Records of off-site environmental radiation surveys shall be retained until the date of termination of the operating license.

PBAPS UNIT 2 App. B-6 Amendment No.B+O, 257

ML052720266

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