View source for L-2019-105, License Amendment Request (TSCR-183): Application to Revise Operating License and Technical Specifications for Permanently Defueled Condition

{{Adams
| number = ML19176A356
| issue date = 06/20/2019
| title = License Amendment Request (TSCR-183): Application to Revise Operating License and Technical Specifications for Permanently Defueled Condition
| author name = Curtland D
| author affiliation = NextEra Energy Duane Arnold, LLC
| addressee name = 
| addressee affiliation = NRC/Document Control Desk, NRC/NRR
| docket = 05000331
| license number = DPR-049
| contact person = 
| case reference number = L-2019-105, NG-19-0055
| document type = Letter type:L, License-Application for Facility Operating License (Amend/Renewal) DKT 50
| page count = 686
| project = 
| stage = Request
}}

=Text=
{{#Wiki_filter:June 20, 2019                                                                NG-19-0055 L-2019-105 10 CFR 50.90 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555 Puane Arnold Energy Center Docket No. 50-331 Renewed Facility Operating License No. DPR-49 License Amendment Request (TSCR-183): Application to Revise Operating License and Technical Specifications for Permanently Defueled Condition Pursuant to 10 CFR 50.90, NextEra Energy Duane Arnold, LLC (NEDA) is submitting a request for an amendment to the Technical Specifications (TS) for the Duane Arnold Energy Center (DAEC). The proposed changes will revise the license and associated Technical Specifications consistent with the permanent cessation of reactor operation and permanent defueling of the reactor.
By letter dated January 18, 2019 (Accession No. ML19023A196), NEDA provided formal notification to the U.S. Nuclear Regulatory Commission (NRG) pursuant to 10 CFR 50.82(a)(1 )(i) and 10 CFR 50.4(b)(8) of the intention to permanently cease power operations at the DAEC in the fourth quarter of 2020.
After the certifications of permanent cessation of power operation and of permanent removal of fuel from the DAEC reactor vessel are docketed, in accordance with 10 CFR 50.82(a)(1 )(i) and (ii) respectively, and pursuant to 10 CFR 50.82(a)(2), the 10 CFR 50 license will no longer authorize reactor operation or emplacement or retention of fuel in the reactor vessel. As a result, certain license conditions and technical specifications may be revised or removed to reflect the permanently defueled condition. In general, the changes propose the elimination of items applicable in operating conditions where fuel is placed in the reactor vessel. The revisions to the DAEC license and technical specifications are proposed in accordance with 10 CFR 50.51(b) and 10 CFR 50.36(c)(6).
The Enclosure to this letter provides NEDA's evaluation of the proposed change.
Attachment 1 to the enclosure provides markups of the TS showing the proposed changes, and Attachment 2 provides the clean TS pages containing the proposed TS changes. The changes to the TS Bases are provided for information in Attachment 3 and will be incorporated in accordance with the TS Bases Control Program upon implementation of the approved amendment.
NextEra Energy Duane Arnold, LLC, 3277 DAEC Road, Palo, IA 52324

Document Control Desk NG-19-0055 Page 2 of 2 NEDA requests approval of the proposed license amendment by August 1, 2020.
NEDA requests that the approved amendment become effective following submittal of the certifications required by 10 CFR 50.82(a)(1 )(i) and (ii).
In accordance with 10 CFR 50.91, a copy of this application with enclosures is being provided to the designated State of Iowa official.
As discussed in the Enclosure, the proposed change does not involve a significant hazards consideration pursuant to 10 CFR 50.92, and there are no significant environmental impacts associated with the change. The DAEC Onsite Review Group has reviewed the proposed license amendment.
The NRG is currently reviewing a supporting licensing action to change the organizational staffing and training requirements contained in DAEC TS Section 1.1, "Definitions" and Section 5.0, "Administration" that was submitted for approval by letter dated April 19, 2019 (ML19109A031).
This letter contains no new or revised regulatory commitments.
If you have any questions or require additional information, please contact Michael Davis, Licensing Manager, at 319-851-7032.
I declare under penalty of perjury that the foregoing is true and correct.
Executed on June )-0 , 2019 Dean Curtland Site Director NextEra Energy Duane Arnold, LLC Enclosure cc:    Regional Administrator, USNRC, Region Ill, Project Manager, USNRC, Duane Arnold Energy Center Resident Inspector, USNRC, Duane Arnold Energy Center A Leek (State of Iowa)

Enclosure NEXTERA ENERGY DUANE ARNOLD, LLC DUANE ARNOLD ENERGY CENTER NG-19-0055 LICENSE AMENDMENT REQUEST (TSCR-183)
DESCRIPTION AND EVALUATION OF THE PROPOSED CHANGES Page 1 of 85

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 2 of 85 NEXTERA ENERGY DUANE ARNOLD, LLC DUANE ARNOLD ENERGY CENTER License Amendment Request {TSCR-183): Application to Revise Operating License and Technical Specifications for Permanently Defueled Condition EVALUATION OF PROPOSED CHANGE 1.0 Summary Description 2.0 Detailed Description 3.0 Technical Evaluation 4.0 Regulatory Evaluation 4.1    Applicable Regulatory Requirements/Criteria 4.2    Precedent 4.3    No Significant Hazards Consideration 4.4    Conclusions 5.0 Environmental Considerations 6.0 References  ;.... Proposed Technical Specification Changes (Mark-Up)  - Revised Technical Specification Pages (Clean, with Proposed Changes)  - Proposed Technical Specification Bases Changes (Mark-Up)

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 3 of 85 1.0    

==SUMMARY==
DESCRIPTION NextEra Energy Duane Arnold, LLC (NEDA) requests an amendment to the Duane Arnold Energy Center (DAEC) Operating License (OL) and Technical Specifications (TS). The proposed changes will revise the OL and TS consistent with the permanent cessation of reactor operation and permanent defueling of the reactor. The revised OL and TS will be identified as the DAEC Post Defueled Technical Specifications (POTS).
By letter dated January 18, 2019 (Reference 1), NEDA provided formal notification to the U.S. Nuclear Regulatory Commission (NRC) pursuant to 10 CFR 50.82(a)(1)(i) and 10 CFR 50.4(b )(8) of the intention to permanently cease power operations at the DAEC in the fourth quarter of 2020.
After the certifications of permanent cessation of power operation and of permanent removal of fuel from the DAEC reactor vessel are docketed, in accordance with 10 CFR 50.82(a)(1 )(i) and (ii) respectively, and pursuant to 10 CFR 50.82(a)(2), the 10 CFR 50 license will no longer authorize reactor operation or emplacement or retention of fuel in the reactor vessel. As a result, certain license conditions and technical specifications may be revised or removed to reflect the permanently defueled condition. In general, the changes propose the elimination of items applicable in operating conditions where fuel is placed in the reactor vessel.
The proposed changes to the DAEC OL and TS are in accordance with 10 CFR 50.36(c)(1) through (c)(5). The proposed changes also include administrative changes to content format and revised page numbering. The TS Table of Contents is revised accordingly.
The current DAEC TS contain limiting conditions for operation (LCOs) that provide for appropriate functional capability of equipment required for safe operation of the facility, including safe storage and management of irradiated fuel. Since the safety function related to safe storage and management of irradiated fuel at an operating plant is similar to the corresponding function at a permanently defueled facility, the existing TS provide an appropriate level of control. However, the majority of the existing TS are only applicable with the reactor in an operational mode. LCOs and associated surveillance requirements (SRs) that will not apply in the permanently defueled condition are being proposed for deletion. The remaining portions of the TS are being proposed for revision and incorporation as the POTS to provide a continuing acceptable level of safety that addresses the reduced scope of postulated design basis accidents with a permanently defueled plant.
In the development of the proposed POTS changes, NEDA reviewed POTS requirements from other plants that have permanently shut down, as listed in Section 4.2, Precedent.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 4 of 85 The proposed changes would become effective following submittal of the certifications required by 10 CFR 50.82(a)(1 )(i) and (ii).
Related Licensing Actions By letter dated April 19, 2019 (Reference 2), NEDA submitted a License Amendment Request (LAR) proposing changes to the organization, staffing and training requirements contained in TS Section 1.1, "Definitions" and Section 5.0, "Administration" that complements and supports this request.
2.0   DETAILED DESCRIPTION The proposed change is requested as a result of NEDA's formally-stated intention to permanently cease power operation at DAEC in the fourth quarter of 2020 and to transfer all fuel in the reactor to the Spent Fuel Pool (SFP) soon thereafter. The proposed amendment revises the DAEC OL and TS for a permanently defueled and shutdown condition. To support the proposed changes, NEDA has evaluated the design basis accidents (DBAs) that will be applicable in a permanently shutdown and defueled condition. NEDA has also evaluated the General Design Criteria (GDC) with respect to compliance in the permanently shutdown and defueled condition. The OBA and GDC evaluations provide the framework and basis for the proposed changes.
Design Basis Accident Analyses Applicable to Proposed Change Chapter 15 of the DAEC Updated Final Safety Analysis Report (UFSAR) contains the DBAs and transient scenarios applicable to DAEC. The most severe postulated accident for nuclear power plants involves damage to the nuclear reactor core and the release of large quantities of fission products to the reactor coolant system (RCS). Many of the accident scenarios postulated in the UFSAR involve failures or malfunctions of systems that could affect the reactor core.
With the termination of reactor operations at DAEC and the permanent removal of fuel from the reactor as certified in accordance with 10 CFR 50.82(a)(1 )(i) and (ii), and pursuant to 10 CFR 50.82(a)(2), the majority of the OBA scenarios postulated in the UFSAR will no longer be possible. During decommissioning, the irradiated fuel will be stored in the Spent Fuel Pool (SFP) or the Independent Spent Fuel Storage Installation (ISFSI) until it is shipped offsite in accordance with the schedule to be provided in the Post Shutdown Decommissioning Activities Report (PSDAR) and the Spent Fuel Management Plan. With the reactor permanently shut down and defueled, many associated systems and instrumentation, as well as the turbine generator, are no longer in operation and have no function related to the safe storage and management of the spent nuclear fuel.
* Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 5 of 85 Chapter 15 of the UFSAR describes the safety analysis aspects of the DAEC that were evaluated to demonstrate that the plant could be operated safely and that radiological consequences from postulated accidents do not exceed regulatory requirements. The spectrum of UFSAR Chapter 15 events is divided into three classes in accordance with their anticipated frequency as follows:
Transients - Transients are subdivided into two categories: Anticipated Operational Occurrences (AOOs) and Abnormal Operating Transients (AOTs). AOOs are expected to occur at least once over the life of the plant and are the result of single equipment failures or single operator errors that can be reasonably expected during any mode of normal plant operation. AOTs are generally AOOs with an additional equipment failure or operator error, in addition to that which initiated the AOO. AOTs are not postulated to occur over the life of the plant.
Accidents -Accidents are defined as highly improbable, hypothesized events that affect one or more of the radioactive material barriers.
Special Events - Special Events are those where the plant has demonstrated its ability to respond to specific events that were postulated after the plant was initially designed and licensed. These events have unique requirements for demonstrating the plant's ability to mitigate the Special Event.
A list of Chapter 15 events and whether each applies to a permanently defueled condition is provided in Table 2.1 below. The UFSAR Chapter 15 OBA accident scenario that remains credible in the permanently defueled condition, with fuel stored in the SFP, is a fuel handling accident (FHA).
Table 2.1 UFSAR                  Postulated Accident or Transient                    Permanently Section                                                                      Defueled Applicabilit 15.1          Transients 15.1.1        Transients Resulting in a Reactor Vessel Water Temperature Decrease 15.1.1.1      Feedwater Controller Failure - Maximum Demand 15.1.1.2      Loss of Feedwater Heatin 15.1.1.3      Inadvertent HPCI Actuation 15.1.2        Transients Resulting in a Nuclear System Pressure Increase

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 6 of 85 15.1.2.1    Generator Load Rejection (Turbine Control Valve Fast Closure 15.1.2.1.1 Main Generator Load Rejection with Bypass Valve      Not Applicable LRWBP - Hi h Power 15.1.2.1.2 Main Generator Load Rejection with Bypass Valve      Not Applicable Failure LRNBP - Hi h Power 15.1.2.1.3 Generator Load Rejection from Low Power Without      Not Applicable B pass 15.1.2.2 15.1.2.2.1 Main Turbine Trip with Bypass (TTWBP) - High         Not Applicable Power 15.1.2.2.2 Main Turbine Trip with Bypass Valve Failure          Not Applicable (TTNBP) - High Power 15.1.2.2.3 Main Turbine Trip with Bypass Valve Failure          Not Applicable (TTNBP - Low Power 15.1.2.3    Main Steam Line Isolation Valve Closure 15.1.2.3.1 Closure of all Main Steam Line Isolation Valves      Not Applicable (MSIV - High Power 15.1.2.3.2 Closure of All Main Steam Line Isolation Valves with Not Applicable direct Scram Failure (MSIVF - Hi h Power 15.1.2.3.3 Closure of One Main Steam Line Isolation Valve (1    Not Applicable MSIV - Hi h Power 15.1.3      Transients Resulting in a Core Coolant Flow Decrease 15.1.3.1    Recirculation Flow Control Failure - Decreasing     Not Applicable Flow 15.1.3.2    Tri of One Recirculation Pum 15.1.3.3 15.1.4      Transients Reactivity And Power Distribution Anomalies 15.1.4.1    Rod Withdrawal Error at Power 15.1.4.2    Rod Withdrawal Error at Startu 15.1.4.3 15.1.4.4.1 Fuel Assembly Insertion Error During Refueling -     Not Applicable Inadvertent Criticalit 15.1.4.4.2 Fuel Loadin Error- Mislocated Bundle 15.1.4.4.3 Fuel Loading Error - Rotated Bundle 15.1.5      Transients Resultin in an Increase in Core Flow 15.1.5.1    Startu of an Idle Recirculation Pum 15.1.5.2    Recirculation Flow Controller Failure - Increasing  Not Applicable Flow Fast

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 7 of 85 15.1.5.3    Recirculation Flow Controller Failure - Slow Flow   Not Applicable Runout 15.1.6      Transients Resulting in an Increase in Reactor      Not Applicable Coolant lnvento 15.1.7      Transients Resulting in a Reactor Vessel Coolant Invento Decrease 15.1.7.1 15.1.7.2 15.1.7.3    Loss of Feedwater Flow 15.1.7.4    Tri of One Feedwater Water Pump 15.2        Accidents 15.2.1      Loss-Of-Coolant Accidents 15.2.1.1    Reactor Recirculation Pipe Breaks 15.2.1.2    Core S ra Line Break 15.2.1.3    Feedwater Line Break 15.2.1.4    Main Steam Line Break - Inside Containment 15.2.1.5    Main Steam Line Break - Outside Containment 15.2.2      Instrument Line Breaks 15.2.3      Recirculation Pump Seizure Accident 15.2.4 15.2.5 15.3        S ecial Events 15.3.1      Anticipated Transients Without Scram A TWS 15.3.1.1    ATWS-MSIVC 15.3.1.2    ATWS-PRFO 15.3.1.3    ATWS-LOOP                                           Not Applicable 15.3.1.4    ATWS-IORV                                           Not Applicable 15.3.2      Station Blackout SBO) 15.3.2.1    Station Blackout SBO 15.3.3      Fire - Safe Shutdown Anal sis 15.3.3.1 15.3.3.2 15.3.3.3 15.3.3.4 15.3.4 15.3.4.1    Thermal-Hydraulic Stability - Exclusion/Buffer Zone Not Applicable Determination 15.3.4.2    Thermal-Hydraulic Stability - Safety Limit MCPR     Not Applicable Protection 15.3.5     Analysis of Reactor Internals Pressure Differentials RIPD 15.3.5.1    RIPD - Normal Limits

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 8 of 85 15.3.5.2    RIPD - Upset Limits                                         Not Applicable 15.3.5.3    RIPD - Emergency Limits                                     Not Applicable 15.3.5.4    RIPD - Faulted Limits                                       Not Applicable 15.3.5.5    RIPD - Flow-Induced Loads                                   Not Applicable 15.3.5.6    RIPD -Acoustic Loads                                        Not Applicable Fuel Handling Accident Analysis for the Permanently Shut Down and Defueled Condition Summary On April 16, 2001, the NRG issued License Amendment 237 to the OL and TS of DAEC. The amendment implemented an alternative source term (AST) per 10 CFR 50.67 to perform the radiological consequence analysis of the design-basis FHA to support changes to the TS (Reference 3). The analysis of the FHA that supported these changes assumed the FHA occurred over the reactor core 60 hours after reactor shutdown from full power and did not take credit for secondary containment, secondary containment isolation or filtration by the Standby Gas Treatment (SBGT) System.
After the reactor has been completely defueled following permanent shut down, an FHA over the reactor core is no longer a credible accident. A fuel drop over the spent fuel pool is bounded by the analysis of a drop over the reactor core because the kinetic energy for the drop of thirty feet over the vessel produces a much greater number of damaged fuel pins on impact that the shorter drops that could occur over the fuel pool.
DAEC UFSAR Chapter 15.2 states that the dose consequences of an FHA are less than the limits set forth in 10 CFR 50.67 and Regulatory Guide 1.183.
After the reactor has been completely defueled following permanent shutdown, all fuel in the SFP will have decayed such that an FHA in the SFP is bounded by the analysis of UFSAR Chapter 15.2.
Fuel Damage The DAEC UFSAR describes the number of rods assumed to fail as a result of a FHA is 151 fuel rods. Since a fuel drop over the spent fuel pool is bounded by the analysis of a drop over the reactor core, this level of damage remains bounding in the permanently shut down and defueled condition.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 9 of 85 Methods and Assumptions The FHA analysis uses the Alternate Source Term (AST) Methodology outlined in NUREG-1465, Regulatory Guide 1.183 as detailed in Amendment 237. Since a fuel drop over the spent fuel pool is bounded by the analysis of a drop over the reactor core, this analysis remains bounding and the methods and assumptions listed in Amendment 237 remain unchanged.

==3.0   TECHNICAL EVALUATION==

The following tables identify each section that is proposed to be changed, the proposed changes and the basis for eacH change. Changes to the OL are listed first followed by changes to the TS. Proposed additions are shown using red underline and deletions are shown using red strikethrough. provides the marked-up version of the DAEC OL and TS. The proposed changes to the TS are considered a major rewrite; consequently, revision bars are not used. Additionally, TS sections that are not affected by this LAR are included in Attachments 1 and 2 so they can be annotated, as part of the major rewrite, with the Amendment number assigned to this LAR. Finally, the following administrative changes are not shown in the marked-up OL, TS, and TS Bases pages because they do not affect the technical content of the OL and TSs:
* Reformatting (margins, font, tables, line spacing, etc.) content to create a continuous electronic file;
* Renumbering of pages, where appropriate, to condense and reduce the number of pages; and
   ** Revisions to the TS Table of Contents. provides the re-typed Renewed Facility License and POTS in their entirety. Since the changes to the TS are considered a major rewrite, revision bars are not used.
The markups of the TS Bases, provided in Attachment 3, are provided for information only. TS Bases sections that will be deleted in their entirety are not included in . Upon approval of this amendment, changes to the TS Bases will be incorporated in accordance with TS 5.5.10, "Technical Specifications Bases Control Program." Since the changes to the TS Bases are considered a major rewrite, revision bars are not used.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 10 of 85 LICENSE License Title Current Title                                   Proposed Title Renewed Facility Operatinq License              Renewed Facility '"';:::-.:.-'-'--:;:; License Basis The License title is modified to eliminate the reference to "Operating." After certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2).
License Item 1. B Current                                         Proposed Construction of the Duane Arnold Energy         Deleted.
Center (facility) has been substantially completed in conformity with Construction Permit No. DPPR-70; the application, as amendment; the provisions of the Act; and the rules and regulations of the Commission; Basis License Item 1.B is proposed for deletion in its entirety. Decommissioning of DAEC is not dependent on the regulations that govern construction of the facility.
License Item 1.C Current                                         Proposed The facility will operate in conformity with    The facility will operatebe maintained in the applications, as amended; the               conformity with the applications, as provisions of the Act; and the rules and        amended; the provisions of the Act; and regulations of the Commission;                  the rules and regulations of the Commission; Basis License Item 1.C is revised to align with the permanently defueled condition. After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Thus, removal of the reference to operating provides accuracy in the 10 CFR Part 50 license description.
Therefore, the changes are consistent with the requirements associated with a permanently shut down and defueled condition.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 11 of 85 License Item 1.D Current                                           Proposed There is reasonable assurance: (i) that the There is reasonable assurance: (i) that the activities authorized by this renewed             activities authorized by this renewed operating license can be conducted                operating license can be conducted without endangering the health and safety         without  endangering the health and safety of the public; and (ii) that such activities      of the public; and (ii) that such activities will be conducted in compliance with the          will be conducted in compliance with the rules and regulations of the Commission;          rules and regulations of the Commission; Basis License Item 1.D is modified to eliminate the reference to "operating." After certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2).
License Item 1.E Current                                           Proposed NextEra Energy Duane Arnold, LLC is               NextEra Energy Duane Arnold, LLC is technically qualified and NextEra Energy          technically qualified and NextEra Energy Duane Arnold, LLC, Central Iowa Power             Duane Arnold, LLC, Central Iowa Power Cooperative and Corn Belt Power                   Cooperative and Corn Belt Power Cooperative are financially qualified to          Cooperative are financially qualified to engage in the activities authorized by this       engage in the activities authorized by this renewed operating license in accordance           renewed operating license in accordance with the rules and regulations of the            with the rules and regulations of the Commission;                                       Commission; Basis License Item 1.E is modified to eliminate the reference to "operating." After certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2).
License Item 1. G Current                                           Proposed The issuance of this renewed operating            The issuance of this renewed operating license will not be inimical to the common        license will not be inimical to the common defense and security or to the health and         defense and security or to the health and safety of the public;                             safety of the public; Basis License Item 1.G is modified to eliminate the reference to "operating." After certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2).

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 12 of 85 License Item 1.H Current                                         Proposed After weighing the environmental,               After weighing the environmental, economic, technical, and other benefits of      economic, technical, and other benefits of the facility against environmental costs        the facility against environmental costs and considering available alternatives, the and considering available alternatives, the issuance of renewed Facility Operating          issuance of renewed Facility Operating License No. DPR-49 is in accordance with License No. DPR-49 is in accordance with 10 CFR Part 50, Appendix D, of the              10 CFR Part 50, Appendix D, of the Commission's regulations and all                Commission's regulations and all applicable requirements of said Appendix        applicable requirements of said Appendix D have been satisfied;                          D have been satisfied; Basis License Item 1.H is modified to eliminate the reference to "Operating,IIAfter certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2).
License Item 1.1 Current                                         Proposed The receipt, possession, and use of             Deleted.
source, by-product and special nuclear material as authorized by this renewed operating license will be in accordance with the Commission's regulations in 10 CFR Part 30 and 70, including 10 CFR Section 30.33, 70.24 and 70.31.
Basis This condition is proposed for deletion in its entirety. The Commission's finding regarding possession and use of byproduct, source, and special nuclear material is not dependent on decommissioning of the facility. Additionally, possession and use of byproduct, source, and special nuclear material at DAEC during decommissioning activities is covered by License Condition 2.B, which will remain in effect. Therefore, License Condition 1.1 is not needed.
License Item 2 Current                                         Proposed Renewed Facility Operating License No.          Renewed     Facility Operating License No.
DPR-49 is hereby issued to NextEra              DPR-49 is hereby issued to NextEra Energy Duane Arnold, LLC, Central Iowa          Energy Duane Arnold, LLC, Central Iowa Power Cooperative (CIPCO) and Corn Belt Power Cooperative (CIPCO) and Corn Belt Power Cooperative (Corn Belt) to read as        Power Cooperative (Corn Belt) to read as follows:                                        follows:

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 13 of 85 Basis After certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2).
License Item 2.A Current (first sentence only}                     Proposed* (first sentence only}
This renewed operating license applies to         This renewed operating license applies to the Duane Arnold Energy Center, a boiling the Duane Arnold Energy Center, a water reactor and associated equipment            permanently defueled boiling water reactor (the facility), owned by NextEra Energy           and associated equipment (the facility),
Duane Arnold, LLC, Central Iowa Power             owned by NextEra Energy Duane Arnold, Cooperative and Corn Belt Cooperative             LLC, Central Iowa Power Cooperative and and operated by NextEra Energy Duane              Corn Belt Cooperative and operated by Arnold,  LLC.                                     NextEra Energy Duane Arnold, LLC.
Remaining sentences in Item 2.A are               Remaining sentences in Item 2.A are unchanged.                                        unchanged.
Basis After certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2).
License Item 2.8(1)
Current                                           Proposed NextEra Energy Duane Arnold, LLC,                 NextEra Energy Duane Arnold, LLC, pursuant to Section 104b of the Act and 10 pursuant to Section 104b of the Act and 10 CFR Part 50, "Licensing of Production and CFR Part 50, "Licensing of Production and Utilization Facilities," to possess, use and      Utilization Facilities," to possess, and use operate the facility; and CIPCO and Corn          and operate the facility as required for Belt to possess the    facility at the            nuclear fuel storage; and CIPCO and Corn designated location in Linn County, Iowa,         Belt to possess the facility at the in accordance    with the  procedures   and       designated   location in Linn County, Iowa, limitations set forth in this license;            in accordance with the procedures and limitations set forth in this license; Basis The proposed language change associated with operating the facility in this license condition is removed. After certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2).
Thus, this item is revised to aliqn with the permanently defueled condition.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 14 of 85 License Item 2. 8(2)
Current                                         Proposed NextEra Energy Duane Arnold, LLC,               NextEra Energy Duane Arnold, LLC, pursuant to the Act and 10 CFR Part 70,         pursuant to the Act and 10 CFR Part 70, to receive, possess and use at any time         to receive, possess and use at any time special nuclear material as reactor fuel, in    special nuclear material that was used as accordance with the limitations for             reactor fuel, in accordance with the storage and amounts required for reactor        limitations for storage and ameunts operation, as described in the Updated          required fer reacter eperatien, as Final Safety Analysis Report, as                described in the Updated Final Safety supplemented and amended as of June             Analysis  Report, as supplemented and 1992 and as supplemented by letters             amended as of June 1992 and as dated March 26, 1993, and November              supplemented by letters dated March 26, 17,2000.                                        1993, and November 17, 2000.
Basis The language in this license condition is proposed to be changed to reflect that special nuclear material for fuel used for reactor operations can no longer be received, only stored. After certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, the changes are consistent with the requirements associated with a permanently shutdown and defueled condition.
License Item 2. 8(3)
Current                                         Proposed NextEra Energy Duane Arnold, LLC,               NextEra Energy Duane Arnold, LLC, pursuant to the Act and 10 CFR Parts 30,        pursuant to the Act and 10 CFR Parts 30, 40 and 70, to :receive, possess and use at 40 and 70, to receive, possess and use at any time any byproduct, source and              any time any byproduct, source   aoo special nuclear material as sealed neutron special nuclear material as sealed neutren sources for reactor startup, sealed sources seurces fer reacter startup, Q[_sealed for reactor instrumentation and radiation       sources for reacter instrumentatien and monitoring equipment calibration, and as        radiation monitoring equipment calibration, fission detectors in amounts   as required;     and as fissien detecters in ameunts as required and to possess any byproduct, source and SQecial nuclear material as sealed neutron sources Qreviously used for reactor startuQ and reactor instrumentation; and fission detectors; Basis The requirements regarding receipt of sealed neutron sources for reactor startup and nuclear instrumentation is proposed for deletion from this license condition. This license

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 15 of 85 condition is revised to reflect authorization only for continued possession of those sources previously used for reactor startups, produced as a byproduct, and those required for calibrations. After certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, the use of startup sources will no longer be needed. The changes are consistent with the requirements associated with a permanently shut down and defueled condition. The use of sources for radiations monitoring will continue to be required.
License Item 2. 8(5)
Current                                           Proposed NextEra Energy Duane Arnold, LLC,                 NextEra Energy Duane Arnold, LLC, pursuant to the Act and 10 CFR Parts 30           pursuant to the Act and 10 CFR Parts 30 and 70, to possess, but not to separate,           and 70, to possess, but not to separate, such byproduct and special nuclear                 such byproduct and special nuclear materials as may be produced by the               materials as may bethat were produced by operation of the facility.                         the operation of the facility.
Basis This license condition will be revised to replace "as may be" with "that were." This license condition is proposed for revision to allow possession of byproduct and special nuclear materials that were produced by operation of the DAEC reactor. After certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, the changes are consistent with the requirements of associated with a permanently shut down and defueled condition.
License Item 2.C Current                                            Proposed This renewed operating license                     This renewed operating license shall be deemed to contain and is                  shall be deemed to contain and is subject to the conditions specified in             subject to the conditions specified in the following Commission                          the following Commission regulations in 10 CFR Chapter I;                   regulations in 10 CFR Chapter I; Part 20, Section 30.34 of Part 30,                 Part 20, Section 30.34 of Part 30, Section 40.41 of Part 40, Sections                 Section 40.41 of Part 40, Sections 50.54 and 50.59 of Part 50, and                   50.54 and 50.59 of Part 50, and Section 70.32 of Part 70; is subject              Section 70.32 of Part 70; is subject to all applicable provisions of the               to all applicable provisions of the Act and to the rules, regulations,                Act and to the rules, regulations, and orders of the Commission now                  and orders of the Commission now or hereafter in effect; and is subject            or hereafter in effect; and is subject

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 16 of 85 to the additional conditions                       to the additional conditions specified or incorporated below:                   specified or incorporated below:
Basis License Item 2.C is modified to eliminate the reference to "operating." After certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2).
License Item 2.C(1)
Current                                            Pro12osed Maximum Power Level                                Deleted.
NextEra Energy Duane Arnold, LLC is authorized to operate the Duane Arnold Energy Center at steady state reactor core power levels not in excess of 1912 megawatts (thermal).
Basis This License condition is deleted in its entirety to reflect the permanently defueled condition of the facility. After certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor pursuant to 10 CFR 50.82(a)(2). The license need not limit reactor core power levels since the reactor will not be authorized to operate.
License Item 2.C(2)
Current                                            Pro12osed Technical S12ecifications                          Technical SQecifications The Technical Specifications contained in          The Technical Specifications contained in Appendix A, as revised through                     Appendix A, as revised through Amendment No. 307, are hereby                      Amendment No. -W-7, are hereby incorporated in the license. NextEra               incorporated in the license. NextEra Energy Duane Arnold, LLC shall operate             Energy Duane Arnold, LLC shall the facility in accordance with the                operatemaintain the facility in accordance Technical Specifications.                          with the Permanently Defueled Technical Specifications.
(a) For Surveillance Requirements (SRs) whose acceptance criteria                 (a) i;'.or Sl:IPJeillaRee ReEf l:liremeRts are modified, either directly or                    (SRs) 11.1l=lose aeeeptaRee eriteria indirectly, by the increase in                      are moeifiee, eitl=ler eireetly or authorized maximum power level in                   iREiireetly, ey tl=le iRerease iR 2.C.(1) above, in accordance with                   al:ltl=lorizee maximl:lm power level iR Amendment No. 243 to Facility                       -*-*       I    -*-, ..
                                                           ' ) f"' /,1\ ~ L - ,_ :~
                                                                                    ~
                                                                                               .... :.a.L

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 17 of 85 Operating License DPR-49, those                 AmeRsmeRt Ne. 24J te J;:aeility SRs are not required to be                      QpeFatiR&sect; bieeRse QPR 49, tl=lese performed until their next                      SRs aFe Ret FeEfUiFes te ee scheduled performance, which is                 perfmmes uRtil tl=leiF Rext due at the end of the first                     sel=lesules perfeFmaRee, 1.!a1J:iiel=I is surveillance interval that begins on            sue at tl=le eRs sf tl=le fiFSt the date the Surveillance was last              SUFVeillaRee iRtmval tl=lat ee&sect;iRS SR performed prior to implementation               tl=le sate tl=le SuFVeillaRee 1.vas last of Amendment No. 243.                           perfeFmes pFieF te implemeRtatieR ef AmeRsmeRt Ne. 24J.
(b) Deleted.
(e) Qeletes.
Basis This License condition is revised to reflect the permanently defueled condition of the facility. After certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). The License condition is revised to remove the reference to reactor operation as well as the reference to the now deleted condition 2.C.(1).
License Item 2.C(4)
Current                                           Proposed The licensee is authorized to operate the         Deleted.
Duane Arnold Energy Center following installation of modified safe-ends on the eight primary recirculation system inlet lines which are described in the licensee letter dated July 31, 1978, and supplemented by letter dated December 8, 1978.
Basis After certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor pursuant to 10 CFR 50.82(a)(2). Thus, the requirement for installation of equipment to support operation is not necessary.
License Item 2.C(11)
Current                                           Proposed The information in the UFSAR                      Deleted.
supplement, as revised, submitted pursuant to 10 CFR 54.21 (d), shall be

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 18 of 85 incorporated into the UFSAR no later than the next scheduled update required by 10 CFR 50.71(e) following the issuance of this renewed operating license. Until this update is complete, the licensee may not make changes to the information in the supplement. Following incorporation into the UFSAR, the need for prior Commission approval of any changes will be governed by 10 CFR 50.59.
Basis After certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor pursuant to 10 CFR 50.82(a)(2). Thus, the requirement for the addition of UFSAR information to support operation is not necessary.
License Item 2.C(12)
Current                                        Proposed The UFSAR supplement, as revised,              Deleted.
submitted pursuant to 10 CFR 54.21(d),
and as supplemented by Appendix A of NUREG-1955, "Safety Evaluation Report Related to the License Renewal of Duane Arnold Energy Center," dated November 2010, as supplemented by letter from the licensee to the NRG dated November 23, 2010, describes certain programs to be implemented and activities to be completed before the period of extended operation.
: a. NextEra Energy Duane Arnold, LLC shall implement those new programs and enhancements to existing programs no later than February 21, 2014.
: b. NextEra Energy Duane Arnold, LLC shall complete those activities no later than February 21, 2014.
The licensee shall notify the NRG in writing within 30 days after having

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 19 of 85 accomplished item (a) above and include the status of those activities that have been or remain to be completed in item (b) above.
Basis This License condition imposed program requirements necessary for the DAEC to continue operation beyond February 21, 2014. After certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor pursuant to 10 CFR 50.82(a)(2). Thus, the program requirements to support extended operation are not necessary.
License Item 2.C(13)
Current                                         Proposed The licensee shall implement the most           Deleted.
recent staff-approved version of the Boiling Water Reactor Vessels and Internals Project (BWRVIP) Integrated Surveillance Program (ISP) as the method to demonstrate compliance with the requirements of 10 CFR Part 50, Appendix H. Any changes to the BWRVIP ISP capsule withdrawal schedule must be submitted for staff review and approval.
Any changes to the BWRVIP ISP capsule withdrawal schedule which affects the time of withdrawal of any surveillance capsules must be incorporated into the licensing basis. If any surveillance capsules are removed without the intent to test them, these capsules must be stored in a manner which maintains them in a condition which would support re-insertion into the reactor pressure vessel if necessary.
Basis After certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Thus, once the DAEC vessel is permanently defueled and the remaining BWRVIP ISP capsule is removed, NextEra Energy Duane Arnold, LLC will terminate its participation in the BWRVIP ISP program.

Duane Arnold Energy Center
* Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 20 of 85 License Item 2.D Current                                         Proposed This license is effective as of the date of     This license is effective as of the date of issuance and shall expire at midnight           issuance and is effective until the February 21, 2034.                              Commission notifies the licensee in writing that the license is terminated sAall e:X13iFe
_,. -:..J-~_ .... ,. c-i.._r ..... - ')"1 ')('\"lJI
_ ..  **-  1:::,1 .. * - - - - * , - * , - - -
Basis After certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor pursuant to 10 CFR 50.82(a)(2). Thus, February 21, 2034 no longer has significance and does not govern termination of the license.
Appendix B Additional Conditions Current                                         Proposed Amendment 260 (1}                               Amendment 260 (1}
At the time of the closing of the                 At tAe time ef tAe elesiA&sect; ef tAe transfer of the license from Interstate           tFaAsfeF ef tAe lieeAse fFem IAteFstate Power and Light Company (IPL) to                  Pe11JeF ami bi&sect;At Gem13aAy (IPb) ta FPLE Duane Arnold*, IPL shall                     FPbE DuaAe Ameld*, IPb sAall transfer to FPLE Duane Arnold* IPL's              tFaAsfeF te FPbE DuaAe AFAeld* IPb's decommissioning funds accumulated                 deeemmissieAiA&sect; fuAds aeeumulated as of such time, with a aggregate                 as ef SUGA time, 111itA a a&sect;&sect;Fe&sect;ate minimum value of at least $186                     miAimum value sf at least $186 million, and FPLE Duane Arnold* shall              millieA, aAd FPbE Ol:laAe Ameld* sAall deposit such funds in an external                  de13esit SUGA fuAds iA aA e:Xtemal decommissioning trust fund                         eeeemmissieAiA&sect; trnst fuAe established by FPLE Duane Arnold*                 establisAed by FPbE DuaAe .A.meld*
for DAEC. NextEra Energy Duane                    RWDAEG. NextEra Energy Duane Arnold shall take all necessary steps             Arnold shall take all necessary steps to ensure that this external trust fund           to ensure that tRis the external trust is maintained in accordance with the              fund established at the time of the requirements of the order approving               closing of transfer of the license from the license transfer, NRC regulations,             Interstate Power and Light (IPL} to and consistent with the safety                     FPLE Duane Arnold is maintained in evaluation supporting the order. The              accordance with the requirements of trust agreement shall be in a form                the December 23, 2005 order acceptable to the NRC.                            approving the license transfer, NRC regulations, and consistent with the
* On April 16, 2009, the name "FPL                 safety evaluation supporting the order.
Energy Duane Arnold, LLC was                       The trust agreement shall be in a form changed to "NextEra Energy      Duane               acceptable to the NRC.
Arnold, LLC."

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 21 of 85
* GA A13Fil ~ e, 2QQ9, tl=ie AaFfle "J;:Pb EAeFgy QuaAe ArnelEI, bbG was chaAgeEI te "NextEm EAeFgy QuaAe ArnelEI, bbG."
Basis The revisions to the condition pertaining to decommissioning trust funding are to clarify current requirements and remove statements that are no longer relevant.
Current                                        Proposed Amendment 260 (3)                              DELETED NextEra Energy Duane Arnold shall take no action to cause FPL Group Capital, or its successors and assigns, to void, cancel, or modify its $50 million contingency commitment to NextEra Energy Duane Arnold, as represented in the license transfer application, or cause it to fail or perform or impair its performance under the commitment, or remove or interfere with NextEra Energy Duane Arnold's ability to draw upon the commitment, without the prior written consent from the NRG. An executed copy of the Support Agreement shall be submitted to the NRG no later than 30 days after completion of the license transfer. Also, NextEra Energy Duane Arnold shall inform the NRG in writing any time that it draws upon the $50 million commitment.
Basis As stated in the NRC's Safety Evaluation for the DAEC license transfer, dated December 23, 2005 (ML053420246), the purpose of the support agreement is to ensure the licensee has sufficient funds to cover operating costs. Moreover, the Support Agreement, which was provided as Enclosure 9 to the August 1, 2005 License Transfer Application (ML052160266), states that the agreement terminates when the plant ceases commercial operations. After certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor pursuant to 10 CFR 50.82(a)(2). Thus, DAEC will cease commercial operation and this License Condition will no lonqer apply.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 22 of 85 TECHNICAL SPECIFICATIONS TS SECTION 1.1, DEFINITIONS TS 1.1, "Definitions," provides defined terms that are applicable throughout the TS and TS Bases. A number of the Definitions are proposed to be deleted, because they have no relevance to and no longer apply to the permanently defueled facility status.
AVERAGE PLANAR LINEAR HEAT                             This definition is not proposed for GENERATION RATE (APLHGR)                               inclusion in the POTS because the term is not used in any POTS specification, and the reactor has been permanently defueled.
CORE ALTERATION                                        This definition is not proposed for inclusion in the POTS because the term is not used in any POTS specification. This term is no longer applicable since fuel will be permanently removed from the reactor.
CORE OPERATING LIMITS REPORT (COLR)                    This definition is not proposed for inclusion in the POTS because the term is not used in any POTS specification. This term is no longer applicable when power operation is not permitted.
DRAIN TIME                                             This definition is not proposed for inclusion in the POTS because the term is not used in any POTS specification. This term is no longer applicable since fuel will be permanently removed from the reactor.
END OF CYCLE RECIRCULATION PUMP TRIP                   This definition is not proposed for (EOC RPT) SYSTEM RESPONSE TIME                         inclusion in the POTS because the term is not used in any POTS specification. This term is no longer applicable when power operation is not permitted.
INSERVICE TESTING                                      This definition is not proposed for inclusion in the POTS because the term is not used in any POTS specification. lnservice testing in accordance with 10 CFR 50.55a

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 23 of 85 will no longer be required once the reactor is permanently shut down and defueled.
LEAKAGE                               This definition is not proposed for inclusion in the POTS because none of the structures, systems, or components (SSCs) from or into which leakage is monitored are credited in the analysis of a Fuel Handling Accident, which is the only remaining credible accident.
MINIMUM CRITICAL POWER RATIO (MCPR)   This definition is not proposed for inclusion in the POTS because the term is not used in any POTS specification. This definition only applies to an operating core.
MODE                                  This definition is not proposed for inclusion in the POTS because operating Modes are not used in any POTS specification. Modes are defined for operating or refueling conditions and do not apply to a facility in the permanently defueled condition.
PRESSURE AND                          This definition is not proposed for TEMPERATURE LIMITS                    inclusion in the POTS because REPORT (PTLR)                         the term is not used in any POTS specification. This definition only applies to an operating reactor.
RATED THERMAL POWER (RTP)             This definition is not proposed for inclusion in the POTS because the term is not used in any POTS specification. This definition only applies to an operating reactor.
REACTOR PROTECTION SYSTEM (RPS)       This definition is not proposed for RESPONSE TIME                         inclusion in the POTS because the term is not used in any POTS specification.
SHUTDOWN MARGIN (SOM)                 This definition is not proposed for inclusion in the POTS because the term is not used in any POTS specification. This definition only

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 24 of 85 applies to an operating reactor.
THERMAL POWER                                          This definition is not proposed for inclusion in the POTS because the term is not used in any POTS specification. This definition only applies to an operating reactor.
TURBINE BYPASS SYSTEM RESPONSE TIME                    This definition is not proposed for inclusion in the POTS because the term is not used in any POTS specification. Once the reactor is permanently shut down and defueled, the turbine will not be operating. Therefore, this definition does not apply.
Table 1.1-1 MODES                                      This table describes the conditional requirements for all reactor operating Modes at DAEC. This table is not proposed for inclusion in the POTS because reactor operating Modes will no longer be applicable to the permanently shut down and defueled reactor.
TS Section 1.3 COMPLETION TIMES TS 1.3 establishes the Completion Time convention and provides guidance for its use, including several illustrative examples.
Current                                       Proposed PURPOSE                                       PURPOSE The purpose of this section is to            The purpose of this section is to establish the Completion Time                establish the Completion Time convention and to provide guidance for       convention and to provide guidance for its use.                                     its use.
The following discussion and examples contain references to reactor thermal power and reactor MODES.
Specifically 1 Reguired Actions of several examples direct a change in reactor thermal power or entrv into various reactor MODES. Although these Reguired Actions do not apply to a permanently shut down and defueled

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 25 of 85 facility, the discussion and examples are retained because they continue to have illustrative value. For purposes of these examples, reactor MODES are defined below.
MODE 1 - Power Operation MODE 2 - Startup MODE 3 - Hot Shutdown, reactor coolant> 212&deg;F MODE 4 - Cold Shutdown, reactor coolants; 212&deg;F MODE 5 - Refueling Basis After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). DAEC will be authorized only to possess special nuclear material. Therefore, references to reactor thermal power and operating MODES are no longer applicable. TS 1.3, Completion Times, is revised by adding a paragraph stating that, although operating MODES and reactor thermal power no longer apply to the permanently shut down and defueled DAEC, the discussion and examples in TS 1.3 are retained for illustrative purposes. For purposes of the illustrative examples, a brief definition of reactor MODES is given.
Example 1.3-2 contains discussion of LCO 3.0.3. This discussion will be removed because LCO 3.0.3 is proposed for deletion, as discussed later in this document.
TS Section 1.4 Frequency TS Section 1.4 defines the proper use and application of Frequency requirements, including several illustrative examples.
Current                                        Proposed PURPOSE                                        PURPOSE The purpose of this section is to define       The purpose of this section is to define the proper use and application of              the proper use and application of Frequency requirements.                        Frequency requirements.
The following discussion and examples contain references to reactor thermal power and reactor MODES.
Specifically, Reguired Actions of several examples direct a change in reactor thermal power or entry into various reactor MODES. Althouah these

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 26 of 85 Reguired Actions do not apply to a permanently shut down and defueled facility, the discussion and examples are retained because they continue to have illustrative value. For purposes of these examples, reactor MODES are defined below.
MODE 1 - Power Operation MODE 2 - Startup MODE 3 - Hot Shutdown, reactor coolant> 212&deg;F MODE 4 - Cold Shutdown, reactor coolants 212&deg;F MODE 5 - Refueling Basis After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). DAEC will be authorized only to possess special nuclear material. Therefore, references to reactor thermal power and operating MODES are no longer applicable. TS 1.4, Frequency, is revised by adding a paragraph stating that, although operating MODES and reactor thermal power no longer apply to the permanently shut down and defueled DAEC, the discussion and examples in TS 1.4 are retained for illustrative purposes. For purposes of the illustrative examples, a brief definition of reactor MODES is given.
TS Section 2.0 SAFETY LIMITS (Sls)
The fuel cladding, reactor pressure vessel and primary containment are the principle barriers to prevent the release of radioactive materials to the environs during operations. TS 2.1 establishes Safety Limits to protect the integrity of these barriers during normal plant operations and anticipated transients.
Pursuant to 10 CFR 50.36(c)(1), safety limits are limiting parameters necessary to protect the physical barriers that guard against uncontrolled release of radioactivity from a nuclear reactor. TS Section 2.0 is proposed for deletion in its entirety, since the safety limits do not apply to a reactor that is in a permanently shut down and defueled condition. These specifications do not apply to the safe storage and handling of spent fuel in the SFP.
Because the TS will not be renumbered, a markup is provided to identify this section as deleted.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 27 of 85 Current TS                                  Basis for Chanae TS 2.1 Safety Limits                        TS 2.1 will be deleted.
The fuel cladding, reactor pressure vessel and primary containment are the principle barriers to prevent the release of radioactive materials to the environs during operations. TS 2.1 establishes Safety Limits to protect the integrity of these barriers during normal plant operations and anticipated transients.
Pursuant to 10 CFR 50.82(a)(2), the facility license for DAEC will no longer authorize operation of the reactor or placement or retention of fuel in the reactor. Since the Safety Limits apply to an operating reactor, they have no function in the permanently defueled condition. Therefore, the safety limits are proposed for deletion.
TS 2.2 Safety Limit Violation               TS 2.2 will be deleted.
TS 2.2 defines the action to take in the event of a violation of a SL as defined in TS 2.1.
Pursuant to 10 CFR 50.82(a)(2), the facility license for DAEC will no longer authorize operation of the reactor or placement or retention of fuel in the reactor. Since the Safety Limits apply to an operating reactor, they have no function in the permanently defueled condition. Likewise, action to take in the event of a Safety Limit non-compliance, as described in TS 2.2, is proposed for deletion.
TS 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY TS 3.0, "Limiting Condition for Operation (LCO) Applicability," establishes the general requirements applicable to all Specifications and applies at all times, unless otherwise stated. After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2).
Consequently, some LCOs are no longer applicable and some must be revised to reflect the permanently defueled condition.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 28 of 85 Current TS LCO 3.0.1                          Proposed TS LCO 3.0.1 LCOs shall be met during the MODES or         LCOs shall be met during the MODES or other specified conditions in the              other specified conditions in the Applicability, except as provided in LCO       Applicability, except as provided in LCO 3.0.2, LCO 3.0.7, LCO 3.0.8, and LCO           3.0.2, LCO 3.0.7, LCO 3.0.8, and LCO 3.0.9.                                         ~-
Basis The DAEC will no longer be authorized to operate the reactor, therefore, MODES do not apply. Deletion of LCOs 3.0.7, 3.0.8 and 3.0.9 is discussed later.
Current TS LCO 3.0.2                          Proposed TS LCO 3.0.2 Upon discovery of a failure to meet an        Upon discovery of a failure to meet an LCO, the Required Actions of the              LCO, the Required Actions of the associated Conditions shall be met, except associated Conditions shall be met, except as provided in LCO 3.0.5 and LCO 3.0.6.       as provided in LCO 3.0.5 and LCO 3.0.6.
If the LCO is met or is no longer applicable  If the LCO is met or is no longer applicable J:)rior to expiration of the specified        J:)rior to expiration of the specified Completion Time(s), completion of the         Completion Time(s), completion of the Required Action(s) is not required, unless    Required Action(s) is not required, unless otherwise stated.                             otherwise stated.
Basis Deletion of LCOs 3.0.5 is discussed later.
Current TS LCO 3.0.3                          Proposed TS LCO 3.0.3 - Deleted.
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 hour to place the unit, as applicable, in:
: a.        MODE 2 within 9 hours;
: b.        MODE 3 within 13 hours; and
: c.        MODE 4 within 37 hours.
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,

Duane Arnold Energy Center bocket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 29 of 85 completion of the actions required by LCO 3.0.3 is not required.
LCO 3.0.3 is only applicable in MODES 1, 2, and 3.
Basis LCO 3.0.3 is applicable in MODES 1, 2, and 3 only. Once the DAEC is permanently shut down and defueled, reactor operating MODES will not apply. Therefore, this LCO will no Ion er be applicable.
Current TS LCO 3.0.4                            Proposed TS LCO 3.0.4 When an LCO is not met, entry into a            When an LCO is not met, entry into a MODE or other specified condition in the        MODE or other specified condition in the Applicability shall only be made:               Applicability shall only be made:
: a.      When the associated ACTIONS to          a. When the associated ACTIONS to be entered permit continued                    be entered permit continued operation in the MODE or other*               operation in the MODE or other specified condition in the                    specified condition in the Applicability for an unlimited period         Applicability for an unlimited period of time;                                       of time;
: b.      After performance of a risk             b. After performance of a risk assessment addressing                         assessment addressing inoperable systems and                         inoperable systems and components, consideration of the               components, consideration of the results, determination of the                  results, determination of the acceptability of entering the MODE             acceptability of entering the MODE or other specified condition in the           or other specified condition in the Applicability, and establishment of           Applicability, and establishment of risk management actions, if                    risk management actions, if appropriate; exceptions to this               appropriate; exceptions to this Specification are stated in the               Specification are stated in the individual Specifications, or                  individual Specifications, or C.      When an allowance is stated in the      c. When an allowance is stated in the individual value, parameter, or other          individual value, parameter, or other Specification.                                Specification.
This Specification shall not prevent changes in MODES or other specified conditions in the Applicability that are re uired to comp! with ACTIONS or that

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 30 of 85 are part of a shutdown of the unit.             are part of a shutdown of the unit.
Basis This LCO is revised to remove references to MODES since the DAEC reactor will no longer be operating. The last paragraph is removed as it is related to MODE changes and plant shutdown, neither of which apply to the DAEC in the permanently defueled condition.
Current TS LCO 3.0.5                            Proposed TS LCO 3.0.5 - Deleted.
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.
Basis This LCO allows flexibility in declaring equipment operable to allow testing to demonstrate operability. It is not anticipated that this flexibility will be needed once the DAEC is permanently shut down and defueled.
Current TS LCO 3.0.7                            Proposed TS LCO 3.0.7 - Deleted.
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.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 31 of 85 Basis This LCO allows flexibility to permit performance of special tests and operations. It is not anticipated that this flexibility will be needed once the DAEC is permanently shut down and defueled.
Current TS LCO 3.0.8                              Proposed TS LCO 3.0.8 - Deleted.
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 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 hours; 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 hours.
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.
Basis This LCO applies only to snubbers installed at DAEC. Snubbers are designed to prevent unrestrained pipe motion under dynamic loads as might occur during a seismic event or severe transient, while allowing normal thermal motion during startup and shutdown. This function is not necessary in a permanently shut down and defueled facility. Therefore, this LCO will be deleted.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 32 of 85 Current TS LCO 3.0.9                         Proposed TS LCO 3.0.9 When one or more required barriers are        When one or more required barriers are unable to perform their related support      unable to perform their related support function(s), any supported system LCO(s)    function(s), any supported system LCO(s) are not required to be declared not met      are not required to be declared not met solely for this reason for up to 30 days     solely for this reason for up to 30 days provided that at least one train or          provided that at least one train or subsystem of the supported system is         subsystem of the supported system is OPERABLE and supported by barriers           OPERABLE and supported by barriers capable of providing their related support   capable of providing their related support function(s), and risk is assessed and        function(s), and risk is assessed and managed. This specification may be          managed. This specification may be concurrently applied to more than one train  concurrently applied to more than one train or subsystem of a multiple train or          or subsystem of a multiple train or subsystem supported system provided at       subsystem supported system provided at least one train or subsystem of the          least one train or subsystem of the supported system is OPERABLE and the         supported system is OPERABLE and the barriers supporting each of these trains or  barriers supporting each of these trains or subsystems provide their related support     subsystems provide their related support function(s) for different categories of      function(s) for different categories of initiating events.                           initiating events.
For the purposes of this specification, the  For the purposes of this specification, the High Pressure Coolant Injection system,      High Pressure Coolant Injection system, the Reactor Core Isolation Cooling system,   the Reactor Core Isolation Cooling system, and the Automatic Depressurization           and the Automatic Depressurization System are considered independent            System are considered independent subsystems of a single system.               subsystems of a single system.
If the required OPERABLE train or            If the required OPERABLE train or subsystem becomes inoperable while this      subsystem becomes inoperable while this specification is in use, it must be restored specification is in use, it must be restored to OPERABLE status within 24 hours or        to OPERABLE status within 24 hours or the provisions of this specification cannot  the provisions of this specification cannot be applied to the trains or subsystems       be applied to the trains or subsystems supported by the barriers that cannot        supported by the barriers that cannot perform their related support function(s). perform their related support function(s).
At the end of the specified period, the      At the end of the specified period, the required barriers must be able to perform    required barriers must be able to perform their related support function(s) or the     their related support function(s) or the supported system LCO (s) shall be            supported system LCO (s) shall be declared not met.                            declared not met.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 33 of 85 Basis This LCO provides guidance that will remain applicable after the DAEC is permanently defueled. The second paragraph, however, is specific to systems that will no longer be operational in the permanently defueled condition. Therefore, this paragraph will be deleted.
* Current TS SR 3.0.1                             Proposed TS SR 3.0.1 SRs shall be met during the MODES or            SRs shall be met during the MODES or other specified conditions in the               etAef-specified conditions in the Applicability for individual LCOs, unless       Applicability for individual LCOs, unless otherwise stated in the SR. Failure to          otherwise stated in the SR. Failure to meet a Surveillance, whether such failure       meet a Surveillance, whether such failure is experienced during the performance           is experienced during the performance of the Surveillance or between                  of the Surveillance or between performances of the Surveillance, shall be      performances of the Surveillance, shall be failure to meet the LCO. Failure to perform     failure to meet the LCO. Failure to perform a Surveillance within the specified             a Surveillance within the specified Frequency shall be failure to meet the LCO      Frequency shall be failure to meet the LCO except as provided in SR 3.0.3.                 except as provided in SR 3.0.3.
Surveillances do not have to be performed       Surveillances do not have to be performed on inoperable equipment or variables            on inoperable equipment or variables outside specified limits.                       outside specified limits.
Basis This LCO is revised to remove references to MODES since the DAEC reactor will no longer be operating.
Current TS SR 3.0.4                             Proposed TS SR 3.0.4 Entry into a MODE or other specified            Entry into a MODE or other specified condition in the Applicability of an            condition in the Applicability of an LCO shall only be made when the LCO's           LCO shall only be made when the LCO's Surveillances have been met within their        Surveillances have been met within their specified Frequency, except as provided         specified Frequency, except as provided by SR 3.0.3. When an LCO is not met due by SR 3.0.3. When an LCO is not met due to Surveillances not having been met,           to Surveillances not having been met, entry into a MODE or other specified            entry into a MODE or other specified condition in the Applicability shall only be    condition in the Applicability shall only be made in accordance with LCO 3.0.4.              made in accordance with LCO 3.0.4.
This provision shall not prevent entry into     This provision shall not prevent entry into MODES or other specified conditions in          MODES or other specified conditions in the Applicability that are required to          the Applicability that are required to comply with ACTIONS or that are part of a comply with ACTIONS or that are part of a shutdown of the unit.                           shutdown of the unit.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request
* Enclosure to NG-19-0055 Page 34 of 85 Basis This SR is revised to remove references to MODES and plant shutdown, neither of which apply to the DAEC in the permanently defueled condition.
TS SECTION 3.1 REACTIVITY CONTROL SYSTEMS Current                                          Proposed TS 3.1.1 - SHUTDOWN MARGIN (SOM)                 TS 3.1.1 - Deleted TS 3.1.2 - Reactivity Anomalies                  TS 3.1.2 - Deleted TS 3.1.3 - Control Rod OPERABILITY               TS 3.1.3 - Deleted TS 3.1.4 - Control Rod Scram Times               TS 3.1.4 - Deleted TS 3.1.5 - Control Rod Scram                     TS 3.1.5 - Deleted Accumulators TS 3.1.6 - Rod Pattern Control                   TS 3.1.6- Deleted TS 3.1. 7 - Standby Liquid Control (SLC)         TS 3.1.7 - Deleted System TS 3.1.8 - Scram discharge Volume                TS 3.1.8 - Deleted (SDV) Vent and Drain Valves Basis TS Section 3.1, "Reactivity Control Systems," contains LCOs that provide for appropriate control of process variables, design features, or operating restrictions required to protect the integrity of fission product barriers. The TS listed below do not apply once the reactor is permanently shut down and defueled; therefore, their corresponding LCOs (and associated SRs) are proposed to be deleted.
TS 3.1.1, "Shutdown Margin," the requirements in this TS Section are specified to ensure:
: a. The reactor can be made subcritical from all operating conditions and transients and Design Basis Accidents;
: b. The reactivity transients associated with postulated accident conditions are controllable within acceptable limits; and
: c. The reactor will be maintained sufficiently subcritical to preclude inadvertent criticality in the shutdown condition.
TS 3.1.1 is applicable in MODES 1, 2, 3, 4, and 5.
TS 3.1.2, "Reactivity Anomalies," ensures reactivity shall be controllable such that subcriticality is maintained under cold conditions and acceptable fuel design limits are not exceeded during normal operation and abnormal operational transients. Therefore, reactivity anomaly is used as a measure of the predicted versus measured (i.e.,
monitored) core reactivity during power operation. The continual confirmation of core reactivity is necessary to ensure that the Design Basis Accident (OBA) and transient safety analyses remain valid. TS 3.1.2 is applicable in MODES 1 and 2.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 35 of 85 TS 3.1.3, "Control Rod OPERABILITY," ensures that the performance of the control rods in the event of a Design Basis Accident (OBA) or transient meets the assumptions used in the safety analyses as described in the UFSAR. TS 3.1.3 is applicable in MODES 1 and 2.
TS 3.1.4, "Control Rod Scram Times," ensures the Control Rod Drive (CRD) System controls reactivity changes during Abnormal Operational Transients and Design Basis Accidents (DBAs) to ensure that specified acceptable fuel design limits are not exceeded. TS 3.1.4 is applicable in MODES 1 and 2.
TS 3.1.5, "Control Rod Scram Accumulators," requires that control rod scram accumulators are provided to ensure that the control rods scram under varying reactor conditions. The control rod scram accumulators store sufficient energy to fully insert a control rod at any reactor vessel pressure. TS 3.1.5 is applicable in MODES 1 and 2.
TS 3.1.6, "Rod Pattern Control," assures that the control rod patterns are consistent with the assumptions of the Control Rod Drop Accident (CRDA) analyses in the UFSAR when the reactor is in MODES 1 and 2 with Thermal Power ::;; 10% Reactor Thermal Power.
TS 3.1.7, "Standby Liquid Control (SLC) System," provides the capability of bringing the reactor, at any time in a fuel cycle, from full power and minimum control rod inventory (which is at the peak of the xenon transient) to a subcritical condition with the reactor in the most reactive, xenon free state without taking credit for control rod movement. In addition, the SLC System is relied upon to satisfy the requirements of 10 CFR 50.62 (Ref. 1) on Anticipated Transient Without Scram (ATWS). TS 3.1.7 is applicable in MODES 1 and 2.
TS 3.1.8, "Scram Discharge Volume (SDV) Vent and Drain Valves," this system functions to 1) limit the amount of reactor coolant discharged during a reactor scram; and 2) ensure there is sufficient volume to accept the reactor coolant discharged during a scram. TS 3.1.8 is applicable in MODES 1 and 2.
The above TSs are related to assuring the appropriate functional capability of plant equipment, and control of process variables, design features, or operating restrictions required for safe operation of the facility only when the reactor is in MODES 1 through
: 5. After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, the TS listed in the previous paragraphs, which only address their associated specific plant equipment, control of process variables, design features, or operating restrictions are no longer applicable. Based on the above, the proposed deletion of all TS in Section 3.1, including associated SRs, is acceptable with no impact on continued safe maintenance

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 36 of 85 of the facility. With the TS section deleted in its entirety, the corresponding TS Bases will also be deleted.
TS SECTION 3.2 POWER DISTRIBUTION LIMITS Current                                          Proposed TS 3.2.1 -AVERAGE PLANAR LINEAR                  TS 3.2.1 - Deleted HEAT GENERATION RATE (APLHGR)
TS 3.2.2 - MINIMUM CRITICAL POWER                TS 3.2.2 - Deleted RATIO (MCPR)
Basis TS Section 3.2, "Power Distribution Limits," contains LCOs that provide for appropriate control of process variables, design features, or operating restrictions required to protect the integrity of fission product barriers. The TS listed below do not apply once the reactor is permanently shut down and defueied; therefore, their corresponding LCOs (and associated SRs) are proposed to be deleted.
TS 3.2.1, "AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR),"
places limits on the APLHGR to ensure that the fuel design limits are not exceeded during Abnormal Operational Transients; and, also to assure that the Peak Cladding Temperature (PCT) during the postulated design basis Loss Of Coolant Accident (LOCA) does not exceed the limits specified in 10 CFR 50.46. TS 3.2.1 is applicable when reactor thermal power is~ 21.7%.
TS 3.2.2, "MINIMUM CRITICAL POWER RATIO (MCPR)," places limits on the MCPR to ensure that no fuel damage results during Abnormal Operational Transients. TS 3.2.2 is applicable when reactor thermal power is~ 21.7%.
The above TSs are related to assuring the appropriate functional capability of plant equipment, and control of process variables, design features, or operating restrictions required for safe operation of the facility only when reactor thermal power is ~ 21. 7%.
After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, the TS listed in the previous paragraphs, which only address their associated specific plant equipment, control of process variables, design features, or operating restrictions are no longer applicable. Based on the above, the proposed deletion of all TS in Section 3.2, including associated SRs, is acceptable with no impact on continued safe maintenance of the facility. With the TS section deleted in its entirety, the corresponding TS Bases will also be deleted.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 37 of 85 TS SECTION 3.3 INSTRUMENTATION Current                                           Proposed TS 3.3.1.1 - Reactor Protection System            TS 3.3.1.1 - Deleted (RPS) Instrumentation TS 3.3.1.2 - Source Range Monitor (SRM) TS 3.3.1.2 - Deleted Instrumentation Basis The RPS initiates a reactor scram when one or more monitored parameters exceed their specified limits, to preserve the integrity of the fuel cladding and the Reactor Coolant Pressure Boundary (RCPB), minimize the energy that must be absorbed following a Loss of Coolant Accident (LOCA), and prevent inadvertent criticality. This can be accomplished either automatically or manually.
TS 3.3.1.1, "Reactor Protection System (RPS) Instrumentation," ensures safe operation of the reactor by specifying Limiting Safety System Settings (LSSS) in terms of parameters directly monitored by the RPS, as well as LCOs on other reactor system parameters and equipment performance. TS 3.3.1.1 is applicable in MODES 1, 2, and 5 as specified in TS Table 3.3.1.1-1.
The SRMs provide the operator with information relative to the neutron flux level at very low flux levels in the reactor core. As such, TS 3.3.1.2, "Source Range Monitor (SRM)
Instrumentation," is used by the operator to monitor the approach to criticality and determine when criticality is achieved. TS 3.3.1.2 is applicable in MODES 2, 3, 4, and 5 as specified in TS Table 3.3.1.2-1.
The above TSs are related to assuring the appropriate functional capability of plant equipment, and control of process variables, design features, or operating restrictions required for safe operation of the facility only when the reactor is in MODES 1 through
: 5. After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement o"r retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, the TS listed in the previous paragraphs, which only address their associated restrictions are no longer applicable. Based on the above, the proposed deletion of all TS in Section 3.3.1, including associated SRs, is acceptable with no impact on continued safe maintenance of the facility. With the TS section deleted in its entirety, the corresponding TS Bases will also be deleted.
Current                                           Proposed TS 3.3.2.1 - Control Rod Block                   TS 3.3.2.1 - Deleted Instrumentation

J Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 38 of 85 Basis Control rods provide the primary means for control of reactivity changes. TS 3.3.2.1, "Control Rod Block Instrumentation" ensures that specified fuel design limits are* not exceeded for postulated transients and accidents. TS 3.3.2.1 is applicable at various reactor thermal power levels and with the reactor: mode switch in the shutdown position as specified in TS Table 3.3.2.1-1.
The above TS is related to assuring the appropriate functional capability of plant
.equipment, and control of process variables, design features, or operating restrictions required for safe operation of the facility only when the reactor is in MODES 1 through
: 5. After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, the TS listed in the previous paragraphs, which only address their associated specific plant equipment, control of process variables, design features, or operating restrictions are no longer applicable. Based on the above, the proposed deletion of all TS in Section 3.3.2, including associated SRs, is acceptable with no impact on continued safe maintenance of the facility. With the TS section deleted in its entirety, the corresponding TS Bases will also be deleted.
Current                                          Proposed TS 3.3.3.1 - Post Accident Monitoring            TS 3.3.3.1 - Deleted .
(PAM) Instrumentation TS 3.3.3.2 - Remote Shutdown System              TS 3.3.3.2 - Deleted Basis The primary purpose of the PAM instrumentation is to display plant variables that provide information required by the control room operators during accident situations.
This information provides the necessary support for the operator to .determine that the actions automatically initiated by the Engineered Safety .Features (ESF) equipment have successfully accomplished their safety functions for Design Basis Events.
TS 3.3.3.1, "Post Accident Monitoring (PAM) Instrumentation," ensures that there is sufficient information available on selected plant parameters to monitor and assess plant status and behavior following an accident. TS 3.3.3.1 is applicable in MODES 1 and 2.
TS 3.3.3.2, "Remote Shutdown System," this system provides the control room operator with sufficient instrumentation and controls to place and maintain the plant in a safe shutdown condition from a lqcation other than the control room. This capability is necessary to protect against the possibility of the control room becoming inaccessible.
TS 3.3.3.2 is applicable in MODES 1 and 2.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 39 of 85 The above TSs are related to assuring the appropriate functional capability of plant equipment, and control of process variables, design features, or operating restrictions required for safe operation of the facility only when the reactor is in MODES 1 and 2.
After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, the TS listed in the previous paragraphs, which only address their associated specific plant equipment, control of process variables, design features, or operating restrictions are no longer applicable. Based on the above, the proposed deletion of all TS in Section 3.3.3, including associated SRs, is acceptable with no impact on continued safe maintenance of the facility. With the TS section deleted in its entirety, the corresponding TS Bases will also be deleted.
Current                                           Proposed TS 3.3.4.1 - End of Cycle Recirculation           TS 3.3.4.1 - Deleted Pump Trip (EOC-RPT) Instrumentation TS 3.3.4.2 - Anticipated Transient Without        TS 3.3.4.2 - Deleted Scram Recirculation Pump Trip (ATWS-RPT) Instrumentation Basis TS 3.3.4.1, "End of Cycle Recirculation Pump Trip (EOC-RPT) Instrumentation,"
initiates a Recirculation Pump trip to reduce the peak reactor pressure and power resulting from turbine trip or generator load rejection transients to provide additional margin to core thermal MCPR Safety Limits (SLs). TS 3.3.4.1 is applicable when reactor thermal power is;;:: 26%.
The Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) System initiates an RPT, adding negative reactivity, following events in which a scram fails to occur, to lessen the effects of an ATWS event. Tripping the recirculation pumps adds negative reactivity from the increase in steam voiding in the core area as core flow decreases. When the Reactor Vessel Water Level - Low Low or the Reactor Steam Dome Pressure - High setpoint is reached, the recirculation pump motor breakers trip.
TS 3.3.4.2, "Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT)
Instrumentation" ensures initiation of an RPT. TS 3.3.4.2 is applicable in MODE 1.
The above TSs are related to assuring the appropriate functional capability of plant equipment, and control of process variables, design features, or operating restrictions required for safe operation of the facility only when the reactor is in MODE 1. After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, the TS listed in the previous paragraphs, which only address their associated specific plant equipment,

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 40 of 85 control of process variables, design features, or operating restrictions are no longer applicable. Based on the above, the proposed deletion of all TS in Section 3.3.4, including associated SRs, is acceptable with no impact on continued safe maintenance of the facility. With the TS section deleted in its entirety, the corresponding TS Bases will also be deleted.
Current                                          Proposed TS 3.3.5.1 - Emergency Core Cooling              TS 3.3.5.1 - Deleted System (ECCS) Instrumentation TS 3.3.5.2 - Reactor Pressure Vessel             TS 3.3.5.2 - Deleted (RPV) Water Inventory Control Instrumentation TS 3.3.5.3 - Reactor Core Isolation              TS 3.3.5.3 - Deleted Cooling (RCIC) Instrumentation Basis TS 3.3.5.1, "Emergency Core Cooling System (ECCS) Instrumentation," ensures initiation of appropriate responses from emergency systems to ensure that the fuel is adequately cooled in the event of a design basis accident or transient. For most Abnormal Operational Transients and Design Basis Accidents (DBAs), a wide range of dependent and independent parameters are monitored. TS 3.3.5.1 is applicable in MODES 1, 2, and 3 in accordance with TS Table 3.3.5.1-1.
TS 3.3.5.2, "Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation,"
supports the requirements of LCO 3.5.2, "Reactor Pressure Vessel (RPV) Water Inventory Control," and the definition of DRAIN TIME. The RPV Water Inventory Control Instrumentation supports operation of core spray (CS) and low pressure coolant injection (LPCI). TS 3.3.5.2 is applicable in MODES 4 and 5 and when automatic isolation of an associated penetration flow path is credited in calculating DRAIN TIME in accordance with TS Table 3.3.5.2-1.
TS 3.3.5.3, "Reactor Core Isolation Cooling (RCIC) Instrumentation," ensures initiation of actions to ensure adequate core cooling when the reactor vessel is isolated from its primary heat sink (the main condenser) and normal coolant makeup flow from the Reactor Feedwater System is unavailable, such that initiation of the low pressure Emergency Core Cooling Systems (ECCS) pumps does not occur. TS 3.3.5.3 is applicable in MODE 1, and in MODES 2 and 3 with reactor steam dome pressure >
150psig.
The above TSs are related to assuring the appropriate functional capability of plant equipment, and control of process variables, design features, or operating restrictions required for safe operation of the facility only when the reactor is in MODES 1 through
: 5. After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no lonQer authorize operation of the reactor or placement or

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 41 of 85 retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, the TS listed in the previous paragraphs, which only address their associated specific plant equipment, control of process variables, design features, or operating restrictions are no longer applicable. Based on the above, the proposed deletion of all TS in Section 3.3.5, including associated SRs, is acceptable with no impact on continued safe maintenance of the facility. With the TS section deleted in its entirety, the corresponding TS Bases will also be deleted.
Current                                           Proposed TS 3.3.6.1 - Primary Containment                  TS 3.3.6.1 - Deleted Isolation Instrumentation TS 3.3.6.2 - Secondary Containment                TS 3.3.6.2 - Deleted Isolation Instrumentation TS 3.3.6.3 - Low-Low Set (LLS)                    TS 3.3.6.3 - Deleted Instrumentation Basis TS 3.3.6.1, "Primary Containment Isolation Instrumentation," initiates automatic closure of appropriate Primary Containment Isolation Valves (PCIVs) to limit fission product release during and following postulated Design Basis Accidents. Primary containment isolation within the time limits specified for those isolation valves designed to close automatically ensures that the release of radioactive material to the environment will be consistent with the assumptions used in the analyses for a OBA.TS 3.3.6.1 is applicable in MODES 1, 2 and 3 in accordance with TS Table 3.3.6.1-1.
TS 3.3.6.2, "Secondary Containment Isolation Instrumentation," initiates automatic closure of appropriate Secondary Containment Isolation Valves and/or Dampers (SCIV/Ds) and starts the Standby Gas Treatment (SBGT) System to limit fission product release during and following postulated Design Basis Accidents. Secondary containment isolation and establishment of vacuum with the SBGT System ensures that fission products that leak from primary containment following a OBA, are released outside primary containment, or are released during certain operations when primary containment is not required are maintained within applicable limits. TS 3.3.6.2 is applicable in MODES 1, 2 and 3 in accordance with TS Table 3.3.6.2-1.
TS 3.3.6.3, "Low-Low Set (LLS) Instrumentation," ensures the Safety Relief Valve (SRV) discharge lines are not adversely impacted by thrust loads caused by valve actuation. LLS Instrumentation also mitigates the effects of postulated pressure loads on the torus shell or suppression pool by preventing multiple actuations in rapid succession of the SRVs subsequent to their initial actuation; TS 3.3.6.3 is applicable in MODES 1, 2, and 3.
The above TSs are related to assuring the appropriate functional capability of plant equipment, and control of process variables, desiQn features, or operatinQ restrictions

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 42 of 85 required for safe operation of the facility only when the reactor is in MODES 1 through
: 3. After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, the TS listed in the previous paragraphs, which only address their associated specific plant equipment, control of process variables, design features, or operating restrictions are no longer applicable. Based on the above, the proposed deletion of all TS in Section 3.3.6, including associated SRs, is acceptable with no impact on continued safe maintenance of the facility. With the TS section deleted in its entirety, the corresponding TS Bases will also be deleted.
Current                                          Proposed TS 3.3.7.1 - Standby Filter Unit (SFU)           TS 3.3.7.1 - Standby Filter Unit (SFU)
Instrumentation                                  Instrumentation APPLICABILITY:                                   APPLICABILITY:
MODES 1, 2, and 3,                               MODES 1, 2, and 3, During movement of irradiated fuel               During movement of irradiated fuel assemblies in the secondary                     assemblies in the secondary containment,                                    containment, Durin CORE ALTERATIONS.
Basis The SFU System is designed to provide a radiologically controlled environment to ensure the habitability of the control room for the safety of control room operators under all plant conditions.
TS 3.3.7.1, "Standby Filter Unit (SFU) Instrumentation," ensures automatic action to pressurize the control building envelope to minimize the consequences of radioactive
* material in the control building envelope. TS 3.3.7.1 is required in MODES 1, 2, and 3, during movement of irradiated fuel in the secondary containment, and during CORE ALTERATIONS.
The above TS is proposed to be maintained with a change in the required applicability.
After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, the requirement for the SFU System to be operable in MODES 1, 2, and 3, as well as during CORE ALTERATIONS will be deleted as these conditions will not occur at the DAEC once it is permanently defueled.
The remaining TS 3.3.7.1 and associated SRs are retained unchanged. The TS Bases will be updated to be consistent with the proposed TS 3.3.7.1.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 43 of 85 Current                                         Proposed TS 3.3.8.1 - Loss of Power (LOP)                TS 3.3.8.1 - Loss of Power (LOP)
Instrumentation                                 Instrumentation APPLICABILITY:                                 APPLICABILITY:
MODES 1, 2, and 3,                             MODES 1, 2, and 3, When the associated Diesel                     When the associated Diesel Generator is required to be Operable           Generator is required to be Operable by LCO 3.8.2, "AC Sources -                    by LCO 3.8.2, "AC Sources-Shutdown."                                     Shutdown."
TS 3.3.8.2 - Reactor Protection System          TS 3.3.8.2 - Deleted.
(RPS) Electric Power Monitors Basis TS 3.3.8.1, "Loss of Power (LOP) Instrumentation," monitors the 4.16 KV emergency bus voltages and the Startup and Standby Transformer secondary winding voltages.
This monitoring ensures that if insufficient power is available, the buses are disconnected from the offsite power sources and connected to the onsite Diesel Generator (DG) power sources.
The above TS is proposed to be maintained with a change in the required applicability.
After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, the requirement for the LOP Instrumentation to be operable in MODES 1, 2, and 3 will be deleted as these conditions will not occur at the DAEC once it is permanently defueled.
The requirement for this TS LCO to be met when the associated Diesel Generator is required, by LCO 3.8.2, to be Operable will be maintained since TS 3.8.2, "AC Sources" is being retained in the POTS. The remaining TS 3.3.8.1 and associated SRs are retained unchanged. The TS Bases will be updated to be consistent with the proposed TS 3.3.8.1.
TS 3.3.8.2, "Reactor Protection System (RPS) Electric Power Monitors," provides protection of electrical loads supplied from the RPS bus against unacceptable voltage and frequency conditions. TS 3.3.8.2 is applicable in MODES 1 and 2 and in MODES 3, 4, and 5 with any control rod withdrawn from a core cell containing one or more fuel assemblies.
TS 3.3.8.2 assures the appropriate functional capability of plant equipment, and control of process variables, design features, or operating restrictions required for safe operation of the facility only when the reactor is in MODES 1 through 5. After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 44 of 85 fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, TS 3.3.8.2, which only addresses associated specific plant equipment, control of process variables, design features, or operating restrictions are no longer applicable. Based on the above, the proposed deletion TS 3.3.8.2, including associated SRs, is acceptable with no impact on continued safe maintenance of the facility. With the TS section deleted in its entirety, the corresponding TS Bases will also be deleted.
TS SECTION 3.4 REACTOR COOLANT SYSTEM (RCS)
Current                                        Proposed TS 3.4.1 - Recirculation Loops Operating       TS 3.4.1 - Deleted TS 3.4.2 - Jet Pumps                           TS 3.4.2 - Deleted TS 3.4.3 - Safety Relief Valves (SRVs)         TS 3.4.3 - Deleted and Safety Valves (SVs)
TS 3.4.4 - RCS Operational LEAKAGE             TS 3.4.4 - Deleted TS 3.4.5 - RCS Leakage Detection               TS 3.4.5 - Deleted Instrumentation TS 3.4.6 - RCS Specific Activity               TS 3.4.6 - Deleted TS 3.4.7 - Residual Heat Removal (RHR)         TS 3.4. 7 - Deleted Shutdown Cooling System - Hot Shutdown TS 3.4.8 - Residual Heat Removal (RHR)         TS 3.4.8 - Deleted Shutdown Cooling System - Cold Shutdown TS 3.4.9 - RCS Pressure and                    TS 3.4.9 - Deleted Temperature (Pff) Limits TS 3.4.10 - Reactor Steam Dome                 TS 3.4 ..10- Deleted Pressure Basis TS 3.4, "Reactor Coolant System (RCS)," contains LCOs that provide for appropriate control of process variables, design features, or operating restrictions needed for appropriate functional capability of RCS equipment required for safe operation of the facility.
The TS listed below do not apply once the reactor is permanently defueled; therefore, their corresponding LCOs, and associated SRs, are proposed for deletion.
TS 3.4.1, "Recirculation Loops Operating," is applicable in MODES 1 and 2. The Reactor Coolant Recirculation System is designed to provide a forced coolant flow through the core to remove heat from the fuel. The recirculation system also controls reactivity over a wide span of reactor power by varying the recirculation flow rate to control the void content of the reactor coolant. It consists of two recirculation pump

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19..:0055 Page 45 of 85 loops external to the reactor vessel.
TS 3.4.2, "Jet Pumps," is applicable in MODES 1 and 2. The jet pumps are part of the Reactor Coolant Recirculation System and are designed to provide forced circulation through the core to remove heat from the fuel.
TS 3.4.3, "Safety Relief Valves (SRVs) and Safety Valves (SVs)," ensures the reactor vessel is protected from overpressure during upset conditions by self-actuated safety valves. As part of the nuclear pressure relief system, the SRVs and SVs are designed such that peak pressure in the nuclear system will not exceed the ASME Code limits for the Reactor Coolant Pressure Boundary (RCPB). TS 3.4.3 is applicable in MODES 1, 2, and 3.
TS 3.4.4, "RCS Operational LEAKAGE," is applicable in MODES 1, 2, and 3. Limits on RCS operational LEAKAGE are required to ensure appropriate action is taken before the integrity of the RCPB is impaired. This LCO specifies the types and limits of LEAKAGE to ensure protection of the RCS pressure boundary.
TS 3.4.5, "RCS Leakage Detection Instrumentation," provides a means for detecting and, to the extent practical, identifying the location of the source of RCS leakage.
Systems for separating the LEAKAGE of an identified source from an unidentified source are necessary to provide prompt and quantitative information to the operators to permit them to take immediate corrective action. TS 3.4.5 is applicable in MODES 1, 2, and 3.
TS 3.4.6, "RCS Specific Activity," provides limits on the maximum allowable level of radioactivity in the reactor coolant to ensure that in the event of a release of any radioactive material to the environment during a OBA, radiation doses are maintained within the limits of 10 CFR 50.67. TS 3.4.6 is applicable in MODE 1, and in MODES 2 and 3 with any main steam line not isolated.
TS 3.4.7, "Residual Heat Removal (RHR) Shutdown Cooling System - Hot Shutdown,"
ensures decay heat, produced by irradiated fuel in the shutdown reactor core, is removed to reduce the temperature of the reactor coolant to :5 212&deg;F. TS 3.4.7 is applicable in MODE 3 with reactor steam dome pressure less than the RCIC Steam Supply Line Pressure - Low isolation pressure.
TS 3.4.8, "Residual Heat Removal (RHR) Shutdown Cooling System - Cold Shutdown,"
also ensures decay heat, produced by irradiated fuel in the shutdown reactor core, is removed to reduce the temperature of the reactor coolant to :5 212&deg;F; however, TS 3.4.8 is applicable in MODE 4.
TS 3.4.9, "RCS Pressure and Temperature (PIT) Limits," ensures the pressure and

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 46 of 85 temperature changes during RCS heatup and cooldown remain within the design assumptions and the stress limits for cyclic operation. TS 3.4.9 is applicable at all times.
TS 3.4.10, "Reactor Steam Dome Pressure," ensures compliance with an assumed initial condition of design basis accidents and transients and is conservative to the value used in the determination of compliance with reactor pressure vessel overpressure protection criteria. TS 3.4.10 is applicable in MODES 1 and 2.
The above TS$ are related to assuring the appropriate functional capability of plant equipment, and control of process variables, design features, or operating restrictions required for safe operation of the facility only when the reactor is in MODES 1 through
: 4. TS 3.4.9 applies to pressure and temperature limits of the reactor regardless of MODE. After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2).
Therefore, the TS listed in the previous paragraphs, which only address their associated specific plant equipment, control of process variables, design features, or operating restrictions are no longer applicable. With the reactor in a permanently shut down and defueled condition, reactor pressure and temperature limits do not apply. Based on the above, the proposed deletion of all TS in Section 3.4, including associated SRs, is acceptable with no impact on continued safe maintenance of the facility. With the TS section deleted in its entirety, the corresponding TS Bases will also be deleted.
TS SECTION 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC)
SYSTEM
*Current                                          Proposed TS 3.5.1 - ECCS - Operating                      TS 3.5.1 - Deleted TS 3.5.2 - Reactor Pressure Vessel (RPV) TS 3.5.2 - Deleted Water Inventory Control TS 3.5.3 - RCIC System                           TS 3.5.3 - Deleted Basis TS 3.5, "Emergency Core Cooling Systems (ECCS), RPV Water Inventory Control, and Reactor Core Isolation Cooling (RCIC)," contains LCOs that provide for appropriate control of process variables, design features, or operating restrictions needed for appropriate functional capability of RCS equipment required for safe operation of the facility.
The TS listed below do not apply once the reactor is permanently defueled; therefore, their corresponding LCOs, and associated SRs, are proposed for deletion. Similarly, the corresponding TS Bases are also proposed for deletion.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 47 of 85 TS 3.5.1, "ECCS - Operating," is applicable in MODE 1 and in MODES 2 and 3, except High Pressure Coolant Injection (HPCI) is not required to be operable with the reactor steam dome pressure :5 150 psig and Automatic Depressurization System (ADS) valves are not required to be operable with the reactor steam dome pressure :5 100 psig. The ECCS is designed to limit the release of radioactive materials to the environment following a Loss of Coolant Accident (LOCA). The ECCS network consists of the High Pressure Coolant Injection (HPCI) System, the Core Spray (CS) System, the Low Pressure Coolant Injection (LPCI) mode of the Residual Heat Removal (RHR) System, and the ADS.
TS 3.5.2, "Reactor Pressure Vessel (RPV) Water Inventory Control," ensures the RPV water level remains above the top of the active irradiated fuel at all times to prevent elevated fuel cladding temperatures when the reactor is in cold shutdown or refueling.
TS 3.5.2 is applicable in MODES 4 and 5.
TS 3.5.3, "RCIC System," in MODE 1 and in MODES 2 and 3 with reactor steam dome pressure greater than 150 psig. The RCIC System is designed to operate either automatically or manually following Reactor Pressure Vessel (RPV) isolation accompanied by a loss of coolant flow from the Feedwater System to provide adequate*
core cooling and control of the RPV water level.
The above TSs are related to assuring the appropriate functional capability of plant equipment, and control of process variables, design features, or operating restrictions required for safe operation of the facility only when the reactor is in MODES 1 through
: 5. After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, the TS listed in the previous paragraphs, which only address their associated specific plant equipment, control of process variables, design features, or operating restrictions are no longer applicable. Based on the above, the proposed deletion of all TS in Section 3.5, including associated SRs, is acceptable with no impact on continued safe maintenance of the facility. With the TS section deleted in its entirety, the corresponding TS Bases will also be deleted.
TS SECTION 3.6 CONTAINMENT SYSTEMS Current                                          Proposed TS 3.6.1.1 - Primary Containment                 TS 3.6.1.1 - Deleted TS 3.6.1.2- Primary Containment Air Lock TS 3.6.1.2 - Deleted TS 3.6.1.3 - Primary Containment                 TS 3.6.1.3 - Deleted Isolation Valves (PCIVs)
TS 3.6.1.4 - Drywell Air Temperature             TS 3.6.1.4 - Deleted TS 3.6.1.5 - Low-Low Set (LLS) Valves            TS 3.6.1.5 - Deleted

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 48 of 85 TS 3.6.1.6 - Reactor Building-to-                TS 3.6.1.6 - Deleted Suppression Chamber Vacuum Breakers TS 3.6.1.7 - Suppression Chamber-to-             TS 3.6.1.7 - Deleted Drywell Vacuum Breakers Basis TS 3.6.1.1, "Primary Containment," is applicable in MODES 1, 2, and 3. The function of the primary containment is to isolate and contain fission products released from the Reactor Primary System following a Loss of Coolant Accident (LOCA) and to confine the postulated release of radioactive material.
TS 3.6.1.2, "Primary Containment Air Lock," allows personnel access to the drywell and to provide primary containment isolation during the process of personnel entering and exiting the drywell. TS 3.6.1.2 is applicable in MODES 1, 2, and 3.
TS 3.6.1.3, "Primary Containment Isolation Valves (PCIVs)," ensures the PCIVs function to limit fission product release during and following postulated DBAs. TS 3.6.1.3 is applicable in MODES 1, 2, and 3.
TS 3.6.1.4, "Drywell Air Temperature," limits the drywell average air temperature to a value below that used in the UFSAR Chapter 15 safety analyses. TS 3.6.1.4 is applicable in MODES 1, 2, and 3.
TS 3.6.1.5, "Low-Low Set (LLS) Valves," is applicable in MODES 1, 2, and 3. The LLS valves open and stay open so that cycling more than one SRV is prevented on subsequent actuations. This mitigates the induced loads on the containment and the thrust loads on the SRV discharge lines by increasing the time between subsequent SRV actuations. Therefore, the LLS function prevents excessive short duration SRV cycles that would occur with valve actuation at the relief setpoint.
TS 3.6.1.6, "Reactor Building-to-Suppression Chamber Vacuum Breakers," ensures vacuum is relieved when primary containment depressurizes below reactor building pressure. TS 3.6.1.6 is applicable in MODES 1, 2, and 3.
TS 3.6.1.7, "Suppression Chamber-to-Drywell Vacuum Breakers," relieve vacuum in the drywell. TS 3.6.1.7 is applicable in MODES 1, 2, and 3.
The above TSs are related to assuring the appropriate functional capability of plant ,
equipment, and control of process variables, design features, or operating restrictions required for safe operation of the facility only when the reactor is in MODES 1 through
: 3. After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, the TS

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 49 of 85 listed in the previous paragraphs, which only address their associated restrictions are no longer applicable. Based on the above, the proposed deletion of all TS in Section 3.6.1, including associated SRs, is acceptable with no impact on continued safe maintenance of the facility. With the TS section deleted in its entirety, the corresponding TS Bases will also be deleted.
Current                                          Proposed TS 3.6.2.1 - Suppression Pool Average            TS 3.6.2.1 - Deleted Temperature TS 3.6.2.2 - Suppression Pool Water              TS 3.6.2.2 - Deleted Level TS 3.6.2.3 - Residual Heat Removal               TS 3.6.2.3 - Deleted (RHR) Suppression Pool Cooling TS 3.6.2.4 - Residual Heat Removal               TS 3.6.2.4 - Deleted (RHR) Suppression Pool Spray Basis TS 3.6.2.1,  "Suppression    Pool Average  Temperature,"   ensures limitations on the suppression pool average temperature are enforced to provide assurance that the containment conditions assumed for the safety analyses are met. TS 3.6.2.1 is applicable in MODES 1, 2, and 3.
TS 3.6.2.2, "Suppression Pool Water Level," ensures limitations on the suppression pool water level are enforced to provide assurance that the primary containment conditions assumed for the safety analyses are met. TS 3.6.2.1 is applicable in MODES 1, 2, and 3.
TS 3.6.2.3, "Residual Heat Removal (RHR) Suppression Pool Cooling," is required in MODES 1, 2, and 3. The RHR Suppression Pool Cooling (SPC) System can be used to remove heat from the suppression pool following a design basis accident.
TS 3.6.2.4, "Residual Heat Removal (RHR) Suppression Pool Spray," reduces pressure in the suppression chamber. Although not required by the accident analysis to ensure that the suppression chamber remains within the analyzed design pressure and temperature limits, condensing the steam in the suppression chamber airspace reduces the long-term pressure response in the primary containment. TS 3.6.2.4 is applicable in MODES 1, 2, and 3.
The above TSs are related to assuring the appropriate functional capability of plant equipment, and control of process variables, design features, or operating restrictions required for safe operation of the facility only when the reactor is in MODES 1 through
: 3. After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 50 of 85 retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, the TS listed in the previous paragraphs, which only address their associated specific plant equipment, control of process variables, design features, or operating restrictions are no longer applicable. Based on the above, the proposed deletion of all TS in Section 3.6.2, including associated SRs, is acceptable with no impact on continued safe maintenance of the facility. With the TS section deleted in its entirety, the corresponding TS Bases will also be deleted.
Current                                           Proposed TS 3.6.3.1 - Containment Atmosphere               TS 3.6.3.1 - Previously deleted by Dilution (CAD) System                                           Amendment 265 TS 3.6.3.2 - Primary Containment Oxygen TS 3.6.3.2 - Deleted Concentration Basis TS 3.6.3.2, "Primary Containment Oxygen Concentration," maintains the containment atmosphere with a low concentration of oxygen (i.e., < 4.0 volume percent), rendering it inert to combustion. TS 3.6.3.2 is applicable in MODE 1 from 24 hours after reactor thermal power is > 15% following startup and to 24 hours prior to reducing reactor thermal power to < 15% prior to reactor shutdown.
TS 3.6.3.2 is related to assuring the appropriate functional capability of plant equipment, and control of process variables, design features, or operating restrictions required for safe operation of the facility only when the reactor is in MODE 1. After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, the TS listed in the previous paragraphs, which only address their associated specific plant equipment, control of process variables, design features, or operating restrictions are no longer applicable.
Based on the above, the proposed deletion of all TS in Section 3.6.3, including associated SRs, is acceptable with no impact on continued safe maintenance of the facility: With the TS section deleted in its entirety, the corresponding TS Bases will also be deleted.
Current                                           Proposed TS 3.6.4.1 - Secondary Containment                TS 3.6.4.1 - Deleted TS 3.6.4.2 - Secondary Containment                TS 3.6.4.2 - Deleted Isolation Valves/Dampers (SCIV/Ds)
TS 3.6.4.3 - Standby Gas Treatment                TS 3.6.4.3 - Deleted (SBGT) System Basis TS 3.6.4.1, "Secondary Containment," is applicable in MODES 1, 2, and 3. The function of the secondary containment is to contain, dilute, and hold up fission products that may

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 51 of 85 leak from primary containment following a Design Basis Accident.
TS 3.6.4.2, "Secondary Containment Isolation Valves/Dampers (SCIV/Ds)," limits fission product release during and following postulated Design Basis Accidents. TS 3.6.4.2 is applicable in MODES 1, 2, and 3.
TS 3.6.4.3, "Standby Gas Treatment (SBGT) System," ensures that radioactive materials that leak from the primary containment into the secondary containment following a Design Basis Accident (OBA) are filtered and adsorbed prior to exhausting to the environment. TS 3.6.4.3 is applicable in MODES 1, 2, and 3.
The above TSs are related to assuring the appropriate functional capability of plant equipment, and control of process variables, design features, or operating restrictions required for safe operation of the facility only when the reactor is in MODES 1 through
: 3. After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, the TS listed in the previous paragraphs, which only address their associated specific plant equipment, control of process variables, design features, or operating restrictions are no longer applicable. Based on the above, the proposed deletion of all TS in Section 3.6.4, including associated SRs, is acceptable with no impact on continued safe maintenance of the facility. With the TS section deleted in its entirety, the corresponding TS Bases will also be deleted.
TS SECTION 3.7    PLANT SYSTEMS Current                                          Proposed TS 3.7.1 - Residual Heat Removal Service         TS 3.7.1 - Deleted Water (RHRSW) System TS 3.7.2- River Water Supply (RWS)               TS 3.7.2 - Deleted System and Ultimate Heat Sink (UHS)
TS 3.7.3- Emergency Service Water                TS 3.7.3 - Deleted System (ESW)
TS 3.7.4 - Standby Filter Unit (SFU)             TS 3.7.4 - Retain with revisions System TS 3.7.5 - Control Building Chiller (CBC)        TS 3.7.5 - Retain with revisions System TS 3.7.6- Main Condenser Offgas                  TS  3.7.6 -  Deleted TS 3.7.7 - Main Turbine Bypass System            TS  3.7.7 -  Deleted TS 3.7.8 - Spent Fuel Pool Water Level           TS  3.7.8 -  Retain with revisions TS 3.7.9 - Control Building/Standby Gas          TS  3.7.9 -  Deleted Treatment Instrument Air System

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 52 of 85 Basis TS 3.7, "Plant Systems," contains LCOs that provide for appropriate control of process variables, design features, or operating restrictions needed for appropriate functional capability of equipment required for safe operation of the facility.
The TS proposed for deletion are listed below. Once the reactor is permanently shut down and defueled, these TS do not apply; therefore, their corresponding LCOs, and associated SRs, are proposed for deletion. The TS proposed to be retained, with revisions, are discussed after the deletions.
TS 3.7.1, "Residual Heat Removal Service Water (RHRSW) System," is applicable in MODES 1, 2, and 3. The RHRSW System is designed to provide cooling water for the Residual Heat Removal (RHR) System heat exchangers, required for a safe reactor shutdown following a Design Basis Accident (OBA) or transient.
TS 3.7.2, "River Water Supply (RWS) System and Ultimate Heat Sink (UHS)," is applicable in MODES 1, 2, and 3. The RWS System provides cooling water required support for various systems required for a safe reactor shutdown following a Design Basis Accident (OBA) or transient. The UHS ensures sufficient water inventory is available for the RWS System. Note: RWS and the UHS are support systems required to mitigate the consequences of a FHA. This will be reflected in the TS Bases.
TS 3.7.3, "Emergency Service Water System (ESW)," is applicable in MODES 1, 2, and
: 3. The ESW System provides cooling water for the removal of heat from equipment and various minor heat loads required for a safe reactor shutdown following a Design Basis Accident (OBA) or transient. The ESW System also provides cooling to unit components, as desired, during normal operation. Note: ESW supports systems required to mitigate the consequences of a FHA. This will be reflected in the TS Bases.
TS 3.7.6, "Main Condenser Offgas," reduces the gaseous radwaste emissions during plant operation. TS 3.7.6 is applicable in MODE 1 and in MODES 2 and 3 with any main steam line not isolated and Steam Jet Air Ejectors in operation.
TS 3.7.7, "Main Turbine Bypass System," is applicable when reactor thermal power is~
21.7%. The Main Turbine Bypass System is designed to control steam pressure when reactor steam generation exceeds turbine requirements during unit startup, sudden load reduction, and cooldown. It allows excess steam flow from the reactor to the condenser without going through the turbine.
TS 3.7.9, "Control Building/Standby Gas Treatment Instrument Air System," provides compressed air to systems and components that function to limit fission product release and control the environment from which the unit can be safely operated following a OBA. TS 3.7.9 is applicable in MODES 1, 2, and 3. Note: This system supports

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 53 of 85 systems required to mitigate the consequences of a FHA. This will be reflected in the TS Bases.
The above TSs are related to assuring the appropriate functional capability of plant equipment, and control of process variables, design features, or operating restrictions required for safe operation of the facility only when the reactor is in MODES 1 through
: 3. After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, the TS listed in the previous paragraphs, which only address their associated specific plant equipment, control of process variables, design features, or operating restrictions are no longer applicable. Based on the above, the proposed deletion of the above TS in Section 3.7, including the associated SRs, is acceptable with no impact on continued safe maintenance of the facility. With the TS sections above deleted, the corresponding TS Bases will also be deleted.
The following TS contain LCOs for plant equipment, and control of process variables, design features, or operating restrictions required for safe maintenance of the facility during a fuel handling accident as described is the UFSAR. As such, these TS will be retained in the POTS and revised to align with the permanently defueled condition. As follows:

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 54 of 85 3.7 PLANT SYSTEMS 3.7 .4 Standby Filter Unit (SFU} System LCO 3.7.4                            Two SFU subsystems shall be OPERABLE.
                                                                  -NOTE The control building envelope (CBE) boundary may be opened intermittently under administrative control.
APPLICABILITY:                       MGQeS ~. ~. aREI 3, During movement of irradiated fUel assemblies in the secondary containment, 91:!Fing GGRe Ab+ER/t.+IGNS.                                          .
ACTIONS CONDITION                                REQUIRED ACTION                   COMPLETION TIME A.      One SFU subsystem                          A.1    Restore SFU subsystem          7days inoperable for reasons                             to OPERABLE status.
other than CoRdition B.
I\
      ~       r\n~ - - - - ~- ~Cf I
              - - - . *~-
                                        -- -             S4     Initiate actions to implement mitigating Immediately in-       -       *"
actions.
                   *-*__ __ .. ""nnc:~  l"DC:
AN&#xa3;).
                    -F
                          ~---
                           --*J
                                   "'.)
84     l.'er:if:y: mitigating astions 24 )10Uffi ensure Gl3 e occupant e~ssures te FaEHele~ical hazards will net exceed Ian inoperable CBE ~                                            limits aREI 1.iemy ey boundary                                                       ;;idministratiw mg;;ins tAat G~E;; QGGYpfJAtS arg pmteGted ffem smeke and chemical h~rds.
ANG 8:3    Restore Gl3e eoundaPJ          90 days te GPeRlt,13be status.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 55 of 85 G,. Aequii:ed AGtien aM      -GA-        Bein MODE 3.          12 hours associated Completion
             +ime et: CenElition A OF  AN{;)
B not met in MODE 1,     ~           Bein MODE 4.          36 hOUFS 2, OF 3.
Required Action and
 ~~-
                                                          ~IO+E associated Completion     bCO a.Q.3 is net appliExlele.
Time of Condition A not met during
                                       -9.1        Place OPERABLE SFU    Immediately movement of irradiated fuel           ~temln!fle ation mode.
assemblies in the        Q_
secondary containment .dwmg        -B.2.,..:t. Suspend movement of   Immediately GORE ALTERATIONS.                ~ r e demblies f i r ein l the ondary containment I[]
ANO D.2.2 Suspend GOAE               Immediately
                                                   ~IONS.
e-    Both gi;;;:y suesystems  -t:=1-      Enter bCO a.o.a       Immediately inepei:aele in MGQE ~.
2 or a feF reasens other than Cendition B.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 56 of 85 CONDITION                REQUIRED ACTION            COMPLETION TIME
 ~F-.         Both SFU subsystems                  NG+e inoperable during      LCG   a.o.a is not applicable.
movement of irradiated fuel assembles in the secondary containment   f:.1 Suspend movement of        Immediately ell:IFiR&sect; CGRe              irradiated fuel assemblies Ab+eRA+IGMS.                 in the secondary containment.
OR                              C ANQ One or more SFU subsystems inoperable  F.2 S1:1spenel CGRe             lmmeeliately due to an inoperable         ,A,b+eg,AJ:JGf!IJS.
CBE boundary during movement of irradiated fuel assemblies in the secondary containment Gl:IFiR~ GGRe 16<b+eRi6J:IGNS.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 57 of 85 3.7 PLANT SYSTEMS 3.7.5 Control Building Chiller (CBC) System LCO 3.7.5            Two CBC subsystems shall be OPERABLE.
APPLICABILITY:       MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary containment, During CORE ALTERATIONS.
ACTIONS CONDITION                      REQUIRED ACTION             COMPLETION TIME A. One CBC subsystem            A.1    Restore CBC               30 days inoperable.                         subsystem to OPERABLE status.
B. Two CBC subsystems            B.1    Verify control building   Once per 4 hours inoperable.                          area temperatures
                                                < 90&deg;F.
AND B.2    Restore one CBC           72 hours subsystem to OPERABLE status.
G,.   ~eqYii:eg AGtiQR aRQ        G:4     BeiR MODE3.               12 hgyn; asseeiated Cem13letien
           +ime Gt: GQR9itiQR A gr: B    AN{;)
net met in MODE 1, 2,
           ~                             ~      Be in MODE 4.             3@  R8UF5

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 58 of 85 Required Action and                     ~JO+e
  ~-         associated Completion    bCO a.Q.a is Ret applisaele.
Time ofCondition A not met during          .Q..1    Place OPERABLE CBC      Immediately movement of               ~system in operation.
irradiated fuel assemblies in the       OR secondary containment~           .Q..2-:4 Suspend movement of      Immediately CORE                             irradiated fuel Ab+E~r+IO~U;.                    assemblies in the secondary containment.
C AWQ D.2.2 al:fspeRB CO~E             IR=lr:Reeliately
                                             ,A,b+E~IO~JS.
 ~.        Required Action and                     NQ+E associated Completion   bGG a.9.3 is Ret apf3lisaele.
Time of Condition B not met during movement             Suspend movement         Immediately of irradiated fuel              of irradiated fuel assemblies in the secondary containment
                                    ~I      assemblies in the secondary during CGRE                     containment Ab+EA,C.J:IGNS.
ANQ g       SHSf3eRd CORE            Immediately
                                            ,OJ:+EA/i.+IONS.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 59 of 85 3.7 PLANT SYSTEMS 3.7.8 Spent Fuel Storage Pool Water Level LCO 3.7.8            The spent fuel storage pool water level shall be ~ 36 ft.
APPLICABIUTY:          During movement of irradiated fuel assemblies in the spent fUel sbJrage pool.
ACTIONS CONDITION                      REQUIRED ACTION              COMPLETION TIME A.       Spent fuel storage          A.1             NOTE pool water level not               LCO @.0.8 is not within limit.                      applicable.
Suspend movement of Immediately irradiated fuel
* assemblies in the spent fuel storage pool.
Basis TS 3.7.4, "Standby Filter Unit (SFU) System," is applicable in MODES 1, 2, and 3, during movement of irradiated fuel assemblies in the secondary containment, and during CORE ALTERATIONS. The SFU System provides a protected environment from which occupants can control the unit following an uncontrolled release of radioactivity, hazardous chemicals or smoke. Specifically, the SFU System provides emergency treatment of outside supply air and a Control Building Envelope (CBE) boundary that limits the inleakage of unfiltered air.
TS 3.7.4 is proposed to be maintained with a revision to remove references to MODES, CORE ALTERATIONS and LCO 3.0.3. After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, the requirement for the SFU to be operable in MODES 1, 2, and 3 and during CORE ALTERATIONS will be deleted as these conditions will not occur at the DAEC once it is permanently defueled. References to LCO 3.0.3 are removed since LCO 3.0.3 has been deleted as discussed earlier. TS 3.7.4 Conditions and Actions will also be revised to align with the permanently defueled condition. TS 3.7.4 SRs will be retained unchanged. The TS Bases will be updated to be consistent with the proposed TS 3. 7.4.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 60 of 85 TS 3.7.5, "Control Building Chiller (CBC) System," is applicable in MODES 1, 2, and 3, during movement of irradiated fuel assemblies in the secondary containment, and during CORE ALTERATIONS. The CBC System provides temperature control for the control building HVAC system under both normal and accident conditions.
TS 3.7.5 is proposed to be maintained with a revision to remove references to MODES and CORE ALTERATIONS. After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, the requirement for the CBC to be operable in MODES 1, 2, and 3 and during CORE ALTERATIONS will be deleted as these conditions will not occur at the DAEC once it is permanently defueled. References to LCO 3.0.3 are removed since LCO 3.0.3 has been deleted as discussed earlier. TS 3.7.5 Conditions and Actions will also be revised to align with the permanently defueled condition. TS 3.7.5 SR will be retained unchanged. The TS Bases will be updated to be consistent with the proposed TS 3.7.5.
TS 3.7.8, "Spent Fuel Pool Water Level," is applicable during movement of irradiated fuel assemblies in the spent fuel storage pool. The minimum water level in the spent fuel storage pool ensures the FHA analysis assumptions are met.
TS 3.7.8 is proposed to be maintained with a revision to remove reference to LCO 3.0.3.
The reference to LCO 3.0.3 is removed since LCO 3.0.3 has been deleted as discussed earlier.
TS SECTION 3.8 ELECTRICAL POWER SYSTEMS Current                                        Proposed TS 3.8.1 - AC Sources - Operating              TS 3.8.1 - Deleted TS 3.8.2 - AC Sources - Shutdown               TS 3.8.2 - Retain with revisions TS 3.8.3 - Diesel Fuel Oil, Lube Oil, and      TS 3.8.3 - Unchanged Starting Air TS 3.8.4 - DC Sources - Operating              TS 3.8.4 - Deleted TS 3.8.5 - DC Sources - Shutdown               TS 3.8.5 - Retain with revisions TS 3.8.6 - Battery Cell Parameters             TS 3.8.6 - Retain with revisions TS 3.8. 7 - Distribution Systems -             TS 3.8. 7 - Deleted Operating TS 3.8.8 - Distribution Systems -              TS 3.8.8 - Retain with revisions Shutdown

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 61 of 85 Basis TS 3.8, "Electrical Power Systems," contains LCOs that provide for appropriate functional capability of plant electrical equipment required for safe operation of the facility.
The TS proposed for deletion are listed below. Once the reactor is permanently shut down and defueled these TS do not apply; therefore, their corresponding LCOs, and associated SRs, are proposed for deletion. The TS proposed to be retained, with revisions, are discussed after the TS deletions.
TS 3.8.1, "AC Sources - Operating," is applicable in MODES 1, 2, and 3. The AC Electrical Power System ensures an available source of power to the Engineered Safety Feature (ESF) Systems via essential buses 1A3 and 1A4.
TS 3.8.4, "DC Sources - Operating," is applicable in MODES 1, 2, and 3. The DC Electrical Power System provides the AC Emergency Power System with control power.
It also provides both motive and control power to selected safety related equipment.
TS 3.8.7, "Distribution Systems - Operating," is applicable in MODES 1, 2, and 3. The AC and DC Electrical Power Distribution Systems are designed to provide sufficient capacity, capability, redundancy, and reliability to ensure the availability of necessary power to ESF Systems so that the fuel, Reactor Coolant System, and containment design limits are not exceeded.
The above TSs are related to assuring the appropriate functional capability of plant equipment, and control of process variables, design features, or operating restrictions required for safe operation of the facility only when the reactor is in MODES 1 through
: 3. After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, the TS listed in the previous paragraphs, which only address their associated specific plant equipment, control of process variables, design features, or operating restrictions are no .
longer applicable. Based on the above, the proposed deletion of the above TS in Section 3.8, including the associated SRs, is acceptable with no impact on continued safe maintenance of the facility. With the TS sections above deleted, the corresponding TS Bases will also be deleted.
The following TS contain LCOs for plant equipment, and control of process variables, design features, or operating restrictions required for safe operation of the facility during a fuel handling accident as described is the UFSAR. As such, these TS will be retained in the POTS and revised to align with the permanently defueled condition. As follows:

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 62 of 85 3.8 ELECTRICAL POWER SYSTEMS 3.8.2 AC Sources    Sht.1tdewn LCO 3.8.2        The following AC electrical power sources shall be OPERABLE:
: a. One qualified circuit between the offsite transmission network and the on site Class 1E AC electrical power distribution subsystem(s) required by LCO 3.8.8, "Distribution Systems-Sl:i1:Jtele;11R"; and
: b. One Diesel Generator (DG) capable of supplying one division of the onsite Class 1E AC electrical power distribution subsystem(s) required by LCO 3.8.8.
APPLICABILITY:   MODJ;;S 4 aRa        e, During movement of irradiated fuel assemblies in the secondary containment.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 63 of85 ACTIONS
                                        . -~-
bGG 3.Q,3 is Ret appliGal:lle.
CONDITION                   REQUIRED ACTION                      COMPLETION TIME A. One required offsite                   NOTE                     -
circuit inoperable. Enter applicable Condition and Required Actions of LCO 3.8.8, with one required division de-energized as a result of Condition A.
A.1         Declare affected                Immediately required feature{s).
                                             'Nith no offsite power available, inoperable.
OR
                                  ~           S1::1speREI GG~e                h;i1:J:1eEliately
                                             .A,b+e~:+IGfl.lS.
AWQ.
A.2.~     Suspend movement                Immediately of irradiated fuel assemblies in the secondary containment.
ANS
                                  ~           IRitiate aeUeR te Festere IFAFAeeliately Feq1::1ii:ee effsite p~**eF Gii:G1::1it te oi;;ie~,liilbe
                                             &taw&:,
B.      One required DG      &        S1:1s13eRel GQRE              IFAFA eeliate I;'
inoperable.                     Ab+eMTIOfl.lS.
ANG, D- ~~
Suspend movement               Immediately of irradiated fuel assemblies in secondary containment ANG,
                                   ~          IRitiate aGU8R te              l1:J:11:J:18Eliately -
restere req1::1ireEI CG te oi:ie~A.liilbe
                                              ~

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 64 of 85 3.8 ELECTRICAL POWER SYSTEMS 3.8.5 DC Sources             Sl:i1:1telovm LCO 3.8.5              DC electrical power subsystems shall be OPERABLE to support the DC electrical power distribution subsystem(s) required by*
LCO 3.8.8, "Distribution Systems                 af:lbltElewR."
APPLICABILITY:         MOCEa 4 aRs          e, During movement of irradiated fuel assemblies in the secondary containment.
ACTIONS CONDITION                               REQUIRED ACTION                       COMPLETION TIME A.      One or more required               A.1       Declare affected                 Immediately DC electrical power                          required feature(s) subsystems                                   inoperable.
inoperable.
OR
                                                ~         ab1Sf:l9R9   GO~E                lmmeEliately ALTER/\TIO~,s.
ANS-A.2..-2   Suspend movement                 Immediately of irradiated fuel assemblies in the secondary containment.
AWQ.
A-:      (eo AtiR 1:1e el)                ~          IRiUate aetleR ta               lmmeeliate!y i:estei:e FEl(:!blii:eel blG elesti:isal pei;1,1ei:                           .
sblsl:lsystems t8 OPERABLE status.

Duane Arnold Energy Center Docket No. 50~331 License Amendment Request Enclosure to NG-19-0055 Page 65 of 85 3.8 ELECTRICAL POWER SYSTEMS 3.8.6 Battery Cell Parameters LCO 3.8.6           Battery cell parameters for the Division I and Division 11125 voe and the 250 VDG batteries shall be within limits.
APPLICABILITY:      When associated DC electrical power subsystems are required to be OPERABLE.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 66 of 85 3.8 ELECTRICAL POWER SYSTEMS 3.8.8 Distribution Systems      Shutdo1,1m LCO 3.8.8           The necessary portions of the AC and DC electrical power distribution subsystems shall be OPERABLE to support equipment required to be OPERABLE.
APPLICABILITY:      MODES 4 and      a.
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.1        Declare associated      Immediately AC or DC electrical                     supported required power distribution                      feature(s) inoperable.
subsytems inoperable.
OR Immediately A:2-:4     Suspend CORE ALTERATIONS.
ANG A.2-~      Suspend movement        Immediately of irradiated fuel assemblies in the secondary containment.
Initiate action to      lmmed!ately restoFe required AC and DC electrical power distribution subsystems to OPERAELE status.
(continued)
(continued)                 A2.4      Declar:e associated      Immediately required shutdown cooling s1:1bsystem(s)
Inoperable.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 67 of 85 Basis TS 3.8.2, "AC Sources - Shutdown," is applicable in MODES 4 and 5, and during movement of irradiated fuel assemblies in the secondary containment. The AC Electrical Power System ensures an available source of power to the Engineered Safety Feature (ESF) Systems via essential buses 1A3 and 1A4.
TS 3.8.2 is proposed to be maintained with revisions to remove references to Shutdown, MODES 4 and 5 and CORE ALTERATIONS. After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, the requirement for AC Sources to be operable in MODES 4 and 5 and during CORE ALTERATIONS will be deleted as these conditions will not occur at the DAEC once it is permanently defueled.
TS 3.8.2 Conditions and Actions will also be revised to align with the permanently defueled condition. Since the specified condition of applicability is exited upon suspension of movement of irradiated fuel assemblies in secondary containment, immediate action to restore inoperable equipment is no longer required. Surveillance Requirements to ensure AC Sources operability will be added to TS 3.8.2. The TS Bases will be updated to be consistent with the proposed TS 3.8.2.
TS 3.8.5, "DC Sources - Shutdown," is applicable in is applicable in MODES 4 and 5 and during movement of irradiated fuel assemblies in the secondary containment. The DC Electrical Power System provides the AC Emergency Power System with control power. It also provides both motive and control power to selected safety related equipment.
TS 3.8.5 is proposed to be maintained with revisions to remove references to Shutdown, MODES 4 and 5, CORE ALTERATIONS and LCO 3.0.3. Reference to LCO 3.0.3 is removed this LCO has been deleted as previously discussed. After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, the requirement for the DC Sources to be operable in MODES 4 and 5 and references to Shutdown and CORE ALTERATIONS will be deleted as these conditions will not occur at the DAEC once it is permanently defueled. TS 3.8.5 Conditions and Actions will also be revised to align with the permanently defueled condition. Since the specified condition of applicability is exited upon suspension of movement of irradiated fuel assemblies in*
secondary containment, immediate action to restore inoperable equipment is no longer required. Surveillance Requirements to ensure DC Sources operability will be added to TS 3.8.5. The TS Bases will be updated to be consistent with the proposed TS 3.8.5.
TS 3.8.6, "Battery Cell Parameters," is applicable when associated DC electrical power subsystems are required to be OPERABLE. The battery cell parameter requirements

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 68 of 85 ensure availability of the required DC power to maintain the facility in a safe condition after a postulated FHA.
TS 3.8.6 is proposed to be maintained with revisions to remove references to 250 V DC.
The 250 V DC system does not support any equipment needed to mitigate the consequences of a postulated FHA. Surveillance Requirements for the 125 V DC batteries are unchanged, Surveillance Requirements for 250 V DC are deleted. The TS Bases will be updated to be consistent with the proposed TS 3.8.6.
TS 3.8.8, "Distribution Systems - Shutdown," is applicable in is applicable in MODES 4 and 5, and during movement of irradiated fuel assemblies in the secondary containment. The AC and DC Electrical Power Distribution Systems are designed to provide sufficient capacity, capability, redundancy, and reliability to ensure the availability of necessary power to ESF Systems so that the fuel, Reactor Coolant System, and containment design limits are not exceeded TS 3.8.8 is proposed to be maintained with revisions to remove referer:ices to Shutdown, MODES 4 and 5, CORE ALTERATIONS and LCO 3.0.3. Reference to LCO 3.0.3 is removed this LCO has been deleted as previously discussed. After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, the requirement for the Distribution Systems to be operable in MODES 4 and 5 and references to Shutdown and CORE ALTERATIONS will be deleted as these conditions will not occur at the DAEC once it is permanently defueled. TS 3.8.8 Conditions and Actions will also be revised to align with the permanently defueled condition. Since the specified condition of applicability is exited upon suspension of movement of irradiated fuel assemblies in secondary containment, immediate action to restore inoperable equipment is no longer required. TS 3.8.8 SR will be retained unchanged. The TS Bases will be updated to be consistent with the proposed TS 3.8.8.
TS SECTION 3.9 REFUELING OPERATIONS Current                                        Proposed TS 3.9.1 - Refueling Equipment Interlocks TS 3.9.1 - Deleted TS 3.9.2 - Refuel Position One-Rod-Out         TS 3.9.2 - Deleted Interlock TS 3.9.3 - Control Rod Position                TS 3.9.3 - Deleted TS 3.9.4 - Control Rod Position Indication TS 3.9.4 - Deleted TS 3.9.5 - Control Rod OPERABILITY -           TS 3.9.5 - Deleted Refueling TS 3.9.6 - Reactor Pressure Vessel (RPV) TS 3.9.6 - Deleted I
Water Level

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 69 of 85 TS 3.9.7 - Residual Heat Removal (RHR)           TS 3.9.7 - Deleted
- High Water Level TS 3.9.8 - Residual Heat Removal (RHR)           TS 3.9.8 - Deleted
- Low Water Level Basis TS 3.9, "Refueling Operations," contains LCOs that provide for appropriate functional capability of parameters and equipment within containment that are required for mitigation of design basis accidents during refueling operations.
The TS listed below do not apply once the reactor is permanently defueled; therefore, their corresponding LCOs, and associated SRs, are proposed for deletion.
TS 3.9.1, "Refueling Equipment Interlocks," is applicable during in-vessel fuel movement with equipment associated with the interlocks when the reactor mode switch is in the Refuel position. Refueling equipment interlocks restrict the operation of the refueling equipment or the withdrawal of control rods to serve as a backup to procedural core reactivity controls to prevent the reactor from achieving criticality during refueling.
TS 3.9.2, "Refuel Position One-Rod-Out Interlock," is applicable in MODE 5 with the reactor mode switch in the Refuel position and any control rod withdrawn. The refuel position one-rod-out interlock restricts the movement of control rods to reinforce unit procedures that prevent the reactor from becoming critical during refueling operations.
TS 3.9.3, "Control Rod Position," prevents loading fuel assemblies into the core with a control rod not fully inserted. TS 3.9.3 is applicable when loading fuel assemblies into the core.
TS 3.9.4, "Control Rod Position Indication," is applicable in MODE 5. The full-in position indication for each control rod provides necessary information to the refueling interlocks to prevent inadvertent criticalities during refueling operations.
TS 3.9.5, "Control Rod OPERABILITY - Refueling," is applicable in MODE 5. TS 3.9.5 provides for the reliable control of reactivity changes during refueling operations, the capability to maintain the reactor subcritical under all conditions and to limit the potential amount and rate of reactivity increase caused by a malfunction in the CRD System.
TS 3.9.6, "Reactor Pressure Vessel (RPV) Water Level," ensures a minimum water level of 23 feet above the top of irradiated fuel assemblies seated within the RPV. TS 3.9.6 is applicable during movement of irradiated fuel assemblies in the RPV and during movement of new fuel assemblies or handling of control rods within the RPV, when irradiated fuel assemblies are seated within the RPV.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 70 of 85 TS 3.9.7, "Residual Heat Removal (RHR) - High Water Level," is applicable in MODE 5 with irradiated fuel in the RPVand the water level~ 21 feet-1 inch above the top of the RPV flange. The purpose of the RHR System in MODE 5 is to remove decay heat and sensible heat from the reactor coolant.
TS 3.9.8, "Residual Heat Removal (RHR) - Low Water Level," is applicable in MODE 5 with irradiated furl in the RPV and the water level< 21 feet-1 inch above the top of the RPV flange. The purpose of the RHR System in MODE 5 is to remove decay heat and sensible heat from the reactor coolant.
The above TSs are related to assuring the appropriate functional capability of plant equipment, and control of process variables, design features, or operating restrictions required for safe refueling operation of the facility only when the reactor is in MODE 5 or during movement of fuel assemblies within the RPV. After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Consequently, entry into MODE 5 and fuel movement within the RPV are not authorized. Therefore, the TS listed in the previous paragraphs, which only address these specific plant systems, control of process variables, design features, or operating restrictions are no longer applicable. Based on the above, the proposed deletion of all TS in Section 3.9, including associated SRs, is acceptable with no impact on continued safe maintenance of the facility. With the TS section deleted in its entirety, the corresponding TS Bases will also be deleted.
TS SECTION 3.10 SPECIAL OPERATIONS Current                                         Proposed TS 3.10.1 - System Leakage and                 TS 3.10.1 - Deleted Hydrostatic Testing Operation TS 3.10.2 - Reactor Mode Switch Interlock TS 3.10.2 - Deleted Testing TS 3.10.3 - Single Control Rod                 TS 3.10.3 - Deleted Withdrawal - Hot Shutdown TS 3.10.4 - Single Control Rod                 TS 3.10.4- Deleted Withdrawal - Cold Shutdown TS 3.10.5 - Single Control Rod Drive           TS 3.10.5 - Deleted (CRD) Removal - Refueling TS 3.10.6 - Multiple Control Rod               TS 3.10.6 - Deleted Withdrawal - Refueling TS 3.10.7-Control Rod Testing-                 TS 3.10.7 - Deleted Operating TS 3.10.8 - SHUTDOWN MARGIN (SOM) TS 3.10.8 - Deleted Test- Refueling

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 71 of 85 Basis TS 3.10, "Special Operations," contains LCOs that provide for appropriate functional capability of parameters and equipment required for mitigation of design basis accidents during specific operating scenarios.
The TS listed below do not apply once the reactor is permanently defueled; therefore, their corresponding LCOs, and associated SRs, are proposed for deletion.
TS 3.10.1, "System Leakage and Hydrostatic Testing Operation," allows certain reactor coolant pressure tests to be performed in MODE 4 when the metallurgical characteristics of the RPV require the pressure testing at temperatures> 212&deg;F (normally corresponding to MODE 3) or to allow completing these reactor pressure tests when the initial conditions do not require temperatures> 212&deg;F. TS 3.10.1 is applicable in MODE 4 with average reactor coolant temperature> 212 &deg;F.
TS 3.10.2, "Reactor Mode Switch Interlock Testing," permits operation of the reactor mode switch from one position to another to confirm certain aspects of associated interlocks during periodic tests and calibrations in MODES 3, 4, and 5. TS 3.10.2 is applicable in MODES 3 and 4 with the reactor mode switch in the Run, Startup/Hot Standby, or Refuel position, and MODE 5 with the reactor mode switch in the Run or Startup/Hot Standby position.
TS 3.10.3, "Single Control Rod Withdrawal - Hot Shutdown," is applicable in MODE 3 with the reactor mode switch in the Refuel position. The purpose of this LCO is to permit the withdrawal of a single control rod for testing while in Hot Shutdown, by imposing certain restrictions.
TS 3.10.4, "Single Control Rod Withdrawal - Cold Shutdown," is applicable in MODE 4 with the reactor mode switch in the Refuel position. The purpose of this LCO is to permit the withdrawal of a single control rod for testing while in Cold Shutdown, by imposing certain restrictions.
TS 3.10.5, "Single Control Rod Drive (CRD) Removal - Refueling," permits the removal of a single CRD during refueling operations by imposing certain administrative controls.
TS 3.10.5 is applicable in MODE 5 with LCO 3.9.5 not met.
TS 3.10.6, "Multiple Control Rod Withdrawal - Refueling," is applicable in MODE 5 with LCO 3.9.3, LCO 3.9.4, or LCO 3.9.5 not met. The purpose of this LCO is to permit multiple control rod withdrawal during refueling by imposing certain administrative controls.
TS 3.10.7, "Control Rod Testing - Operating," permits control rod testing, while in MODES 1 and 2, by imposinQ certain administrative controls. TS 3.10.7 is applicable in

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 72 of 85 MODES 1 and 2 with LCO 3.1.6 not met.
TS 3.10.8, "SHUTDOWN MARGIN (SOM) Test- Refueling," permits SOM testing to be performed for those plant configurations in which the RPV head is either not in place or the head bolts are not fully tensioned. TS 3.10.8 is applicable in MODE 5 with the reactor mode switch in Startup/Hot Standby position.
The above TSs are related to assuring the appropriate functional capability of plant equipment, and control of process variables, design features, or operating restrictions required for safe operation of the facility during specific operating scenarios. After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Therefore, the TS listed in the previous paragraphs, which only address their associated specific plant equipment, control of process variables, design features, or operating restrictions are no longer applicable. Based on the above, the proposed deletion of all TS in Section 3.10, including associated SRs, is acceptable with no impact on continued safe maintenance of the facility. With the TS section deleted in its entirety, the corresponding TS Bases will also be deleted.
TS Section 4.0 DESIGN FEATURES TS 4.0 contains a brief description of the DAEC location, description and requirements for the DAEC reactor core and a description of and requirements for fuel storage at DAEC.
Current TS                                        Proposed TS TS 4.1 Site Location                              TS 4.1 Site Location The plant site, which consists of                 The plant site, which consists of approximately 500 acres, is adjacent to           approximately 500 acres, is adjacent the Cedar River approximately 2.5 miles           to the Cedar River approximately 2.5 northeast of the Village of Palo, Iowa.           miles northeast of the Village of Palo, Distance from the reactor centerline to           Iowa. Distance from the reactor the nearest site boundary is                      centerline to the nearest site boundary approximately 2000 ft. The boundary of            is approximately 2000 ft. The the exclusion area defined in 10 CFR              boundary of the exclusion area 100 is delineated by the property lines.          defined in 10 CFR *100 is delineated The distance to the outer boundary of             by the property lines. The distance to the low population zone is 6 miles. The           the outer boundary of the low plan of the site is shown on UFSAR                population zone is 6 miles. The plan Figures 1.2-1 and 1.2-2.                          of the site is shown on UFSAR Figures 1.2-1 and 1.2-2.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 73 of 85 Basis TS 4.1 provides a brief description of the DAEC and its location. Pursuant to 10 CFR 50.82(a)(2), the facility license for DAEC will no longer authorize operation of the reactor or placement or retention of fuel in the reactor. With the reactor permanently shut down and defueled, its location within the site boundary is inconsequential. Therefore, TS 4.1 will be revised to remove this reference to the DAEC reactor centerline. There are no TS Bases associated with TS 4.1.
Current TS                                       ProRosed TS TS 4.2 Reactor Core                              TS 4.2 will be deleted.
Basis TS 4.2 contains descriptions of and requirements for fuel assemblies and control rod assemblies in the DAEC reactor core during operation of the unit. Pursuant to 10 CFR 50.82(a)(2), the facility license for DAEC will no longer authorize operation of the reactor or placement or retention of fuel in the reactor. With the reactor permanently shut down and defueled, the operational reactor core, as described in TS 4.2, will no longer exist.
Therefore, TS 4.2 will be deleted. Because the TS will not be renumbered, a markup is provided to identify this section as deleted. There are no TS Bases associated with TS 4.2.
Current TS                                       ProRosed TS 4.3 Fuel Storage                                 4.3 Fuel Storage 4.3.1 Criticality                                4.3.1 Criticality 4.3.1.2 The new fuel storage racks are           4.3.~ .2 +l=le Re1N f1:1el steFage Faeks aFe designed and shall be maintained with:           desigRed aRd sl=lall be maiRtaiRed witl=I:
: a. Fuel assemblies having a maximum               a. F1:1el assemblies l=la11iRg a k-infinity of 1.31 in the normal                   ma*im1:1m k iRfiRity ef ~ .a~ iR tl=le reactor core configuration at cold                 ReFmal FeacieF eme eeRfig1:1FatieR conditions;                                        at eeld eeRditieRs;
: b. keff ~ 0.95 if fully flooded with             &.---keff ~ Q.9a if f1:1lly fleeded witl=I unborated water, which includes an                1:1Rbmated wateF, \VRiel=I iRel1:1des aR allowance for uncertainties as                    alle1.\(aRee feF 1:1ReeFtaiRties as described in Section 9.1 of the                   deseFibed iR SeetieR 9.~ eftl=le UFSAR;                                            UFSAR; C. keff ~ 0.90 if dry, which includes an        &.-keff ~ Q.9Q if dpt, 1.Yl=lisl=I iRsl1:1des aR allowance for uncertainties as                    allewaRee feF 1:1ReeFtaiRties as described in Section 9.1 of the                   deseFibed iR SeetieR 9. ~ ef tl=le UFSAR; and                                        UFSAR; aRd
: d. A nominal 6.625 inch center to                d. A RemiRal e.e2a iRSR eeRteF te center distance between fuel                      seRteF aistaRse betweeR f1:1el assemblies placed in storage racks.                    -    *-        ,...,_    .. ---
                                                         ~ - - - - L I : - - ~1~--,.,1 ;~ _._ ___ ,.,....

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 74 of 85 racks.
4.3.3 Capacity                                   4.3.3 Capacity The spent fuel storage pool is designed          The spent fuel storage pool is designed and shall be maintained with a storage           and shall be maintained with a storage capacity limited to no more than 2563 fuel       capacity limited to no more than 2563 assemblies in a vertical orientation,            fuel assemblies in a vertical orientation, including no more than 152 fuel                  including no more than 152 fuel assemblies stpred in the cask pit in             assemblies stored in the cask pit in accordance with UFSAR Section 9.1.               accordance with UFSAR Section 9.1.
The new fuel storage vault is equipped with      The new fuel storage vault is equipped racks for storage of up to 110 fuel              with racks for storage of up to 11 O fuel assemblies in a vertical orientation.            assemblies in a vertical orientation.
Basis TS 4.3 contains a description of and requirements for fuel storage at DAEC.
TS 4.3.1.1 details the design and maintenance of the spent fuel storage racks. This TS section will remain applicable in the permanently shut down and defueled condition. TS 4.3.1.1 is retained without changes.
TS 4.3.1.2 details the design and maintenance of the new fuel storage racks. After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Consequently, the DAEC will not be receiving or storing new fuel and TS 4.3.1.2 will no longer be applicable.
Therefore, TS 4.3.1.2 will be deleted in its entirety.
Note: Since 4.3.1.2 is deleted, there is no need to retain the numbering for TS 4.3.1.1.
The requirements of 4.3.1.1 will, therefore, appear directly under 4.3.1.
TS 4.3.2 ensures SFP water level is maintained to prevent inadvertent draining of the SFP. This TS section will remain applicable in the permanently shut down and defueled condition. TS 4.3.2 is retained without changes.
TS 4.3.3 contains a description of and requirements for capacity of the spent fuel pool and the new fuel storage vault. After the certifications required by 10 CFR 50.82(a)(1) are docketed for DAEC, the 10 CFR Part 50 license will no longer authorize operation of the reactor or placement or retention of fuel in the reactor vessel pursuant to 10 CFR 50.82(a)(2). Consequently, the DAEC will not be receiving or storing new fuel and the reference to the new fuel vault will no longer be applicable. Therefore, TS 4.3.3 is revised to delete this reference.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 75 of 85 There are no TS Bases associated with Section 4.3 of the TS.
TS Section 5.5 Programs and Manuals This section provides a description and requirements regarding programs and manuals that are to be established, implemented, and maintained. TS 5.5 will remain applicable once the reactor is permanently shut down and defueled. As such, it is proposed to be retained and revised to reflect the permanently defueled condition as described below.
Current TS                                Basis for Chanae TS 5.5.2 Primary Coolant Sources          TS 5.5.2 will be deleted.
Outside Containment This program was established to provide 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.
This program is proposed for deletion. Once the DAEC is permanently shut down and defueled, there will no longer be any transient or accident conditions associated with primary coolant sources. Thus, TS 5.5.2 will not be retained.
TS 5.5.5 Component Cyclic or              TS 5.5.5 will be deleted.
Transient Limit This program provides controls to track cyclic and transient occurrences to ensure reactor vessel integrity. This program is proposed for deletion. Once the DAEC is permanently shut down and defueled, there will no longer be a need to ensure reactor vessel integrity.
Therefore, TS 5.5.5 will not be retained.
TS 5.5.7 Ventilation Filter Testing       TS 5.5.7 will be retained with changes.
Program (VFTP)
This program was established to implement required testing of Engineered Safety Feature (ESF) filter ventilation systems. Those ESF systems included the SBGT System and the SFU System.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 76 of 85 Once the DAEC is permanently shut down and defueled, the SBGT system is no longer required to be operable and the associated TS have been deleted. Therefore, it is proposed that the VFTP requirements for SBGT be deleted from TS 5.5.7. Since SFU is required post defuel, the VFTP requirements for SFU will be retained and remain unchanged.
TS 5.5.8 Explosive Gas and Storage    TS 5.5.8 will be retained with changes.
Tank Radioactivity Monitoring Program This program provides controls for potentially explosive gas mixtures contained in the Offgas System downstream of the recombiners and the quantity of radioactivity contained in unprotected outdoor liquid storage tanks.
Once the DAEC is permanently shut down and defueled, the Offgas System is no longer required to be operable and the associated TS have been deleted. Therefore, it is proposed that the monitoring requirements for potentially explosive gas mixtures contained in the Offgas System be deleted from TS 5.5.8. The monitoring requirements for radioactivity contained in unprotected outdoor liquid storage tanks remains unchanged.
TS 5.5.12 Primary Containment         TS 5.5.12 will be deleted.
Leakage Rate Testing Program This program was established to implement the leakage rate testing of the primary containment as required by 10 CFR 50.54(0) and 10 CFR 50 Appendix J, Option B, as modified by approved exemptions.
The program is proposed for deletion because the DAEC Part 50 license will no longer authorize emplacement or retention of fuel in the reactor vessel once the certifications required by 10 CFR 50.82(a)(1) have been submitted. This program pertains only to

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 77 of 85 verifying the operability of the containment systems. The requirements for containment systems (TS 3.6) are being deleted as described previously in this document. Thus, TS 5.5.12 will not be retained.
TS Section 5.6 Reporting Requirements This section provides a description and requirements for various types of data that must be maintained and reported to the NRC. TS 5.6 will remain applicable once the reactor is permanently shut down and defueled. As such, it is proposed to be retained and revised to reflect the permanently defueled condition. The Reference 2 License Amendment Request submitted to the NRC on April 19, 2019 proposed several changes to TS 5.6. One additional change is proposed to TS 5.6 as part of this request, as discussed below.
Current TS                                Basis for Chanae TS 5.6.6 Post Accident Monitoring         TS 5.6.6 will be deleted.
(PAM) Report A PAM report is required by Conditions B or F of LCO 3.3.3.1. As previously discussed, LCO 3.3.3.1 has been proposed for deletion once the DAEC is permanently shut down and defueled. Therefore, the required conditions to prepare and submit a PAM report no longer apply.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 78 of 85

==4.0  REGULATORY EVALUATION==

4.1   Applicable Regulatory Requirements/Criteria The proposed changes have been evaluated to determine whether applicable regulations and requirements continue to be met. NextEra Energy Duane Arnold, LLC (NEDA) has determined that the proposed changes do not require any exemptions or relief from regulatory requirements.
4.1.1   10 CFR 50.82, Termination of License The portions of 10 CFR 50.82 providing the basis for this license amendment request (LAR) are:
(a) For power reactor licensees-(1) (i) When a licensee has determined to permanently cease operations the licensee shall, within 30 days, submit a written certification to the NRG, consistent with the requirements of
                           &sect; 50.4(b)(8);
(ii) Once fuel has been permanently removed from the reactor vessel, the licensee shall submit a written certification to the NRG that meets the requirements of&sect; 50.4(b)(9) and; (2) Upon docketing of the certifications for permanent cessation of operations and permanent removal of fuel from the reactor vessel, or when a final legally effective order to permanently cease operations has come into effect, the 10 CFR part 50 license no longer authorizes operation of the reactor or emplacement or retention of fuel into the reactor vessel.
By letter dated January 18, 2019 (Accession No. ML19023A196),
NEDA provided formal notification to the U.S. Nuclear Regulatory Commission (NRG) pursuant to 10 CFR 50.82(a)(1)(i) and 10 CFR 50.4(b)(8) of the intention to permanently cease power operations at the DAEC in the fourth quarter of 2020.
After the certifications of permanent cessation of power operation and of permanent removal of fuel from the DAEC reactor vessel are docketed, in accordance with 10 CFR 50.82(a)(1)(i) and (ii) respectively, and pursuant to 10 CFR 50.82(a)(2), the 10 CFR 50 license will no longer authorize reactor operation or emplacement or retention of fuel in the reactor vessel. As a result, DAEC will be authorized only to possess special nuclear material.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 79 of 85 4.1.2  10 CFR 50.36 Technical Specifications In 10 CFR 50.36, the Commission established its regulatory requirements related to the content of the TS.
10 CFR 50.36(c)(6) Decommissioning states:
This paragraph applies only to nuclear power reactor facilities that have submitted the certifications required by&sect; 50.82(a)(1) and to non-power reactor facilities which are not authorized to operate.
Technical specifications involving safety limits, limiting safety system settings, and limiting control system settings; limiting conditions for operation; surveillance requirements; design features; and administrative controls will be developed on a case-by-case basis.
After the certifications of permanent cessation of power operation and of permanent removal of fuel from the DAEC reactor vessel are docketed, in accordance with 10 CFR 50.82(a)(1)(i) and (ii) respectively, and pursuant to 10 CFR 50.82(a)(2), the 10 CFR 50 license will no longer authorize reactor operation or emplacement or retention of fuel in the reactor vessel. As a result, DAEC will be authorized only to possess special nuclear material. This proposed amendment deleted DAEC TS that are no longer applicable to a permanently defueled facility while modifying some of the remaining TS to correspond to the permanently shut down condition.
4.1.3   10 CFR 50.51, Continuation of License 10 CFR 50.51 (b) states:
Each license for a facility that has permanently ceased operations, continues in effect beyond the expiration date to authorize ownership and possession of the production or utilization facility, until the Commission notifies the licensee in writing that the license is terminated. During such period of continued effectiveness the licensee shall:
(1) Take actions necessary to decommission and decontaminate the facility and continue to maintain the facility, including, where applicable, the storage, control and maintenance of the spent fuel, in a safe condition, and

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 80 of 85 (2) Conduct activities in accordance with all other restrictions applicable to the facility in accordance with the NRC regulations and the provisions of the specific 10 CFR part 50 license for the facility.
4.1.4     10 CFR 50.46, Acceptance Criteria for Emergency Core Cooling Systems for Light-Water Nuclear Reactors 10 CFR 50.46(a)(1)(i) states 'This section does not apply to a nuclear power reactor facility for which the certifications required under &sect;50.82(a)(1) have been submitted."
4.1.5     10 CFR 50.62, Requirements for Reduction of Risk from Anticipated Transients without Scram (ATWS) Events for Light-Water-Cooled Nuclear Power Plants 10 CFR 50.62(a) states "The requirements of this section apply to all commercial lightwater- cooled nuclear power plants, other than nuclear power reactor facilities for which the certifications required under &sect;50.82(a)(1) have been submitted."
4.2 Precedent The proposed changes are largely consistent with the Post Defueled Technical Specifications currently in effect for the permanently shut down and,defueled Vermont Yankee Nuclear Power Station (ML15117A551),
Crystal River Nuclear Plant, Unit 3 (Accession No. ML152248286), San
         . Onofre Nuclear Generating Station, Units 2 and 3 (ML15139A390),
Kewaunee Power Stations (ML14237A045), and Fort Calhoun Station Unit 1 (ML 1801 OA087).
4.3    No Significant Hazards Consideration NextEra Energy Duane Arnold, LLC (NEDA), pursuant to 50.90, requests an amendment to the Duane Arnold Energy Center (DAEC) Technical Specifications (TS). The proposed changes will revise the license and associated TS consistent with the permanent cessation of reactor operation and permanent defueling of the reactor by deleting or revising some TS. The TS requirements being changed would be applicable once it has been certified that all fuel has been permanently removed from the DAEC reactor in accordance with 10 CFR 50.82(a)(1 )(ii). Once the final certification is submitted documenting the permanent cessation of operations and permanent fuel removal, the 10 CFR 50 license for DAEC no longer will

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 81 of 85 authorize operation of the reactor or placement of fuel in the reactor vessel, in accordance with 10 CFR 50.82(a)(2).
NEDA has evaluated whether a significant hazards consideration is involved with the proposed amendment(s) by focusing on the three standards set forth in 10 CFR 50.92, "Issuance of amendment," as discussed below:
: 1. Does the proposed change involve a significant increase in the probability or consequences of an accident previously evaluated?
Response: No The proposed changes would not take effect until DAEC has certified to the NRG that it has permanently ceased operation and entered a permanently defueled condition. Because the 10 CFR Part 50 license for DAEC will no longer authorize operation of the reactor, or emplacement or retention of fuel into the reactor vessel with the certifications required by 10 CFR Part 50.82(a)(1) submitted, as specified in 10 CFR Part 50.82(a)(2), the occurrence of postulated accidents associated with reactor operation is no longer credible. DAEC's accident analyses are contained in Chapter 15 of the Updated Final Safety Analysis Report (UFSAR). In a permanently defueled condition, the only credible UFSAR described accident that remains is the Fuel Handling Accident (FHA).
Other Chapter 15 accidents will no longer be applicable to a permanently defueled reactor.
The UFSAR-described FHA analyses for DAEC shows that, following the required decay time after reactor shutdown and provided the SFP water level requirement of TS LCO 3.7.8 is met, the dose consequences are acceptable without relying on secondary containment or the Standby Gas Treatment System. The control building envelop is credited for reduction of operator dose. Consequently, the TS requirements for the Standby Filter Unit and Control Building Chillers are retained.
The probability of occurrence of previously evaluated accidents is not increased, since safe storage and handling of fuel will be the only operations performed, and therefore, bounded by the existing analyses.
Additionally, the occurrence of postulated accidents associated with reactor operation will no longer be credible in the permanently defueled condition. This significantly reduces the scope of applicable accidents.
The deletion of TS definitions and rules of usage and application requirements that will not be applicable in a defueled condition has no impact on facility SSCs or the methods of operation of such SSCs. The

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 82 of 85 deletion of design features and safety limits not applicable to the permanently shut down and defueled DAEC has no impact on the remaining applicable OBA.
The removal of LCOs or SRs that are related only to the operation of the nuclear reactor or only to the prevention, diagnosis, or mitigation of reactor-related transients or accidents do not affect the applicable DBAs previously evaluated since these DBAs are no longer applicable in the permanently defueled condition.
Therefore, the proposed change does not involve a significant increase in the probability or consequences of an accident previously evaluated.
: 2. Does the proposed change create the possibility of a new or different kind of accident from any accident previously evaluated?
Response: No The proposed changes to delete or modify certain DAEC Operating License, TS, and current licensing bases (CLB) have no impact on facility SSCs affecting the safe storage of spent irradiated fuel, or on the methods of operation of such SSCs, or on the handling and storage of the spent irradiated fuel itself. The removal of TS that are related only to the operation of the nuclear reactor, or only to the prevention, diagnosis, or mitigation of reactor related transients or accidents, cannot result in different or more adverse failure modes or accidents than previously evaluated because the reactor will be permanently shut down and defueled.
The proposed modification or deletion of requirements of the DAEC Operating License, TS, and CLB do not affect systems credited in the accident analysis for the remaining credible OBA at DAEC. The proposed Operating License and POTS will continue to require proper control and monitoring of safety significant parameters and activities. The TS regarding SFP water level and spent fuel storage is retained to preserve the current requirements for safe storage of irradiated fuel. The proposed amendment does not result in any new mechanisms that could initiate damage to the remaining relevant safety barriers for defueled plants (fuel cladding, spent fuel racks, SFP integrity, and SFP water level). Since extended operation in a defueled condition and safe fuel handling will be the only operation allowed, and therefore bounded by the existing analyses, such a condition does not create the possibility of a new or different kind of accident.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 83 of 85 Therefore, the proposed change does not create the possibility of a new or different kind of accident from any previously evaluated.
: 3. Does the proposed change involve a significant reduction in a margin of safety?
Response: No The proposed changes are to delete or modify certain Operating License, TS and CLB once the DAEC facility has been permanently shut down and defueled. As specified in 10 CFR 50.82(a)(2), the 10 CFR 50 license for DAEC will no longer authorize operation of the reactor or emplacement or retention of fuel into the reactor vessel following submittal of the certifications required by 10 CFR 50.82(a)(1 ). As a result, the occurrence of certain design basis postulated accidents are no longer considered credible when the reactor is permanently defueled.
The only remaining credible UFSAR described accident is a FHA. The proposed changes do not adversely affect the inputs or assumptions of any of the design basis analyses that impact the FHA.
The proposed changes are limited to those portions of the Operating License, TS, and CLB that are not related to the safe storage of irradiated fuel. The requirements proposed to be revised or deleted from the Operating License, TS, and CLB are not credited in the existing accident analysis for the remaining postulated accident (i.e., FHA); and, as such, do not contribute to the margin of safety associated with the accident analysis. Certain postulated DBAs involving the reactor are no longer possible because the reactor will be permanently shut down and defueled and DAEC will no longer be authorized to operate the reactor.
Therefore, the proposed changes have no impact to the margin of safety.
Based on the above, NEDA concludes that the proposed change presents no significant hazards consideration under the standards set forth in 10 CFR 50.92, and, accordingly, a finding of "no significant hazards consideration" is justified.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 84 of 85 4.4 Conclusions Based on the considerations discussed above, (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner, (2) such activities will be conducted in compliance with the Commission's regulations, and (3) the issuance of the amendment will not be inimical to the common defense and security or to the health and safety of the public.

==5.0   ENVIRONMENTAL CONSIDERATION==
S NEDA has evaluated the proposed amendment for environmental considerations.
The review has determined that the proposed amendment would change a requirement with respect to installation or use of a facility component located within the restricted area, as defined in 10 CFR 20, or would change an inspection or surveillance requirement. However, the proposed amendment does not involve (i) a significant hazards consideration, (ii) a significant change in the types or significant increase in the amounts of any effluent that may be released offsite, or (iii) a significant increase in individual or cumulative occupational radiation exposure. Accordingly, the proposed amendment meets the eligibility criterion for categorical exclusion set for in 10 CFR 51.22(c)(9).
In addition, the proposed changes involve changes to recordkeeping, reporting, or administrative procedures or requirements. Accordingly, the proposed amendment meets the eligibility criterion for categorical exclusion set forth in 10 CFR 51.22(c)(10).
Therefore, pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the proposed amendment.

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request Enclosure to NG-19-0055 Page 85 of 85

==6.0 REFERENCES==

6.1   Letter from Mano K. Nazar, NextEra Energy Duane Arnold, LLC to U.S.
Nuclear Regulatory Commission - "Duane Arnold Energy Center - Certification of Permanent Cessation of Power Operations," dated January 18, 2019, (ADAMS Accession No. ML19023A196).
6.2  Letter from Dean Curtland, NextEra Energy Duane Arnold, LLC to U.S.
Nuclear Regulatory Commission - "License Amendment Request (TSCR-181):
Application to Align Technical Specification Staffing and Administrative Requirements for Permanently Defueled Condition," dated April 19, 2019, (ML19109A031).                                                       .
6.3  Letter from D. Hood (U.S. Nuclear Regulatory Commission) to G. Van Middlesworth - "Issuance of Amendment Regarding Secondary Containment Operability During Movement of Irradiated Fuel and Core Alterations," dated April 16, 2001, (ML011070147).
LIST OF ATTACHMENTS  - Proposed Technical Specification Changes (Mark-Up)  - Revised Technical Specification Pages (Clean, with Proposed Changes)  - Proposed Technical Specification Bases Changes (Mark-Up)

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request NG-19-0055 Enclosure, Attachment 1 Page 1 of 375 ATTACHMENT 1 PROPOSED TECHNICAL SPECIFICATION CHANGES (MARK-UP)

NEXTERA ENERGY DUANE ARNOLD, LLC CENTRAL IOWA POWER COOPERATIVE CORN BELT POWER COOPERATIVE DOCKET 50-331 DUANE ARNOLD ENERGY CENTER RENEWED FACILITY OPERATING LICENSE Renewed License No. DPR-49
: 1. The Nuclear Regulatory Commission (the Commission) having found that:
A. The application for license filed by FPL Energy Duane Arnold, LLC, Central Iowa Power Cooperative and Corn Belt Power Cooperative (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. Constn,1Gtion of the Dt,mne Arnold energy Center (fasility) has been s1:.1bstantially
* soR'lr,,leted in sonforR'lity with ConstF1:.1stion PeFA'lit No. DPPR 70; the ar,,r,,lisation, as aR'lended; the r,,rovisions of the Ast; and the r1:.1les and reg1:.1lations of the CoR'lR'lission; C. The facility will 013erate
* formity with the application, as amended; the provisions of the Act; and the rules and regulations of the             om *
* be maintained D. There is reasonable assurance: (i) that the activities authorized by this renewed 013erating license can be conducted without endangering the health and safety of the public; and (ii) that such activities will be conducted in compliance with the rules and regulations of the Commission; E. NextEra Energy Duane Arnold, LLC is technically qualified and NextEra Energy Duane Arnold, LLC, Central Iowa Power Cooperative and Corn Belt Power Cooperative are financially qualified to engage in the activities authorized by this renewed or,,erating 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 Commission's regulations; G. The issuance of this renewed 013erating 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 issuance of renewed Facility Or,,erating License No. DPR-49 is in accordance with 10 CFR Part 50, Appendix D, of the Commission's regulations and all applicable requirements of said Appendix D have been satisfied; On April 16, 2009, the name "FPL Energy Duane Arnold, LLC" was changed to "NextEra Energy Duane Arnold, LLC."
                                           !Amendment                       Renewed License No. DPR-49
                                                                                             ~

I'Deleted I. The reoeipt, possession, and use of souroe, by produot and speoial nuolear material as authorized by this renewed operating lioense will be in aooordanoe with the Commission's regulations in 1Q Gp'.R Part dQ and 7Q, inoluding 1Q Gp'.R eeotion dQ.dd, 7Q.24 and 7Q.d1.                                                                  .-p-e-rm_a_n_e_n_t-ly_d_e-fu_e_l-ed---.
: 2. Renewed Facility Operating License No. DPR-49 is hereby issued to NextEra Energy Duane Arnold, LLC, Central Iowa Power Cooperative (CIPCO) and Corn Belt Power Cooperative (Corn Belt) to read as follows:
A. This renewed operating license applies to the Duane Arnold Energy Center, a oiling water reactor and associated equipment (the facility), owned by NextEra Energy Duane Arnold, LLC, Central Iowa Power Cooperative and Corn Belt Power Cooperative and operated by NextEra Energy Duane Arnold, LLC. The facility is located on NextEra Energy Duane Arnold, LLC's, Central Iowa Power Cooperative's and Corn Belt Power Cooperative's site near Palo in Linn County, Iowa. This site consists of approximately 500 acres adjacent to the Cedar River and is described in the "Final Safety Analysis Report" as supplemented
                .and amended (Amendments 1 through 14) and the Environmental Report as supplemented and amended (Supplements 1 through 5).
B. Subject to the conditions and requirements incorporated herein, the Commission hereby licenses:                as required for nuclear fuel storage (1) NextEra Energy Du ne Arnold, LLC, pursuant to Section104b of the Act and 10 CFR Part 50, "Licensin of Production and Utilization Facilities," to possess, ti-Se-and ~
operate the facility, and CIPCO and Corn Belt to possess the facility at the designated location in Linn County, Iowa, in accordance with the procedures and limitations set forth in this license;                               that was used (2) NextEra Energy Duane Arnold, LLC, pursuant to the Act and            CFR Part 70, to reoeive, possess and use at any time special nuclear materia as reactor fuel, in accordance with the limitations for storage and amounts required for reaotor operation, as described in the Updated Final Safety Analysis Report, as supplemented and amended as of June 1992 and as supplemented by letters dated March 26, 1993, and November 17, 2000.                                or (3) NextEra Energy Duane Arnold, LLC, pursuant to the Act and 10 FR Parts 30, 40 and 70, to receive, possess and use at any time any byproduct, source and speoial nuolear material as sealed neutron souroes for reaotor startup, ealed sources for roaster instrumentation and radiation monitoring equipment calibration, afl<e-afS fission detesters in amounts as required; (4) NextEra Energy Duane Arnold, LLC, pursuant to the Act and 1O CF and 70, to receive, possess and use in amounts as required any bY, roduct, source or special nuclear material without restriction to chemical or physi al form, for sample analysis or instrument calibration or associated radioactive app atus components; . - - - - -.....
rlthat were (5) NextEra Energy Duane Arnold, LLC, pursuant to the Act and O CFR Parts 30 a~~~
70, to possess, but not to separate, such byproduct and spe ial nuclear materials as                        I may be produced by the operation of the facility.
and to possess any byproduct, source and special nuclear material as sealed neutron sources previously used for reactor enewed License No. DPR-49 startup or reactor instrumentation; and fission detectors;
                                                                                    !A_m_e_n_d_m_e_n_t
                                                                                    .....                 _ __.~

C. This renewed oper:ating license shall be deemed to contain and is subject to the conditions specified in the following Commission regulations in 10 CFR Chapter I; Part 20, Section 30.34 of Part 30, Section 40.41 of Part 40, Sections 50.54 and 50.59 of Part 50, and Section 70.32 of Part 70; is subject to all applicable provisions of the Act and to the rules, regulations, and orders of the Commission now or hereafter in effect; and is subject to the additional conditions specified or incorporated below:
(1) Maximum Power Level ~.....D_e_le_t_e_d_ _ _ _.....,
                ~JexU:ra Ener&sect;y Duane Arnold, LLG is authorized to operate the Duane Arnold Ener&sect;y Genter at steady state reaotor sore power levels not in exoess of 1912 me&sect;awatts (thermal).
(2) Technical Specifications                                           Permanently Defueled The Technical Specifications contained in Appendix A, as re ised through                   I:,..
Amendment No. ~ . are hereby incorporated in the licens NextEra Energy Duane              1 Arnold, LLC sh operate the facility in accordance with the Technical Specifications.
maintain Lioense DPR 4Q, those SRs are not required to be performed until their next soheduled performanoe, whioh is due at the end of the first surveillanoe interval that be&sect;ins on the date the Surveillanoe was last performed prior to implementation of Amendment ~Jo. 24J.
(b) Deleted.
(3) Fire Protection Program NextEra Energy Duane Arnold, LLC shall implement and maintain in effect all provisions of the approved fire protection program that comply with 10 CFR 50.48(a) and 10 CFR 50.48(c), as specified in the licensee amendment request dated August 5, 2011 (and supplements dated October 14, 2011, April 23, 2012, May 23, 2012, July 9, 2012, October 15, 2012, January 11, 2013, February 12, 2013, March 6, 2013, May 1, 2013, May 29, 2013, two supplements dated July 2, 2013, and supplements dated August 5, 2013 and August 28, 2013) and as approved in the safety evaluation report dated September 10, 2013. Except where NRC approval for changes or deviations is required by 10 CFR 50.48( c), and provided no other regulation, technical specification, license condition or requirement would require prior NRC approval, the licensee may make changes to the fire protection program without prior approval of the Commission if those changes satisfy the provisions set forth in 10 CFR 50.48(a) and 10 CFR 50.48(c), the change does not require a change to a technical specification or a license condition, and the criteria listed below are satisfied.
Renewed License No. DPR-49 Amendment~           -f

Risk-Informed Changes that May Be Made Without Prior NRC Approval A risk assessment of the change must demonstrate that the acceptance criteria below are met. The risk assessment approach, methods, and data shall be acceptable to the NRC and shall be appropriate for the nature and scope of the change being evaluated; be based on the as-built, as-operated, and maintained plant; and reflect the operating experience at the plant. Acceptable methods to assess the risk of the change may include methods that have been used in the peer-reviewed fire PRA model, methods that have been approved by NRC through a plant-specific license amendment or NRC approval of generic methods specifically for use in NFPA 805 risk assessments, or methods that have been demonstrated to bound the risk impact.
(a) Prior NRC review and approval is not required for changes that clearly result in a decrease in risk. The proposed change must also be consistent with the defense-in-depth philosophy and must maintain sufficient safety margins. The change may be implemented following completion of the plant change evaluation.
(b) Prior NRC review and approval is not required for individual changes that result in a risk increase less than 1x1Q-7/year (yr) for CDF and less than 1x1Q-8/yr for LERF. The proposed change must also be consistent with the defense-in-depth philosophy and must maintain sufficient safety margins. The change may be implemented following completion of the plant change evaluation.
Other Changes that May Be Made Without Prior NRC Approval
: 1. Changes to NFPA 805, Chapter 3, Fundamental Fire Protection Program. Prior NRC review and approval are not required for changes to the NFPA 805, Chapter 3, fundamental fire protection program elements and design requirements for which an engineering evaluation demonstrates that the alternative to the Chapter 3 element is functionally equivalent or adequate for the hazard. The licensee may use an engineering evaluation to demonstrate that a change to NFPA 805, Chapter 3 element is functionally equivalent to the corresponding technical requirement. A qualified fire protection engineer shall perform the engineering evaluation and conclude that the change has not affected the functionality of the component, system, procedure, or physical arrangement, using a relevant technical requirement or standard.
The licensee may use an engineering evaluation to demonstrate that changes to certain NFPA 805, Chapter 3 elements are acceptable because the alternative is "adequate for the hazard." Prior NRC review and approval would not be required for alternatives to four specific sections of NFPA 805, Chapter 3, for which an engineering evaluation demonstrates that the alternative to the Chapter 3 element is adequate for the hazard. A qualified fire protection engineer shall perform the engineering evaluation and conclude that the change has not affected the functionality of the component, system, procedure, or physical arrangement, using a relevant technical requirement or standard. The four specific sections of NFPA 805, Chapter 3, are as follows:
Renewed License No. DPR-49 Amendment 286
* Fire Alarm and Detection Systems (Section 3.8);
* Automatic and Manual Water-Based Fire Suppression Systems (Section 3.9);
* Gaseous Fire Suppression Systems (Section 3.1 O); and,
* Passive Fire Protection Features (Section 3.11).
This License Condition does not apply to any demonstration of equivalency under Section 1.7 of NFPA 805.
: 2. Fire Protection Program Changes that Have No More than Minimal Risk Impact Prior NRC review and approval are not required for changes to the licensee's fire protection program that have been demonstrated to have no more than a minimal risk impact. The licensee may use its screening proces~ as approved in the NRC safety evaluation report dated September 10, 2013 to determine that certain fire protection program changes meet the minimal criterion. The licensee shall ensure that fire protection defense-in-depth and safety margins are maintained when changes are made to the fire protection program.
Transition License Conditions (1) Before achieving full compliance with 10 CFR 50.48(c), as specified by (2) and (3) below, risk-informed changes to the licensee's fire protection program may
        *not be made without prior NRC review-and approval unless the change has been demonstrated to have no more than a minimal risk impact, as described in (2) above.
(2) The licensee shall implement the modifications to its facility, as described in Enclosure 2, Attachment S, Table S-1, "Plant modifications Committed," of DAEC letter NG-13-0287, dated July 2, 2013, to complete the transition to full compliance with 10 CFR 50.48(c) by December 31, 2014. The licensee shall maintain appropriate compensatory measures in place until completion of these modifications.
(3) The licensee shall implement the items listed in Enclosure 2, Attachment S, Table S-2, "Implementation Items," of DAEC letter NG-13-0287, dated July 2, 2013, by March 9, 2014.
0 (4) ~ ~ : : : : : ~ d to o~el tlae D"""" A,aold EReFjjy Geate, lellowiR&sect; installation of modified safe ends on the eif;!ht 13rimary reoiroulation systen:i inlet lines whioh are desoribed in the lioensee letter dated cluly :iJ1, 1978, and su1313lemented by letter dated Deoember 8, 4Q.?g_
(5) Physical Protection NextEra Energy Duane Arnold, LLC shall fully implement and maintain in effect all provisions of the Commission-approved physical security, training and qualification, Renewed License No. DPR-49 Amendment~          +

and safeguards contingency plans including amendments made pursuant to provisions of the Miscellaneous Amendments and Search Requirements revisions to 10 CFR 73.55 (51 FR 27817 and 27822) and to the authority of 10 CFR 50.90 and 10 CFR 50.54(p). th*e combined set of plans, which contains Safeguards Information protected under 10 CFR 73.21, is entitled: "Duane Arnold Energy Center Physical Security Plan," submitted by letter dated May 16, 2006.
NextEra Energy Duane Arnold, LLC shall fully implement and maintain in effect all provisions of the Commission-approved Duane Arnold Energy Center/NextEra Energy Duane Arnold, LLC Cyber Security Plan (CSP), including changes made pursuant to the authority of 10 CFR 50.90 and 10 CFR 50.54(p). The Duane Arnold Energy Center/NextEra Energy Duane Arnold, LLC CSP was approved by License Amendment No. 278, as supplemented by changes approved by license Amendment No. 284, and Amendment 291.
(6) Deleted (7) Additional Conditions The Additional Conditions contained in Appendix B, as revised through Amendment No. 279, are hereby incorporated into this license. NextEra Energy Duane Arnold, LLC shall operate the facility in accordance with the Additional Conditions.
(8) The licensee is authorized to revise the Updated Final Safety Analysis Report by deleting the footnote for Section 9.1.4.4.5 which states: "*The NRC has not endorsed the reactor building crane as single-failure proof (Reference 9)," and by deleting Reference 9 of the references for Section 9.1.
(9) 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 (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 (10) 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.
Renewed License No. DPR-49 Amendment 291

                                  !Deleted                       ! _                   7_
(11) ~ " ia lhe UF~R '"**'"'""'' as naYise,, ""'"'"'' *"""""' ta 1Q ci;R 64.21 (d), shall so insorporatod into tho UPaAR no later than tho no)Et sshod1,1lod 1,1pdato roq1,1ired 13y 10 ci;R 60.71 (o) following the iss1,1anse of this renewed operating lisonso. Until this 1,1pdato is sornpleto, tho lisensee may not rnal(o shangos ts tho infoFfflation in tho s1,1pplernent. POllowing insorporation into tho ui;sAR, the need for prior Csrnrnissisn appro>v<al of any shan&sect;os *1f<ill 13e &sect;OYorned sy 1o cm 60.69.
::~:::~~~:~*;:~:=::::;:1!:;:1:;*G!=~:::::r:=d J
(12)                                                                                                                     13y Arnold energy Center," dated ~loYernl3er 2010, as s1,1pplernented 13y letter fForn the lisensee to tho ~IRC dated ~lo>v<ernl3or 2a, 2010, dessril3es sertain programs to 13e implemented and aotiYitios to so
=io=_e_-_le=t=e=d~~~~-=            sornpletsd 13efore tho period of o>Etendod operation.
                                        ,a,. Ne>Etera eneF&sect;y D1,1ane Arnold, LLC shall implement those new pro&sect;rarns and enhansernents to e*istin&sect; programs no later than FOl3r1,1ary 21, 2014.
e-:- ~Je>Etera energy D1,1ane /\rnols, LLC shall sornplete those astivities no later than i;esr1,1ary 21,
                                              ~
Tho lisensee shall notify the ~IRC in writing within aO days after havin&sect; assornplishos item (a) al3o>v<e ans insl1,1so the stat1,1s of those aotivities that have seen or remain ts so ssrnpletes in item (13) al3s>v<e.
(13) The lisensoe shall implement the most resent st(lff approYos >v<ersion of the Bailin&sect; Water Roaster J
iessols and Internals Projest (BWPI.VIP) Integrates S1,1F&#xa5;eillanse Program (ISP) as the rnothos to sernonstrato sornplianse with tho req1,1irernents of 10 ci;R Part 60, Appensi* M. Any shanges to tho .
I...-----
* B1A'Pi.VIP ISP saps1,1lo withsrawal sshos1,1lo rn1,1st 13e s1,113rnittes for staff review ans appro*;al. Any
       ._D_e_l_e_t_e_d_  ___.      changes to tho BWRVIP laP saps1,1lo withsrawal sshos1,1le whish affests the time ofwithsrawal of any s1,1F&#xa5;eillanso saps1,1les rn1,1st so insorporates into the lisensing 13asis. If any s1,1rveillanso saps1,1los are removes vvitho1,1t tho intent to test thorn, these saps1,1los rn1,1st so stores in a manner whish maintains them in a sonsition whish ws1,1ld s1,1pport re insertion into the roaster press1,1re vessel if nesossary.
D. This license is effective as of the date of issuance and shall m1pire at rnisnight i;esr1,1ary 21,
                              ~
* is effective until the Commission notifies the licensee in writing that the license is terminated.
FOR THE NUCLEAR REGULATORY COMMISSION Original signed by Eric J. Leeds Eric J. Leeds, Director Office of Nuclear Reactor Regulation

==Enclosures:==
: 1. Appendix A Technical Specifications
: 2. Appendix B Additional Conditions Date of Issuance: December 16, 2010 Renewed License No. DPR-49       Y Amendment~         'I

APPENDIX B ADDITIONAL CONDITIONS OPeRATl~JG LICENSE NO. bPR-49                                        I NextEra Energy Duane Arnold, LLC (the term licensee in Appendix B refers to NextEra Energy Duane Arnold, LLC or prior license holders) shall comply with the following conditions on the schedule noted below:
t Amendment Number            Additional Conditions                                    Implementation Date 223
                ~
NextEra Energy Duane Arnold, LLC is authorized to relocate certain requirements included in Appendix A to licensee-controlled documents.
This amendment is effective immediately and shall be implemented within 180 days of the date r
Implementation of this amendment                        of this amendment.
shall include the relocation of these requirements to the appropriate documents, as described in the licensee's application dated October 30, 1996, as supplemented and consolidated in its March 31, 1998, submittal. These relocations were evaluated in the NRC staffs Safety Evaluation enclosed with this amendment.
260 (1)          At U:ie tiR=ie of tl=le olosing of tl=le transfer        This amendment is of tl=le lioense fron:i Interstate Power and             effective immediately Ligl=lt GoR:ipany (IPL) to f PLe Duane                   and shall be implemented 127~                       Arnold*, IPL sl=lall transfer to FPLe Duane              within 30 days of the date Arnold* IPL's deoon:in:iissioning funds aooun:iulated as of suol=I tin:ie, witl=I a aggregate n:iinin:iun:i value of at least $180 of this amendment.
t n:iillion, and f PLe Duane /\rnold* sl=lall deposit suol=I funds in an mEternal deoon:iR=iissioning trust fund establisl=led
                       -th-e-- by f PLe Duane Arnold* for DAeG. NextEra                 established at the
_ _Jl=rii:=!Tn'\1--CllJ~ne Arnold shall take all necessa time of the closing steps to ensure            tRis external trust fund s
.-!D_e_c_e_m_b_e_r_2_3_,_2_0_0_5__,UD.eiQtained in accordance with the requirements     of the transfer of the 1
of~ order approving the license transfer,              license from NRC regulations, and consistent with the               Interstate Power safety evaluation supporting the order. The            and Light Company trust agreement shall be in a form acceptable          (IPL) to FPLE to the NRC.                                            Duane Arnold
          .:1a On April 10, 2009, tl=le naR:ie "p'PL energy Duane Arnold, LLG" was ol=langed to "~Jmaera energy Duane Arnold, LLG."
Amendment No. 275

                                                                                                  \
Amendment Number          AddWonalCondWons                                      Implementation Date 260 (2)      DELETED
              ~
260 (3)     Nextera energy Duane Arnold shall take no aotion to oause FPL Group Capital, or its suooessors and assigns, to void, oanoel, or rnodi:fy its $50 rnillion
_D_E_L_E_T_E_D....__ _~ oontingenoy oornrnitrnent to l'>Jmc-tera energy
.___ _ _ _ _ ___, Duane /\mold, as represented in the lioense transfer applioation, or oause it to roil or perforrn or irnpair its perrorrnanoe under the oornrnitn:ient, or rernove or interfere with l'>Jextera energy Duane Arnold's ability to draw upon the oomrnitrnent, *without the prior written oonsent fFOFR the l'>JRG. An exeouted oopy Of the Support
                        /\greernent shall be subrnitted to the l'>JRG no later than aO days after oornpletion of the lioense transfer. /\lso, l'>Jextera energy Duane
                        /\mold shall inforrn the l'>JRG in writing any tirne that it draws upon the $50 rnillion oornrnitrnent.
Amendment },fo. 279

Definitions 1.1 1.0 USE AND APPLICATION 1.1 Definitions
  ----------------------------------------------------N()TE----------------------------------------------------
The defined terms of this section appear in capitalized type and are applicable
. throughout these Technical Specifications and Bases.
Definition ACTIONS                                  ACTIONS shall be that part of a Specification that prescribes Required Actions to be taken *under designated Conditions within specified Completion Times.
AVERAGE PLANAR                           The APLHGR shall be applioable to a speoifio planar LINEAR HEAT                              hei&sect;ht and is equal to the suRl of the heat &sect;eneration GENERATION RATE                          rate per unit len&sect;th of fuel rod for all the fuel rods in (APLHGR)
I the spesified bundle at the spesified hei&sect;ht divided by the nuR1ber of fuel rods in the fuel bundle at the hei&sect;ht.
CHANNEL CALIBRATION                     A CHANNEL CALIBRATl()N 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 CALIBRATl()N shall encompass all devices in the channel required for channel ()PERABILITY and the CHANNEL FUNCTl()NAL TEST. Calibration of instrument channels with Resistance Temperature Detector t
(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.
(continued)
DAEC                                               1.1-1                              Amendment No.~

Definitions 1.1 1.1 Definitions (continued)
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 param,eter.
CHANNEL FUNCTIONAL          A CHANNEL FUNCTIONAL TEST shall be the TEST                        injection of a simula.ted or actual signal into the channel as close to the sensor as practicable to verify OPERABILITY of all devices in the channel required             l.,
for channel OPERABILITY. The CHANNEL                           1 FUNCTIONAL TEST may be performed by means of any series of sequential, overlapping, or total channel ~
steps.
CORE /\LTERATIO~J           CORE ALTERATION shall be the movement of any f1:1el, so1:1rses, or reastivity sontrol somponents, within the Feaster ,,essel ,,,,ith the 11essel head remo,,ed and f1:1el in the vessel. The following mmeptions are not sonsidered to be CORE ALTERATIONS:
a:-     Movement of so1:1rse range monitors, losal power range monitors, intermediate range monitors, traversing insore probes, or spesial movable detectors (insl1:1ding 1:1r1dervessel replasement);
                                     ~
                              &. Control rod movement, provided there are no fl:lel assemblies in the assosiated sore sell.
S1:1spension of CORE ALTERATIO~Jg sl:iall not presl1:1de sompletion of movement of a somponent to a safe position.
(continued)
DAEC                                  1.1-2                            Amendment No.~

Definitions 1.1 1.1 Definitions (continued)
GORE OPERATl~JG LIMIT8     The GOLR is the unit spesifis dosument that provides REPORT (GOLR)              sysle spesifis parameter limits fur the surrent reload oysle.
These sysle spesifis limits shall be determined fur eash reload oysle in assordanse with Spesifisation 5.e.5. Plant operation within these limits is addressed in indi\1idual Spesifisations.
DOSE EQUIVALENT 1-131 shall be that concentration of DOSE EQUIVALENT 1-131 1-131 (microcuries/ml), 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 Federal Guidance Report (FGR) 11, "Limiting Values of Radionuclide Intake and Air Concentration and Dose Conversion Factors for Inhalation, Submersion, and Ingestion," 1989 and FGR 12, "External Exposure to Radionuclides in Air, Water, and Soil," 1993.
DRAIN TIME                 The DRAIN TIME is the time it would take fur the 1.vater inventory in and above the Roaster Pressure Vessel (RPV) to drain to the Roaster Vessel \Nater Level Safety Limit of T.S. 2.1.1.3 assuming:
a) The water in1,entory above the T.S. 2.1.1.3 Safety Limit is divided by the limiting drain rate; (sont'd)
(continued)
DAEC                               1.1-3                              Amendment~

Definitions 1.1 1.1 Definitions (continued)
DRAIN TIME (sont'd)        b) The limiting drain rate is the laFger of the drain rate through a single penetration flov: path with the highest flow rate, or the sum of the drain rates through multiple penetration flow paths susseptible to a sommon mode failure (e.g., seismis event, loss of normal power, single human error), for all penetration flow paths below the T.a. 2.1.1.3 eafeiy Limit mEGept:
: 1. Penetration flm.v paths eonnested to an intast slosed system, or isolated by manual or automatis valves that are looked, sealed, or otherwise sesured in the slosed position, blank flanges, or other devises that prevent flow of roaster sealant through the penetration flow paths;
: 2. Penetration flov.' paths sapable of being isolated by 1Jalves thQt 1.vill slose automatisally without o#site po>.\*er prior to the RPV ,.,,,ater level being equal to the T.a. 2.1.1.3 aafety Limit when astuated by RPV \Nater le1Jel isolation instrumentation; or
: d. Penetration fie&#xa5;.* paths with isolation de,,,ices that san be slosed prior to the RPV water le1Jel being equal to the T.a. 2.1.1.3 Safety Limit by a dedisated operator trained in the task, who is in eontinuous eommunieation with the eontrol room, is stationed at the sontrols, and is sapable of elosing the penetration flov: path isolation de1Jiee without offsite pm.*:er.
e) The penetration flm.v paths required to be e1Jaluated per paragraph b) are assumed to open instantaneously and are not subsequently isolated, and no 1.vater is assumed to be subsequently added to the RPV water in1Jentory; d) No additional draining events ossur; and e) Realistis eross seetional areas and drain rates are
                                ~
A bounding DRAIN TIME may be used in lieu of a salsulated value.
(continued)
DAEC                           1.1-4                                 Amendment~

Definitions.
1.1 1.1 Definitions (continued)
E~m oi,:: CYCLE            The EOG RPT SYSTEM RESPONSE TIME shall be that RECIRCULATION PUMP         time interval from initial signal generation by the TRIP (EOG RPT) SYSTEM      assoeiated turbine stop valve limit sv,iteh or from when RESPO~JSE TIME             the turbine eontrol valve hydrmilie oil eontrol oil pressure drops below the pressure s*Niteh setpoint to aetuation of the breaker seeondary (auxiliary) eontaot. 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.
INSERVIGE TESTING          The INSERVIGE TESTl~JG PROGRAM is the lieensee program that fulfills the requirements of 10 ci;R 50.55a(f).
(continued)
DAEC                              1.1-5                             Amendment~

Definitions 1.1 1.1 Definitions (continued)
LEAKAGE                     LEAKAGE shall be:
a,. leleRtifieel LEAKAGE
: 1. LEAKAGE iRto the elryvvell, s1:1sh as that from p1:1mp seals or valve paskiRg, that is sapt1:1reel aRel s0Rel1:1steel to a s1:1mp or sollestiRg taRk; or
: 2. LE/\K/\GE iRto the elry'l,vell atmosphere from so1:1rses that are both spesifisally losateel aRel kRowR Rot to iRterfure with the operatioR of leakage eletestioR systems;
                               ~     URieleRtifieel LEAKAGE
                                     /\II LEAKAGE iRto the elF)0Nell that is Rot ieleRtifieel LEAKAGE;
                               &-    Total LEAKAGE a1:1m of the ieleRtifieel aRel 1:1RieleRtifieel LEAKAGE LOGIC SYSTEM                A LOGIC SYSTEM FUNCTIONAL.TEST shall be a test FUNCTIONAL TEST             of all logic components required for OPERABILITY 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            The MCPR shall be the smallest sritisal power PO'NER RATIO (MCPR)         ratio (CPR) that mcists iR the sore fur eash slass of fuel.
The CPR is that pm.".'er iR the assembly that is sals1:1lateel by applisatioR of the appropriate sorrelatioR(s) to sa1:1se some poiRt iR the assembly to mcperieRse traRsitioR boiliRg, elivieleel by the ast1:1al assembly operatiRg power.
TraRsitioR boiliRg meami the boiliRg regime betweeR R1:1sleate aRel film boiliRg. TraRsitioR boiliRg is the regime iR whish both R1:1sleate aRel (continued)
DAEC                                 1.1-6                                 Amendment~
l

Definitions 1.1 1.1      Definitions (continued)
MINIMUM CRITICAL                filFR boiliRg oss1:1r iRterFRitteRtly with Reither type beiRg PO'A'ER RATIO (MCPR)             soFRpletely stable.
MODE                             A MODE shall sorrespoRd to aRy ORO iRsl1:1sive soFRbiRatioR of FRode switsh positioR, average roaster soolaRt teFRperat1:1Fe, aRd reastor vessel head slos1:1re bolt teRsioRiRg spesified iR Table 1.1 1 with f1:1el iR the roaster 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,                         ' I subsystem, division, component, or device to perform its specified safety function(s) are also capable of performing their related support function(s).
PRESSURE AND                      The PTLR is the 1:1Rit spesifis dos1:1FReRt that provides TEMPERATURE LIMITS                the roaster vessel press1:1re aRd teFRperat1:1re liFRits, REPORT (PTLR)                     iRsl1:1diRg heat1:1p aRd sooldowR rates, for the s1:1rrent .
roaster vessel fl1:10Rse period. These press1:1Fe aRd teFRperat1:1ro liFRits shall be deterFRiRed for eash fl1:10Rse period iR assordaRse with SpesifisatioR 5.e.7.
RATED Tl=IERMAL                  RTP shall be a total reastor sore heat traRsfer rate to POVVER (RTP)                     the roaster soolaRt of 1912 M'A't.
REACTOR                          The RPS RESPONSE TIME shall be that tiFRe iRterval PROTECTION SYSTEM                froFR wheR the FRORitored paraFReter exseeds its RPS (RPS) RESPO~JSE                  trip setpoiRt at the shaRROI SeRsor l:IRtil de
:::i::JMe           .             eRergizatioR of the ssraFR pilot valve soleRoids. The respoRse tiFRe FRay be FReas1:1red by FReaRs of aRy series of seq1:10Rtial, overlappiRg, or total steps so that the eRtire respORSO tiFRe is FReas1:1red.
(continued)
DAEC                                     1.1-7                               Amendment~

Definitions 1.1 1.1 Definitions (continued)
SHUTDOWN M/\RGl~J            SOM sl:iall Be tl:ie aR'lOl::IRt of Feastivity BY wl:iisl:i tl:ie (SOM)                        roastOF is Sl::IBGFitisal OF wo1::1ld BO Sl::IBGFitisal tl:iF01::1gl:io1::1t tl:ie opemtiRg sysle ass1::1R'liRg tl:iat:
a.,.      Tl:ie FeastoF is >EOROR fFOe;
                             ,13..,. Tl:ie R'!OelemtoF teR'lpemt1::1Fe is): 68&deg;r (20&deg;G),
GOFFOspoRdiRg to tl:ie R'!ost roastive state; aRd .
                             &.,       /\II GORtFOI FOds aFO f1::1lly iRserteel O>EGept foF tl:ie siRgle soRtFOI md of l:iigl:iest reastivity v:ortl:i, wl:iisl:i is aSSl::IR'!Od to BO f1::1lly 1.'.'itl:idFaWR 1.vitl:i tl:ie ooFO iR its R'!ost Feaotive state el1::1FiRg tl:ie opemtiRg oyole. '.'Vitl:i GORtFOI FOSS Rot oapaBle of BOiRg f1::1lly iRserteel, tl:ie reaotivity 111ortl:i of tl:iese ooRtFOI mds R'll::ISt BO aGGOl::IRted foF iR tl:ie detOFR'liRatioR of
                                       .ggM,.
(continued)
DAEC                                    1.1-8                                        Amendment~

Definitions 1.1 1.1 Definitions (continued)
THERMAL POVVER              THERMAL PQ\O/ER shall be the total reaotor sore heat transfer rate to the reaotor ooolant.
TURBINE BYPASS SYSTEM       The TURBl~~E BYPASS SYSTEM RESPO~JSE TIME              RESPO~JSE TIME oonsists of two oomponents:
a-,. The time from initial movement of the main t1:1rbine stop valve or oontrol va1,,e 1:1ntil 80% of the t1:1rbine bypass oapaoity is established; and
                             &. The time from initial movement of the main t1:1rbine stop valve or oontrol valve 1:1ntil initial mo,,ement of the turbine bypass ,,{alve.
The response time may be meas1:1red by means of any series of seq1:1ential, overlapping, or total steps so that the entire response time is meas1:1red.
(oontin1:1ed)
DAEC                              1.1-9                               Amendment~

Definitions 1.1 Table 1.1 1 (page 1 of 1)
MODES REAbTQR MQQE                   NJERAGE 8WITbH                REAbTQR MQQE             TITLE P081TIQN                 bOOLAr>JT TEMPERATl:JRE (0 J;'.)
4        Poi.var Operation               -R-1:ifl                         WA
     ~        Startup                          Rcfue1C.it or Startup/Hot       WA Standby
     ~        -Met 81:lutele'o'ii'flc.it      -ehutdowR                        7~
4        ~ 81:lutelewflC.it               ShutdowR                        ~~
     ~        Refuelifl~Cet                    8hutdoi.,.in or Refuel          WA W     All roaster vessel head slosure bolts fully tensioned.
t9*   One or more roaster vessel head slosuro bolts less than fully tensioned.
DAEC                                         1.1-10                         Amendment~

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)
DAEC                                   1.2-1                              Amendment~

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 ...
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)
DAEC                                 1.2-2                          Amendment~
l_

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 ...
A.2.2.1 Reduce ...
OR A.2.2.2 Perform ...
OR A.3    Align ...
This example represents a more complicated use of logical connectors. Required Actions A.1, A.2, and A.3 are alternative choices, only one of which must be performed as indicated by the use of the logical connector OR and the left justified placement.
Any one of these three Actions may be chosen. If A.2 is chosen, then both A.2.1 and A.2.2 must be performed as indicated by the logical connector AND. Required Action A.2.2 is met by performing A.2.2.1 or A.2.2.2. The indented position of the logical connector OR indicates that A.2.2.1 and A.2.2.2 are alternative choices, only one of which must be performed.
DAEC                                  1.2-3                            Amendment~

Completion Times 1.3 1.0 USE AND APPLICATION 1.3 Complet1on Times PURPOSE            The purpose of this section is to establish the Completion Time convention and to provide guidance for its use.
BACKGROUN          Limiting Conditions for Operation (LCOs) specify minimum requirements for ensuring safe operation of the unit The INSERT 1.3-1              ACTIONS associated with an LCO state Conditions that typically describe the ways in which the requirements of the LCO can fail to be met. Specified with each stated Condition are Required Action(s) and Completion Times(s).
DESCRIPTION       The Completion Time is the amount of time allowed for completing a Required Action. It is referenced to the time of discovery of a situation (e.g., inoperable equipment or variable not within limits) that requires entering an ACTIONS Condition unless otherwise specified, providing the unit is in a MODE or specified condition stated in the Applicability of the LCO. Required Actions must be completed prior to the expiration of the specified Completion Time. An ACTIONS Condition remains in effect and the Required Actions apply until the Condition no longer exists or the unit is not within the LCO Applicability.
If situations are discovered that require entry into more than one Condition at a time within a single LCO (multiple Conditions), the Required Actions for each Condition must be performed within the associated Completion Time. When in multiple Conditions, separate Completion Times are tracked for each Condition starting from the time of discovery of the situation that required entry into the Condition.
Once a Condition has been entered, subsequent 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.
(continued)
DAEC                                  1.3-1                              Amendment~

Completion Times 1.3 1.3 Completion Times DESCRIPTION        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 first inoperability; and
: b. Must remain inoperable or not within limits after the first inoperability is resolved.
The total Completion Time allowed for completing a Required Action to address the subsequent inoperability shall be limited to the more restrictive of either:
: a. The stated Completion Time, as measured from the initial entry into the Condition, plus an additional 24 hours; or
: b. The stated Completion Time as measured from discovery of the subsequent inoperability.
The above Completion Time extensions do not apply to those Specifications that have exceptions that allow completely separate re-entry into the Condition (for each 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 hours," where the Completion Time is referenced from a previous completion of the Required Action versus the time of Condition entry) or as a time modified by the phrase "from discovery ... "
Example 1.3-3 illustrates one use of this type of Completion Time.
The 10 day Completion Time specified for Condition A and B in Example 1.3-3 may not be extended.
(continued)
DAEC                                  1.3-2                             Amendment~

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 hours Action and r                     associated Completion Time not met. B.2 Be in MODE 4.        36 hours 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 hours AND in MODE 4 within 36 hours. A total of 12 hours is allowed for reaching MODE 3 and a total of 36 hours (not 48 hours) is allowed for reaching MODE 4 from the time that Condition B was entered. If MODE 3 is reached within 6 hours, the time allowed for reaching MODE 4 is the next 30 hours ,
because the total time allowed for reaching MODE 4 is 36 hours.
If Condition B is entered while in MODE 3, the time allowed for reaching MODE 4 is the next 36 hours.
(continued)
DAEC                                 1.3-3                             Amendment~

r Completion Times 1.3 1 .3   Completion Times EXAMPLES              EXAMPLE 1.3-2 (continued)
ACTIONS, CONDITION              REQUIRED ACTION          COMPLETION TIME A. One pump          A.1 Restore pump to        7 days     ,
inoperable.             OPERABLE status.              l B. Required             B.1 Be in MODE 3.          12 hours Action and                                                        /
associated          AND Completion Time not met.       B.2 Be in MODE 4.          36 hours I
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 Bis entered, Conditions A and Bare exited, and therefore, the Required Actions of Condition B may be terminated.
When a second pump is declared inoperable while the first pump is still inoperable, Condition A is not re-entered for the second pump. LGO d.0.d is eRtered, siRse the /\GTION8 do Rot iRGll:lde a GoRditioR for more thaR ORO iRoperable pl:lmp. The GompletioR Time slosk for GoRditioR A does Rot stop after LGO d.0.d is eRtered, bl:lt soRtiRl:les to be trasked from the time GoRditioR /\
was initially enteFed.
                       'Nhile iR LGO d.0.d, if ORO of the iRoperable pl:lmps is restored to OPERABLE statl:ls aRd the GompletioR Time for GoRditioR A has Rot expired, LGO d.0.d may be exited aRd operatioR soRtiRl:led iR assordaRse 1J.1ith GoRditioR /\.
(continued)
DAEC                                      1.3-4                              Amendment~

Completion Times 1.3 1.3 Completion Times EXAMPLES           EXAMPLE 1.3-2 (continued)
VVhile in LCO a.O.a, if one of the inoperable p1:1mps is restored to OPERABLE stat1:1s and the Completion Time for Condition A has mc:pired, LCO a.O.a may be mc:ited and operation sontin1:1ed in assordanse v1ith Condition B. The Completion Time for Condition B is trasked from the time the Condition A Completion Time expired.
On restoring one of the pumps to OPERABLE status, the Condition A Completion Time is not reset, but continues from the time the first pump was declared inoperable. This Completion Time may be extended if the pump restored to OPERABLE status was the first inoperable pump. A 24 hour extension to the stated 7 days is allowed, provided this does not result in the second pump being inoperable for> 7 days.
(continued)
DAEC                                1.3-5                             Amendment~

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 Function X 7 days Function X          subsystem to subsystem           OPERABLE status. AND inoperable.
10 days from discovery of failure to meet the LCO B. One            8.1 Restore Function Y 72 hours Function Y         subsystem to subsystem           OPERABLE status. AND inoperable.
10 days from discovery of failure to meet the LCO C. One            C.1 Restore            72 hours Function X          Function X subsystem          subsystem to inoperable.        OPERABLE status.
AND           OR One           C.2 Restore            72 hours Function Y        Function Y subsystem         subsystem to inoperable        OPERABLE status.
(continued)
DAEC                                  1.3-6                       Amendment~

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 discovered).
If Required Action C.2 is completed within the specified Completion Time, Conditions Band Care exited. If the Completion Time for Required Action A.1 has not expired, operation may continue in accordance with Condition A. The remaining Completion Time in Condition A is measured from the time the affected subsystem was declared inoperable (i.e., initial entry into Condition A).
The Completion Times of Conditions A and Bare modified by a logical connector, with a separate 10 day Completion Time measured from the time it was discovered the LCO was not met.
In this example, without the separate Completion Time, it would be possible to alternate between Conditions A, B, and C in such a manner that operation could continue indefinitely without ever restoring systems to meet the LCO. The separate Completion Time modified by the phrase "from discovery of failure to meet the LCO" is designed to prevent indefinite continued operation while not meeting the LCO. This Completion Time allows for an exception to the normal "time zero" for beginning the Completion Time "clock". In this instance, the Completion Time "time zero" is specified as commencing at the time the LCO was initially not met, instead of at the time the associated Condition was entered.
(continued)
DAEC                                1.3-7                             Amendment~

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) to 4 hours valves                 OPERABLE inoperable.            status.
B. Required
* B.1 Be in MODE 3.          12 hours Action and associated         AND Completion Time not met.      B.2 Be in MODE 4.          36 hours 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 hours provided this does not result in any subsequent valve being inoperable for> 4 hours.
If the Completion Time of 4 hours (plus the extension) expires while one or more valves are still inoperable, Condition B is entered.
(continued)
DAEC                                  1.3-8                             Amendment~

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 hours valves                        OPERABLE status.
inoperable.
B. Required                  B.1 Be in MODE 3.             12 hours Action and associated              AND Completion Time not met.            B.2 Be in MODE 4.             36 hours I
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)
DAEC                                        1.3-9                                    Amendment~

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 8 inoperable.          SR 3.x.x.x.        hours OR A.2 Reduce              8 hours THERMAL POWER to ::;; 50%
RTP.
B. Required        B.1 Be in MODE 3.       12 hours Action and associated Completion Time not met.
(continued)
DAEC                                 1.3-10                            Amendment~

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 hour interval of Required Action A.1 begins when Condition A is entered and the initial performance of Required Action A.1 must be complete within the first 8 hour interval. If Required Action A.1 is followed and the Required Action is not met within the Completion Time (plus the extension allowed by SR 3.0.2),
Condition B is entered. If Required Action A.2 is followed and the Completion Time of 8 hours 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)
DAEC                                 1.3-11                           Amendment~

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 hour subsystem              subsystem inoperable.            isolated.           AND Once per 8 hours thereafter AND A.2 Restore subsystem 72 hours to OPERABLE status.
B. Required             B.1 Be in MODE 3.       12 hours Action and associated          AND Completion Time not met.       B.2 Be in MODE 4.       36 hours Required Action A.1 has two Completion Times. The 1 hour Completion Time begins at the time the Condition is entered and each "Once per 8 hours thereafter'' interval begins upon performance of Required Action A.1.
If after Condition A is entered, Required Action A.1 is not met within either the initial 1 hour or any subsequent 8 hour interval from the previous performance (plus the extension allowed by SR 3.0.2), Condition B is entered. The Completion Time clock for Condition A does not stop after Condition Bis entered, but continues from the time Condition A was initially entered. If Required Action A.1 (continued)
DAEC                                  1.3-12                             Amendment~

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 Required COMPLETION       Action should be pursued without delay and in a controlled TIME             manner.
DAEC                                1.3-13                              Amendment~

INSERT 1.3-1 Page 1 of 1 The following discussion and examples contain references to reactor thermal power and reactor MODES. Specifically, Required Actions of several examples direct a change in reactor thermal power or entry into various reactor MODES. Although these Required Actions do not apply to a permanently shut down and defueled facility, the discussion and examples are retained because they continue to have illustrative value. For purposes of these examples, reactor MODES are defined below.
MODE 1 - Power Operation MODE 2 - Startup MODE 3 - Hot Shutdown, reactor coolant> 212&deg;F MODE 4 - Cold Shutdown, reactor coolant~ 212&deg;F MODE 5 - Refueling

Frequency 1.4 1.0 USE AND APPLICATION 1 .4 Frequency PURPOSE          The purpose of this section is to define the proper use and I......_ _ _ _ _ __!---_:~~application of Frequency requirements .
INSERT 1.4-1 DESCRIPTION      Each Surveillance Requirement (SR) has a specified Frequency in which the Surveillance must be met in order to meet the associated LCO. An understanding of the correct application of the specified Frequency is necessary for compliance with the SR.
The "specified Frequency" is referred to throughout this section and each of the Specifications of Section 3.0, Surveillance Requirement (SR) Applicability. The "specified Frequency" consists of the requirements of the Frequency column of each SR, as well as certain Notes in the Surveillance column that modify performance requirements.
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       Y Notes in the Surveillance, as part of the Surveillance, or both.       ~,
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 (conUnued)
DAEC                                 1.4-1                            Amendment~

Frequency 1.4 1.4  Frequency DESCRIPTION     criteria. Some Surveillances contain notes that modify (continued)    the Frequency of performance or the conditions during which the acceptance criteria must be satisfied. For these Surveillances, the MODE-entry restrictions of SR 3.0.4 may not apply. Such a Surveillance is not required to be performed prior to entering a MODE or other specified condition in the Applicability of the associated LCO if any of the following three conditions are satisfied:
: a.      The Surveillance is not required to be met in the MODE or other specified condition to be entered; or
: b.      The Surveillance is required to be met in the MODE or other specified condition to be entered, but has been performed within the specified Frequency (i.e., it is current) and is known not to be failed; or
: c.      The Surveillance is required to be met, but not performed, in the MODE or other specified condition to be entered, and is known not to be failed.
Examples 1.4-3, 1.4-4, 1.4-5, and 1.4-6 discusses these special situations.
(continued)
DAEC                               1.4-2                           Amendment~

Frequency 1.4 1.4 Frequency (continued)
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.
EXAMPLE 1.4-1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                           FREQUENCY Perform CHANNEL CHECK.                           12 hours Example 1.4-1 contains the type of SR most often encountered in the Technical Specifications (TS). The Frequency specifies an interval (12 hours) 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 hours, 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 exc_eeded 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.
If the interval as specified by SR 3.0.2 is exceeded while the unit is not in a MODE or other specified condition in the Applicability of the LCO for which performance of the SR is required, then SR 3.0.4 becomes applicable. The Surveillance must be performed within the Frequency requirements of SR 3.0.2, as modified by SR 3.0.3, prior to entry into the MODE or other specified condition or the LCO is considered not met (in accordance with SR 3.0.1) and LCO 3.0.4 becomes applicable.
(continued)
DAEC                                 1.4-3                        Amendment No. 293

Frequency f.4 1.4  Frequency EXAMPLES       EXAMPLE 1.4-2 (continued)
SURVEILLANCE REQUIREMENTS SURVEILLANCE                         FREQUENCY Verify flow is within limits.                       Once within r
12 hours after~ 25%
RTP 24 hours 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 hours.
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.
               "Thereafter" indicates future performances must be established per SR 3.0.2, but only after a specified condition is first met (i.e.,
the "once" performance in this example). If reactor power decreases to< 25% RTP, the measurement of both intervals stops. New intervals start upon reactor power reaching 25%
RTP.*
(continued)
DAEC                                                         Amendment No. 258

Frequency 1.4 1.4 Frequency EXAMPLES       EXAMPLE 1.4-3 (continued)
SURVEILLANCE REQUIREMENTS SURVEILLANCE                            FREQUENCY
                --------------------------N()TE----------------------------
Not required to be performed until 12 hours after 2 25% RTP.
Perform channel adjustment.                                 7 days The interval continues whether or not the unit operation is
              < 25% RTP between performances.
As the Note modifies the required performance of the Surveillance, it is construed to be part of the "specified Frequency." Should the 7 day interval be exceeded while operation is< 25% RTP, this Note allows 12 hours after power reaches 2 25% RTP to perform the Surveillance. The Surveillance is still considered to be within the "specified Frequency." Therefore, if the Surveillance 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 hours (plus the extension allowed by SR 3.0.2) with power 2 t
25% RTP.
Once the unit reaches 25% RTP, 12 hours would be allowed for completing the Surveillance. If the Surveillance were not performed within this 12 hour 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.
(continued)
DAEC                             1.4-5                                 Amendment~

Frequency 1.4 1.4  Frequency EXAMPLES        EXAMPLE 1.4-4 (continued)
SURVEILLANCE REQUIREMENTS SURVEILLANCE                            FREQUENCY
                 -------------------------N()TE-----------------------------
Only required to be met in MODE 1.
Verify leakage rates are within limits.                     24 hours Example 1.4-4 specifies that the requirements of this Surveillance do not have to be met until the unit is in M()DE 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 hour interval (plus the extension allowed by SR 3.0.2), but the unit was not in M()DE 1, there would be no failure of the SR nor failure to meet the LC().
Therefore, no violation of SR 3.0.4 occurs when changing M()DES, even with the 24 hour Frequency exceeded, provided the M()DE change was not made into MODE 1. Prior to entering M()DE 1 (assuming again that the 24 hour Frequency were not met), SR 3.0.4 would require satisfying the SR.
(continued)
DAEC                              1.4-6                                      Amendment~

Frequency 1.4 1.4  Frequency EXAMPLES       EXAMPLE 1.4-5 (continued)
SURVEILLANCE REQUIREMENTS SURVEILLANCE                             FREQUENCY
                --------------------------N()TE-----------------------------
()nly required to be performed in MODE 1.
t Perform complete cycle of the valve                          7 days The interval continues, whether or not the unit operation is in M()DE 1, 2 or 3 (the assumed Applicability of the associated LCO) between performances.
As the Note modifies the required performance of the Surveillance, the Note is construed to be part of the "specified Frequency." Should the 7 day interval be exceeded while operation is not in M()DE 1, this Note allows entry into and operation in M()DES 2 and 3 to perform the Surveillance. The Surveillance is still considered to be performed within. the "specified Frequency" if completed prior to entering MODE 1.
Therefore, if the Surveillance were not performed within the 7 day (plus the extension allowed by SR 3.0.2) interval, but operation was not in MODE 1, 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 result in entry into MODE 1.
Once the unit reaches M()DE 1, the requirement for the Surveillance to be performed within its specified Frequency applies and would require that the Surveillance had been performed. If the Surveillance were not performed prior to entering MODE 1, there would then be a failure to perform a Surveillance within the specified Frequency, and the provisions of SR 3.0.3 would apply.
(continued)
DAEC                             1.4-7                                 Amendment No. 2Qd

Frequency 1.4 1.4  Frequency EXAMPLES        EXAMPLE 1.4-6 (continued)
SURVEILLANCE REQUIREMENTS SURVEILLANCE                             FREQUENCY
                 --------------------------N()TE----------------------------
Not required to be met in M()DE 3.
Verify parameter is within limits.                           24 hours Example 1.4-6 specifies that the requirements of this Surveillance do not have to be met while the unit is in M()DE 3 (the assumed Applicability of the associated LC() is MODES 1, 2, and 3). 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 hour interval (plus the extension allowed by SR 3.0.2), and the unit was in M()DE 3, there would be no failure of the SR nor failure to meet the LC(). Therefore, no violation of SR 3.0.4 occurs when changing M()DES to enter M()DE 3, even with the 24 hour Frequency exceeded, provided the M()DE change does not result in entry into MODE 2. Prior to entering MODE 2 (assuming again that the 24 hour Frequency were not met), SR 3.0.4 would require satisfying the SR.
DAEC                                   1.4-8                                 Amendment No. 293

INSERT 1.4-1 Page 1 of 1 The following discussion and examples contain references to reactor thermal power and reactor MODES. Specifically, Required Actions of several examples direct a change in reactor thermal power or entry into various reactor MODES. Although these Required Actions do not apply to a permanently shut down and defueled facility, the discussion and examples are retained because they continue to have illustrative value. For purposes of these examples, reactor MODES are defined below.
MODE 1 - Power Operation MODE 2 - Startup MODE 3 - Hot Shutdown, reactor coolant> 212&deg;F MODE 4 - Cold Shutdown, reactor coolant :5 212&deg;F MODE 5 - Refueling

!DELETED           I 2.~S/\rETY LIMITS (SLs) 2.1.1 Reastor Core SLs 2.1.1.1    ruel Cladding Integrity '.0/ith the reastor stearn dorne pressure ~ 686 psig or sore flow~ 10% rated sore flow:
Tl=4ERM/\L POVVER shall be~ 21.7% RTP.
2.1.1.2    MCPR VVith the reastor stearn dorne pressure~ 686 psig and sore flow~ 10% rated sore flow:
MCPR shall be~ 1.08 for two resiroulation loop operation or
                                ~ 1.11 for single resiroulation loop operation.
t 2.1.1.3    Reastor Vessel \Nater Level Reastor vessel water level shall be greater than 15 inshes above the top of astive irradiated fuel.
2.1.2 Reastor Coolant Systern Pressure SL Reastor stearn dorne pressure shall be~ 1335 psig.
2.2 SL Violations
            'Nith any SL violation, the follov:ing astions shall be sornpleted within 2 hours:
            ~        Restore sornplianse with all SLs; and
            ~        rully insert al_l insertable rods.
DAEC                                      2.0-1                        Amendment No. 297

LCO Applicability 3.0 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY LCO 3.0.1            LCOs shall be met during the MODEa or other specified conditions in the Applicability, except as provided in LCO 3.0.2.,..b(;G 3.0.7, LGO 3.0.8, aRd LGO 3.0.Q.
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 LGO 3.0.5 aRd 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       r   \OJheR aR LGO is Rot met aRd the assosiated AGTIONa are Rot
!D_e_le_te_d_._ _ _____._
et, aR assosiated AGTIO~J is Rot provided, or if direeted by the assoeiated AGTIONg, the i:mit shall be plased iR a MODE OF other spesified soRditioR iR whish the LGO is Rot applieable. AstioR shall be iRitiated withiR 1 ho1:1r to plase the 1:1Rit, as applisable, iR:
a,.       MODE 2 v:ithiR Q ho1:1rs; a--:-     MODE 3 withiR 13 ho1:1rs; aRd
                           &.-       MODE 4 withiR 37 ho1:1rs.
ExeeptioRs to this apesifieatioR are stated iR the iRdivid1:1al apesifisatioRs.
Where sorreetive meas1:1res are eompleted that permit operatioR iR assordaRee with the LGO or AGTIONg, sompletioR of the astiORS req1:1ired by LGO 3.0.3 is Rot req1:1ired.
LGO 3.0.3 is ORiy applieable iR MODEg 1, 2, aRd d.
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; (continued)
DAEC                                        3.0-1                            Amendment :J7+

LCO Applicability 3.0 3.0 LCO APPLICABILITY LCO 3.0.4   b.      After performance of a risk assessment addressing (continued)         inoperable systems and components, consideration of the results, determination of the acceptability of entering the MODE or other specified condition in the Applicability, and establishment of risk management actions, if appropriate; exceptions to this Specification are stated in the individual Specifications, or
: c.      When an allowance is stated in the individual value, parameter, or other Specification.
This gpeeifieation shall not prevent ehanges in MOQEg or other speeified eonditions in the Applieability that are req1::1ired to eomply with ACTIQNg or that are part of a sh1::1tdov:n of the 1::1nit.
r LCO 3.0.5 LCO 3.0.6       When a supported system LCO is not met solely due to a support system LCO not being met, the Conditions and Required Actions associated with this supported system are not required to be entered. Only the support system LCO ACTIONS are required to be entered. This is an exception to LCO 3.0.2 for the supported system. In this event, an evaluation shall be performed in accordance with Specification 5.5.11, "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)
DAEC                               3.0-2                             Amendment~            -f"

LCO Applicability 3.0 3.0     LCO APPLICABILITY (continued)
LCO 3.0.7          Speoial Oper=ations LCOs in Seotion 3.10 allow speoified Teohnioal
_!D_e_le_t_e_d_._ _ _ _ J: -peoifioations (TS) reeiuirements to be ohan&sect;ed to permit performanoe of speoial tests and operations. Unless otherwise speoified, all other TS reeiuirements remain unohan&sect;ed.
Complianoe v1ith Speoial Oper=ations LCOs is optional. \0/hen a Speoial Operations LCO is desired to be met but is not met, the ACTIONS of the Speoial Operations LCO shall be met. \0/hen a Speoial Operations LCO is not desired to be met, entry into a MODE or other speoified oondition in the Applioability shall only be made in aooordanoe with the other applioable Speoifioations.
LCO 3.0.8         'A'hen one or more reeiuired snubbers are unable to perform their
,....!D-e-le_t_e_d_.- - - -
~------~
J   assooiated support funotion(s), any affeoted supported LCO(s) are not reeiuired to be deolared not met solely for this reason if risk is assessed and mana&sect;ed, and:
: a. the snubbers not able to perform their assooiated support funotion(s) are assooiated 'Nith only one train or subsystem of multiple train or subsystem supported system or are assooiated with a sin&sect;le trairi or subsystem supported system and are able to perform their assooiated support funotion within 72 hours; or
: b. the snubbers not able to perform their assooiated support funotion (s) are assooiated 'Nith more than one train or subsystem of a multiple train or subsystem supported system and are able to perform their assooiated support funotion within 12 hours.
* At the end of the speoified period the reeiuired snubbers must be able to perform their assooiated support funotion(s), or the affeoted supported system LCO(s) shall be deolared not met.
LCO 3.0.9         When one or more required barriers are unable to perform their related support function(s), any supported system LCO(s) are not required to be declared not met solely for this reason for up to 30 days provided that at least one train or subsystem of the supported system is OPERABLE and supported by barriers capable of providing their related (continued)
DAEC                                    3.0-3                           Amendment !2:7+

LCO Applicability 3.0 3.0    LCO APPLICABILITY (continued)
LCO 3.0.9    support function(s), and risk is assessed and managed. This (continued)  specification may be concurrently applied to more than one train or subsystem of a multiple train or subsystem supported system provided at least one train or subsystem of the supported system is OPERABLE and the barriers supporting each of these trains or subsystems provide their related support function(s) for different categories of initiating events.
F"or tl:ie purposes of tl:iis spesifisation, tl:ie Fligl:i Pressure Coolant lnjestion system, tl:ie Reastor Gore Isolation Cooling system, and tl:ie Automatio Depressuri;zation System are oonsidered independent subsystems of a single system.
If the required OPERABLE train or subsystem becomes inoperable while this specification is in use, it must be restored to OPERABLE status within 24 hours or the provisions of this specification cannot be applied to the trains or subsystems supported by the barriers that cannot perform their related support function(s).
At the end of the specified period, the required barriers must be able to perform their related support function(s) or the supported system LCO (s) shall be declared not met.
DAEC                                     3.0-3a                               Amendment~

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 exoept 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 t
specified Frequency, then compliance with the requirement to declare the LCO not met may be delayed, from the time of discovery, up to 24 hours or up to the limit of the specified Frequency, whichever is greater. This delay period is permitted to allow performance of the Surveillance. A risk evaluation shall be performed for any Surveillance delayed greater than 24 hours 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)
DAEC                               3.0-4                           Amendment~

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 MODEg or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.
DAEC                              3.0-5                            Amendment~

               ~DELETED                    '.
3.1 REAG~ONTROL S&#xa5;STEMs d.1.1 a~UTDOVVN MARGIN (aDM)
LCO d.1.1              aDM shall be:
a-:- ~ 0.d8% Ak/k, with the highest 'North sontrol rod analytisally determined; or
                       &.-  ~ 0.28% Ak/k, with the highest 1..vorth sontrol rod determined by test-:
APPLICABILITY:         MODEa 1, 2, d, 4, and 5.
ACTIO~Jg CQNDITION                      REQUIRED ACTION               COMPLETIQN TIME A:     aDM not within limits in      A:4     Restore aDM to within      e hOl:irS MQDE 1 or 2.                           -HfR-its.:
 ~     ReEll:iired iAcetion and       M       Be in MODE d.               12 hours assosiated Completion Time of Condition A not ffiet-:.
G-:-  aDM not '1.Vithin limits in    ~       Initiate astion to fl:illy  Immediately MODE d.                                insert all insertable sontrol rods.
:- gDM not within limits in       .Q-4    Initiate aetion to fl:illy  Immediately MODE 4.                                insert all insertable eontrol rods.
ANQ (sontinl:ied)
DAEC                                       3.1-1                                 Amendment~

J I I d

Reastivity Anomalies
                                                                                      ~
SURVEILLO  ..~JCE REQUIREME  ... N+S SURVEILLANCE                                 FREQUENCY SR 3.1.2.1     ven"f~ GOFO Feastivity diffemnse bet*11een th
               ~I                                                   Once within mon1t0Fed  eo k and the l3FOdieted wf.thffi.FOeri                      ~u eom e  k is   24 hm1Fs afteF
                      +/- 1% Ak/k.                              e1r   Feashing eq1::1ilibFi1::1m sonditions following start1::1t3 afteF f1::1el R=l8)l8FR8Rt &#xa5;JitRiR the FeastoF 13FeSSl::IFe 11essel OF sontFOI FOd Fe13lasement ANG 1QQQ Ml,OJg,q::
theFeafteF d1::1Fing 013eFations in MQgE 1 g/\EC                                                                ,A,men dment 3Q4

- - - - - - ~ -------- -------- ----- -
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Control Rod Soram AooumulatoFs
                                                                                  ~
ACTIO~JS (oontinued) co~mlTION                 REQUIRED ACTION               COMPLETION TIME T\vo OF morn oontrol rod ~       Restom ohaFging wateF        1 houF fFom soFam aooumulatoFs              headeF pFeSSUFe to            diSGOl/el)' of inopeFable with FeaotoF         ~ 940 psig.                   oondition B steam dome pFessurn                                           GOnGUFFOnt VJith
     ~ QOO psig.                                                   ohaFging wateF header pFeSSUFO
                                                                   ~ 940 psig ANG B.2.1            ~JOTE Only applioable if the assooiated oontrol rod soram time was within the limits of Table 3.1.4 1 during the last soram time Surveillanoe.
Deolare the assooiated        1 houF oontml rod soram time "slow."
B.2.2 Deolare the assooiated         1 houF oontml rod inoperable.
(oontinued)
DAEC                              3.1 16                              Amendment 223

Control Rod Ssram /\soumulators
                                                                                             ~
/\CTIO~JS (sontinued)
CONQITIQN                       ReQldlReQ ACTION                CQMPbeTION TIMe G.. Qne or more sontrol rod     G,,.:1-    Verifji all sontrol rods       Immediately upon ssram assumulators                      assosiated with
* dissoYeP,i of sharging inoperaele i,&1ith reastor              inoperaele                    water header steam dome pressure                     assumulators are              pressure
      ~ QOO psig.                            fully inserted.                ~ Q40 psig AN.Q
                                  ~           Qeslare the                   1 hour assosiated sontrol rod inoperaele.
~      Required Astion and        .Q4                    ~JOTe assosiated                            Not applisaele if all Completion Time of                    inoperaele sontrol Required /\stion B.1                  rod ssram OF C.1 not met.                       assumulators are assosiated with fully inserted sontrol fee&.
Plase the reaotor              Immediately mode si.1i.1itsh in the Shutdown position.
SldRVelbb/\NCe ReQldlReMeNTS SldRVelbb/\~JCe                                     FReQUe~JCY SR d.1.5.1       Verify eash sontrol rod ssram assumulator                In assordanse with pressure is~ Q40 psig.                                   the Surveillanoe Frequensy Control Program t
Q/\eC                                     d.1 17                             Amendment 280

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APU=IGR
                                                                                     ~
             ~DELETED 3.2 PO'.O/ER DISTRIBUTION LIMITS 3.2.1 AVERAGE PLANAR LINEAR FIEAT GEf:'JERATION RATE (APU=IGR)
LCO 3.2.1            All /\PLFIGRs sRall be less tRan or eeiual to tRe limits spesified in tRe COLR.
APPLICABILITY:      TFIERMAL POVVER ~ 21.7% RTP.
ACTIONS CONDITION                     REQUIRED ACTION               COMPLETIOf:'J
                                                                              ~
A:   Any APU=IGR not witRin         A,4     Restore APLFIGR(s) to   2  ROUFS fffRff&.-                             witRin limits.
  ~    Reeiuired ,Acstion and         S:4     Reduse TFIERMAL         4 ROUFS assosiated Completion                  PO'NER to~ 21.7%
Time not met.                         mP-:        I 8URVEILLAf:'JCE REQUIREMENTS SURVEILLANCE                               rREQUEf:'JCY SR 3.2.1.1        Verify all APLFIGRs are less tRan or eeiual to     Onoe v,ithin tRe lirnits spesified in tRe COLR.                 12 ROUFS after
                                                                      ~21.7% RTP In assordanse with tRe 8urveillanse rreeiuensy Control Pro&sect;ram             t DAEC                                     3.2-1                           Amendment~

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RPS IRstr1::1meRtatioR 3.3.1.1 DELETED 3.3.1.1 Reastor ProtestioR System (RPS) IRstr1::1meRtatioR 3.3.1.2  DELETED 3.3.2.1  DELETED 3.3.3.1  DELETED 3.3.3.2  DELETED .
APPLICABILITY:
3.3.4.1  DELETED 3.3.4.2  DELETED ACTIONS                                                      3.3.5.1  DELETED 3.3.5.2  DELETED
--------------i~+e----13.3.5.3                                        DELETED Separate CoRditioR eRtry is allmued for cash shaRRel.        3.3.6.1  DELETED
------------------13.3.6.2                                            DELETED 3.3.6.3  DELETED co~mlTION                  REQUIRED ACTION               COMPLETION TIME 0Re or more req1::1ired    A4   Piasa shaRROI iR            12 ho1::1rs shaRRels iRoperable.            ffif:r.
                                  ~    Piasa assosiated trip       12 ho1::1rs system iR trip.
0Re or more                M    Piasa shaRRel iR ORO trip   e ho1::1rs Fl::IRStiORS 1.vith ORO or      system iR trip.
more req1::1ired shaRRels iRoperable        Q.g iR both trip systems.
                                  ~    Piasa oRe trip system iR    e ho1::1rs ffif:r.
(SORtiRl::ICd)
DAEC                                     3.3-1                          Amendment~

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LU, lnstrnmentation a.a.a.a A""T"lr'\1"'"'  / -L"    -..I\
  -    -    -   \   1,11  *-,
CO~JDITIO~J                        REQUIRED ACTION            COMPLETIO~J TIME 9-:-    Required Aotion and                  .Q.4    Deolare tl:ie          Immediately assooiated Completion                       assooiated LU, Time of Condition A, B,                     11al1Je(s) inoperable.
or C not met.
Botl:i LLS 1Jal1Jes inoperable due to inoperable el:iannels.
8URVEILLANCE REQUIREME~JTS
+. Refer to Table 3.3.e.3 1 to determine wl=liol:i SRs apply for eael:i Funetion.
~     Wl:ien a el:iannel is plaeed in an inoperable status solely for performanoe of required Surveillanees, entry into assoeiated Conditions and Required /\otions may be delayed for up to e l:iours pro1Jided tl=le assooiated Funetion maintains LLS initiation eapability.
SURVEILLANCE                                   FREQUENCY SR 3.3.e.3.1                Perform Cl=IANNEL i;uNCTIO~JAL TEST for           In aeeordanee portion of tl=le el=lannel outside primary        \Vith the oontainment.                                      Surveillanoe rrequenoy Control Program SR 3.3.e.3.2                Perform Cl=IA~JNEL FUNCTIO~JAL TEST.              In aeoordanoe
                                                                               \vitl:i tl:ie Surveillanoe i;requenoy Control Program (oontinued)
DAEC                                            a.a 11                        Amendment 30&sect;
* i mm m
. 111 iI I1

SFU System Instrumentation 3.3.7.1 3.3 INSTRUMENTATION 3.3.7.1 Standby Filter Unit (SFU) System Instrumentation LCO 3.3.7.1                Two channels of the Control Building Intake Area Radiation - High Function shall be OPERABLE.
APPLICABILITY:             MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary containment, During CORE /\LTER/\TIONS.
ACTIONS
                                                                                                              +-
--------------------------* ---------------------NOTE--------------------------------------------------------
Separate Condition entry is allowed for each channel.
CONDITION                            REQUIRED ACTION                    COMPLETION TIME A.      One or both channels                  A.1    Declare associated             1 hour inoperable.                                  SFU subsystem(s) inoperable.
OR A.2    Place associated SFU           1 hour subsystem(s) in the isolation mode.
DAEC                                              3.3-74                                Amendment~

SFU System Instrumentation 3.3.7.1 SURVEILLANCE REQUIREMENTS
-----------------------------------------------------N()l"E---------------------------------------------------
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 hours provided the other channel is OPERABLE.
SURVEILLANCE                                            FREQUENCY SR 3.3.7.1.1                  Perform CHANNEL CHECK.                                    . In accordance with the Surveillance Frequency Control Program SR 3.3.7.1.2                  Perform CHANNEL FUNCTl()NAL TEST.                           In accordance with the Surveillance Frequency Control Program SR 3.3.7.1.3                 Perform CHANNEL CALIBRATION. The                             In accordance Allowable Value shall be ~ 5 mR/hr.                          with the Surveillance Frequency Control Program SR 3.3.7.1.4                 Perform L()GIC SYSl"EM FUNCTIONAL                            In accordance TEST.                                                       with the Surveillance Frequency Control Program DAEC                                             3.3-75                                  Amendment~

LOP Instrumentation 3.3.8.1 3.3 INSTRUMENTATION 3.3.8.1 Loss of Power (LOP) Instrumentation LCO 3.3.8.1               The LOP instrumentation for each Function in Table 3.3.8.1-1 shall be OPERABLE.
APPLICABILITY:            MODES 1, 2, aRd a, When the associated Diesel Generator is required to be OPERABLE by LCO 3.8.2, "AC Sources Sh1:Jtdovm."
ACTIONS
--------------------------------------------------------NOTE---------------------------------------------------
Separate Condition entry is allowed for each channel.
CONDITION                            REQUIRED ACTION                    COMPLETION TIME A.      One or more Function 1              A.1      Place channel in trip.        1 hour or 3 channels inoperable.
B.      One or more Function 2              B.1      Declare associated            1 hour from discovery channels inoperable.                         Diesel Generator (DG)         of loss of initiation inoperable.                   capability for feature(s) in one or both divisions AND                                    24 hours B.2      Place channel in trip.
(continued)
DAEC                                              3.3-76                               Amendment~

LOP Instrumentation 3.3.8.1 ACTIONS (continued)
CONDITION                REQUIRED ACTION           COMPLETION TIME C. Required Action and   C.1     Declare associated DG  Immediately associated Completion         inoperable.
Time not met.
DAEC                           3.3-77                       Amendment~

LOP Instrumentation 3.3.8.1 SURVEILLANCE REQUIREMENTS
----------------------------------------------------NO"fES-------------------------------------------'---------
: 1. Refer to Table 3.3.8.1-1 to determine which SRs apply for each LOP Function.
: 2. When 1a 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 2 hours provided the associated Function maintains DG initiation capability.
SURVEILLANCE                                         FREQUENCY SR 3.3.8.1.1                 Perform CHANNEL FUNC"flONAL "fEST.                        In accordance with the Surveillance Frequency Control Pro ram SR 3.3.8.1.2                 Perform CHANNEL FUNC"flONAL "fES"f.                       In accordance with the Surveillance Frequency Control Program SR 3.3.8.1.3                 Perform CHANNEL CALIBRA"flON.                             In accordance with the Surveillance Frequency Control Program SR 3.3.8.1.4                 Perform CHANNEL CALIBRATION.                              In accordance with the Surveillance Frequency Control Program SR 3.3.8.1.5                 Perform LOGIC SYS"fEM FUNC"flONAL                         In accordance with "fEST                                                     the Surveillance Frequency Control Program DAEC                                             3.3-78                                 Amendment~

LOP Instrumentation 3.3.8.1 Table 3.3.8.1-1 (page 1 of 1)
Loss of Power Instrumentation REQUIRED CHANNELS            SURVEILLANCE       ALLOWABLE FUNCTION              PER BUS           REQUIREMENTS        VALUE
: 1. 4.16 kV Emergency Bus Undervoltage (Loss of Voltage)
: a. Bus Undervoltage                                   SR 3.3.8.1.2        > 595 Vand SR 3.3.8.1.4        ;2275V SR 3.3.8.1.5
: 2. 4.16 kV Emergency Bus Undervoltage (Degraded Voltage)
: a. Bus Undervoltage                   4              SR 3.3.8.1.1        ~ 3780 Vand SR 3.3.8.1.3        ~3822V SR 3.3.8.1.5
: b. Time Delay                         4              SR 3.3.8.1.1        ~ 7.92 seconds and SR 3.3.8.1.3        ~ 8.5 seconds SR 3.3.8.1.5
: 3. 4.16 kV Emergency Transformer          2              SR 3.3.8.1.2        ~2450V Supply Undervoltage                                   SR 3.3.8.1.3 SR 3.3.8.1.5 DAEC                                             3.3-79                                 Amendment~

RPS Elestris Power Monitoring a.a.s.2 3.3 INSTRUMENTATIO N               IDELETED                 I on System (RPS) Eleotrio Pov.mr Monitoring L(;Q   a.a.s.2               RPS Eleotrioal Proteotion Assemslies (EP,O.s) sRall se OPE RABLE for eaoR inservioe RPS motor generator set or alternate pO'.'JO r supply.
APPLl(;ABILl+Y:       MOQ ES 1 anel 2, MQQ ES a, 4 anel a 1,&#xa5;itR any eontrol reel ,,,itRelra,,,,n from a sore sell sontaining one or more fl:lel assemslies.
A(;+IQ~JS
(;Q~Ql+IO~                       REQldlREQ A(;+IO~J            (;QMPLE+IQ~ +IME A. Qne or sotR inseri,ioe          A:4     Rerno11e assooiateel     72   ROUFS pm.ver supplies i..vi tR one            inseflolise power EPA inoperasle.                         supply(s) from seflolise.
 ~      Qne or sotR inseriJiee          g.,4     Remo11e asseoiateel     1  ROUF power supplies\.\1itR                   insefloliee power sotR EP/\s inepe rasle.                 supply(s) from sefloliee.
 -b-:-  Requireel /\stion a nel         ~        Be in MQQE     a.       12   ROUFS assosiateel (;amp letion
        +ime of (;onelition ,.,I\
or B not met in MQ QE 1
        ~
(eontinueel)
DAEC                                         3.3-8Q                             Amendment~

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Reoirsulation Loops Operating M-4
         \J/"1DELETED 3.4 REACTOR COOLANT aYaTEM (RCa) 3.4 .1 Resirsulation Loops Operating LCO 3.4.1           Two resiroulation loops with rnatohed purnp speeds shall be in operation with sore flov.i as a funotion of Tl=IERMAL POVVER outside the Exslusion Region speoified in the COLR.
One resiroulation loop may be in operation 1Nith sore flow as a funstion of Tl=IERMAL POVVER outside the Exolusion Region speoified in the COLR and with the follmving limits applied when the assooiated LCO is applioable:
a.,. LCO 3.2.1, "AVERAGE PLANAR LINEAR l=IEAT GENERATION RATE 0'\PLl=IGR)," single loop operation lirnits spesified in the COLR; a-:-  LCO 3.2.2, "Ml~JIMUM CRITICAL PO'NER RATIO (MCPR),"
single loop operation lirnits speoified in the .COLR; and
                    &:-   LCO 3.3.1.1, "Reaetor Proteotion aystem (RPa)
Instrumentation," i;unstion 2.b (Average Power Range Monitors i;:1mv Biased l=ligh asram), Allowable Value of Table 3.3.1.1 1 is reset for single loop operation.
APPLICABILITY:      MODEa 1 and 2.
ACTIO~Jg CONDITION                    REQUIRED ACTION               COMPLETION TIME No resirsulation loops                 Plase the reastor      Immediately in operation.                          mode switoh in the Shutdown position.
(eontinued)
DAEC                                    3.4-1                         Amendment~

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A:JM3At>3M.::I                                3:JMV11131\MA8 8+/-M3V\13MIAt>3M 3:JNV1113AMAS, tt=-e SA&sect; pLie SAMS

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EGGS     OpeFating
          ~DELETED                                                                   ~
3.5 EMERGENCY GORE COOLING SYSTEMS (EGGS), RPV VV/\TER l~JVE~ffORY                          l, CONTROL, A~JD REACTOR GORE ISOLATION GOOLl~JG (RGIG) SYSTEM                         '1 3.a.1 EGGS        Operating LGO 3.a.1             EasR EGGS injestion/spray subsystem and tRe Automatis beprossurization System (ADS) funstion of four safety/relief valves sRall be OPERABLE.
APPLICABILITY:        MODE 1, MODES 2 and 3, exsept HigR Pressure Coolant lnjestion (HPGI) is not requirod to be OPERABLE witR roaster steam dome pressuFe ~ 1aO psig and /\DS valves are not required to be OPERABLE v1itR roaster steam dome pressure~ 100 psig.
 /\GTIO~JS LGO 3.0.4 .b is not applisablo to HPGI.
CONDITION                         REQUIRED /\GTIO~J       COMPLETION TIME A-:      One Residual Heat            A4        Restore RHR pump to  30 Days Removal (RHR) pump                     OPERABLE status.
inoperable.
~        One low pressure EGGS -S:4             Restore low pressure 7 days subsystem inopeFable for               EGGS subsystem to reasons otRer tRan                     OPERABLE status.
Condition A.
~        One Gore Spray               {;.:-4    Restore Gore Spray   72 ROUFS subsystem inoperable.                  subsystem to OPERABLE status.
ANQ One or :&\lo RHR             Qg pump(s) inoperable.                                         72 ROUFS
                                      ~         Restore RHR pump(s) to OPERABLE status.
.0.-:-  BotR Gore Spray               .Q.:4     Restore one Gore     72 ROUFS subsystems inoperable.                  Spray subsystem to OPERABLE status.
(sontinued)
DAEC                                        3.5-1                      Amendment~

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                                                                                            &:&.4-8URVEILLANGE REQUIREMENT8 (sontin1:1ed) 8URVEILLA~JGE                                            FREQUE~JGY 1\11"\Tt:
SR a.5.1.2 The low press1:1re soolant injestion (LPGI) system may be sonsidered OPERABLE d1:1ring alignment and operation for deoay heat removal in MODE a, if oapable of being man1:1ally realigned and not otherv1ise inoperable.
                                          ~JOTE
               ~Jot req1:1ired to be met for system vent flow paths opened 1:1nder administrative oontrol.
Verify eaoh EGGS injeotion.tspray s1:1bsystem power                 In aooordanoe operated and a1:1tomatio valve in the flow path, that is not      with the look.ed, sealed, or otherwise seo1:1red in position, is in the     81:1rveillanoe oorreot position.                                                  Freq1:1enoy Control Program SR a.5.1.a   Verify a aO day s1:1pply of nitrogen e>Eists for eaoh AD8           In aooordanoe aoo1:1m1:1lator.                                                   with the 81:1rveillanoe Freq1:1enoy Control Program 8R a.5.1.4    Verify the following EGGS p1:1mps develop the speoified             In aooordanoe flow rate against a system head oorresponding to the               with the speoified roaster press1:1re.                                       INSERVIGE TESTING PROGRAM S&#xa5;8TEM FIEAD NG-. GORRE8POND1~JG
                                             ~       TO A REACTOR SYSTEM         FLOW RATE PUMPS PRESSURE OF
(;efe 8pray          ~  2718 gpm        4      ~     11a psig hPQ             ~  4a20 gpm         4    ;;::. ' ) ( ) ~~:~
                                                      -     -- .---*u (oontin1:1ed)
DAEG                                                                 Amendment a06

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Primary Containment d.e.1.1
        ~DELETED 3.6 CONTAl~JMENT 8&#xa5;8TEM8 d.e.1.1 Primary Containment LCO d.e.1.1          Primary eontainment shall be OPERABLE.
APPL!C/\BILITY:       MODES 1, 2, and d.
ACTIONS CONDITION                  REQldlRED ACTION       COMPLETION TIME A-:     Primary eontainment         A4    Restore 13rimary   1 hour ino13erable.                      eontainment to OPERABLE status.
.g.,. Reeiuired ,Acetion and      M     Be in MODE d . 12 hours assoeiated Com13letion Time not met.               ANG
                                    ~     Be in MODE 4.      de hours DAEC                                   3.6-1                     Amendment~

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Rl=IR8\N System 3:-74 LCO a.7.1          Tvi!o Rl=IRSW s1:1bsystems shall be OPERABLE.
APPLICABILITY:     MODES 1, 2, and    a.
ACTIONS CQ~JDITIQN                    REQbllRED iAcCTIQtiJ.         CQMPLETION TIME A:  One Rl=IR8'N p1:1mp inopeFable.
A4      RestoFe Rl=IRS'JIJ p1:1mp to OPERiA1BLE stat1:1s.
ao days                 1 S:- One Rl=IR8'Al p1:1mp in     M       RestoFe one Rl=IRSl,OJ     7 days eaeh s1:1bsystem                    p1:1mp to QPERABLE inopeFable.                         stat1:1s.
 ~   One Rl=IR8'N                G-:4                ~JOTE s1:1bsystem inopeFable              EnteF applieable fOF reasons othm than               Conditions aRd Condition A                         Reei1:1iFed ,~etions of LCO a.4 .7, "Resid1:1al l=leat Remo1'al (Rl=IR)
Sh1:1tdown Coolin&sect; System l=lot Sh1:1tdm.vn,"
feF Rl=IR sh1:1tdown soolin&sect; made inopemble by Rl=IRS'N System.
Restoro Rl=IR8VV           7 days s1:1bsystem to QPERABLE stat1:1s.
(sontin1:1ed)
DAEC                                  3.7-1                          Amendment~          ,Y

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R\/\.'S System and Ul=IS Deleted.                                                                       ~
3.7.2 River \O.'ater e1:Jpply (R\/\.'S) System and Ultimate l=leat Sink (Ul=IS)
LCO d.7.2             Two R\AJS s1:Jbsystems and Ul=IS sl=iall be OPERABU:.
APPLICABILITY:        MODES 1, 2, and d.
ACTIONS CONDITION                         REQbHRED '&deg;'C+ION                     COMPLE+ION TIME A:    One RVVS s1:Jbsystem              A:4        Restore tl=ie R\O.'S            7 days inoperable.                                  s1:Jbsystem to I
OPERABLE stat1:Js.
S:-   ReEf1:Jired Astion and                             ~JOTE assosiated Completion             Enter applisable Conditions Time of Condition A not           and ReEf1:Jired Astions of LCO ffie-t:-                          d.4.7, "Resid1:Jal l=leat Removal (Rl=IR) Sl=i1:Jtdo1,vn Coolin&sect;
      ~                                 System l=lot Sl:i1:Jtdo1,,~1n," for Rl=IR sl=i1:Jtdo111n soolin&sect; made Botl=i R'NS s1:Jbsystems          inoperable by R'NS System.
inoperable.
      ~                                 -84     Be in MODE       a.                12 ROUFS Ul=IS inoperable.                 ANQ S:-2    Be in MODE 4.                      de ROl:JFS DAEC                                         3.7-3                                Amendment~

41
*I '
   . \fl I ! !    ! I ! i

ESVV System
                                                                               ~
LGO 3.7.3           Two ES'N suesystems sRall ee OPERABLE.
APPLICABILITY:      MODES 1, 2, anel 3.
AGTIO~JS GONDITIQN                    REQl:JIRED ,A,GTIO~J          COMPLETION TIME A:      One ESVV                                NOTES suesystem          :  EnteF applisaele Gonelitions inopemele.               anel ReeiuiFeel '&deg;'etions of LGO 3.8.1, "AG SouFees OpeFatin&sect;," feF eliesel
                                 &sect;eneFatoF maele inopei:aele ey ESW System.
                            ~    EnteF applisaele Gonelitions anel ReeiuiFeel Aetions of LGO 3.4 .7, "Resielual l=leat Remo1,1al ~Rl=IR} SRutelo\'.1n Coolin&sect; System l=lot SRutelo111,r.1n," feF Rl=IR sRutelo1,yn eoolin&sect; maele inopeFaele ey ES'N System.
A4    RestoFe tRe ES',Oiit          7 elays suesystem to OPERABLE status.
 ~      ReeiuiFeel AeUon   M      Be in MODE 3.                 12 ROUFS anel ,A,ssoeiateel Completion Time    ANQ of Gonelition A not met            ~      Be in MQDE 4.                 36  ROUFS
       ~
BotR ES'.'V suesystems inopeFaele.
DAEC                                 3.7-5                         Amendment~

*~
SFU System 3.7.4
   ' 3.7 PLANT SYSTEMS 3.7.4 Standby Filter Unit (SFU) System LCO 3.7.4                 Two SFU subsystems shall be OPERABLE.
     -------------------------------------------------------N()"fE--------------------------------------------------
The control building envelope (CBE) boundary may be opened intermittently under administrative control.
APPLICABILITY:            MODEa 1, 2, and d, During movement of irradiated fuel assemblies in the secondary containment; During GORE ALTERATIONa.
ACTIONS
                                                                                                                           -t-C()NDITl()N                            REQUIRED ACTION                        C()MPLETl()N TIME A.      One SFU subsystem                  A.1       Restore SFU subsystem             7 days inoperable for reasons                       to ()PERABLE.status.
other than Condition B.
Q-4.      Initiate astions to               Immediately implement mitigating astions.
ANG
                                                ~         Verify mitigating astions         24 hours ensure GBE ossupant m<posures to radiologisal Rai!aF8S \\till RS~ 8*See8 an inoperable CBE                                         limits and &#xa5;erify ey boundary                                                  administrati,,e means that GBE oseupants are protested from smoke and el=lemieal hmmrds.
ANG
                                                ~         Restore GBE eounda~               QQ days to OPERABLE status.
(continued)
DAEC                                              3.7-7                           Amendment No. 3Q5

SFU System 3.7.4 ACTIONS   continued CONDITION                   REQUIRED ACTION           COMPLETION TIME Req1:1ired /\etion and    (;4     Be in MODE d.           12 ho1:1rs associated Completion Time of Condition A or    AN-Q.
B not met in MODE 1,      ~       Be in MODE 4.           d6 hOl:JFS 2, OF d.
Required Action and                      NOTE associated Completion    LGO d.0.d is not applicable.
Time of Condition A not met during G.1    Place OPERABLE SFU       Immediately movement of subsystem in the irradiated fuel isolation mode.
assemblies in the B
secondary containment d1:1ring G.2-4 Suspend movement of       Immediately GORE irradiated fuel ALTER/\TIO~rn.
assemblies in the econdary containment.
B D.2.2 S1:1spend GORE            Immediately
                                      /\LTER/\TIONS.
t Both SP:U s1:1bsystems   e:4     Enter LGO d.0.d         Immediately inoperable in MODE 1, 2 or d for reasons other than Condition B.
(continued)
DAEC                               3.7-8                    Amendment No. d05

SFU System 3.7.4 ACTIONS (continued CONDITION                    REQUIRED ACTION             COMPLETION TIME Both SFU subsystems                    ~JOTE inoperable during         LGO d.0.d is not applieable.
movement of irradiated fuel assembles in the secondary containment     ~-1 Suspend movement of          Immediately during GORE                    irradiated fuel assemblies ALTERATIO~rn.                  in the secondary containment.
OR One or more SFU subsystems inoperable     F.2 Suspend GORE                 Immediately due to an inoperable           ALTERATIONS.
CBE boundary during movement of irradiated fuel assemblies in the secondary containment during GORE ALTERATIONS.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                               FREQUENCY SR 3.7.4.1         Operate each SFU subsystem for                 In accordance with the
                   ~ 15 minutes.                                  Surveillance Frequency Control Program SR 3.7.4.2         Perform required SFU filter testing in         In accordance with the accordance with the Ventilation Filter Testing VFTP Program (VFTP).
(continued)
DAEC                                 3.7-9                        Amendment~

SFU System 3.7.4 SURVEILLANCE REQUIREMENTS (continued)
SR 3.7.4.3 SURVEILLANCE Verify each SFU subsystem actuates on an actual or simulated initiation signal.
FREQUENCY In accordance with the Surveillance Frequency Control Program t
SR 3.7.4.4   Perform required CSE unfiltered air inleakage   In accordance with testing in accordance with the Control Building the Control Envelope Habitability Program.                  Building Envelope Habitability Program DAEC                             3.7-10                        Amendment~

CBC System 3.7.5
: 3. 7 PLANT SYSTEMS 3.7.5 Control Building Chiller (CBC) System LCO 3.7.5          Two CBC subsystems shall be OPERABLE.
APPLICABILITY:      MODEe 1, 2, and a, During movement of irradiated fuel assemblies in the secondary containment; During GORE ALTERATIONe.                                           {"
ACTIONS CONDITION                       REQUIRED ACTION           COMPLETION TIME A. One CBC subsystem           A.1        Restore CBC            30 days inoperable.                          subsystem to OPERABLE status.
B. Two CBC subsystems           B:1      Verify control building Once per 4 hours inoperable.                           area temperatures
                                             < 90&deg;F.
AND B.2       Restore one CBC        72 hours subsystem to OPERABLE status.*
-b-:  ReeiuiFed Astien and        -b-:-4     Be in MODE   a.        12 heurs assesiated Gem13letien Time eJ Genditien A er B    AN-Q net met in MODE 1, 2,
      ~                           ~          Be in MODE 4.          a@ heurs (continued)
DAEC                                     3.7-11                      Amendment~
_I

CBC System 3.7.5 ACTIONS (continued)
CONDITION                 REQUIRED ACTION          COMPLETION TIME Required Action and                  ~JOTE
~-     associated Completion  LGO 3.0.3 is not applisable.
Time of Condition A not met during        .Q.1    Place OPERABLE CBC     Immediately movement of             \-.irsystem in operation.
irradiated fuel assemblies in the      OR secondary containment d1:1ring  .Q.24 Suspend movement of      Immediately GORE                          irradiated fuel ALTER/\TIO~Hi.                assemblies in the secondary containment.
C D.2.2  a1:1spend GORE         Immediately
                                     /\LTERATI O~J g.
(continued) t DAEC                            3.7-12                       Amendment~

CBC System 3.7.5 ACTIONS continued CONDITION                     REQUIRED ACTION               COMPLETION TIME Required Action and                         NOTe associated Completion         LCO 3.0.3 is not applioal31e.
Time of Condition B not met during movement                 Suspend movement           Immediately   ,
of irradiated fuel                  of irradiated fuel assemblies in the                   assemblies in the secondary containment d1,1ring CORe secondary containment.                                      t.
ALTeRATIO~rn.
f
                                    ~     g1,1spend CORe             Immediately ALTeRATIO~rn.
t SURVEILLANCE REQUIREMENTS SURVEILLANCE                                 FREQUENCY SR 3.7.5.1           Verify each CBC subsystem has the              In accordance with the capability to remove the available heat load. Surveillance Frequency Control Program DAEC                                   3.7-13                       Amendment~

Main Condenser Off&sect;as
                                                                                      ~
3.7 PLANT SY~~D_el_et_e_d_ _ __
3.7.6~as LCO 3.7.6     TRe gross gaR1R1a activity rate of tRe noble gases R1easured at tRe eteaR1 clot Air Ejector (eclAE) offgas pretreatR1ent Rlonitor sRall be ~ 4:-Q Ci/second after decay of 30 Rlinutes.
APPLICABILITY:       MODE 1, MODES 2 and 3 1:.iitR any R1ain steaR1 line not isolated and eclAE in operation.
ACTIONS CO~JDITION                       ~EQbll~ED ,A,CTION           COMPLETIO~J TIME A:   Gross gaR1R1a acti 1,ity      A4      ~estore gross gaR1R1a       72 ROUFS.
rate of tRe noble gases               activity rate of tRe noble not witRin liRlit.                    gases ~e ~&#xa5;iiRiR liFRi~.
S:-  ~eeiuired /\etion and         M          Isolate all R1ain        12 ROUFS assoeiated CoR1pletion                   steaR1 lines.
TiRle not R1et.
                                     ~
S:-2       Isolate 8clAE.           12 ROUFS
                                    ~
                                    ~          Be in MODE     a.        12 ROUFS ANQ
                                    ~          Be in MODE 4.            36 ROUFS DAEC                                     3.7-14                         Amendment~

Main Turbine Bypass aystem
                                                                                        ~
3.7 PLANT SYSTEMS The Main Turbine Bypass aystem The Main Turbine Bypass aystem shall be OPERABLE.
Deleted LCO 3.2.2, "Ml~JIMUM GRITIG/\L PO'NER RATIO (MGPR)," limits for an inoperable Main Turbine Bypass aystem, as spesified in the GOLR, are made applisable.
        /\PPLICABILITY:   THERM/\L PO'.OJER ~ 21.7% RTP.
        /\CTIO~Jg GONDITIO~J                   REQUIRED /\GTION             COMPLETION TIME Requirements of tl:ie      A4       aatisfy tl:ie           2 hours LCO not met.                        requirements of the
                                                 ,bGG-:-
Required Astion and        -B:4     Reduse THERM/\L         4 hours assosiated Completion               PO'.OJER to~ 21.7%
Time not met.                      m DAEC                                  3.7-16                        Amendment~

Spent Fuel Storage Pool Water Level 3.7.8 3.7 PLANT SYSTEMS
' 3.7.8 Spent Fuel Storage Pool Water Level LCO 3. 7 .8         The spent fuel storage pool water level shall be 2 36 ft.
APPLICABILITY:        During movement of irradiated fuel assemblies in the spent fuel storage pool.
ACTIONS CONDITION                          REQUIRED ACTION             COMPLETION TIME A.      Spent fuel storage             A.1               NOTE pool water level not                    LGO   a.a.a is Rot within limit.                           applioable.
Suspend movement of      Immediately irradiated fuel assemblies in the spent fuel storage pool.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                    FREQUENCY t
SR 3.7.8.1               Verify the spent fuel storage pool water         In accordance with level is 2 36 ft.                               the Surveillance Frequency Control Program DAEC                                        3.7-18                        Amendment~

CB/SBGT Instrument Air System
                                                                                 ~
3.7 P ~ o e l e t e d                            ;
: 3. 7.9 ~
* Gas TroalR1eRI (G~ISBGD IaslrnRleRI Air SysleRl LCO d.7.9           Two CB/SBGT Instrument Air subsystems shall be OPERABLE.
APPLICABILITY:      MODES 1, 2, and d.
ACTIONS CONDITIO~J              REQl:IIRED 1'.\,CTIO~J         COMPLETIO~J TIME A:       One CB/SBQT          M     Deslare reeiuired          4 hours from Instrument Air              feature~s), su1313orted   dissovery of subsystem                    by the ino13erable       Condition .P, ino13erable.                 GB1lSBGT Instrument Air  sonsurrent with subsystem, ino13erable     ino13erability of
                                    ~,,hen the redundant       redundant required required feature(s)      feature(s) are ino13erable.
ANG A!J:   Restore the CB1lSBQT      +aays Instrument Air subsystem to OPERABLE status. :-    Required Astion and M      Be in MODE d.              12 hours Assosiated Com13letion Time of  ANG Condition A not ma:-                 ~      Be in MODE 4.             de hours
        ~
Both CB/SBQT Instrument Air subsystems ino13erable.
DAEC                                3.7-19                    Amendment~

I ..
 ,11   *
     . :I I !

AC Souroes       Operating Deleted
                                                                                                  ~
Operating LCO 3.8.1            The following AC eleatriaal power souroes shall be OPERABLE:
                    &.-    Two qualifieel airauits betv.men the offsite transrnission netv.1ork anel the onsite Class 1E AC Eleetrieal Pm111er Distribution Systern; anel a-:-   Two eliesel generators (DGs).
APPLICABILITY:      MODES 1, 2, anel 3.
t ACTIONS LCO 3.0.4 .b is not appliaable to DGs.
CONDITION                        REQUIRED ACTION                 COMPLETION TIME One offsite eireuit          A-4     Periorrn SR 3.8.1.1 for     1 hour inoperable.                          OPERABLE offsite eireuit Onee per 24 MaFS thereaf:l:er
                                    ~       Restore offsite airauit     Prior to entering to OPERABLE status.         MODE 2 frorn MODE
                                                                        ~
(aontinueel)
                                                                       !Amendment            I DAEC                                    3.8-1                                      tAMD299      +- .

t r - - - - - - ~ ~ ~ . -----   - --- --- -   - - - ------- -
j ! ii         .
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       ~
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                              \
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AC Sources      Shutdovm 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 onsite Class 1E AC electrical power distribution subsystem(s) required by LCO 3.8.8, "Distribution Systems -
Shutdown"; and
: b. One Diesel Generator (DG) capable of supplying one division of the onsite Class 1E AC electrical power distribution subsystem(s) required by LCO 3.8.8.
APPLICABILITY:   MODES 4 and 5, During movement of irradiated fuel assemblies in the secondary containment.
DAEC                               3.8-11                            Amendment~

AC Sources   Shutdovm 3.8.2 ACTIONS LCO 3.0.3 is Rot applioable.
CONDITION                    REQUIRED ACTION                 COMPLETION TIME A. One required offsite    ----------------NOTE------------------
circuit inoperable. Enter applicable Condition and Required Actions of LCO 3.8.8, with one required division de-energized as a result of Condition A.
A.1          Declare affected           Immediately required feature(s),
with no offsite power available, inoperable.
                             ~           SuspeRd CORE               Immediately ALTERATIONS.
ANG A.2.~       Suspend movement           Immediately of irradiated fuel assemblies in the secondary containment.
ANG
                             ~           IRitiate aotioR to FOstoFe Immediately rnquiFed OFHiite po*.veF siFGuit to OPERABLE status.
(continued)
DAEC                             3.8-12                               Amendment~

AC Sources     Shutdown 3.8.2 ACTIONS (continued)
CONDITION                        REQUIRED ACTION             COMPLETION TIME B.        One required DG                      aus13end CORE            ln,n,ediately inoperable.                          ALTERATIONS.
Suspend movement         Immediately of irradiated fuel assemblies in secondary containment Initiate action to r:estore required DG to OPERABLE status.
ln,n,ediately
                                                                                                   +
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                   FREQUENCY SR d.8.2.1                               Nona; 4,. The f.ollowing SRs ar:e not requir:ed to be 13erf.orn1ed: SR d.8.1.d, SR d.8.1.Q through SR d.8.1.1 d.
INSERT 3.8.2-1
:- SR d.8.1.1d is oonsidered to be n,et without the EGGS initiation signals OPERABLE when the EGGS initiation signals are not requir:ed to be OPERABLE 13er Table d.d.5.1 1.
F'or AC sou roes required to be OPERABLE, the       In aooordance SRs of S13ecification d.8.1, exoe13t SR d.8.1.8,    with a1313licable are a1313lioable.                                    gR,s DAEC                                     3.8-13                           Amendment~

INSERT 3.8.2-1 Page 1 of 5 SR 3.8.2.1      Verify correct breaker alignment and indicated              In accordance with power availability for the required offsite circuit.        the Surveillance Frequency Control Program SR 3.8.2.2      ------------------------N()TES-----------------------------
: 1. All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.
: 2. A modified DG start involving idling and gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer.
When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.2.7 must be met.
Verify the required DG starts from standby                  In accordance with conditions and achieves steady state voltage                the Surveillance 2 3744V ands 4576V and frequency 2 59.5Hz                   Frequency Control and s 60.5Hz.                                               Program (continued)

INSERT 3.8.2-1 Page 2 of 5 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE                                           FREQUENCY SR 3.8.2.3      -------------------------N()l"ES----------------------------
: 1. This SuNeillance need not be performed.
: 2. DG loadings may include gradual loading as recommended by the manufacturer.
: 3. Momentary transients outside the load range do not invalidate this test.
: 4. l"his SuNeillance shall be conducted on only one DG at a time.
: 5. l"his SR shall be preceded by and immediately follow, without shutdown, a successful performance of SR 3.8.2.2 or SR 3.8.2.7.
Verify the required DG is synchronized and                   In accordance with loaded and operates for~ 60 minutes at a                     the SuNeillance load ~ 2750kw and :s; 2950kw.                                Frequency Control Program SR 3.8.2.4      Verify that the required fuel oil day tank                   In accordance with contains ~ 220 gal of fuel oil.                              the SuNeillance Frequency Control Program SR 3.8.2.5      Check for the presence of water in the fuel oil in           In accordance with the required day tank and remove water as                    the SuNeillance necessary.                                                   Frequency Control Program (continued)

INSERT 3.8.2-1 Page 3 of 5 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE                                           FREQUENCY SR 3.8.2.6      Verify the fuel oil transfer system operates to              In accordance with transfer fuel oil from storage tank to the day               the Surveillance tank.                                                        Frequency Control Program SR 3.8.2.7      -------------------------N()TE------------------------------
AII DG starts may be preceded by an engine prelube period.
Verify the required DG starts from standby                   In accordance with condition and achieves:                                      the Surveillance Frequency Control
: a. in ~ 10 seconds, voltage 2 3744V and                      Program frequency z 5~.5Hz; and
: b. steady state, voltage 2 3744V and ~ 4576V and frequency 2 59.5Hz and~ 60.5Hz.
(continued)

INSERT 3.8.2-1 Page 4 of 5 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE                                           FREQUENCY SR 3.8.2.8      -------------------------N()TE------------------------------
This Surveillance need not be performed.
Verify the required DG rejects a load greater                In accordance than or equal to its associated single largest               with the post-accident load, and:                                     Surveillance
: a.      Following load rejection, the frequency is           Frequency
                        ~ 64.5Hz.                                             Control Program
: b. Within 1.3 seconds following load rejection, the voltage is~ 3744V and
                        ~ 4576V.
: c. Within 3.9 seconds following load rejection, the frequency is~ 59.5Hz and
                        ~ 60.5Hz.
SR 3.8.2.9      -------------------------N()TE------------------------------
This Surveillance need not be performed.
Verify the required DG's automatic trips are                 In accordance bypassed on an actual or simulated Loss of                   with the
()ffsite Power (L()()P) signal except:                       Surveillance Frequency
: a. Engine overspeed; and                                 Control Program
: b. Generator lockout.
(continued)

INSERT 3.8.2-1 Page 5 of 5 SURVEILLANCE REQUIREMENTS continued)
SURVEILLANCE                                           FREQUENCY SR 3.8.2.10     -------------------------N()TE------------------------------
This Surveillance need not be performed.
Verify under manual control the required DG:                 In accordance
: a. Synchronizes with offsite power source                with the while loaded with emergency loads upon a              Surveillance simulated restoration of offsite power;               Frequency Control Program
: b. Transfers loads to offsite power source; and
: c. Returns to ready-to-load operation.

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-----------------------------------------------------
For Conditions B, E, and F, separate Condition entry is allowed for each DG.
CONDITION                             REQUIRED ACTION                   COMPLETION TIME A.      Fuel oil level less                  A.1     Restore fuel oil level to     48 hours than a 7 day supply                          within limits.
and greater than a 6 day supply.
B.      One or more DGs with                 B.1     Restore lube oil             48 hours t
lube oil inventory less                      inventory to within than a 7 day supply                          limits.
and greater than a 6 day supply.
C.      Stored fuel oil total                C.1     Restore fuel oil total        30 days particulates not within                      particulates to within limit.                                       limits.
                                                                                        . (continued)
DAEC                                             3.8-14                              Amendment~

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 ACTIONS (continued)
CONDITION                   REQUIRED ACTION               COMPLETION TIME D. New fuel oil properties    D.1    Restore stored fuel oil    30 days not within limits.                properties to within limits.
E. One or more DGs with       E.1    Restore required           48 hours required starting air             starting air receiver receiver pressures                pressure to within
     < 150 psig and                    limits.
2 75 psig.
F. Required Action and        F.1    Declare associated DG      Immediately associated Completion             inoperable.
Time not met.
OR One or more DGs with diesel fuel oil, lube oil, or starting air subsystems not within limits for reasons other than Condition A, B, C, D, or E.
DAEC                                3.8-15                          Amendment~

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                     FREQUENCY SR 3.8.3.1  Verify fuel oil storage tank contains                  In accordance with a 2: 7 day supply of fuel.                            the Surveillance Frequency Control Program SR 3.8.3.2  Verify lube oil inventory is a 2: 7 day supply for     In accordance with each DG.                                              the Surveillance Frequency Control Program SR 3.8.3.3  Verify fuel oil properties of new and stored fuel      In accordance with oil are tested in accordance with, and                the Diesel Fuel Oil maintained within the limits of, the Diesel Fuel      Testing Program Oil Testing Program.
SR 3.8.3.4  Verify required air start receiver pressure is  ~      In accordance with 150 psig.                                             the Surveillance Frequency Control Program SR 3.8.3.5  Check for the presence of water in the fuel oil in     In accordance with the fuel oil storage tank and remove water as         the Surveillance necessary.                                             Frequency Control Program DAEC                              3.8-16                        Amendment~

DC aOl,JFGes           OpOFating Deleted                                                                                            ~
3.8 E ECTRICAL POWER SYSTEMS 3.8.4 LCO a.8.4                Both Division 1 and Division 2 125 VDC elestFisal po*.veF s1,1bsysteFAs and the 250 VDC eleetFieal pov.ieF s1,1bsysteFA shall be OPERABLE.
/\PPLIC/\BILITY:         MODEa 1, 2, and d.
/\CTIO~rn GGfl.191+1Qfl.l                   ReQbllRe9 AG+IQfl.l                      GQMPbe+IQfl.l +IMe A,     GAe 12a V9G elestFisal          A4         Rests Fe 12a V9G               g ASl:JFS
* psweF s1:Jbsystem                          elestFisal psweF iAspemble.                                 s1:Jbsystem ts GPeRABbe statl:JS.
 ~       NG+e: May be 1:Jseel sA a      ~          9eslaFe Feetl:liFeel           4 ASl:JFS fFem Eiisssi.iei:y sf sAe time sAly basis fsF                   feat1:JFe(s), sl:lppsFteel by  GsAEiitisA A 6SAS1:JFF8At witl:l easl:l battery eli11isioA.                tl:le iAspeFable 12a V9G       iAspeFability sf FeEi1:JAEiaAt so1:JFse, iAspeFable           FeE11:JiFeel feat1:JFe(s).
WA8A tl:le F881:JAEiaAt Feetl:liFeel featl:lm(s) aFe iAspei:able.
                                                                                                                   /
ANG
                                        ~          RestoFe 12a V9G                10 elays elestFisal poweF s1:Jbsystem to GPeR,lliBbe stat1:Js.
 .g.,  Reetl:liFeel AstioA aAEi         M          Be iA MQ9e        a.           12 ASl:JFS Assosiateel GompletioA
       +ime of GoAEiitioA A AOt         ANG met:-
                                        ~          Be iA MQ9e 4.                  a@ AOl:JFS G,. 2a0 V9G elestFisal poweF         G-4        9eslaFe assosiateel            lmmeeliately s1:Jbsystem iAopemble.                      Sl:lppoFteel feat1:JFes iAspeFable .
 ~     +we OF moFe 9G elestFisal        .Q4        eAteF bGQ      a.a.a.         lmmeeliately poweF s1:Jbsystoms iAopeFable.
DAEC                                        3.8-17                              Amendment No.             ~

J

Jii DC Sources      Sh1:1tdov:n 3.8.5 3.8 ELECTRICAL POWER SYSTEMS 3.8.5 DC Sources      Sh1:1tdown LCO 3.8.5          DC electrical power subsystems shall be OPERABLE to support the DC electrical power distribution subsystem(s) required by LCO 3.8.8, "Distribution Systems         Sh1:1tdown."
APPLICABILITY:     MODES 4 and 5, During movement of irradiated fuel assemblies in the secondary containment.
ACTIONS LGO 3.0.3 is not applieable.
CONDITION                        REQUIRED ACTION                 COMPLETION TIME A. One or more required       A.1         Declare affected          Immediately DC electrical power                    required feature(s) subsystems                            inoperable.
inoperable.
OR A-&.4-     S1:1spend GORE             Immediately ALTERATIONe.
A.2../2:   Suspend movement           Immediately of irradiated fuel assemblies in the secondary containment.
(continued)
DAEC                                   3.8-21                              Amendment~

DC Sources     Shutdown 3.8.5
* ACTIONS CONDITION                    REQUIRED ACTION               COMPLETION TIME (oontinued)             ~          Initiate aotion to      Immediately FOStOFe FeEtUiFed DC eleotFioal powOF susbsystems to OPERABLE status.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                  FREQUENCY SR d.8.5.1                           ~JOTE The following SRs arn not FOEtUiFOd to be peFfoFmed: SR d.8.4.7 and SR d.8.4.8.
FoF DC eleotFioal po1NOF subsystems FOEtUiFed     In aooOFdanoe INSERT 3.8.5-1            to be OPERABLE the following SRs arn              with applieable applioable:                                       ~
SR d.8.4.1   SR g_g.4.4     SR d.8.4.7 SR d.8.4.2   SR d.8.4.5     SR d.8.4.8.
SR g_g.4 .d  SR d.8.4 .e DAEC                                  3.8-22                            Amendment~

INSERT 3.8.5-1 Page 1 of 3 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                 FREQUENCY SR 3.8.5.1      Verify battery terminal voltage is ~ 130.5 V on     In accordance with float charge for the 125 voe battery.               the Surveillance Frequency Control Program SR 3.8.5.2      Verify no visible corrosion at battery terminals    In accordance with and connectors.                                     the Surveillance Frequency Control OR                                                  Program Verify battery connection resistance within limits.
SR 3.8.5.3      Verify battery cells, cell plates, and racks show
* In accordance with no visual indication of physical damage or          the Surveillance abnormal deterioration that could degrade           Frequency Control battery performance.                                Program SR 3.8.5.4      Remove visible corrosion and verify battery cell to In accordance with cell and terminal connections are coated with       the Surveillance anti-corrosion material.                            Frequency Control Program SR 3.8.5.5      Verify battery connection resistance within limits. In accordance with the Surveillance Frequency Control Program (continued)

INSERT 3.8.5-1 Page 2 of 3 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE                                            FREQUENCY SR 3.8.5.6      Verify each required battery charger supplies                 In accordance with 2 293 amps at 2 132.5 V for the 125 voe                       the Surveillance subsystem.                                                    Frequency Control Program SR 3.8.5.7      -------------------------N()TES------------------------------
: 1. The modified performance discharge test in SR 3.8.5.8 may be performed in lieu of the service test in SR 3.8.5.7.
: 2. This Surveillance need not be performed.
Verify battery capacity is adequate to supply,                In accordance with and maintain in ()PERABLE status,                             the Surveillance the required emergency loads for the design                   Frequency Control duty cycle when subjected to a battery service                Program test.
(continued)

INSERT 3.8.5-1 Page 3 of 3 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE                                             FREQUENCY SR 3.8.5.8      --------------------------N()TE-------------------------------
This Surveillance need not be performed.
Verify battery capacity is 2: 80% of the                       In accordance with manufacturer's rating when subjected to a                      the Surveillance performance discharge test or a modified                       Frequency Control performance discharge test.                                    Program 12 months when battery shows degradation or has reached 85% of expected life with capacity < 100% of manufacturer's rating 24 months when battery has reached 85% of the expected life with capacity 2: 100% of manufacturer's rating

Battery Cell Parameters 3.8.6 3.8 ELECTRICAL POWER SYSTEMS 3.8.6 Battery Cell Parameters LCO 3.8.6                 Battery cell parameters for the Division I and Division II 125 VDC and the 250 VDC batteries shall be within limits.                                    -f-APPLICABILITY:            When associated DC electrical power subsystems are required to be OPERABLE.
ACTIONS
-------------------------------------------------------NOTE-----------------------------------------------------
Separate Condition entry is allowed for each battery.
CONDITION                             REQUIRED ACTION                   COMPLETION TIME A.         One or more batteries             A.1         Verify pilot cell           1 hour with one or more                              electrolyte level and battery cell                                  float voltage meet parameters not within                         Table 3.8.6-1 Table 3.8.6-1                                 Category C limits.
Category A or B limits.                           AND A.2         Verify parameters           24 hours for required battery AND cells meet Table 3.8.6-1 Once per 7 days Category C limits.
thereafter AND A.3         Restore parameters          31 days for required battery cells to Table 3.8.6-1 Category A and B limits.
(continued) t DAEC                                              3.8-23                         Amendment No. 2d4

Battery Cell Parameters 3.8.6 ACTIONS (continued)
CONDITION                REQUIRED ACTION              COMPLETION TIME B. Required Action and      B.1       Declare associated     Immediately associated Completion              battery inoperable.
Time of Condition A not met.
OR One or more batteries with average electrolyte temperature of the representative cells not within limits.
OR One or more batteries with one or more battery cell parameters for required battery cells not within Table 3.8.6-1 Category C limits.
DAEC                             3.8-24                       Amendment No. 234

Battery Cell Parameters 3.8.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                FREQUENCY Verify battery cell parameters meet Table       In accordancewith t
SR 3.8.6.1 3.8.6-1 Category A limits.                      the Surveillance Frequency Control Program SR 3.8.6.2    Verify battery cell parameters meet Table       In accordance with 3.8.6-1 Category B limits.                      the Surveillance Frequency Control Program t
Once within 24 hours after battery discharge
                                                               < 110 V for 125 V afK:I. ~ 220 V for
                                                               ~
Once within 24 hours after battery overcharge
                                                               > 150 V for 125 V afK:I. :> aoo v tor
                                                               ~
SR 3.8.6.3  Verify average electrolyte temperature of         In accordance with representative cells is~ 65&deg;F for each battery. the Surveillance Frequency Control Program DAEC                               3.8-25                    Amendment~

Battery Cell Parameters 3.8.6 Table 3.8.6-1 (page 1 of 1)
Battery Cell Parameter Requirements CATEGORY A:               CATEGORY B:         CATEGORY C:
LIMITS FOR                LIMITS FOR           LIMITS FOR EACH                      EACH                 EACH PARAMETER                 DESIGNATED                CONNECTED            CONNECTED PILOT CELL                    CELL                CELL Electrolyte Level       > Minimum level           > Minimum level        Above top of plates, indication mark, and      indication mark, and   and not overflowing
:::; % inch above         :::; % inch above maximum level             maximum level indication mark(a)        indication mark(a)
Float                   2 2.13 V                  2 2.13 V               > 2.07 V Voltage Specific                2 1.195                   2 1.190                Not more than Gravity(b)(c)                                                            0.020 below AND                    average of all connected cells Average of all connected cells        AND
                                                   > 1.200 Average of all connected cells 2 1.190 (a)     It is acceptable for the electrolyte level to temporarily increase above the specified maximum level during equalizing charges provided it is not overflowing.
(b)     Corrected for electrolyte temperature and level. Level correction is not required, however, when on float charge and battery charging current is < 2 amps.
(c)    A battery charging current of< 2 amps when on float charge is acceptable for meeting specific gravity limits following a battery recharge, for a maximum of 7 days.
When charging current is used to satisfy specific gravity requirements, specific gravity of each connected cell shall be measured prior to expiration of the 7 day allowance.
DAEC                                        3.8-26                             Amendment~

Distribution aystems        Operating
                                                                                          ~
3.8 ELECTRICAL POWER SYSTEMS                   !Deleted 3.8.7 6istribution aystems        Operating LCO 3.8.7            The f.ollowing AC and DC elestrisal power distribution subsystems shall be OPERABLE:
a:-  Di1Jision 1 and Di1Jision 2 AC elestrisal power distribution subsystems;
                     &.-  Di1Jision 1 and Division 2 125 VDC elestrisal power distribution subsystems;
                     &. 250 VDC elestrisal pov.ier distribution subsystem; 4-   Intake strusture elestrisal power distribution subsystems; aRQ
                     &. 125 VDC RCIC Motor Control Center (MCC).
APPLICABILITY:       MODEa 1, 2, and 3.
ACTIONa CO~JDITION                       REQldlRED ACTION                COMPLETIO~J TIME A:     One or more AC               A4        Restore AC elestrisal     8 hours elestrisal power                       power distribution distribution                           subsystems to             ANQ subsystems                             OPERABLE status.
inoperable, e*sept f.or                                          1e hours from the intake strusture                                             disso1.iery of elestrisal power                                                 failure to meet distribution                                                     LCO 3.8.7.a orb subsystems.
 ~      One or more essential        .g,4      Restore the 125 VDC       8 hours 12a ~&#xa3;DC elestrisal                    elestrisal power power distribution                     distribution              ANQ subsystems inoperable                  subsystems to e*septfor the RCIC                     OPERABLE status.          16 hours from
        ~                                                                etisse~(eP_,<< ef failure to meet LCO 3.8.7.a orb (sontinued)
DAEC                                      3.8-27                            Amendment~

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            .i f

Distribution Systems     g1:u1tdowA 3.8.8 3.8 ELECTRICAL POWER SYSTEMS 3.8.8 Distribution Systems      g1:i1:-1tdov.1R LCO 3.8.8          The necessary portions of the AC and DC electrical power distribution subsystems shall be OPERABLE to support equipment required to be OPERABLE.
APPLICABILITY:      MODEa 4 aRd a.
During movement of irradiated fuel assemblies in the secondary containment.
'ACTIONS LGO     a.O.a is Rot applioable.
CONDITION                           REQUIRED ACTION                  COMPLETION TIME A. One or more required          A.1          Declare associated         Immediately AC or DC electrical                       supported required power distribution                        feature(s) inoperable ..
subsytems inoperable.
Immediately a1:-1speRd GORE ALTERATION a.
Suspend movement            Immediately of irradiated fuel assemblies in the secondary containment.
IRitiate aotioR to          Immediately restore req1:-1ired AG aRd DC eleotrioal po'l,*er distrib1:1tion s1:-1bsystems to OPERABLE stat1:-1s.
(GORtiRl:-led)
DAEC                                      3.8-30                             Amendment~

Distribution Systems     Shutdown 3.8.8 ACTIONS (continued)
CONDITION                   REQUIRED ACTION                COMPLETION TIME (oontinued)             ~         DeolaFe assoeiated        Immediately FOquiFed shutdown oooling subsystem(s) inopemble.
SURVEILLANCE REQUIREMENTS
                               ============;::::::==== ====
SURVEILLANCE                                   FREQUENCY SR 3.8.8.1          Verify correct breaker alignments and           In accordance with the indicated power availability to required AC     Surveillance and DC electrical power distribution            Frequency Control subsystems.                                     Program
)
DAEC                                 3.8-31                          Amendment~

Refueling Equipment lnterloeks
!DELETED            I                                                                  ~
3.9 ~ELING OPERATIONS a.9.1 Refueling Equipment lnterloeks LCO a.9.1           The refueling equipment interlocks assoeiated v,ith the Refuel position shall be OPERABLE.
APPLICABILITY:      During in vessel fuel movement with equipment assoeiated with the interloel<s *.vhen the roaster mode switeh is in the Refuel position.
CONDITIO~J                      REQUIRED /\CTIO~J             COMPLETION TIME One or more required            A4      Suspend in vessel        Immediately refueling equipment                     fuel movement with interloeks inoperable.                  equipment assoeiated 1,.vith the inoperable interloek(s).
DAEC                                      3.9-1                          Amendment~

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System Leakage aRd l=iydrostatis Testing OperatioR
      ~DELETED                ~                                                        a.10.1 3.1 OGIAL OPERATION a.10.1 System Leakage aRd l=iydrostatio TestiRg OpeFatioR LGO a.10.1        The aveFage FOaetoF eoolaRt temJ3erahJFO speeified iR Tal31e 1.1 1 foF MODE 4 may Be shanged to "~A," and OJ30Fation eonsidemd not to 13e iR MODE a; aRd the FOEJUiFemeRts of LGO a.4 .8, "Residual l=ieat Removal (Rl=iR) 8hutelovm Cooling System Gold 8hutdowR," may Be suspeneled, to allow maetoF eoolaRt temperatum > 212&deg;F:
* FoF pelioFmaRse of a system leakage OF hydrostatis test, As a GORSeEJUeRGe of maiRtaiRiRg aeleEJUate pFeSSUFe foF a system leakage or hydrostatis test, or
* As a GORSeEJUeRGe of maiRtaiRiRg adeEJl:late pFeSSUFe for GORtFOI rod ssram time testiRg iRitiated iR GORjURGtioR \".'ith a system leakage OF hydrostatis test, pFovided the followiRg MODE     a LGOs aFO met:
a:-    LGO a.a.e.2, "8esoRdaFy GoRtaiRmeRt Isolation a,
IRstrumeRtatioR," FuRstioRs 1, aRd 4 of TaBle a.a.e.2 1;
                 &. LGO a.e.4 .1, "8esoRdaF)' GoRtaiRmeRt'';
                 &. LGO a.e.4 .2, "8esondaf)' GoRtaiRmeRt lsolatioR Valves/DamJ3eFS (8GIV/Ds)"; and 4:-    LGO a.e.4 .a, "8taRdBy Gas TreatmeRt (8BGT) System."
APPLICABILITY:   MODE 4 with a*,erage FOastor soolaRt temperature::> 212&deg;F.
DAEC                                 3.10-1                             Amendment -2e4

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Design Features 4.0 4.0 DESIGN FEATURES 4.1 Site Location The plant site, which consists of approximately 500 acres, is adjacent to the Cedar River approximately 2.5 miles northeast of the Village of Palo, Iowa.
DistaRse from U:ie roaster seRterliRe to the Rearest site bouRdary is approximately 2000 1:1:. The boundary of the exclusion area defined in 10 CFR 100 is delineated by the property lines. The distance to the outer boundary of the low population zone is 6 miles. The plan of the site is shown on UFSAR Figures 1.2-1 and 1.2-2.
     /~Deleted 4.2  ~Gore 4 .2.1 ruel Assemblies The roaster shall soRsist of Rot more thaR a68 fuel assemblies.
Eash assembly shall soRsist of a matrix of Zirealloy or ZIRLO fuel rods with aR iRitial sompositioR of Ratural or slightly emished uraRium dioxide (U02) as fuel material, aRd 'Nater rods. Limited substitutioR of zirsoRium alloy or staiRless steel filler rods for fuel rods, iR assordaRse with appro'Jed applisatioRs of fuel rod soRfiguratioRs, may be used. ruel assemblies shall be limited to those fuel desigRs that have beeR aRalyzed with NRG staff approved sodas aRd methods aRd have beeR shovJR by tests or aRalyses to somply with all safety do.sigR bases. /\ limited Rumber of lead test assemblies that have Rot sompleted represeRtative testiRg may be plased iR RORlimitiRg sore regioRs.
     ~       GoRtrol Rod Assemblies The roaster sore shall soRtaiR 89 srusiform shaped soRtrol rod assemblies. The soRtrol materials shall be boroR sarbide aRd hafRium metal, as approved by the NRG.
(continued)
DAEC                                    4.0-1                             Amendment 3

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 the following limits for maximum k-infinity in the normal reactor core configuration at cold conditions and maximum lattice-average U-235 enrichment weight percent:
                                                                         . k-oo        wt%
i)   7x7 and 8x8 pin arrays              ~ 1.29       ~ 4.6 (Legacy Fuel Assemblies only; Holtec and PaR racks) ii) 1Ox10 pin arrays                     ~. 1.29      ~ 4.95 (Holtec and PaR racks)
: b.       keff ~ 0.95 if fully flooded with unborated water, which includes an allowance for uncertainties as described in 9.1 of the UFSAR; and
: c.       A nominal 6.060 inches for HOLTEC designed and 6.625 inches for PaR designed center to center .
distance between fuel assemblies placed in the storage d.
racks.
The Baral neutron absorber shall have a 8 areal 10 density greater than or equal to 0.0162 grams 10 B/cm 2 10 with an uncertainty of 0.0012 grams Btcm .
2 t
4.3.1.2         The nm\' fuel stoFage Faoks aFe designed and shall be maintained with:
a:       ruel assemblies ha'ling a maximum k infinity of 1.31 in the noFmal maotoF oom oonfiguFation at sold oonditions;
                       &.       *eff ~ O.Q5 if fully flooded with unbOFated wateF, whioh inoludes an allowanoe fOF unoertainties as desoFibed in aeotion Q.1 of the Ura/\R;
                       &.       *eff ~ O.QO if dF)', whioh inoludes an allowanoe foF unoertainties as deseFibed in aeetion Q.1 of the UrSAR; aRa El-:-    A nominal 6.625 ineh eentOF to eenteF distanee betv.'een fuel assemblies 13laoed in stoFage moks. 1 (continued)
DAEC                                        4.0-2                        Amendment No.        ~

Design Features 4.0 4.0 DESIGN FEATURES (continued) 4.3.2 Drainage The spent fuel storage pool is designed and shall be maintained to prevent inadvertent draining of the pool below elevation 831 ft. - 2 3/4 in.
4.3.3 Capacity The spent fuel storage pool is designed and shall be maintained with a storage capacity limited to no more than 2563 fuel assemblies in a vertical orientation, including no more than 152 fuel t
assemblies stored in the cask pit in accordance with UFSAR Section 9.1.
The new fuel storage 14*ault is equipped *.vith rasks for storage of up to 110 fuel assemblies in a 11ertisal orientation.
DAEC                                  4.0-3                               Amendment~

Responsibility 5.1 5.0 ADMINISTRATIVE CONTROLS 5.1 Responsibility 5.1.1      The plant manag.er 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 affects nuclear safety.
5.1 .2     The Operations Shift Manager shall be responsible for the control room command function. During any absence of the Operations Shift Manager 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 Operations Shift Manager 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 designed to assume the control room command function.
DAEC                                 5.0-1
* Amendment~

Organization 5.2 5.0 ADMINISTRATIVE CONTROLS 5.2 Organization 5.2.1      Onsite and Offsite Organizations Onsite and offsite organizations shall be established for unit operation and corporate management, respectively. The onsite and offsite organizations shall include the positions for activities affecting safety of the nuclear power plant.
: a. Lines of authority, responsibility, and communication shall be defined and established throughout highest management levels, intermediate levels, and all operating organization positions.
These relationships shall be documented and updated, as appropriate, in organization charts, functional descriptions of departmental responsibilities and relationships, and job descriptions for key personnel positions, or in equivalent forms of documentation. These requirements including the plant specific titles of those personnel fulfilling the responsibilities of the positions delineated in the Technical Specifications shall be documented in the UFSAR or QA Program Description;
: 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 corporate officer with direct responsibility for the plant shall have corporate responsibility for overall plant nuclear safety and shall take any measures needed to ensure acceptable performance of the staff in operating, maintaining, and providing technical support to the plant to ensure nuclear safety; and
: d. The individuals who train the operating staff, carry out health
* physics, or perform quality assurance functions may report to the appropriate onsite manager; however, these individuals shall have sufficient organizational freedom to ensure their independence from operating pressures.
(continued)
DAEC                                   5.0-2                              Amendment~
I_

Organization 5.2 5.2 Organization (continued) 5.2.2      Unit Staff The unit staff organization shall also include the following:
: a. A non-licensed operator shall be assigned to the reactor when containing fuel and an additional non-licensed operator shall be assigned to the reactor when operating in MODES 1, 2, or 3.
: b. Shift crew composition shall meet the requirements stipulated herein and in 10 CFR 50.54(m).
: c. Shift crew composition may be less than the minimum requirement of 10 CFR 50.54(m)(2)(i) and 5.2.2.a and 5.2.2.g for a period of time not to exceed 2 hours 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;
: d. A person qualified to implement radiation protection procedures shall be on site when fuel is in the reactor. The position may be vacant for not more than 2 hours, in order to provide for unexpected absence, provided immediate action is taken to fill the required position.
: e. Not used.
: f. The Operations Manager or Operations Supervisors shall hold an SRO license.
(continued)
DAEC                                  5.0-3                             Amendment~

Organization 5.2 5.2 Organization 5.2.2      Unit Staff (continued)
: g. 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. This function is not required in MODES 4 and 5.
DAEC                                  5.0-4                            Amendment~

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 in ANSI/ANS 3.1-1978. The radiation protection manager shall meet or exceed the qualifications of Regulatory Guide 1.8, September 1975.
5.3.2         For the purpose of 10 CFR 55.4, a licensed Senior Reactor Operator (SRO) and a licensed Reactor Operator (RO) are those individuals who, in addition to meeting the requirements of TS 5.3.1, perform the functions described in 10 CFR 50.54(m).
DAEC                                    5.0-5                         Amendment~

Procedures 5.4 5.0 ADMINISTRATIVE CONTROLS 5.4 Procedures 5.4.1      Written procedures shall be established, implemented, and maintained covering the following activities:
: a. The applicable procedures recommended in Regulatory Guide 1.33, Revision 2, Appendix A, February 1978;
: b. The emergency operating procedures required to implement the requirements of NUREG-0737 and to NUREG-0737, Supplement 1, as stated in Generic Letter 82-33;
: c. Quality assurance for effluent and environmental monitoring;
: d.    [Deleted]; and
: e. All programs specified in Specifications 5.5.
DAEC                                 5.0-6                         Amendment~

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 Assessment Manual (ODAM)
: a. The ODAM 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 ODAM 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 Report and Radioactive Material Release Report required by Specification 5.6.2 and Specification 5.6.3.
: c. Licensee initiated changes to the ODAM:
: 1. Shall be documented and records of reviews performed shall be retained. This documentation shall contain:
: a. Sufficient information to support the change(s) together with the appropriate analyses or evaluations justifying the change(s), and
: b. A determination that the change(s) maintain the levels of radioactive effluent control required by 10 CFR 20.1302, 40 CFR 190, 10 CFR 50.36a, and 10 CFR 50, Appendix I, and not adversely impact the accuracy or reliability of effluent dose or setpoint calculations;
: 2. Shall become effective after the approval of the plant                J,_..
manager; and                                                      .....I
: 3. Shall be submitted to the NRC in the form of a complete, legible copy of the entire ODAM as a part of or concurrent with the Radioactive Material Release Report for the period of the report in which any change in the ODAM was made. Each change shall be identified by (continued)
DAEC                                       5.0-7                         Amendment ~Jo. 234

Programs and Manuals 5.5 5.5   Programs and Manuals 5.5.1        Offsite Dose Assessment Manual (ODAM) (continued) 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        Primarv Coolant Souroes Outside Containment
!D-e-le_t_e_d---~&#xb5;
.....                This program provides oontrols to minimize leakage from those portions of systems outside oontainment that oould oontain highly radioaotive fluids during a serious transient or aooident to levels as Im.\' as praotioable. The systems inolude Gore Spray, l=ligh Pressure Coolant lnjeotion, Residual l=leat Removal, Reaotor Gore Isolation Cooling, Reaotor \'\later Cleanup (only to seoond isolation valve). Post Aooident Sampling (until suoh time as a modifioation eliminates PASS as a potential leakage path), Containment Atmospherio Monitoring, Control Rod Drii,e (soram disoharge volume only) and Liquid Radi..\*aste (only Reaotor Building P:loor and Equipment Drain sump pumps, piping, and tanks up to and inoluding oolleotor tanks). The program shall inolude the klllowing:
a:-    Preventive maintenanoe and periodio visual inspeotion requirements; aM
                    &:-    System leak test requirements for eaoh system at least onoe 5.5.3 per 24 months.
The provisions of SR a.0.2 are applioable.
fDeletedJ t
(continued)
DAEC                                    5.0-8                        Amendment No. 258

Programs and Manuals 5.5 5.5   Programs and Manuals (continued) 5.5.4         Radioactive Effluent Controls Program This program, conforming to 10 CFR 50.36a, provides 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 ODAM, shall be implemented by procedures, and shall include remedial actions to be taken whenever the program limits are exceeded. The program shall include the following elements:
: a. Limitations on the functional capability of radioactive liquid and gaseous monitoring instrumentation including surveillance tests and setpoint determination in accordance with the methodology in the ODAM;
: b. Limitations on the concentrations of radioactive material released in liquid effluents from the site to unrestricted areas, conforming to ten times (1 Ox) the concentrations listed in Appendix B, Table 2, Column 2 to 10 CFR 20.1001 - 20.2402;
: c. Monitoring, sampling, and analysis of radioactive liquid and gaseous effluents pursuant to 10 CFR 20.1302 and with the methodology and parameters in the ODAM;
: d. Limitations on the annual and quarterly doses or dose commitment to a member of the public from radioactive materials in liquid effluents released to unrestricted areas, conforming to 10 CFR 50, Appendix I;
: e. Determination of cumulative and projected dose contributions from radioactive effluents for the current calendar quarter and current calendar year in accordance with the methodology and parameters in the ODAM at least every 31 days;
: f. Limitations on the functional capability and use of the liquid and gaseous effluent treatment systems to ensure that the appropriate portions of these systems which were used to establish compliance with the design objectives in 10 CFR 50, Appendix I, Section II be used when specified to provide reasonable assurance that releases of radioactive material in Hquid and gaseous effluents be kept as low as reasonably achievable; (continued)
DAEC                                     5.0-9                              Amendment~

Programs and Manuals 5.5 5.5   Programs and Manuals 5.5.4          Radioactive Effluent Controls Program (continued)
: g. Limitations on the dose rate resulting from radioactive material released in gaseous effluents from the site to areas at or beyond         J...
the site boundary shall be limited to the following:                    1
: 1. For noble gases: less than or equal to a dose rate of 500 mrem/yr to the whole body and less than or equal to a dose         f' rate of 3000 mrem/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 mrem/yr to any organ;
: h. Limitations on the annual and quarterly air doses resulting from noble gases released in gaseous effluents to areas beyond the site .
boundary, conforming to 10 CFR 50, Appendix I;
: i. Limitations on the annual and quarterly doses to a member of the public from iodine-131, iodine-133, tritium, and all radionuclides in particulate form with half lives > 8 days in gaseous effluents released to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I; and                                                 -f-
: j. Limitations on the annual dose or dose commitment to any member of the public, beyond the site boundary, due to releases         ,r of radioactivity and to radiation from uranium fuel cycle sources, conforming to 40 CFR 190.
The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the                 j.,
Radioactive Effluent Controls Program surveillance frequency.                 - I 5.~5.5GompoReRt Gyslis or TraRsieRt Limit This program provieles soRtrols to trask the ui;:g/\R gestioR 5.d.d, syslis
              ~ aRel traRsieRt ossurreRses to eRsure that sompoReRts are maiRtaiReel withiR
!Deleted _            the elesigR limits.
(continued)
DAEC                                     5.0-10 Gorresteel by ~JRG Letter elateel Ostober 28, 2002                    Amendment -N&.- 248-

Programs and Manuals 5.5 5.5   Programs and Manuals (continued) 5.5.6        DELETED (continued)
DAEC                              5.0-11 Amendment No. 300 I

Programs and Manuals 5.5 5.5    Programs and Manuals (continued) 5.5.7         Ventilation Filter Testing Program (VFTP)
A program shall be established to implement the following required testing o EngineeFOd Safety Feature (ESF) filter ventilation systems.
Standby Filter Unit (SFU)                 The tests described in Specifications 5.5.7.a and 5.5.7.b shall be performed once per 12 months for standby service, after 720 hours of system operation, following significant painting, fire or chemical release in any ventilation zone communicating with the system, after any structural maintenance on the system housing, and after each partial or complete replacement of the HEPA filter train or charcoal adsorber, respectively.
The test described in Specification 5.5.7.c shall be performed once per 12 months for standby service, after 720 hours of system operation and following significant painting, fire or chemical release in any ventilation zone communicating with the system.
The test described in Specification 5.5.7.d shall be performed annually.        *,r For the SBGT System only, the test dessribed in Spesifisation 5.5.7.e shall      -f be performed after eash somplete or partial replasement of the FIEPA filter bank and a~er any strustural maintenanse on the system housing.
For the SBGT System only, the test dessribed in Spesifisation 5.5.7.f            ..,r shall be performed in sonjunstion with the tests dessribed in Spesifisation 5.5.7.G.
: a. Demonstrate for eash of the ESF systems that an in place test of the HEPA filters shows a penetration and system bypass at the value specified and at the system flowrate specified below:
ESF Ventilation System          Penetration      Flowrate (cfm) and System Bypass(%)
SBGT System                    ~Q.4              3600 4400 SFU System                      < 1.0            900 - 1100 (continued)
DAEC                                    5.0-12                       Amendment No. 285

Programs and Manuals 5.5 5.5   Programs and Manuals 5.5.7        Ventilation Filter Testing Program (VFTP) (continued)
: b. Demonstrate for eash of the Egi;: systems that an inplace test of the charcoal adsorber shows a penetration and system bypass at the value specified and at the system flowrate specified below:
ESP: Ventilation System       Penetration        Flowrate (cfm) and System Bypass(%)
SBGT System                   ~Q.4               3600   4400 SFU System                    < 1.0              900 - 1100
: c. Demonstrate for eash of the Egi;: systems that a laboratory test of a sample of the charcoal adsorber, when obtained as described in Regulatory Guide 1.52 Revision 2, shows the methyl iodide penetration less than the value specified below when tested in accordance with ASTM D3803-1989 at a temperature of 30&deg;C and the relative humidity specified below:
ESP: Ventilation System      Penetration     Relative Humidity gBGT System SFU System
                                                 < 0.5%
                                                 < 5.0%
                                                                 ~Qe-%.
                                                                 ~95%
                                                                                            +
: d. Demonstrate for eash of tl:ie ESP: systems that the pressure drop across the combined HEPA filters, tl:ie prefilters (SBGT System only), and the charcoal adsorbers is less than the value specified below and at the system flowrate specified as follows:
(continued)
DAEC                                   5.0-13                       AmendmentNo. 285

Programs and Manuals 5.5 5.5   Programs and Manuals 5.5.7        Ventilation Filter Testing Program (VFTP) (continued)
E8~ Ventilation 8ysteR1         Delta P (inches wg)      Flowrate (cfm) 8BGT 8ysteR1                                         3600   4400 SFU System                        < 6                900-1100 e,.,. DeRlonstrate tl:iat air distribution is uniforRl within 20% of averaged flow per unit aoross 8BGT 8ysteR1 l=IEP/\ filters.
tsually inspeot the 8BGT 8ysteR1 aharooal adsorber to ensure no              f lmv blookage has oaaurred.
The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the VFTP test frequencies.
5.5.8        Explosive Gas and Storage Tank Radioactivity Monitoring Program This program provides controls for potentially explosive gas Rlixtures aontained in the Offgas 8ysteR1 downstreaRl of the reaoR1biners and the quantity of radioactivity contained in unprotected outdoor liquid storage tanks. The liquid radwaste quantities shall be determined in accordance with Standard Review Plan, Section 15.7.3, "Postulated Radioactive Release due to Tank Failures".
The program shall include.;.
             &.-     The liRlits for aonaentrations of hydrogen in the Offgas 8ysteR1 dovmstreaRl of the reaoR1biners and a surveillanae prograRl to ensure the liRlits are maintained. 8uah liRlits shall be appropriate to the systeR1's design ariteria (i.e., 1.vhether or not the system is designed to v,ithstand a hydrogen explosion);
(continued)
DAEC                                    5.0-14                          Amendment ~Jo. 285

Programs and Manuals 5.5 5.5   Programs and Manuals 5.5.8        E>mlosive Gas and Storage Tank Radioactivity Monitoring Program (continue~
e-:-    A surveillance program to ensure that the quantity of radioactivity contained in all outdoor liquid radwaste tanks that are not surrounded by liners, dikes, or walls, capable of holding the tanks' contents and that do not have tank overflows and surrounding area drains connected to the Liquid Radwaste Treatment System is ~ 50 curies, excluding tritium and dissolved or entrained noble gases. The liquid radwaste storage tanks in the Low-Level Radwaste Processing and Storage Facility are considered unprotected outdoor tanks.
The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Explosive Gas and Storage Tank Radioactivity Monitoring Program surveillance frequencies.
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:
: 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 within limits,
: 2. A viscosity within limits for ASTM 2-D fuel oil, and
: 3. Water and sediment within limits;
: b.      Viscosity, water and sediment for stored ASTM 2-D fuel oil are within limits every 31 days; and
: c.      Total particulate concentration of the stored fuel oil is~ 10 mg/I when tested every 92 days.
The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Diesel Fuel          L. . .
Oil Testing Program Testing Frequencies.                                          1-(continued)
DAEC                                    5.0-15                        Amendment -Ne-:~

Programs and Manuals 5.5 5.5   Programs and Manuals (continued) 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 require either of the following:
                                                                                              -t
: 1. A change in the TS incorporated in the license; or
: 2. 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.
: d.      Proposed changes that meet the criteria of Specification 5.5.1 Ob 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; (continued)
DAEC                                     5.0-16                       Amendment No. 241

Programs and Manuals 5.5 5.5   Programs and Manuals 5.5.11       Safety Function Determination Program (SFDP) (continued)
: 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 inapproJJriately 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, no concurrent loss of offsite power or no concurrent loss of onsite diesel generator(s), a safety function assumed in the accident analysis cannot be performed. For the purpose of this program, a loss of safety function may exist when a support system is inoperable, and:                                   .
: 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 1s also inoperable; or
: 3.      A required system redund.ant to support system(s) for the supported systems (1) and (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 Deleted                   the loss of safety function exists are required to be entered. When a loss of safety function is caused by the moperability of a single Technical Specification support system, the appropriate Conditions and Required Actions to enter are those of the support system.
5.5.12       Primary GoRtaiRmeRt Leakage Rate TestiRg ProgFam a:-    A program shall be established to implemeRt the leakage rate testiRg of the primary eoRtaiRmeRt as required by 10 GF"R 50.54(0) a Rd 10 GF"R 50, AppeRdiK cl, OptioR B, as modified by approved eKemptioRs.
                   &. This program shall be iR aooordaRoe with the guideliRes ooRtaiRed iR
                          ~JEI 94 01, RevisioR d A, "IRdustry GuideliRe for lmplemeRtiRg PerformaRoe Based OptioR of 10 GF"R 50, /\ppeRdiK cl," aRd eoRditioRs aRd limitatioRs speoified iR ~JEI 94 01, RevisioR 2 A, as modified by the followiRg eKGeptioRs:
4,. DELETED (continued)
DAEC                                   5.0-17                         Amendment No. 296

Programs and Manuals 5.5 5.5   Programs and Manuals 5.5.12     Primary Containment Leakage Rate Testing Program (oontinued)
                   ~       E*.emption from Sestion Ill.A of 10 CrR Part 50, Appendi* cl, Option B, to allow the sontribution from Main Steam pathway leakage to be e*.oluded from the overall integrated leakage rate from Type A tests.
                   ~       E*.emption from Seotion 11.B of 10 CrR Part 50, Appendi*. cl, Option B, to allov.r the eontribution from Main Stream pathway leakage to be exoluded from the sum of the leakage rates from Type B and Type C test&:
The peak oaloulated oontainment internal pressure for the design basis loss of soolant aseident, Pa, is 45.7 psig.
The maximum allQ!..*Jable primary oontainment leakage rate, La, at Pa, shall be 2.0% of primary oontainment air weight per day..
Leakage Rate asseptanse oriteria are:
                                                                                                     +
Primary Containment leakage rate aooeptanoe oriterion is~ 1.0 La.
During the first startup following testing in aooordanoe with this        t program, the leakage rate aooeptanoe oriteria are: ~ 0.60 La for the Type Band Type C tests; and,~ 0.75 La for the Type A tests; and The air look testing aoeeptanoe oriterion is overall air look leakage fate~ 0.05 La when tested at~~
The provisions of SR a.a.a are applioable to the Primary Containment Leakage Rate Testing Program.
5.5.13    Control Building Envelope Habitability Program A Control Building Envelope (CBE) Habitability Program shall be established and implemented to ensure that CBE habitability is maintained such that, with an OPERABLE Standby Filter Unit System, CBE occupants can control the reactor safely under normal conditions and maintain it in a safe condition following a radiological event, hazardous chemical release, or a smoke challenge. The program shall ensure that adequate radiation protection is provided to permit access and occupancy of the CBE under design basis accident (OBA) conditions without personnel receiving radiation exposures in excess of 5 rem total effective dose equivalent (TEDE) for the duration of the accident. The program shall include the following elements:
: a. The definition of the CBE and the CBE boundary.
: b.      Requirements for maintaining the CBE boundary in its design condition including configuration control and preventive maintenance.
(continued)
DAEC                                     5.0-18                       Amendment ~o. 276

Programs and Manuals 5.5 5.5     Programs and Manuals 5.5.13           Control Building Envelope Habitability Program (continued)
: c.      Requirements for (i) determining the unfiltered air inleakage past the CBE boundary into the CBE in accordance with the testing methods and at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, "Demonstrating Control Room Envelope Integrity at Nuclear Power Reactors," Revision 0, May 2003, and (ii) assessing CBE habitability at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0.
: d.      Measurement, at designated locations, of the CBE pressure relative to all external areas adjacent to the CBE boundary during the pressurization mode of operation by one subsystem of the SFU System, operating at the flow rate required by the VFTP, at a Frequency of 24 months on a Staggered Test Basis . The results
                                                                                   *                       {
shall be trended and used as part of the 24 month assessment of the CBE boundary.
: e.      The quantitative limits on unfiltered air inleakage into the CBE. These limits shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph c. The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of OBA consequences. Unfiltered air leakage limits for hazardous chemicals must ensure that the exposure of CBE occupants to these hazards will be within the assumptions in the licensing basis.
: f.      The provisions of SR 3.0.2 are applicable to the Frequencies for assessing CBE habitability, determining CBE unfiltered inleakage, and measuring CBE pressure and assessing the CBE boundary as required by paragraphs c and d, respectively.
(continued)
* A Staggered Test Basis shall consist of the testing of one of the systems, subsystems, channels, or t
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.
DAEC                                         5.0-18a                            Amendment~

Programs and Manuals 5.5 5.5    Programs and Manuals 5.5.14       Surveillance Frequency Control Program This program provides controls for Surveillance Frequencies. The program shall ensure that Surveillance Requirements specified in the Technical Specifications are performed at intervals sufficient to assure the associated Limiting Conditions for Operation are met.
: a. The Surveillance Frequency Control Program shall contain a list of Frequencies of those Surveillance Requirements for which the Frequency is controlled by the program.
: b. Changes to the Frequencies listed in the Surveillance Frequency Control Program shall be made in accordance with NEI 04-10, "Risk-Informed Method for Control of Surveillance Frequencies," Revision 1.
: c. The provisions of Surveillance Requirements 3.0.2 and 3.0.3 are applicable to the Frequencies established in the Surveillance Frequency Control Program.
5.5.15       Spent Fuel Pool Neutron Absorber Monitoring Program This program provides routine monitoring and actions to ensure that the condition of Baral in the spent fuel pool racks is appropriately monitored to ensure that the Baral neutron attenuation capability described in the criticality safety analysis of UFSAR Section 9.1 is maintained. The program shall include the following:
: a. Neutron attenuation in situ testing for the PaR racks shall be performed at a frequency of not more than 10 years, or more frequently based on observed trends or calculated projections of Baral degradation. The acceptance criterion for minimum Baral areal density will be that value assumed in the criticality safety analysis.
: b. Neutron attenuation testing of a representative Baral coupon for the_
Holtec racks shall be performed at a frequency of not more than 6 years, or more frequently based on observed trends or calculated projections of Baral degradation. The acceptance criterion for minimum Baral density will be that value assumed in the criticality safety analysis.
: c. Description of appropriate corrective actions for discovery on nonconforming Baral.
DAEC                                    5.0-18b                       Amendment~

Reporting Requirements 5.6 5.0 ADMINISTRATIVE CONTROLS 5.6 Reporting Requirements The following reports shall be submitted in accordance with 10 CFR 50.4.
5.6.1         DELETED 5.6.2        Annual Radiological Environmental Operating Report The Annual Radiological Environmental Operating Report covering the operation of the unit during the wevious calendar year shall be submitted by May 15 of each year. The report shall include summaries, interpretations, and analyses of trends of the results of the Radiological Environmental Monitoring Program for the reporting period. The material provided shall be consistent with the objectives outlined in the Offsite Dose Assessment Manual (ODAM), and in 10 CFR 50, Appendix I, Sections IV.B.2, IV.B.3, and IV.C ..
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 ODAM, as well as summarized and tabulated results of these analyses and measurements in the format of the table in Regulatory Guide 4.8.
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.
(continued)
DAEC                                    5.0-19                     Amendment No. 256

Reporting Requirements 5.6 5.6 Reporting Requirements (continued) 5.6.3        Radioactive Material Release Report The Radioactive Material Release Report covering the operation of the unit during the previous calendar 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 ODAM and Process Control Program and in conformance with 10 CFR 50.36a and 10 CFR Part 50, Appendix I, Section IV.8.1.
5.6.4        DELETED 5.6.5        CORE OPERATING LIMITS REPORT (COLR)
: a. Core operating limits shall be established prior to each reload cycle, or prior to any remaining portion of a reload cycle, and shall be documented in the COLR for the following:
: 1. The Average Planar Linear Heat Generation Rate (APLHGR) for Specification 3.2.1;
: 2. The ~inimum Critical Power Ratio (MCPR) for Specification I/
3.2.2,                                                       .~
3.
4.
Exclusion Region in the Power/Flow Map for Specification 3.4.1; and The Minimum Critical Power Ratios (MCPR) in Table 3.3.2.1-1 for Specification 3.3.2.1.
t
: b. The analytical methods used to determine the core operating limits shall be those previously reviewed and approved by the NRC in General Electric Standard Application for Reactor Fuel, NEDE-24011-P-A, (GESTAR II). The revision number is the one approved at the time the reload fuel analyses are performed.
(continued)
DAEC                                   5.0-20                      Amendment No. aoa

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.5        CORE OPERATING LIMITS REPORT (COLR) (continued)
: 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 SOM, transient analysis limits, and accident analysis limits) of the safety analysis are met.
    !DELETED        ~
t  d. The COLR, including any midcycle revisions or supplement~. shall be provided upon issuance for each reload cycle to the NRC.
5.6.6        P/\M Re13ort
                         'Nhen a Feport is mquiFed ey Condition B OFF of LCO 3.3.3.1, "Post Assident Monitming (PAM) lnstFUmentation," a roport shall i '
I ee suemitted within the following 14 days. The Feport shall outline the pFeplanned altemate method(s) of monitming, dessFiee the degme'to whish the altemate method(s) aFe equi1Jalent to the installed PAM .
ehannels, justify the aroas in whish they aro not equi1Jalent, the sause of the inopemeility, and the plans and sshedule foF FestoFing the instFUmentation shannels of the Fu notion to OPERABLE status.
5.6.7        Reactor Coolant System (RCS) PRESSURE AND TEMPERATURE LIMITS REPORT (PTLR)
: a. RCS pressure and temperature limits for heat up, cooldown, low temperature operation, criticality, and hydrostatic testing as well as heatup and cooldown rates shall be established and documented in the PTLR for fhe following:
i) Limiting Conditions for Operation Section 3.4.9, "RCS Pressure and Temperature (PIT) Limits" ii) Surveillance Requirements Section 3.4.9, "RCS Pressure and Temperature (PIT) 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:          '
DAEC                                     5.0-2,1                        Amendment~

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.7        Reactor Coolant System (RCS) PRESSURE AND TEMPERATURE LIMITS REPORT (PTLR) (continued) i) SIR-05-044-A, "Pressure-Temperature Limits Report Methodology for Boiling Water Reactors," Revision 1, dated June 2013.
: c. The PTLR shall be provided to the NRC upon issuance for each reactor vessel fluence period and for any revision or supplement thereto.
r DAEC                               5.0-21a                          Amendment~

High Radiation Area 5.7 5.0 ADMINISTRATIVE CONTROLS 5.7 High Radiation Area As provided in paragraph 20.1601(c) of 10 CFR Part 20, the following controls shall be applied to high radiation areas in place of the controls required by paragraph 20.1601 (a) and (b) of 10 CFR Part 20:
5.7.1        High Radiation Areas with Dose Rates Not Exceeding 1.0 rem/hour at 30 Centimeters from the Radiation Source or from any Surface Penetrated by the Radiation
: a. Each entryway to such an area shall be barricaded and conspicuously posted as a high radiation area. Such barricades may be opened as necessary to permit entry or exit of personnel or equipment.
: b. Access to, and activities in, each such area shall be controlled by means of Radiation Work Permit (RWP) or equivalent that includes specification of radiation dose rates in the immediate work area(s) and other appropriate radiation protection equipment and measures.
: c. Individuals qualified in radiation protection procedures and personnel continuously escorted by such individuals may be exempted from the requirement for an RWP or equivalent while performing their assigned duties provided that they are otherwise following plant radiation protection procedures for entry to, exit from, and work in such areas.
: d. Each individual or group entering such an area shall possess:
: 1.      A radiation monitoring device that continuously displays radiation dose rates in the area; or
: 2.      A radiation monitoring device that continuously transmits dose rates in the area and alarms when the device's dose alarm setpoint is reached, with an appropriate alarm setpoint, or
: 3. A radiation monitoring device that continuously transmits dose rate and cumulative dose information to a remote receiver monitored by radiation protection personnel responsible for controlling personnel radiation exposure within the area, or
: 4. A self-reading dosimeter (e.g., pocket ionization chamber or electronic dosimeter) and,                        (continued)
DAEC                                    5.0-22                       Amendment No. 248 L

High Radiation Area 5.7 5.7 High Radiation Area (continued)
(i)  Be under the surveillance, as specified in the RWP or equivalent, while in the area, of an individual qualified in radiation protection procedures, equipped with a radiation monitoring device that continuously displays radiation dose rates in the area; who is responsible for controlling personnel exposure within the area, or (ii) Be under the surveillance as specified in the RWP or equivalent, while in the area, by means of closed circuit television, of personnel qualified in radiation protection procedures, responsible for controlling personnel radiation exposure in the area, and with the means to communicate with individuals in the area who are covered by such surveillance.
: e. Except for individuals qualified in radiation protection procedures, or personnel continuously escorted by such individuals, entry into such areas shall be made only after dose rates in the area have been determined and entry personnel are knowledgeable of them. These continuously escorted personnel will receive 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)
DAEC                                   5.0-23                        Amendment No. 248

High Radiation Area 5.7 5.7 High Radiation Area (continued)
: b. Access to, and activities in, each area shall be controlled by means of an RWP or equivalent that includes specification of radiation dose rates in the immediate work area(s) and other appropriate radiation protection equipment and measures.
: c. Individuals qualified in radiation protection procedures may be exempted from the requirement for an RWP or equivalent while performing radiation surveys in such areas provided that they are otherwise following plant radiation protection procedures for entry to, exit from, and work in such areas.
: d. Each individual or group entering such an area shall possess:
: 1.      A radiation monitoring device that continuously integrates the radiation rates in the area and alarms when the device's dose alarm setpoint is reached with an appropriate alarm setpoint, or
: 2.      A radiation monitoring device that continuously transmits dose rate and cumulative dose information to a remote receiver monitored by radiation protection personnel responsible for controlling personnel radiation exposure within the area with the means to communicate with and control every individual in the area, or
: 3.      A self-reading dosimeter (e.g., pocket ionization chamber or electronic dosimeter) and, (i)        Be under the surveillance, as specified in the RWP or equivalent, while in the area, of an individual qualified in radiation protection procedures, equipped with a radiation monitoring device that continuously displays radiation dose rates in the area; who is responsible for controlling personnel exposure within the area, or (ii)       Be under the surveillance as specified in the RWP or equivalent, while in the area, by means of closed circuit television, or personnel qualified in radiation protection procedures, responsible for controlling personnel radiation exposure in the area, and with the means to communicate with and control every individual in the area.
(continued)
DAEC                                      5.0-24                     Amendment No. 248 Gorr=ested by NRG LeUer dated Ostober 28, 2002

High Radiation Area 5.7 5.7 High Radiation Area (continued)
: 4.       In those cases where options (2) and (3), above, are impractical or determined to be inconsistent with the "As Low As is Reasonably Achievable" principle, a radiation monitoring device that continuously displays radiation dose rates in the area.
: e.       Except for individuals qualified in radiation protection procedures, or personnel continuously escorted by such individuals, entry into such areas shall be made only after dose rates in the area have been determined and entry personnel are knowledgeable of them. These continuously escorted personnel will receive a pre-job briefing prior to entry into such areas. This dose rate determination, knowledge, and pre-job briefing does not require documentation prior to initial entry.
: f.      Such individual areas that are within a larger area where no enclosure exists for the purpose of locking and where no enclosure can reasonably be constructed around the individual area need not be controlled by a locked door or gate, nor continuously guarded, but shall be barricaded, conspicuously posted, and a clearly visible light shall be activated at the area as a warning device.
DAEC                                  5.0-25                       Amendment No. 248 L

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request NG-19-0055 Enclosure, Attachment 1 Page 1 of 115 ATTACHMENT 2 REVISED TECHNICAL SPECIFICATION PAGES (CLEAN, WITH PROPOSED CHANGES)

NEXTERA ENERGY DUANE ARNOLD, LLC CENTRAL IOWA POWER COOPERATIVE CORN BELT POWER COOPERATIVE DOCKET 50-331 DUANE ARNOLD ENERGY CENTER RENEWED FACILITY LICENSE Renewed License No. DPR-49
: 1. The Nuclear Regulatory Commission (the Commission) having found that:
A. The application for license filed by FPL Energy Duane Arnold, LLC,
* Central Iowa Power Cooperative and Corn Belt Power Cooperative (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. Deleted; C. The facility will be maintained 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: (i) that the activities authorized by this renewed license can be conducted without endangering the health and safety of the public; and (ii) that such activities will be conducted in compliance with the rules and regulations of the Commission; E. NextEra Energy Duane Arnold, LLC is technically qualified and NextEra Energy Duane Arnold, LLC, Central Iowa Power Cooperative and Corn Belt Power Cooperative are financially qualified to engage in the activities authorized by this 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 Commission's regulations; G. The issuance of this 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 issuance of renewed Facility License No. DPR-49 is in accordance with 10 CFR Part 50, Appendix D, of the Commission's regulations and all applicable requirements of said Appendix D have been satisfied;
*on April 16, 2009, the name "FPL Energy Duane Arnold, LLC" was changed to "NextEra Energy Duane Arnold, LLC."
Renewed License No. DPR-49 Amendment

I. Deleted.
: 2. Renewed Facility License No. DPR-49 is hereby issued to NextEra Energy Duane Arnold, LLC, Central Iowa Power Cooperative (CIPCO) and Corn Belt Power Cooperative (Corn Belt) to read as follows:
A. ThJs renewed license applies to the Duane Arnold Energy Center, a permanently defueled boiling water reactor and associated equipment (the facility), owned by NextEra Energy Duane Arnold, LLC, Central Iowa Power Cooperative and Corn Belt Power Cooperative and operated by NextEra Energy Duane Arnold, LLC. The facility is located on NextEra Energy Duane Arnold, LLC's, Central Iowa Power Cooperative's and Corn Belt Power Cooperative's site near Palo in Linn County, Iowa. This site consists of approximately 500 acres adjacent to the Cedar River and is described in the "Final Safety Analysis Report" as supplemented and amended (Amendments 1 through 14) and the Environmental Report as supplemented and amended (Supplements 1 through 5).
B. Subject to the conditions and requirements incorporated herein, the Commission hereby licenses:
(1) NextEra Energy Duane Arnold, LLC, pursuant to Section104b of the Act and 10 CFR Part 50, "Licensing of Production and Utilization Facilities," to possess and use the facility as required for nuclear fuel storage; and CIPCO and Corn Belt to possess the facility at the designated location iri Linn County, Iowa, in accordance with the procedures and limitations set forth in this license; (2) NextEra Energy Duane Arnold, LLC, pursuant to the Act and 10 CFR Part 70, to possess at any time special nuclear material that was used as reactor fuel, in accordance with the limitations for storage, as described in the Updated Final Safety Analysis Report, as supplemented and amended as of June 1992 and as supplemented by letters dated March 26, 1993, and November 17, 2000.
(3) NextEra Energy Duane Arnold, LLC, pursuant to the Act and 10 CFR Parts 30, 40 and 70, to receive, possess and use at any time any byproduct, source or sealed sources for radiation monitoring equipment calibration, and to possess any byproduct, source and special nuclear material as sealed neutron sources previously used for reactor startup or reactor instrumentation; and fission detectors; (4) NextEra Energy Duane Arnold, LLC, 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 associated radioactive apparatus components; (5) NextEra Energy Duane Arnold, LLC, pursuant to the Act and 10 CFR Parts 30 and 70, to possess, but not to separate, such byproduct and special nuclear materials that were produced by the operation of the facility.
Renewed License No. DPR-49 Amendment

C. This renewed license shall be deemed to contain and is subject to the conditions specified in the following Commission regulations in 10 CFR Chapter I; Part 20, Section 30.34 of Part 30, Section 40.41 of Part 40, Sections 50.54 and 50.59 of Part 50, and Section 70.32 of Part 70; is subject to all applicable provisions of the Act and to the rules, regulations, and orders of the Commission now or hereafter in effect; and is subject to the additional conditions specified or incorporated below:
(1) Deleted (2) Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No.          , are hereby incorporated in the license. NextEra Energy Duane Arnold, LLC shall maintain the facility in accordance with the Permanently Defueled Technical Specifications.
(3) Fire Protection Program NextEra Energy Duane Arnold, LLC shall implement and maintain in effect all provisions of the approved fire protection program that comply with 10 CFR 50.48(a) and 10 CFR 50.48(c), as specified in the licensee amendment request dated August 5, 2011 (and supplements dated October 14, 2011, April 23, 2012, May ~3, 2012, July 9, 2012, October 15, 2012, January 11, 2013, February 12, 2013, March 6, 2013, May 1, 2013, May 29, 2013, two supplements dated July 2, 2013, and supplements dated August 5, 2013 and August 28, 2013) and as approved in the safety evaluation report dated September 10, 2013. Except where NRC approval for changes or deviations is required by 10 CFR 50.48( c), and provided no other regulation, technical specification, license condition or requirement would require prior NRC approval, the licensee may make changes to the fire protection program without prior approval of the Commission if those changes satisfy the provisions set forth in 10 CFR 50.48(a) and 10 CFR 50.48(c), the change does not require a change to a technical specification or a license condition, and the criteria listed below are satisfied.
Renewed License No. DPR-49 Amendment

Risk-Informed Changes that May Be Made Without Prior NRC Approval A risk assessment of the change must demonstrate that the acceptance criteria below are met. The risk assessment approach, methods, and data shall be acceptable to the NRC and shall be appropriate for the nature and scope of the change being evaluated; be based on the as-built, as-operated, and maintained plant; and reflect the operating experience at the plant. Acceptable methods to assess the risk of the change may include methods that have been used in the peer-reviewed fire PRA model, methods that have been approved by NRC through a plant-specific license amendment or NRC approval of generic methods specifically for use in NFPA 805 risk assessments, or methods that have been demonstrated to bound the risk impact.
(a) Prior NRC review and approval is not required for changes that clearly result in a decrease in risk. The proposed change must also be consistent with the defense-in-depth philosophy and must maintain sufficient safety margins. The change may be implemented following completion of the plant change evaluation.
(b) Prior NRC review and approval is not required for individual changes that result in a risk increase less than 1 x 1o-7 /year (yr) for CDF and less than 1 x 1o-8/yr for LERF. The proposed change must also be consistent with the defense-in-depth philosophy and must maintain sufficient safety margins. The change may be implemented following completion of the plant change evaluation.
Other Changes that May Be Made Without Prior NRC Approval
: 1. Changes to NFPA 805, Chapter 3, Fundamental Fire Protection Program. Prior NRC review and approval are not required for changes to the NFPA 805, Chapter 3, fundamental fire protection program elements and design requirements for which an engineering evaluation demonstrates that the alternative to the Chapter 3 element is functionally equivalent or adequate for the hazard. The licensee may use an engineering evaluation to demonstrate that a change to NFPA 805, Chapter 3 element is functionally equivalent to the corresponding technical requirement. A qualified fire protection engineer shall perform the engineering evaluation and conclude that the change has not affected the functionality of the component, system, procedure, or physical arrangement, using a relevant technical requirement or standard.
The licensee may use an engineering evaluation to demonstrate that changes to certain NFPA 805, Chapter 3 elements are acceptable because the alternative is "adequate for the hazard." Prior NRC review and approval would not be required for alternatives to four specific sections of NFPA 805, Chapter 3, for which an engineering evaluation demonstrates that the alternative to the Chapter 3 element is adequate for the hazard. A qualified fire protection engineer shall
    *perform the engineering evaluation and conclude that the change has not affected the functionality of the component, system, procedure, or physical arrangement, using a relevant technical requirement or standard. The four specific sections of NFPA 805, Chapter 3, are as follows:
Renewed License No. DPR-49 Amendment 286
* Fire Alarm and Detection Systems (Section 3.8);
* Automatic and Manual Water-Based Fire Suppression Systems (Section 3.9);
* Gaseous Fire Suppression Systems (Section 3.1 O); and,
* Passive Fire Protection Features (Section 3.11 ).
This License Condition does not apply to any demonstration of equivalency under Section 1. 7 of NFPA 805.
: 2. Fire Protection Program Changes that Have No More than Minimal Risk Impact.
Prior NRC review and approval are not required for changes to the licensee's fire protection program that have been demonstrated to have no more than a minimal risk impact. The licensee may use its screening process as approved in the NRC safety evaluation report dated September 10, 2013 to determine that i:ertain fire protection program changes meet the minimal criterion. The licensee shall ensure that fire protection defense-in-depth and safety margins are maintained when changes are made to the fire protection program.
Transition License Conditions (1) Before achieving full compliance with 10 CFR 50.48(c), as specified by (2) and (3) below, risk-informed changes to the licensee's fire protection program may not be made without prior NRC review and approval unless the change has been demonstrated to have no more than a minimal risk impact, as described in (2) above.
(2) The licensee shall implement the modifications to its facility, as described in Enclosure 2, Attachment S, Table S-1, "Plant modifications Committed," of DAEC letter NG-13-0287, dated July 2, 2013, to complete the transition to full compliance with 10 CFR 50.48(c) by December 31, 2014. The licensee shall maintain appropriate compensatory measures in place until completion of these modifications.
(3) The licensee shall implement the items listed 1n Enclosure 2, Attachment S, Table S-2, "Implementation Items," of DAEC letter NG-13-0287, dated July 2, 2013, by March 9, 2014.
(4) Deleted.
(5) Physical Protection NextEra Energy Duane Arnold, LLC shall fully implement and maintain in effect all provisions of the Commission-approved physical security, training and qualification, Renewed License No. DPR-49 Amendment

and safeguards contingency plans including amendments made pursuant to provisions of the Miscellaneous Amendments and Search Requirements revisions to 10 CFR 73.55 (51 FR 27817 and 27822) and to the authority of 10 CFR 50.90 and 10 CFR 50.54(p). The combined set of plans, which contains Safeguards Information protected under 10 CFR 73.21, is entitled: "Duane Arnold Energy Center Physical Security Plan," submitted by letter dated May 16, 2006.
NextEra Energy Duane Arnold, LLC shall fully implement and maintain in effect all provisions of the Commission-approved Duane Arnold Energy Center/NextEra Energy Duane Arnold, LLC Cyber Security Plan (CSP), including changes made pursuant to the authority of 10 CFR 50.90 and 10 CFR 50.54(p). The Duane Arnold Energy Center/NextEra Energy Duane Arnold, LLC CSP was approved by License Amendment No. 278, as supplemented by changes approved by license Amendment No. 284 and Amendment 291.
(6) Deleted (7) Additional Conditions The Additional Conditions contained in Appendix B, as revised through Amendment No. 279, are hereby incorporated into this license. NextEra Energy Duane Arnold, LLC shall operate the facility in accordance with the Additional Conditions.
(8) The licensee is authorized to revise the Updated Final Safety Analysis Report by deleting the footnote for Section 9.1.4.4.5 which states: "*The NRC has not endorsed the reactor building crane as single-failure proof (Reference 9)," and by deleting Reference 9 of the references for Section 9.1.                        *
(9) 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 (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 (10) 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.
Renewed License No. DPR-49 Amendment 291

(11) Deleted.
(12) Deleted.
(13) Deleted.
D. This license is effective as of the date of issuance and is effective until the Commission notifies the licensee in writing that the license is terminated.
FOR THE NUCLEAR REGULATORY COMMISSION Original signed by Eric J. Leeds Eric J. Leeds, Director Office of Nuclear Reactor Regulation

==Enclosures:==
: 1. Appendix A Technical Specifications
: 2. Appendix B Additional Conditions Date of Issuance: December 16, 2010 Renewed License No. DPR-49 Amendment

APPENDIX B ADDITIONAL CONDITIONS LICENSE NO. DPR-49 NextEra Energy Duane Arnold, LLC (the term licensee in Appendix B refers to NextEra Energy Duane Arnold, LLC or prior license holders) shall comply with the following conditions on the schedule noted below:
Amendment Number         Additional Conditions                                  Implementation Date 223           NextEra Energy Duane Arnold, LLC is                   This amendment is 275           authorized to relocate certain                         effective immediately requirements included in Appendix                      and shall be implemented A to licensee-controlled documents.                    within 180 days of the date Implementation of this amendment                      of this amendment.
shall include the relocation of these requirements to the appropriate documents, as described in the licensee's application dated October 30, 1996, as supplemented and consolidated in its March 31, 1998, submittal. These relocations were evaluated in the NRC staff's Safety Evaluation enclosed with this amendment.
260 (1)       NextEra Energy Duane Arnold shall take all             This amendment is 275           necessary steps to ensure that the external trust      effective immediately fund is established at the time of the closing of      and shall be implemented the transfer of the license from Interstate Power      within 30 days of the date (IPL) to FPLE Duane Arnold is maintained in            of this amendment.
accordance with the requirements of the December 23, 2005 order approving the license transfer, NRC regulations, and consistent with the safety evaluation supporting the order. The trust agreement shall be in a form acceptable to the NRC.
260 (2)       DELETED 279 260 (3)       DELETED Amendment

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.
CHANNEL CALIBRATION                      A CHANNEL CALIBRATION shall be the adjustment, as necessary, of the channel output such that it responds within the necessary range and accuracy to known values of the parameter that the channel monitors. The CHANNEL CALIBRATION shall encompass all devices in the channel required for channel OPERABILITY and 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.
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)
DAEC                                              1.1-1                                      Amendment

Definitions 1.1 1.1 Definitions (continued)
CHANNEL FUNCTIONAL          A CHANNEL FUNCTIONAL TEST shall be the TEST                        injection of a simulated or actual signal into the channel as close to the sensor as practicable to verify OPERABILITY of all devices in the channel required for channel OPERABILITY. The CHANNEL FUNCTIONAL TEST may be performed by means of any series of sequential, overlapping, or total channel steps.
DOSE EQUIVALENT 1-131       DOSE EQUIVALENT 1-131 shall be that concentration of 1-131 (microcuries/ml), 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 Federal Guidance Report (FGR) 11, lllimiting Values of Radionuclide Intake and Air Concentration and Dose Conversion Factors for Inhalation, Submersion, and Ingestion," 1989 and FGR 12, "External Exposure to Radionuclides in Air, Water, and Soil," 1993.
LOGIC SYSTEM                A LOGIC SYSTEM FUNCTIONAL TEST shall be a test FUNCTIONAL TEST             of all logic components required for OPERABILITY 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.
(continued)
DAEC                                1.1-2                                Amendment

Definitions 1.1 1.1 Definitions (continued)
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).
DAEC                               1.1-3                                Amendment

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)
DAEC                                   1.2-1                                   Amendment

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)
DAEC                                 1.2-2                              Amendment

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 ...
A.2.2.2 Perform ...
OR A.3    Align ...
This example represents a more complicated use of logical connectors. Required Actions A.1, A.2, and A.3 are alternative choices, only one of which must be performed as indicated by the use of the logical connector OR and the left justified placement.
Any one of these three Actions may be chosen. If A.2 is chosen, then both A.2.1 and A.2.2 must be performed as indicated by the logical connector AND. Required Action A.2.2 is met by performing A.2.2.1 or A.2.2.2. The indented position of the logical connector OR indicates that A.2.2.1 and A.2.2.2 are alternative choices, only one of which must be performed.
DAEC                                  1.2-3                                Amendment

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.
The following discussion and examples contain references to reactor thermal power and reactor MODES. Specifically, Required Actions of several examples direct a change in reactor thermal power or entry into various reactor MODES.
Although these Required Actions do not apply to a permanently shut down and defueled facility, the discussion and examples are retained because they continue to have illustrative value. For purposes of these examples, reactor MODES are defined below.
MODE 1 - Power Operation MODE 2 - Startup MODE 3 - Hot Shutdown, reactor coolant> 212&deg;F MODE 4 - Cold Shutdown, reactor coolant::; 212&deg;F MODE 5 - Refueling BACKGROUND          Limiting Conditions for Operation (LCOs) specify minimum requirements for ensuring safe operation of the unit. The ACTIONS associated with an LCO state Conditions that typically describe the ways in which the requirements of the LCO can fail to be met. Specified with each stated Condition are Required Action(s) and Completion Times(s).
DESCRIPTION        The Completion Time is the amount of time allowed for completing a Required Action. It is referenced to the time of discovery of a situation (e.g., inoperable equipment or variable not within limits) that requires entering an ACTIONS Condition unless otherwise specified, providing the unit is in a MODE or specified condition stated in the Applicability of the LCO. Required Actions must be completed prior to the expiration of the specified Completion Time. An ACTIONS Condition remains in effect and the Required Actions apply until the Condition no longer exists or the unit is not within the LCO Applicability.
If situations are discovered that require entry into more than one Condition at a time within a single LCO (multiple Conditions), the Required Actions for each Condition must be performed within the (continued)
DAEC                                    1.3-1                                Amendment

Completion Times 1.3 1.3 Completion Times (continued) associated Completion Time. When in multiple Conditions, separate Completion Times are tracked for each Condition starting from the time of discovery of the situation that required entry into the Condition.
Once a Condition has been entered, subsequent 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.
However, when a subsequent division, subsystem, component, or variable expressed in the Condition is discovered to be inoperable or not within limits, the Completion Time(s) may be extended. To apply this Completion Time extension, two criteria must first be met. The subsequent inoperability:
: a. Must exist concurrent with the first inoperability; and
: b. Must remain inoperable or not within limits after the first inoperability is resolved.
The total Completion Time allowed for completing a Required Action to address the subsequent inoperability shall be limited to the more restrictive of either:
: a. The stated Completion Time, as measured from the initial entry into the Condition, plus an additional 24 hours; or
: b. The stated Completion Time as measured from discovery of the subsequent inoperability.
The above Completion Time extensions do not apply to those Specifications that have exceptions that allow completely separate re-entry into the Condition (for each 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 (continued)
DAEC                                  1.3-2                                   Amendment

Completion Times 1.3 1.3 Completion Times (continued) zero" may be expressed as a repetitive time (i.e., "once per 8 hours," where the Completion Time is referenced from a previous completion of the Required Action versus the time of Condition entry) or as a time modified by the phrase "from discovery ... "
Example 1.3-3 illustrates one use of this type of Completion Time.
The 10 day Completion Time specified for Condition A and B in Example 1.3-3 may not be extended.
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 hours Action and associated        AND Completion Time not met. B.2 Be in MODE 4.         36 hours Condition B has two Required Actions. Each Required Action has its own separate Completion Time. Each Completion Time is referenced to the time that Condition Bis entered.
The Required Actions of Condition B are to be in MODE 3 within 12 hours AND in MODE 4 within 36 hours. A total of 12 hours is allowed for reaching MODE 3 and a total of 36 hours (not 48 hours) is allowed for reaching MODE 4 from the time that Condition B was entered. If MODE 3 is reached within 6 hours, the time allowed for reaching MODE 4 is the next 30 hours because the total time allowed for reaching MODE 4 is 36 hours.
If Condition B is entered while in MODE 3, the time allowed for reaching MODE 4 is the next 36 hours.
(continued)
DAEC                                1.3-3                                 Amendment

Completion Times 1.3 1.3   Completion Times EXAMPLES             EXAMPLE 1.3-2 (continued)
* ACTIONS*
CONDITION               REQUIRED ACTION        COMPLETION TIME A. One pump         A.1 Restore pump to       7 days inoperable.           OPERABLE status.
B. Required             8.1 Be in MODE 3.         12 hours Action and associated         AND Completion Time not met.        8.2 Be in MODE 4.        36 hours 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 8.1 and B.2 start. If the inoperable pump is
                   , restored to OPERABLE status after Condition B is entered, -
Conditions A and B are exited, and therefore, the Required Actions of Condition B may be terminated.
Wtlen a second pump is declared inoperable while the first pump is still inoperable, Condition A is not re-entered for the second pump.
On restoring one of the pumps to OPERABLE status, the Condition A Completion Time is not reset, but continues from the time the first pump was declared inoperable. This Completion Time may be extended if the pump restored to OPERABLE status was the first inoperable pump. A 24 hour extension to the stated 7 days is allowed, provided this does not result in the second pump being inoperable for> 7 days.
(continued)
DAEC                                     1.3-4                                  Amendment

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 Function X 7 days Function X          subsystem to subsystem           OPERABLE status. AND inoperable.
10 days from discovery of failure to meet the LCO B. One            B.1 Restore Function Y 72 hours Function Y          subsystem to subsystem           OPERABLE status. AND inoperable.
10 days from discovery of failure to meet the LCO C. One            C.1 Restore            72 hours Function X          Function X subsystem          subsystem to inoperable.         OPERABLE status.
AND            OR One           C.2 Restore            72 hours Function Y         Function Y subsystem         subsystem to inoperable        OPERABLE status.                 -
(continued)
DAEC                                  1.3-5                            Amendment

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 discovered).
If Required Action C.2 is completed within the specified Completion Time, Conditions Band Care exited. If the Completion Time for Required Action A.1 has not expired, operation may continue in accordance with Condition A. The remaining Completion Time in Condition A is measured from the time the affected subsystem was declared inoperable (i.e., initial entry into Condition A).
The Completion Times of Conditions A and B are modified by a logical connector, with a separate 10 day Completion Time measured from the time it was discovered the LCO was not met.
In this example, without the separate Completion Time, it would be possible to alternate between Conditions A,* B, and C in such a manner that operation could continue indefinitely without ever restoring systems to meet the LCO. The separate Completion Time modified by the phrase "from discovery of failure to meet the LCO" is designed to prevent indefinite continued operation while not meeting the LCO. This Completion Time allows for an exception to the normal "time zero" for beginning the Completion Time "clock". In this instance, the Completion Time "time zero" is specified as commencing at the time the LCO was initially not met, instead of at the time the associated Condition was entered.
(continued)
DAEC                                1.3-6                                  Amendment

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) to 4 hours valves                 OPERABLE inoperable.            status.
B. Required            B.1 Be in MODE 3.           12 hours Action and associated         AND Completion Time not met.      B.2 Be in MODE 4.           36 hours 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 hours provided this does not result in any subsequent valve being inoperable for> 4 hours.
If the Completion Time of 4 hours (plus the extension) expires while one or more valves are still inoperable, Condition B is entered.
(continued)
DAEC                                  1.3-7                                   Amendment

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 hours valves                       OPERABLE status.
inoperable.
B. Required                8.1 Be in MODE 3.             12 hours Action and associated             AND Completion Time not met.          B.2 Be in MODE 4.             36 hours 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)
DAEC                                      1.3-8                                         Amendment

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 8 inoperable.          SR 3.x.x.x.        hours OR A.2 Reduce              8 hours THERMAL POWER to ::;; 50%
RTP.
B. Required         8.1 Be in MODE 3.      12 hours Action and associated Completion Time not met.
(continued)
DAEC                                  1.3-9                                Amendment

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 hour interval of Required Action A.1 begins when Condition A is entered and the initial performance of Required Action A.1 must be complete within the first 8 hour interval. If Required Action A.1 is followed and the Required Action is not met within the Completion Time (plus the extension allowed by SR 3.0.2),
Condition Bis entered. If Required Action A.2 is followed and the Completion Time of 8 hours is not met, Condition Bis 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)
DAEC                                 1.3-10                                Amendment

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 hour subsystem               subsystem inoperable.             isolated.          AND Once per 8 hours thereafter AND A.2 Restore subsystem 72 hours to OPERABLE status.
B. Required             B.1 Be in MODE 3.       12 hours Action and associated          AND Completion Time not met.       B.2 Be in MODE 4.       36 hours Required Action A.1 has two Completion Times. The 1 hour Completion Time begins at the time the Condition is entered and each "Once per 8 hours thereafter" interval begins upon performance of Required Action A.1.
If after Condition A is entered, Required Action A.1 is not met within either the initial 1 hour or any subsequent 8 hour interval from the previous performance (plus the extension allowed by SR 3.0.2), Condition B is entered. The Completion Time clock for Condition A does not stop after Condition Bis entered, but continues from the time Condition A was initially entered. If.
Required Action A.1 (continued)
DAEC                                 1.3-11                                 Amendment

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 Required COMPLETION       Action should be pursued without delay and in a controlled TIME             manner.
DAEC                                1.3-12                                   Amendment

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.
The following discussion and examples contain references to reactor thermal power and reactor MODES. Specifically, Required Actions of several examples direct a change in reactor thermal power or entry into various reactor MODES.
Although these Required Actions do not apply to a permanently shut down and defueled facility, the discussion and examples are retained because they continue to have illustrative value. For purposes of these examples, reactor MODES are defined below.
MODE 1 - Power Operation MODE 2 - Startup MODE 3 - Hot Shutdown, reactor coolant> 212&deg;F MODE 4 - Cold Shutdown, reactor coolant::;; 212&deg;F MODE 5 - Refueling DESCRIPTION    Each Surveillance Requirement (SR) has a specified Frequency in which the Surveillance must be met in order to meet the associated LCO. An understanding of the correct application of the specified Frequency is necessary for compliance with the SR.
The "specified Frequency" is referred to throughout this section and each of the Specifications of Section 3.0, Surveillance Requirement (SR) Applicability. The "specified Frequency" consists of the requirements of the Frequency column of each SR, as well as certain Notes in the Surveillance column that modify performance requirements.
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.
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 (continued)
DAEC                                1.4-1                               Amendment

Frequency 1.4 1.4  Frequency DESCRIPTION      or the Frequency) is stated such that it is only "required" when (continued)     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 criteria. Some Surveillances contain notes that modify the Frequency of performance or the conditions during which the acceptance criteria must be satisfied. For these Surveillances, the MODE-entry restrictions of SR 3.0.4 may not apply. Such a Surveillance is not required to be performed prior to entering a MODE or other specified condition in the Applicability of the associated LCO if any of the following three conditions are satisfied:
: a.      The Surveillance is not required to be met in the MODE or other specified condition to be entered; or
: b.      The Surveillance is required to be met in the MODE or other specified condition to be entered, but has been performed within the specified Frequency (i.e., it is current) and is known not to be failed; or
: c.      The Surveillance is required to be met, but not performed, in the MODE or other specified condition to be entered, and is known not to be failed.
Examples 1.4-3, 1.4-4, 1.4-5, and 1.4-6 discusses these special situations.
(continued)
DAEC                                 1.4-2                               Amendment

Frequency 1.4 1.4 Frequency (continued)
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.
EXAMPLE 1.4-1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                           FREQUENCY Perform CHANNEL CHECK.                           12 hours Example 1.4-1 contains the type of SR most often encountered in the Technical Specifications (TS). The Frequency specifies an interval (12 hours) 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 hours, 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.
If the interval as specified by SR 3.0.2 is exceeded while the unit is not in a MODE or other specified condition in the Applicability of the LCO for which performance of the SR is required, then SR 3.0.4 becomes applicable. The Surveillance must be performed within the Frequency requirements of SR 3.0.2, as modified by SR 3.0.3, prior to entry into the MODE or other specified condition or the LCO is considered not met (in accordance with SR 3.0.1) and LCO 3.0.4 becomes applicable.
(continued)
DAEC                                 1.4-3                                Amendment

Frequency 1.4 1.4  Frequency EXAMPLES      EXAMPLE 1.4-2 (continued)
SURVEILLANCE REQUIREMENTS SURVEILLANCE                         FREQUENCY Verify flow is within limits.                       Once within 12 hours after z 25%
RTP AND 24 hours 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 z 25% RTP, the Surveillance must be performed within 12 hours.
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.
               "Thereafter" indicates future performances must be established per SR 3.0.2, but only after a specified condition is first met (i.e.,
the "once" performance in this example). If reactor power decreases to < 25% RTP, the measurement of both intervals stops. New intervals start upon reactor power reaching 25%
RTP.
(continued)
DAEC                               1.4-4                                Amendment

Frequency 1.4 1.4 Frequency EXAMPLES      EXAMPLE 1.4-3 (continued)
SURVEILLANCE REQUIREMENTS SURVEILLANCE                            FREQUENCY
               --------------------------N()TE----------------------------
Not required to be performed until 12 hours after 2 25% RTP.
Perform channel adjustment.                                 7 days The interval continues whether or not the unit operation is
              < 25% RTP between performances.
As the Note modifies the required performance of the Surveillance, it is construed to be part of the "specified Frequency." Should the 7 day interval be exceeded while operation is< 25% RTP, this Note allows 12 hours after power reaches 2 25% RTP to perform the Surveillance. The Surveillance is still considered to be within the "specified Frequency." Therefore, if the Surveillance 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 LC(). Also, no violation of SR 3.0.4 occurs when changing M()DES, even with the 7 day Frequency not met, provided operation does not exceed 12 hours (plus the extension allowed by SR 3.0.2) with power 2 25% RTP.
()nee the unit reaches 25% RTP, 12 hours would be allowed for completing the Surveillance. If the Surveillance were not performed within this 12 hour 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.
(continued)
* DAEC                             1.4-5                                     Amendment

Frequency 1.4 1.4  Frequency EXAMPLES        EXAMPLE 1.4-4 (continued)
SURVEILLANCE REQUIREMENTS SURVEILLANCE                           FREQUENCY
                 -------------------------N()TE-----------------------------
()nly required to be met in M()DE 1.
Verify leakage rates are within limits.                     24 hours Example 1.4-4 specifies that the requirements of this Surveillance do not have to be met until the unit is in M()DE 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 hour interval (plus the extension allowed by SR 3.0.2), but the unit was not in M()DE 1, there would be no failure of the SR nqr failure to meet the LC().
Therefore, no violation of SR 3.0.4 occurs when changing M()DES, even with the 24 hour Frequency exceeded, provided the MODE change was not made into M()DE 1. Prior to entering M()DE 1 (assuming again that the 24 hour Frequency were not met), SR 3.0.4 would require satisfying the SR.
(continued)
DAEC                               1.4-6                                        Amendment

Frequency 1.4 1.4  Frequency EXAMPLES         EXAMPLE 1.4-5 (continued)
SURVEILLANCE REQUIREMENTS SURVEILLANCE                             FREQUENCY
                  --------------------------NCJTE-----------------------------
()nly required to be performed in MCJDE 1.
Perform complete cycle of the valve                          7 days The interval continues, whether or not the unit operation is in MCJDE 1, 2 or 3 (the assumed Applicability of the associated LC()) between performances.
As the Note modifies the required performance of the Surveillance, the Note is construed to be part of the "specified Frequency." Should the 7 day interval be exceeded while operation is not in MCJDE 1, this Note allows entry into and operation in M()DES 2 and 3 to perform the Surveillance. The Surveillance is still considered to be performed within the "specified Frequency" if completed prior to entering MCJDE 1.
Therefore, if the Surveillance were not performed within the 7 day (plus the extension allowed by SR 3.0.2) interval, but
               . operation was not in MCJDE 1, it would not constitute a failure of the SR or failure to meet the LCCJ. Also, no violation of SR 3.0.4 occurs when changing MCJDES, even with the 7 day Frequency not met, provided operation does not result in entry into MCJDE 1.
()nee the unit reaches MCJDE 1, the requirement for the Surveillance to be performed within its specified Frequency applies and would require that the Surveillance had been performed. If the Surveillance were not performed prior to entering MCJDE 1, there would then be a failure to perform a Surveillance within the specified Frequency, and the provisions of SR 3.0.3 would apply.
(continued)
DAEC                                1.4-7                                         Amendment

Frequency 1.4 1.4 . Frequency EXAMPLES        EXAMPLE 1.4-6 (continued)
SURVEILLANCE REQUIREMENTS SURVEILLANCE                            FREQUENCY
                 --------------------------N()TE----------------------------
Not required to be met in M()DE 3.
Verify parameter is within limits.                          24 hours Example 1.4-6 specifies that the requirements of this Surveillance do not have to be met while the unit is in M()DE 3 (the assumed Applicability of the associated LC() is M()DES 1, 2, and 3). 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 hour interval (plus the extension allowed by SR 3.0.2), and the unit was in M()DE 3, there would be no failure of the SR nor failure to meet the LC(). Therefore, no violation of SR 3.0.4 occurs when changing M()DES to enter M()DE 3, even with                r the 24 hour Frequency exceeded, provided the M()DE change does not result in entry into M()DE 2. Prior to entering M()DE 2 (assuming again that the 24 hour Frequency were not met), SR 3.0.4 would require satisfying the SR.
DAEC                                   1.4-8                                       Amendment

2.0 DELETED DAEC         2.0-1 Amendment

LCO Applicability 3.0 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY LCO 3.0.1        LCOs shall be met during the specified conditions in the Applicability, except as provided in LCO 3.0.2.
LCO 3.0.2        Upon discovery of a failure to meet an LCO, the Required Actions of the associated Conditions shall be met, except as provided in LCO 3.0.6.
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        Deleted.
LCO 3.0.4       When an LCO is not met, entry into a specified condition in the Applicability shall only be made:
: a.      When the associated ACTIONS to be entered permit continued operation in the specified condition in the Applicability for an unlimited period of time;
: b.      After performance of a risk assessment addressing inoperable systems and components, consideration of the results, determination of the acceptability of entering the specified condition in the Applicability, and establishment of risk management actions, if appropriate; exceptions to this Specification are stated in the individual Specifications, or
: c.      When an allowance is stated in the individual value, parameter, or other Specification.
LCO 3.0.5        Deleted.
LCO 3.0.6        When a supported system LCO is not met solely due to a support system LCO not being met, the Conditions and Required Actions associated with this supported system are not required to be entered.
Only the support system LCO ACTIONS are required to be entered.
This is an exception to LCO 3.0.2 for the supported system. In this event, an evaluation shall be performed in accordance with DAEC                                 3.0-1                                Amendment

LCO Applicability 3.0 3.0 LCO APPLICABILITY LCO 3.0.6       Specification 5.5.11, "Safety Function Determination Program (continued)     (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.
LCO 3.0.7      Deleted.
LCO 3.0.8      Deleted.
LCO 3.0.9      When one or more required barriers are unable to perform their related support function(s), any supported system LCO(s) are not required to be declared not met solely for this reason for up to 30 days provided that at least one train or subsystem of the supported system is OPERABLE and supported by barriers capable of providing their related support function(s), and risk is assessed and managed. This specification may be concurrently applied to more than one train or subsystem of a multiple train or subsystem supported system provided at least one train or subsystem of the supported system is OPERABLE and the barriers supporting each of these trains or subsystems provide their related support function(s) for different categories of initiating events.
Wthe required OPERABLE train or subsystem becomes inoperable while this specification is in use, it must be restored to OPERABLE status within 24 hours or the provisions of this specification cannot be applied to the trains or subsystems supported by the barriers that cannot perform their related support function(s).
At the end of the specified period, the required barriers must be able to perform their related support function(s) or the supported system LCO (s) shall be declared not met.
DAEC                                3.0-2                                  Amendment

SR Applicability 3.0 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY SR 3.0.1      SRs shall be met during the specified conditions in the Applicability for individual LCOs, unless otherwise stated in the SR. Failure to meet a Surveillance, whether such failure is experienced during the performance of the Surveillance or between performances of the Surveillance, shall be failure to meet the LCO. Failure to perform a Surveillance within the specified Frequency shall be failure to meet the LCO. 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 hours or up to the limit of the specified Frequency, whichever is greater. This delay period is permitted to allow performance of the Surveillance. A risk evaluation shall be performed for any Surveillance delayed greater than 24 hours 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)
DAEC                               3.0-3                               Amendment

SR Applicability 3.0 3.0 SR APPLICABILITY (continued)
SR 3.0.4        Entry into a specified condition in the Applicability of an LCO shall only be made when the LCO's Surveillances have
* been met within their specified F_requency, except as provided by SR 3.0.3. When an LCO is not met due to Surveillances not having been met, entry into a specified condition in the Applicability shall only be made in accordance with LCO 3.0.4.
This provision shall not prevent entry into specified conditions in the Applicability that are required to comply with ACTIONS.
DAEC                                3.0-4                                Amendment

3.1 DELETED DAEC        3.1-1 Amendment

3.2 DELETED DAEC        3.2-1 Amendment

3.3 INSTRUMENTATION 3.3.1.1 DELETED 3.3.1.2 DELETED 3.3.2.1 DELETED 3.3.3.1 DELETED 3.3.3.2 DELETED 3.3.4.1 DELETED 3.3.4.2 DELETED 3.3.5.1 DELETED 3.3.5.2 DELETED 3.3.5.3 DELETED 3.3.6.1 DELETED 3.3.6.2 DELETED 3.3.6.3 DELETED DAEC                3.3-1 Amendment

SFU System Instrumentation 3.3.7.1 3.3 INSTRUMENTATION 3.3.7.1 Standby Filter Unit (SFU) System Instrumentation LCO 3.3.7.1               Two channels of the Control Building Intake Area Radiation - High Function shall be OPERABLE.
APPLICABILITY:            During movement of irradiated fuel assemblies in the secondary containment.
ACTIONS
------------------------------------------------NOTE--------------------------------------------------------
Separate Condition entry is allowed for each channel.
CONDITION                           REQUIRED ACTION                    COMPLETION TIME A.      One or both channels                 A. 1    Declare associated            1 hour inoperable.                                  SFU subsystem(s) inoperable.
OR A.2     Place associated SFU         1 hour subsystem(s) in the isolation mode.
DAEC                                              3.3-2                                      Amendment

SFU System Instrumentation 3.3.7.1 SURVEILLANCE REQUIREMENTS
-----------------------------------------------------N()TE---------------------------------------------------
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 hours provided the other channel is ()PERABLE.
SURVEILLANCE                                          FREQUENCY SR 3.3.7.1.1                 Perform CHANNEL CHECK.                                     In accordance with the Surveillance Frequency Control Program SR 3.3.7.1.2                 Perform CHANNEL FUNCTl()NAL TEST.                          In accordance with the Surveillance Frequency Control Program SR 3.3.7.1.3                 Perform CHANNEL CALIBRATl()N. The                          In accordance Allowable Value shall be ::;; 5 mR/hr.                     with the Surveillance Frequency Control Program SR 3.3.7.1.4                 Perform L()GIC SYSTEM FUNCTl()NAL                          In accordance TEST.                                                      with the Surveillance Frequency Control Program DAEC                                              3.3-3                                       Amendment

LOP Instrumentation 3.3.8.1 3.3 INSTRUMENTATION 3.3.8.1 Loss of Power (LOP) Instrumentation LCO 3.3.8.1               The LOP instrumentation for each Function in Table 3.3.8.1-1 shall be OPERABLE.
APPLICABILITY:            When the associated Diesel Generator is required"to be OPERABLE by LCO 3.8.2, "AC Sources."
ACTIONS
--------------------------------------------------------NOTE---------------------------------------------------
Separate Condition entry is allowed for each channel.
CONDITION                            REQUIRED ACTION                    COMPLETION TIME A       One or more Function 1              A.1      Place channel in trip.        1 hour or 3 channels inoperable.
B.      One or more Function 2              B.1      Declare associated            1 hour from discovery channels inoperable.                         Diesel Generator (DG)         of loss of initiation inoperable.                   capability for feature(s) in one or both divisions AND B.2      Place channel in trip.       24 hours (continued)
DAEC                                              3.3-4                                      Amendment

LOP Instrumentation 3.3.8.1 ACTIONS (continued)
CONDITION               REQUIRED ACTION           COMPLETION TIME C. Required Action and   C.1    Declare associated DG  Immediately associated Completion        inoperable.
Time not met.
DAEC                           3.3-5                           Amendment

LOP Instrumentation 3.3.8.1 SURVEILLANCE REQUIREMENTS
----------------------------------------------------NOTES-----------------------------------------------------
: 1. Refer to Table 3.3.8.1-1 to determine which SRs apply for each LOP 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 2 hours provided the associated Function maintains DG initiation capability.
SURVEILLANCE                                        FREQUENCY SR 3.3.8.1.1                 Perform CHANNEL FUNCTIONAL TEST.                         In accordance with the Surveillance Frequency Control ProQram SR 3.3.8.1.2                 Perform CHANNEL FUNCTIONAL TEST.                         In accordance with the Surveillance Frequency Control Program SR 3.3.8.1.3                 Perform CHANNEL CALIBRATION.                             In accordance with the Surveillance Frequency Control Program SR 3.3.8.1.4                 Perform CHANNEL CALIBRATION.                             In accordance with the Surveillance Frequency Control Program SR 3.3.8.1.5                 Perform LOGIC SYSTEM FUNCTIONAL                          In accordance with TEST.                                                    the Surveillance Frequency Control Program DAEC                                              3.3-6                                      Amendment

LOP Instrumentation 3.3.8.1 Table 3.3.8.1-1 (page 1 of 1)
Loss of Power Instrumentation REQUIRED CHANNELS            SURVEILLANCE       ALLOWABLE FUNCTION              PER BUS           REQUIREMENTS         VALUE
: 1. 4.16 kV Emergency Bus Undervoltage (Loss of Voltage)
: a. Bus Undervoltage                                   SR 3.3.B.1.2        c: 595 Vand SR 3.3.8.1.4        _:::2275V SR 3.3.8.1.5
: 2. 4.16 kV Emergency Bus Undervoltage (Degraded Voltage)
: a. Bus Undervoltage                   4              SR 3.3.8.1.1        c: 3780 Vand SR 3.3.8.1.3        _:::3822V SR 3.3.8.1.5
: b. Time Delay                         4              SR 3.3.8.1.1        c:  7.92 seconds and SR 3.3.8.1.3        ::; 8.5 seconds SR 3.3.8.1.5
: 3. 4.16 kV Emergency Transformer          2              SR 3.3.8.1.2        c: 2450 V Supply Undervoltage
* SR 3.3.8.1.3 SR 3.3.8.1.5 DAEC                                              3.3-7                                          Amendment

3.3 INSTRUMENTATION 3.3.8.2 DELETED DAEC                3.3-8 Amendment

3.4 DELETED DAEC        3.4-1 Amendment

3.5 DELETED DAEC        3.5-1 Amendment

3.6 DELETED DAEC        3.6-1 Amendment
: 3. 7 PLANT SYSTEMS 3.7.1 Deleted DAEC               3.7-1 Amendment
: 3. 7 PLANT SYSTEMS 3.7.2 Deleted DAEC               3.7-2 Amendment
: 3. 7 PLANT SYSTEMS 3.7.3 Deleted DAEC               3.7-3 Amendment

SFU System 3.7.4
: 3. 7 PLANT SYSTEMS 3.7.4 Standby Filter Unit (SFU) System LCO 3.7.4                 Two SFU subsystems shall be OPERABLE.
-------------------------------------------------------NOTE--------------------------------------------------
The control building envelope (CBE) boundary may be opened intermittently under administrative control.
APPLICABILITY:            During movement of irradiated fuel assemblies in the secondary containment.
ACTIONS CONDITION                             REQUIRED ACTION                      COMPLETION TIME A.      One SFU subsystem                  A.1       Restore SFU subsystem           7 days inoperable for reasons                       to OPERABLE status.
other than an inoperable CBE boundary.
B.      Required Action and                B.1      Place OPERABLE SFU               Immediately associated Completion                       subsystem in the isolation Time of Condition A                         mode.
not met during movement of                        OR irradiated fuel assemblies in the                  B.2      Suspend movement of              Immediately secondary                                   irradiated fuel assemblies containment.                                in the secondary containment.
(continued)
DAEC                                              3.7-4                                     Amendment

SFU System 3.7.4 ACTIONS (continued)
CONDITION                  REQUIRED ACTION          COMPLETION TIME C. Both SFU subsystems    C.1    Suspend movement of    Immediately inoperable during             irradiated fuel movement of irradiated        assemblies in the fuel assembles in the         secondary containment.
secondary containment.
OR One or more SFU subsystems inoperable due to an inoperable CBE boundary during movement of irradiated fuel assemblies in the secondary containment.
(continued)
DAEC                            3.7-5                          Amendment

SFU System 3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE                               FREQUENCY SR 3.7.4.1    Operate each SFU subsystem for                 In accordance with the
              ~  15 minutes.                                 Surveillance Frequency Control Program SR 3.7.4.2    Perform required SFU filter testing in         In accordance with the accordance with the Ventilation Filter Testing VFTP Program (VFTP).
SR 3.7.4.3    Verify each SFU subsystem actuates on an       In accordance with the actual or simulated initiation signal.         Surveillance Frequency Control Program SR 3.7.4.4    Perform required CBE unfiltered air            In accordance with inleakage testing in accordance with the       the Control Control Building Envelope Habitability         Building Envelope Program.                                       Habitability Program DAEC                             3.7-6                              Amendment

CBC System 3.7.5 3.7 PLANT SYSTEMS
: 3. 7.5 Control Building Chiller (CBC) System LCO 3.7.5            Two CBC subsystems shall be OPERABLE.
APPLICABILITY:       During movement of irradiated fuel assemblies in the secondary containment.
ACTIONS CONDITION                   REQUIRED ACTION              COMPLETION TIME A       One CBC subsystem          A.1    Restore CBC               30 days inoperable.                       subsystem to OPERABLE status.
B. Two CBC subsystems          B.1    Verify control building   Once per 4 hours inoperable.                        area temperatures
                                          < 90&deg;F.
AND B.1    Restore one CBC           72 hours subsystem to OPERABLE status.
(continued)
DAEC                                   3.7-7                              Amendment

I CBC System 3.7.5 ACTIONS (continued)
CONDITION                       REQUIRED ACTION             COMPLETION TIME C. Required Action and              C.1     Place OPERABLE CBC       Immediately associated Completion                    subsystem in operation.
Time of Condition A not met during movement of           OR irradiated fuel assemblies in the secondary                 C.2     Suspend movement of      Immediately containment.                             irradiated fuel assemblies in the secondary containment.
D. Required Action and              0.1     Suspend movement of
* Immediately associated Completion                    irradiated fuel Time of Condition B not                  assemblies in the met during movement of                   secondary containment.
irradiated fuel assemblies in the secondary containment.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                 FREQUENCY SR 3.7.5.1           Verify each CBC subsystem has the              In accordance with the capability to remove the available heat load. Surveillance Frequency Control Program DAEC                                     3.7-8                           Amendment

3.7 PLANT SYSTEMS 3.7.6 Deleted DAEC              3.7-9 Amendment
: 3. 7 PLANT SYSTEMS 3.7.7 Deleted DAEC               3.7-10 Amendment

Spent Fuel Storage Pool Water Level
* 3.7.8
: 3. 7 PLANT SYSTEMS 3.7.8 Spent Fuel Storage Pool Water Level LCO 3.7.8           The spent fuel storage pool water level shall be 2:: 36 ft.
APPLICABILITY:        During movement of irradiated fuel assemblies in the spent fuel storage pool.
ACTIONS CONDITION                           REQUIRED ACTION              COMPLETION TIME A.      Spent fuel storage              A.1      Suspend movement of       Immediately pool water level not                     irradiated fuel within limit.                            assemblies in the spent fuel storage pool.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                      FREQUENCY SR 3.7.8.1               Verify the spent fuel storage pool water           In accordance with level is 2:: 36 ft.                                the Surveillance Frequency Control Program DAEC                                         3.7-11                              Amendment

3.7 PLANT SYSTEMS 3.7.9 Deleted DAEC              3.7-12 Amendment

3.8 ELECTRICAL POWER SYSTEMS 3.8.1 Deleted DAEC                       3.8-1 Amendment

AC Sources 3.8.2 3.8 ELECTRICAL POWER SYSTEMS 3.8.2 AC Sources LCO 3.8.2        The following AC electrical power sources shall be OPERABLE:
: a. One qualified circuit between the offsite transmission network and the onsite Class 1E AC electrical power distribution subsystem(s) required by LCO 3.8.8, "Distribution Systems"; and
: b. One Diesel Generators (DG) capable of supplying one division of the onsite Class 1E AC electrical power distribution subsystem(s) required by LCO 3.8.8.
APPLICABILITY:   During movement of irradiated fuel assemblies in the secondary containment.
DAEC                                3.8-2                               Amendment

AC Sources 3.8.2 ACTIONS CONDITION                REQUIRED ACTION                     COMPLETION TIME
                            ---------------NOTE----------------
A. One required offsite Enter applicable Condition circuit inoperable.
and Required Actions of LCO 3.8.8, with one required division de-energized as a result of Condition A.
A.1      Declare affected                Immediately required feature(s),
with no offsite power available inoperable.
OR A.2      Suspend movement of             Immediately irradiated fuel assemblies in the secondary containment.
B. One required DG        8.1      Suspend movement of             Immediately inoperable.                     irradiated fuel assemblies in secondary containment.
DAEC                             3.8-3                                     Amendment

AC Sources 3.8.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                          FREQUENCY SR 3.8.2.1   Verify correct breaker alignment and indicated              In accordance with power availability for the required offsite circuit.        the Surveillance Frequency Control Program SR 3.8.2.2   ------------------------N()TES-----------------------------
: 1. All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.
: 2. A modified DG start involving idling and gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer.
When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.2. 7 must be met.
Verify the required DG starts from standby                  In accordance with conditions and achieves steady state voltage                the Surveillance 2 3744Vand s 4576V and frequency 2 59.5Hz                   Frequency Control and s 60.5Hz.                                               Program (continued)
DAEC                                  3.8-4                                 Amendment

AC Sources 3.8.2 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE                                           FREQUENCY SR 3.8.2.3   -------------------------N()TE:S----------------------------
: 1. This Surveillance need not be performed.
: 2. DG loadings may include gradual loading as recommended by the manufacturer.
: 3.      Momentary transients outside the load range do not invalidate this test.
: 4. This Surveillance shall be conducted on only one DG at a time.
: 5. This SR shall be preceded by and immediately follow, without shutdown, a successful performance of SR 3.8.2.2 or SR 3.8.2.7.
Verify the required DG is synchronized and                   In accordance with loaded and operates for~ 60 minutes at a                     the Surveillance load ~ 2750kw and ::s; 2950kw.                               Frequency Control Program SR 3.8.2.4   Verify that the required fuel oil day tank                   In accordance with contains ~ 220 gal of fuel oil.                              the Surveillance Frequency Control Program SR 3.8.2.5   Check for the presence of water in the fuel oil in           In accordance with the required day tank and remove water as                    the Surveillance necessary.                                                   Frequency Control Program (continued)
DAEC                                   3.8-5                                 Amendment

AC Sources 3.8.2 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE                                            FREQUENCY SR 3.8.2.6   Verify the fuel oil transfer system operates to               In accordance with transfer fuel oil from storage tank to the day                the Surveillance tank.                                                         Frequency Control Program SR 3.8.2.7   -------------------------N()TE------------------------------
AII DG starts may be preceded by an engine prelube period.
Verify the required DG starts from standby                    In accordance with condition and achieves:                                       the Surveillance Frequency Control
: a. in ::; 10 seconds, voltage      ~ 3744V and                Program frequency~ 59.5Hz; and
: b. steady state, voltage~ 3744V and::; 4576V and frequency~ 59.5Hz and ::; 60.5Hz.
(continued)
DAEC                                  3.8-6
* Amendment

AC Sources 3.8.2 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE                                           FREQUENCY SR 3.8.2.8   -------------------------N()TE------------------------------
This Surveillance need not be performed.
Verify the required DG rejects a load greater                In accordance than or equal to its associated single largest               with the post-accident load, and:                                     Surveillance
: a.      Following load rejection, the frequency is           Frequency Control Program
                     ~ 64.5Hz.
: b. Within 1.3 seconds following load rejection, the voltage is~ 3744V and
                     ~ 4576V.
: c. Within 3.9 seconds following load rejection, the frequency is~ 59.5Hz and
                     ~ 60.5Hz.
SR 3.8.2.9   -------------------------N()TE------------------------------
This Surveillance need not be performed.
Verify the required DG's automatic trips are                 In accordance bypassed on an actual or simulated Loss of                   with the
()ffsite Power (LOOP) signal except:                         Surveillance Frequency
: a. Engine overspeed; and Control Program
: b. Generator lockout.
(continued)
DAEC                                  3.8-7                                  Amendment

AC Sources 3.8.2 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE                                             FREQUENCY SR 3.8.2.10  -------------------------N()TE:------------------------------
This Surveillance does not need to be performed.
Verify under manual control the required DG:                   In accordance with the
: a. Synchronizes with offsite power !;,Ource Surveillance while loaded with emergency loads upon a Frequency simulated restoration of offsite power; Control Program
: b. Transfers loads to offsite power source; and
: c. Returns to ready-to-load operation.
DAEC                                  3.8-8                                 Amendment

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
------------------------------------------------------NO"fE-----------------------------------------------------
For Conditions B, E, and F, separate Condition entry is allowed for each DG.
CONDITION                             REQUIRED AC"flON                  COMPLETION TIME A.      Fuel oil level less                  A.1     Restore fuel oil level to      48 hours than a 7 day supply                          within limits.
and greater than a 6 day supply.
B.      One or more DGs with                 8.1     Restore lube oil               48 hours lube oil inventory less                      inventory to within than a 7 day supply                          limits.
and greater than a 6 day supply.
C.      Stored fuel oil total                C.1     Restore fuel oil total         30 days particulates not within                      particulates to within limit.                                       limits.
(continued)
DAEC                                               3.8-9                                     Amendment

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 ACTIONS (continued)
CONDITION                 REQUIRED ACTION               COMPLETION TIME D. New fuel oil properties    D.1    Restore stored fuel oil    30 days not within limits.                properties to within limits.
E. - One or more DGs with       E.1    Restore required           48 hours required starting air             starting air receiver receiver pressures                pressure to within
      < 150 psig and                    limits.                                           ;
      ;;:: 75 psig.
F. Required Action and        F.1    Declare associated DG      Immediately associated Completion             inoperable.
Time not met.
OR One or more DGs with diesel fuel oil, lube oil, or starting air subsystems not within limits for reasons other than Condition A, B, C, D, or E.
                                                                            \
DAEC                                 3.8-10                               Amendment

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                     FREQUENCY SR 3.8.3.1  Verify fuel oil storage tank contains                  In accordance with a ~ 7 day supply of fuel.                             the Surveillance Frequency Control Program SR 3.8.3.2  Verify lube oil inventory is a ~ 7 day supply for      In accordance with each DG.                                              the Surveillance Frequency Control Program SR 3.8.3.3  Verify fuel oil properties of new and stored fuel      In accordance with oil are tested in accordance with, and                the Diesel Fuel Oil maintained within the limits of, the Diesel Fuel      Testing Program Oil Testing Program.
SR 3.8.3.4  Verify required air start receiver pressure is 2       In accordance with 150 psig.                                             the Surveillance Frequency Control Program SR 3.8.3.5  Check for the presence of water in the fuel oil in     In accordance with the fuel oil storage tank and remove water as         the Surveillance necessary.                                             Frequency Control Program DAEC                              3.8-11                             Amendment

3.8 ELECTRICAL POWER SYSTEMS 3.8.4 Deleted DAEC                       3.8-12 Amendment

DC Sources 3.8.5 3.8 ELECTRICAL POWER SYSTEMS 3.8.5 DC Sources LCO 3.8.5          DC electrical power subsystems shall be OPERABLE to support the DC electrical power distribution subsystems(s) required by LCO 3.8.8, "Distribution Systems."
APPLICABILITY:     During movement of irradiated fuel assemblies in the secondary containment.
ACTIONS CONDITION                      REQUIRED ACTION              COMPLETION TIME A. One or more required       A.1     Declare affected       Immediately DC electrical power                required features(s) subsystems inoperable.             inoperable.
OR A.2      Suspend movement      Immediately of irradiated fuel assemblies in the secondary containment.
DAEC                                  3.8-13                            Amendment

DC Sources 3.8.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                  FREQUENCY SR 3.8.5.1   Verify battery terminal voltage is ~ 130.5 Von       In accordance with float charge for the 125 voe battery.               the Surveillance Frequency Control Program SR 3.8.5.2   Verify no visible corrosion at battery terminals    In accordance with and connectors.                                     the Surveillance Frequency Control OR                                                  Program Verify battery connection resistance within limits.
SR 3.8.5.3   Verify battery cells, cell plates, and racks show   In accordance with no visual indication of physical damage or          the Surveillance abnormal deterioration that could degrade           Frequency Control battery performance.                                Program SR 3.8.5.4   Remove visible corrosion and verify battery cell to In accordance with cell and terminal connections are coated with       the Surveillance anti-corrosion material.                            Frequency Control Program SR 3.8.5.5   Verify battery connection resistance within limits. In accordance with the Surveillance Frequency Control Program (continued)
DAEC                              3.8-14                               Amendment

DC Sources 3.8.5 SURVEILLANCE REQUIREMENTS continued)
SURVEIL LANCE                                            FREQUENCY SR 3.8.5.6    Verify each required battery charger supplies                  In accordance with
              ~ 293 amps at~ 132.5 V for the 125 voe                         the Surveillance subsystem.                                                     Frequency Control Program SR 3.8.5.7   -------------------------N()TES------------------------------
: 1. The modified performance discharge test in SR 3.8.5.8 may be performed in lieu of the service test in SR 3.8.5.7.
: 2. This Surveillance need not be performed.
Verify battery capacity is adequate to supply,                 In accordance with and maintain in ()PERABLE status,                              the Surveillance the required emergency loads for the design                    Frequency Control duty cycle when subjected to a battery service                 Program test.
(continued)
DAEC                                  3.8-15                                Amendment

DC Sources 3.8.5 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE                                             FREQUENCY SR 3.8.5.8   --------------------------N()TE-------------------------------
This Surveillance need not be performed.
Verify battery capacity is ~ 80% of the                        In accordance with manufacturer's rating when subjected to a                      the Surveillance performance discharge test or a modified                       Frequency Control performance discharge test.                                    Program AND 12 months when battery shows degradation or has reached 85% of expected life with capacity < 100% of manufacturer's rating AND 24 months when battery has reached 85% of the expected life with capacity
                                                                             ~ 100% of manufacturer's rating DAEC                                  3.8-16                                 Amendment

Battery Cell Parameters 3.8.6 3.8 ELECTRICAL POWER SYSTEMS 3.8.6 Battery Cell Parameters LCO 3.8.6                 Battery cell parameters for the Division I and Division II 125 VDC 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.
CONDITION                             REQUIRED ACTION                   COMPLETION TIME A.         One or more batteries             A.1         Verify pilot cell           1 hour with one or more                              electrolyte level and battery cell                                  float voltage meet parameters not within                         Table 3.8.6-1 Table 3.8.6-1                                 Category C limits.
Category A or B limits.                           AND A.2         Verify parameters           24 hours for required battery AND cells meet Table 3.8.6-1 Once per 7 days Category C limits.
thereafter AND A.3         Restore parameters          31 days for required battery cells to Table 3.8.6-1 Category A and B limits.
(continued)
DAEC                                              3.8-17                                    Amendment

Battery Cell Parameters 3.8.6 ACTIONS (continued)
CONDITION               REQUIRED ACTION              COMPLETION TIME B. Required Action and      8.1      Declare associated     Immediately associated Completion             battery inoperable.
Time of Condition A not met.
OR One or more batteries with average electrolyte temperature of the representative cells not within limits.
OR One or more batteries with one or more battery cell parameters for required battery cells not within Table 3.8.6-1 Category C limits.
DAEC                            3.8-18                                Amendment

Battery Cell Parameters 3.8.6 SURVEILLANCE REQUIREMENTS
                     =============::::;;:::::= ======
SURVEILLANCE                                       FREQUENCY SR 3.8.6.1    Verify battery cell parameters meet Table              In accordance with 3.8.6-1 Category A limits.                             the Surveillance Frequency Control Program SR 3.8.6.2    Verify battery cell parameters meet Table              In accordance with 3.8.6-1 Category B limits.                             the Surveillance Frequency Control Program AND Once within 24 hours after battery discharge
                                                                      < 110 V for 125 V AND Once within 24 hours after battery overcharge
                                                                      > 150 V for 125 V SR 3.8.6.3  Verify average electrolyte temperature of                In accordance with representative cells is ;: , : 65&deg;F for each battery. the Surveillance Frequency Control Program DAEC                               3.8-19                                Amendment

Battery Cell Parameters 3.8.6 Table 3.8.6-1 (page 1 of 1)
Battery Cell Parameter Requirements CATEGORY A:              CATEGORYB:             CATEGORYC:
LIMITS FOR               LIMITS FOR             LIMITS FOR EACH                     EACH                   EACH PARAMETER              DESIGNATED                CONNECTED              CONNECTED PILOT CELL                    CELL                   CELL Electrolyte Level      > Minimum level          > Minimum level         Above top of plates, indication mark, and     indication mark, and   and not overflowing s % inch above           s % inch above maximum level           maximum level indication mark<a)       indication mark(a)
Float                   2 2.13 V                 2 2.13 V                > 2,.07 V Voltage Specific                2 1.195                  2 1.190                 Not more than Gravity(b)(c)                                                            0.020 below AND                     average of all
                                                                          .connected cells Average of all connected cells         AND
                                                  > 1.200 Average of all connected cells 2 1.190 (a)     It is acceptable for the electrolyte level to temporarily increase above the specified maximum level during equalizing charges provided it is not overflowing.
(b)     Corrected for electrolyte temperature and level.* Level correction is not required, however, when on float charge and battery charging current is < 2 amps.
(c)    A battery charging current of< 2 amps when on float charge is acceptable for meeting specific gravity limits following a battery recharge, for a maximum of 7 days.
When charging current is used to satisfy specific gravity requirements, specific gravity of each connected cell shall be measured prior to expiration of the 7 day allowance.
DAEC                                      3.8-20                                   Amendment

3.8 ELECTRICAL POWER SYSTEMS 3.8.7 Deleted DAEC                       3.8-21 Amendment

Distribution Systems 3.8.8 3.8 ELECTRICAL POWER SYSTEMS 3.8.8 Distribution Systems LCO 3.8.8            The necessary portions of the AC and DC electrical power distribution subsystems shall be OPERABLE to support equipment required to be OPERABLE.
APPLICABILITY:       During movement of irradiated fuel assemblies in the secondary
                   . containment.
ACTIONS CONDITION                        REQUIRED ACTION                 COMPLETION TIME A. One or more required          A.1        Declare associated      Immediately AC or DC electrical                      supported required power distribution                       feature(s) inoperable.
subsytems inoperable.
OR A.2        Suspend movement        Immediately of irradiated fuel assemblies in the secondary containment.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                   FREQUENCY SR 3.8.8.1              Verify correct breaker alignments and           In accordance with the
                       . indicated power availability to required AC     Surveillance and DC electrical power distribution            Frequency Control subsystems.                                     Program DAEC                                     3.8-22                               Amendment

3.9 DELETED DAEC        3.9-1 Amendment

3.10 DELETED DAEC         3.10-1 Amendment

Design Features 4.0 4.0 DESIGN FEATURES 4.1 Site Location The plant site, which consists of approximately 500 acres, is adjacent to the Cedar River approximately 2.5 miles northeast of the Village of Palo, Iowa.
The boundary of the exclusion area defined in 10 CFR 100 is delineated by the property lines. The distance to the outer boundary of the low population zone is 6 miles. The plan of the site is shown on UFSAR Figures 1.2-1 and 1.2-2.
4.2  Deleted 4.3 Fuel Storage 4.3.1 Criticality The spent fuel storage racks are designed and shall be maintained with:
: a. Fuel assemblies having the following limits for maximum k-infinity in the normal reactor core configuration at cold conditions and maximum lattice-average U-235 enrichment weight percent:
k-oo     wt%
i)     7x7 and 8x8 pin arrays             ::; 1.29   ::; 4.6 (Legacy Fuel Assemblies only; Holtec and PaR racks) ii) 1Ox10 pin arrays                      ::; 1.29   ::; 4.95 (Holtec and PaR racks)
: b. kett::; 0.95 if fully flooded with unborated water, which includes an allowance for uncertainties as described in 9.1 of the UFSAR; and
: c. A nominal 6.060 inches for HOLTEC designed and 6.625 inches for PaR designed center to center distance between fuel assemblies placed in the storage racks.
: d. The Baral neutron absorber shall have a 10 8 areal density greater than or equal to 0.0162 grams 10 8/cm 2 with an uncertainty of 0.0012 grams 10 8/cm 2 .
(continued)
DAEC                                    4.0-1                               Amendment No.

Design Features 4.0 4.0 DESIGN FEATURES (continued) 4.3.2 Drainage The spent fuel storage pool is designed and shall be maintained to prevent inadvertent draining of the pool below elevation 831 ft. - 2 3/4 in.
4.3.3 Capacity The spent fuel storage pool is designed and shall be maintained with a storage capacity limited to no more than 2563 fuel assemblies in a vertical orientation, including no more than 152 fuel assemblies stored in the cask pit in accordance with UFSAR Section 9.1.
DAEC                                4.0-2                                  Amendment

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 affects nuclear safety.
5.1.2      The Operations Shift Manager shall be responsible for the control room command function. During any absence of the Operations Shift Manager 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 Operations Shift Manager 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 designed to assume the control room command function.
DAEC                                  5.0-1                                Amendment

Organization 5.2 5.0 ADMINISTRATIVE CONTROLS 5.2 Organization 5.2.1      Onsite and Offsite Organizations Onsite and offsite organizations shall be established for unit operation and corporate management, respectively. The onsite and offsite organizations shall include the positions for activities affecting safety of the nuclear power plant.
: a.      Lines of authority, responsibility, and communication shall be defined and established throughout highest management levels, intermediate levels, and all operating organization positions.
These relationships shall be documented and updated, as appropriate, in organization charts, functional descriptions of departmental responsibilities and relationships, and job descriptions for key personnel positions, or in equivalent forms of documentation. These requirements including the plant specific titles of those personnel fulfilling the responsibilities of the positions delineated in the Technical Specifications shall be documented in the UFSAR or QA Program Description;
: 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 corporate officer with direct responsibility for the plant shall have corporate responsibility for overall plant nuclear safety and shall take any measures needed to ensure acceptable performance of the staff in operating, maintaining, and providing technical support to the plant to ensure nuclear safety; and
: d. The individuals who train the operating staff, carry out health physics, or perform quality assurance functions may report to the appropriate onsite manager; however, these individuals shall have sufficient organizational freedom to ensure their
                  *independence from operating pressures.
(continued)
DAEC                                    5.0-2                                  Amendment

Organization 5.2 5.2 Organization (continued) 5.2.2      Unit Staff The unit staff organization shall also include the following:
: a. A non-licensed operator shall be assigned to the reactor when containing fuel and an additional non-licensed operator shall be assigned to the reactor when operating in MODES 1, 2, or 3.
: b. Shift crew composition shall meet the requirements stipulated herein and in 10 CFR 50.54(m).
: c. Shift crew composition may be less than the minimum requirement of 10 CFR 50.54(m)(2)(i) and 5.2.2.a and 5.2.2.g for a period of time not to exceed 2 hours 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.
: d. A person qualified to implement radiation protection procedures shall be on site when fuel is in the reactor. The position may be vacant for not more than 2 hours, in order to provide for unexpected absence, provided immediate action is taken to fill the required position.
: e. Not used.
: f. The Operations Manager or Operations Supervisors shall hold an
                 *SRO license.
(continued)
DAEC                                  5.0-3                                  Amendment

Organization 5.2 5.2 Organization 5.2.2      Unit Staff (continued)
: g. 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. This function is not required in MODES 4 and 5.
DAEC                                  5.0-4                                 Amendment

Procedures 5.4 5.0 ADMINISTRATIVE CONTROLS 5.4 Procedures 5.4.1      Written procedures shall be established, implemented, and maintained covering the following activities:
: a. The applicable procedures recommended in Regulatory Guide 1.33, Revision 2, Appendix A, February 1978;
: b. The emergency operating procedures required*to implement the requirements of NUREG-0737 and to NUREG-0737, Supplement 1, as stated in Generic Letter 82-33;
: c. Quality assurance for effluent and environmental monitoring;
: d.    [Deleted]; and
: e. All programs specified in Specifications 5.5.
DAEC                                 5.0-6                             Amendment

Programs and Manuals 5.5 5.0 ADMINISTRATIVE CONTROLS 5.5 Programs am:t Manuals The following programs shall be established, implemented and maintained.
5.5.1         Offsite Dose Assessment Manual (ODAM)
: a. The ODAM 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 ODAM 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 Report and Radioactive Material Release Report required by Specification 5.6.2 and Specification 5.6.3.
: c. Licensee initiated changes to the ODAM:
: 1. Shall be documented and records of reviews performed shall be retained. This documentation shall contain:
: a. Sufficient information to support the change(s) together with the appropriate analyses or evaluations justifying the change(s), and
: b. A determination that the change(s) maintain the levels of radioactive effluent control required by 10 CFR 20.1302, 40 CFR 190, 10 CFR 50.36a, and 10 CFR 50, Appendix I, and not adversely impact the accuracy or reliability of effluent dose or setpoint calculations;
: 2. Shall become effective after the approval of the plant manager; and
: 3. Shall be submitted to the NRC in the form of a complete, legible copy of the entire ODAM as a part of or concurrent with the Radioactive Material Release Report for the period of the report in which any change in the ODAM was made. Each change shall be identified by (continued)
DAEC                                       5.0-7                                  Amendment

Programs and Manuals 5.5 5.5   Programs and Manuals 5.5.1        Offsite Dose Assessment Manual (ODAM) (continued) 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        Deleted 5.5.3        Deleted 5.5.4        Radioactive Effluent Controls Program This program, conforming to 10 CFR 50.36a, provides 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 ODAM, shall be implemented by procedures, and shall include remedial actions to be taken whenever the program limits are exceeded. The program shall include the following elements:
: a. Limitations on the functional capability of radioactive liquid and gaseous monitoring instrumentation including surveillance tests and setpoint determination in accordance with the methodology in the ODAM;
: b. Limitations on the concentrations of radioactive material released in liquid effluents from the site to unrestricted areas, conforming to ten times (1 Ox) the concentrations listed in Appendix B, Table 2, Column 2 to 10 CFR 20.1001 -20.2402;
: c. Monitoring, sampling, and analysis of radioactive liquid and gaseous effluents pursuant to 10 CFR 20.1302 and with the methodology and parameters in the ODAM;
: d. Limitations on the annual and quarterly doses or dose commitment to a member of the public from radioactive materials in liquid effluents released to unrestricted areas, conforming to 10 CFR 50, Appendix I;
: e. Determination of cumulative and projected dose contributions from radioactive effluents for the current calendar quarter and current calendar year in accordance with the methodology and parameters in the ODAM at least every 31 days; (continued)
DAEC                                    5.0-8                                  Amendment

Programs and Manuals 5.5 5.5   Programs and Manuals 5.5.4        Radioactive Effluent Controls Program (continued)
: f. Limitations on the functional capability and use of the liquid and gaseous effluent treatment systems to ensure that the appropriate portions of these systems which were used to establish compliance with the design objectives in 10 CFR 50, Appendix I, Section II be used when specified to provide reasonable assurance that releases of radioactive material in liquid and gaseous effluents be kept as low as reasonably achievable;
: g. Limitations on the dose rate resulting from radioactive material released in gaseous effluents from the site to areas at or beyond the site boundary shall be limited to the following:
: 1. For noble gases: less than or equal to a dose rate of 500 mrem/yr to the whole body and less than or equal to a dose rate of 3000 mrem/yr to the skin, and
: 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 mrem/yr to any organ;
: h. Limitations on the annual and quarterly air doses resulting from noble gases released in gaseous effluents to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I;
: i. Limitations on the annual and quarterly doses to a member of the public from iodine-131, iodine-133, tritium, and all radionuclides in particulate form with half lives > 8 days in gaseous effluents released to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I; and
: j. Limitations on the annual dose or dose commitment to any member of the public, beyond the site boundary, due to releases of radioactivity and to radiation from uranium fuel cycle sources, conforming to 40 CFR 190.
The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Radioactive Effluent Controls Program surveillance frequency.
(continued)
DAEC                                  5.0-9                                    Amendment

Programs and Manuals 5.5 5.5   Programs and Manuals (continued) 5.5.5        Deleted 5.5.6        Deleted 5.5.7        Ventilation Filter Testing Program NFTP)
A program shall be established to implement the following required testing of Standby Filter Unit (SFU) filter ventilation systems.
The tests described in Specifications 5.5.7.a and 5.5.7.b shall be performed once per 12 months for standby service, after 720 hours of system operation, following significant painting, fire or chemical release in any ventilation zone communicating with the system, after any structural maintenance on the system housing, and after each partial or complete replacement of the HEPA filter train or charcoal adsorber, respectively.
The test described in Specification 5.5.7.c shall be performed once per 12 months for standby service, after 720 hours of system operation and following significant painting, fire or chemical release in any ventilation zone communicating with the system.
The test described in Specification 5.5.7.d shall be performed annually.
: a. Demonstrate that an inplace test of the HEPA filters shows a penetration and system bypass at the value specified and at the system flowrate specified below:
Penetration      Flowrate (cfm) and System Bypass(%)
SFU System                       < 1.0            900 -1100 (continued)
DAEC                                   5.0-10                                Amendment

Programs and Manuals 5.5 5.5   Programs and Manuals 5.5.7        Ventilation Filter Testing Program (VFTP) (continued)
: b. Demonstrate that an inplace test of the charcoal adsorber shows a penetration and system bypass at the value specified and at the system flowrate specified below:
Penetration        Flowrate (cfm) and System Bypass(%)
SFU System                   < 1.0              900 - 1100
: c. Demonstrate that a laboratory test of a sample of the charcoal adsorber, when obtained as described in Regulatory Guide 1.52 Revision 2, shows the methyl iodide penetration less than the value specified below when tested in accordance with ASTM 03803-1989 at a temperature of 30&deg;C and the relative humidity specified below:
Penetration        Relative Humidity SFU System                    < 5.0%             ~95%
: d. Demonstrate that the pressure drop across the combined HEPA filters and the charcoal adsorbers is less than the value specified below and at the system flowrate specified as follows:
Delta P            Flowrate (cfm)
(inches wg)
SFU System              < 6                 900 -1100 The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the VFTP test frequencies.
(continued)
DAEC                                   5.0-11                               Amendment

Programs and Manuals 5.5 5.5   Programs and Manuals (continued) 5.5.8        Storage Tank Radioactivity Monitoring Program This program provides controls for the quantity of radioactivity contained in unprotected outdoor liquid storage tanks. The liquid radwaste quantities shall be determined in accordance with Standard Review Plan, Section 15.7.3, "Postulated Radioactive Release due to Tank Failures".
The program shall include a surveillance program to ensure that the quantity of radioactivity contained in all outdoor liquid radwaste tanks that are not surrounded by liners, dikes, or walls, capable of holding the tanks' contents and that do not have tank overflows and surrounding area drains connected to the Liquid Radwaste Treatment System is s 50 curies, exc_luding tritium and dissolved or entrained noble gases. The liquid radwaste storage tanks in the Low-Level Radwaste Processing and Storage Facility are considered unprotected outdoor tanks.
The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Storage Tank Radioactivity Monitoring Program surveillance frequencies.
(continued)
DAEC                                   5.0-12                                Amendment

Programs and Manuals 5.5 5.5   Programs and Manuals (continued) 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:
: 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 within limits,
: 2. A viscosity within limits for ASTM 2-D fuel oil, and
: 3. Water and sediment within limits;
: b.      Viscosity, water and sediment for stored ASTM 2-D fuel oil are within limits every 31 days; and
: c.      Total particulate concentration of the stored fuel oil is~ 10 mg/I when tested every 92 days.
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 require either of the following:
: 1. A change in the TS incorporated in the license; or
: 2. A change to the UFSAR or Bases that requires NRC approval pursuant to 10 CFR 50.59.
(continued)
DAEC                                    5.0-13                             Amendment No.

Programs and Manuals 5.5 5.5   Programs and Manuals 5.5.10       Technical Specifications (TS) Bases Control Program (continued)
: c.      The Bases Control Program shall contain provisions to ensure that the Bases are maintained consistent with the UFSAR.
: d.      Proposed changes that meet the criteria of Specification 5.5.1 Ob above shall be reviewed and approved by the NRG prior to implementation. Changes to the Bases implemented without prior NRG approval shall be provided to the NRG on a frequency consistent with 10 CFR 50.71 (e).
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.
(continued)
DAEC                                    5.0-14                            Amendment No.

Programs and Manuals 5.5 5.5   Programs and Manuals 5.5.11       Safety Function Determination Program (SFDP) (continued)
: b. A loss of safety function exists when, assuming no concurrent single failure, no concurrent loss of offsite power or no concurrent loss of onsite diesel generator(s), a safety function assumed in the accident analysis cannot be performed. For the purpose of this program, a loss of safety function may exist when a support system is inoperable, and:
: 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 1s also inoperable; or
: 3.       A required system redundant to support system(s) for the supported systems (1) and (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 tlie loss of safety function exists are required to be entered. When a loss of safety function is caused by the moperability of a single Technical Specification support system, the appropriate Conditions and Required Actions to enter are those of the support system.
5.5.12       Deleted 5.5.13       Control Building Envelope Habitability Program A Control Building Envelope (CBE) Habitability Program shall be established and implemented to ensure that CBE habitability is maintained such that, with an OPERABLE Standby Filter Unit System, CBE occupants can control the reactor safely under normal conditions and maintain it in a safe condition following a radiological event, hazardous chemical release, or a smoke challenge. The program shall ensure that adequate radiation protection is provided to permit access and occupancy of the CBE under design basis accident (OBA) conditions without personnel receiving radiation exposures in excess of 5 rem total effective dose equivalent (TEDE) for the duration of the accident. The program shall include the following elements:
(continued)
DAEC                                   5.0-15                                 Amendment

Programs and Manuals 5.5 5.5     Programs and Manuals 5.5.13            Control Building Envelope Habitability Program (continued)
: a. The definition of the CBE and the CBE boundary.
: b. Requirements for maintaining the CBE boundary in its design condition including configuration control and preventive maintenance.
: c. Requirements for (i) determining the unfiltered air inleakage past the CBE boundary into the CBE in accordance with the testing methods and at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, "Demonstrating Control Room Envelope Integrity at Nuclear Power Reactors," Revision 0, May 2003, and (ii) assessing CBE habitability at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0.
: d.      Measurement, at designated locations, of the CBE pressure relative to all external areas adjacent to the CBE boundary during the pressurization mode of operation by one subsystem of the SFU System, operating at the flow rate required by the VFTP, at a Frequency of 24 months on a Staggered Test Basis*. The results shall be trended and used as part of the 24 month assessment of the CBE boundary.
: e.      The quantitative limits on unfiltered air inleakage into the CBE.
These limits shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph c. The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of OBA consequences. Unfiltered air leakage limits for hazardous chemicals must ensure that the exposure of CBE occupants to these hazards will be within the assumptions in the licensing basis.
: f.      The provisions of SR 3.0.2 are applicable to the Frequencies for assessing CBE habitability, determining CBE unfiltered inleakage, and measuring CBE pressure and assessing the CBE boundary as required by paragraphs c and d, respectively.
(continued)
* 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.
DAEC                                          5.0-16                                 Amendment

Programs and Manuals 5.5 5.5    Programs and Manuals (continued) 5.5.14       Surveillance Frequency Control Program This program provides controls for Surveillance Frequencies. The
(
program shall ensure that Surveillance Requirements specified in the Technical Specifications are performed at intervals sufficient to assure the associated Limiting Conditions for Operation are met.
: a. The Surveillance Frequency Control Program shall contain a list of Frequencies of those Surveillance Requirements for which the Frequency is controlled by the program.
: b. Changes to the Frequencies listed in the Surveillance Frequency Control Program shall be made in accordance with NEI 04-10, "Risk-Informed Method for Control of Surveillance Frequencies," Revision 1.
: c. The provisions of Surveillance Requirements 3.0.2 and 3.0.3 are applicable to the Frequencies established in the Surveillance Frequency Control Program.
5.5.15       Spent Fuel Pool Neutron Absorber Monitoring Program This program provides routine monitoring and actions to ensure that the condition of Baral in the spent fuel pool racks is appropriately monitored to ensure that the Baral neutron attenuation capability described in the criticality safety analysis of UFSAR Section 9.1 is maintained. The program shall include the following:
: a. Neutron attenuation in situ testing for the PaR racks shall be performed at a frequency of not more than 10 years, or more frequently based on observed trends or calculated projections of Baral degradation. The acceptance criterion for minimum Baral areal density will be that value assumed in the criticality safety analysis.
: b. Neutron attenuation testing of a representative Baral coupon for the Holtec racks shall be performed at a frequency of not more than 6 years, or more frequently based on observed trends or calculated projections of Baral degradation. The acceptance criterion for minimum Baral density will be that value assumed in the criticality safety analysis.
: c. Description of appropriate corrective actions for discovery on nonconforming Baral.
DAEC                                     5.0-17                            Amendment

Reporting Requirements 5.6 5.0 ADMINISTRATIVE CONTROLS 5.6 Reporting Requirements The following reports shall be submitted in accordance with 10 CFR 50.4.
5.6.1         DELETED 5.6.2        Annual Radiological Environmental Operating Report The Annual Radiological Environmental Operating Report covering the operation of the unit during the rxevious calendar year shall be submitted by May 15 of each year. The report shall include summaries, interpretations, and analyses of trends of the results of the Radiological Environmental Monitoring Program for the reporting period. The material provided shall be consistent with the objectives outlined in the Offsite Dose Assessment Manual (ODAM), and in 10 CFR 50, Appendix I, Sections IV.B.2, IV.B.3, and IV.C.
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 ODAM, as well as summarized and tabulated results of these analyses and measurements in the format of the table in Regulatory Guide 4.8.
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.
(continued)
DAEC                                    5.0-19                               Amendment

Reporting Requirements 5.6 5.6 Reporting Requirements (continued) 5.6.3        Radioactive Material Release Report The Radioactive Material Release Report covering the operation of the unit during the previous calendar 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 ODAM 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 5.6.5        CORE OPERATING LIMITS REPORT (COLR)
: a. Core operating limits shall be established prior to each reload cycle, or prior to any remaining portion of a reload cycle, and shall be documented in the COLR for the following:
: 1. The Average Planar Linear Heat Generation Rate (APLHGR) for Specification 3.2.1;
: 2. The Minimum Critical Power Ratio (MCPR) for Specification 3.2.2;
: 3. Exclusion Region in the Power/Flow Map for Specification 3.4.1; and
: 4. The Minimum Critical Power Ratios (MCPR) in Table 3.3.2.1-1 for Specification 3.3.2.1.
: b. The analytical methods used to determine the core operating limits shall be those previously reviewed and approved by the NRG in General Electric Standard Application for Reactor Fuel, NEDE-24011-P-A, (GESTAR II). The revision number is the one approved at the time the reload fuel analyses are performed.
(continued)
DAEC                                   5.0-20                               Amendment

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.5        CORE OPERATING LIMITS REPORT (COLR) (continued)
: 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 SOM, transient analysis limits, and accident analysis limits) of the safety analysis are met.
: d. The COLR, including any midcycle revisions or supplements, shall be provided upon issuance for each reload cycle to the NRC.
5.6.6        DELETED 5.6.7        Reactor Coolant System (RCS) PRESSURE AND TEMPERATURE LIMITS REPORT (PTLR)
: a. RCS pressure and temperature limits for heat up, 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 (PIT) Limits" ii) Surveillance Requirements Section 3.4.9, "RCS Pressure and Temperature (PIT) 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:
DAEC                                   5.0-21                                Amendment

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.7        Reactor Coolant System (RCS) PRESSURE AND TEMPERATURE LIMITS REPORT (PTLR) (continued) i) SIR-05-044-A, "Pressure-Temperature Limits Report Methodology for Boiling Water Reactors," Revision 1, dated June 2013.
: c. The PTLR shall be provided to the NRG upon issuance for each reactor vessel fluence period and for any revision or supplement thereto.
DAEC                               5.0-21a                               Amendment

High Radiation Area 5.7 5.0 ADMINISTRATIVE CONTROLS 5.7 High Radiation Area As provided in paragraph 20.1601 (c) of 10 CFR Part 20, the following controls shall be applied to high radiation areas in place of the controls required by paragraph 20.1601(a) and (b) of 10 CFR Part 20:
5.7,1        High Radiation Areas with Dose Rates Not Exceeding 1.0 rem/hour at 30 Centimeters from the Radiation Source or from any Surface Penetrated by the Radiation
: a. Each entryway to such an area shall be barricaded and conspicuously posted as a high radiation area. Such barricades may be opened as necessary to permit entry or exit of personnel or equipment.
: b. Access to, and activities in, each such area shall be controlled by means of Radiation Work Permit (RWP) or equivalent that includes specification of radiation dose rates in the immediate work area(s) and other appropriate radiation protection equipment and measures.
: c. Individuals qualified in radiation protection procedures and personnel continuously escorted by such individuals may be exempted from the requirement for an RWP or equivalent while performing their assigned duties provided that they are otherwise following plant radiation protection procedures for entry to, exit from, and work in such areas.
: d. Each individual or group entering such an area shall possess:
: 1. A radiation monitoring device that continuously displays radiation dose rates in the area; or
: 2. A radiation monitoring device that continuously transmits dose rates in the area and alarms when the device's dose alarm setpoint is reached, with an appropriate alarm setpoint, or
: 3. A radiation monitoring device that continuously transmits dose rate and cumulative dose information to a remote receiver monitored by radiation protection personnel responsible for controlling personnel radiation exposure within the area, or
: 4. A self-reading dosimeter (e.g., pocket ionization chamber or electronic dosimeter) and,                        (continued)
DAEC                                    5.0-22                               Amendment

High Radiation Area 5.7 5.7 High Radiation Area (continued)
(i)  Be under the surveillance, as specified in the RWP or equivalent,
                                 '                                                               I while in the area, of an individual qualified in radiation protection procedures, equipped with a radiation monitoring device that continuously displays rac;iiation dose rates in the area; who is responsible for controlling personnel exposure within the area, or (ii) Be under the surveillance as specified in the RWP or equivalent, .
while in the area, by means of closed circuit television, of personnel qualified in radiation protection procedures, responsible for controlling personnel radiation exposure in the area, and with the m_eans to communicate with individuals in the area who are covered by such surveillance.
: e. Except for individuals qualified in radiation protection procedures, or personnel continuously escorted by such individuals, entry into such areas shall be made only after dose rates in the area have been /
determined and entry personnel are knowledgeable of them. These continuously escorted personnel will receive 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)
DAEC                                   5.0-23                                  Amendment

High Radiation Area 5.7 5.7 High Radiation Area (continued)
: b. Access to, and activities in, each area shall be controlled by means of an RWP or equivalent that includes specification of radiation dose rates in the immediate work area(s) and other appropriate radiation protection equipment and measures.
: c. Individuals qualified in radiation protection procedures may be exempted from the requirement for an RWP or equivalent while performing radiation surveys in such areas provided that they are otherwise following plant radiation protection procedures for entry to, exit from, and work in such areas.
: d. Each individual or group entering such an area shall possess:
: 1.      A radiation monitoring device that continuously integrates the radiation rates in the area and alarms when the device's dose alarm setpoint is reached with an appropriate alarm setpoint, or
: 2.      A radiation monitoring device that continuously transmits dose rate and cumulative dose information to a remote receiver monitored by radiation protection personnel responsible for controlling personnel radiation exposure within the area with the means to communicate with and control every individual in the area, or
: 3.      A self-reading dosimeter (e.g., pocket ionization chamber or electronic dosimeter) and, (i)        Be under the surveillance, as specified in the RWP or equivalent, while in the area, of an individual qualified in radiation protection procedures, equipped with a radiation monitoring device that continuously displays radiation dose rates in the area; who is responsible for controlling personnel exposure within the area, or (ii)       Be under the surveillance as specified in the RWP or equivalent, while in the area, by means of closed circuit television, or personnel qualified in radiation protection procedures, responsible for controlling personnel radiation exposure in the area, and with the means to communicate with and control every individual in the area.
(continued)
DAEC                                     5.0-24                                Amendment

High Radiation Area 5.7 5.7 High Radiation Area (continued)
: 4.      In those cases where options (2) and (3), above, are impractical or determined to be inconsistent with the "As Low As is Reasonably Achievable" principle, a radiation monitoring device that continuously displays r~diation dose rates in the area.
: e.       Except for individuals qualified in radiation protection procedures, or personnel continuously escorted by such individuals, entry into such areas shall be made only after dose rates in the area have been determined and entry personnel are knowledgeable of them. These continuously escorted personnel will receive a pre-job briefing prior to entry into such areas. This dose rate determination, knowledge, and pre-job briefing does not require documentation prior to initial entry.
: f.      Such individual areas that are within a larger area where no enclosure exists for the purpose of locking and where no enclosure
               ,can reasonably be constructed around the individual area need not be controlled by a locked door or gate, nor continuously guarded, but shall be barricaded, conspicuously posted, and a clearly visible light shall be activated at the area as a warning device.
DAEC                                  5.0-25                                Amendment

Duane Arnold Energy Center Docket No. 50-331 License Amendment Request NG-19-0055 Enclosure, Attachment 3 Page 1 of 108 ATTACHMENT 3 PROPOSED TECHNICAL SPECIFICATION BASES CHANGES (MARK-UP)

LCO Applicability B 3.0 B 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY BASES LCOs              LCO 3.0.1 through LCO 3.0.9 establish the general requirements applicable to all Specifications in Sections 3.1 through 3.10 and apply at all times, unless otherwise stated.
f *i*t ac11y LCO 3.0.1         LCO 3.0.1 establishes the Applicability tatement within each individual Specification as the require ent for when the LCO is required to be met (i.e., when the
* sin the MODES or other specified conditions of the Applicability statement of each Specification).
LCO 3.0.2         LCO 3.0.2 establishes that upon discovery of a failure to meet an LCO, the associated ACTIONS shall be met. The Completion Time of each Required Action for an ACTIONS Condition is applicable from the point in time that an ACTIONS Condition is entered. The Required Actions establish those remedial measures that must be taken within specified Completion Times when the requirements of an LCO are not met. This Specification establishes that:
: a.      Completion of the Required Actions within the specified Completion Times constitutes compliance with a Specification; and
: b.      Completion of the Required Actions is not required when an LCO is met within the specified Completion Time, unless otherwise specified. the facility may need to be placed There are two basic types of Required Actions. Th first type of Required Action specifies a time limit in which the L        must be met. This time limit is the Completion Time to restore inoperable system or component to OPERABLE status o to restore variables to within specified limits. If this type of Re ired Action is not completed within the specified Completion Tim , a sh1:Jtdown may be req1:Jired to plase the 1:Jnit in a MODE or condition in which the Specification is not applicable. (Whether stated as a Required Action or not, correction of the entered Condition is an action that may always be considered upon entering ACTIONS.) The second type of Required Action 183 (continued)
DAEC                               B 3.0-1                                     TSCR~

LCO Applicability B 3.0 BASES LCO 3.0.2                  specifies #le remedial measures that permit eontinued operation (continued)         of the unit that is not further restrioted by the Completion Time. In this case, compliance with the Required Actions provides an
 !th_e_f_a_c_ili.....
ty_ _ _.....,!acceptable level of safety ~oontinued operation.
Completing the Required Actions is not required when an LCO is met or is no longer applicable, unless otherwise stated in the individual Specifications.
The nature of some Required Actions of some Conditions necessitates that, once the Condition is entered, the Required Actions must be completed even'though the associated Condition no longer exists. The individual LCO's ACTIONS specify the Required Actions where this is the case. /\n mcample of this is in II                                          "  "  II equipment The Completion Times of the Required Actions e also                 _
applicable when a system or component is moved from service intentionally. The reasons for intentiona relying on the ACTIONS include, but are not limite o, performance of Surveillances, preventive main e nee, corrective maintenance, or investigation of operational oblems. Entering ACTIONS for these reasons must be done in a manner that does not compromise safety. Intentional entry into ACTIONS should not be made for operational convenience. Additionally, if intentional entry into ACTIONS would result in redundant equipment being inoperable, alternatives should be used instead. Doing so limits
                                                                                                     +
the time both subsystems/divisions of a safety function are inoperable and limits the time oonditions mcist whioh may result in LGO     a.a.a being entered. Individual Specifications may specify a       y time limit for performing an SR when equipment is removed from             -I service or bypassed for testing. In this case, the Completion Times of the Required Actions are applicable when this time limit expires, if the equipment remains removed from service or bypassed.
When a change in MODE or other specified condition is required to comply with Required Actions, the~ may enter a MODE or
                          &tRef-specified condition in which a        her Specification becomes applicable. In this case, the Compl ion Times of the associated Required Actions would apply from he point in time that the new Specification becomes applicable nd the ACTIONS Condition(s) are entered.
_ facility
                                                                                   !183 (cont~ued)
DAEC                                         B 3.0-2                                   TSCR~

LCO Applicability B 3.0
                    ~Deleted.
BASES (continued) / '
                 ~
LCO 3.0.3         LCO a.a.a establishes the astions that must be implemented
                  \\'hen an LCO is not met and:
a:-     An assosiated Required Astion and Completion Time is not met and no other Condition applies; or
                  &.      The sondition of the unit is not spesifisally addressed by the assosiated ACTIONS. This means that no sombination of Conditions stated in the ACTIONS san be made that mmstly sorresponds to the astual sondition of the unit.
Sometimes, possible sombinations of Conditions are sush
* that entering LCO a.a.a is warranted; in sush oases, the
                          /\CTIO~Ja spesifisally state a Condition oorresponding to sush sombinations and also that LCO a.a.a be entered immediately.
This Spesifisation delineates the time limits for plasing the unit in a safe MODE or other spesified sondition when operation sannot be maintained within the limits for safe operation as defined by the LCO and its ACTIO~Ja. It is not intended to be used as an operational sonveniense that permits routine 1Joluntary removal of redundant systems or somponents from servise in lieu of other alternatives that would not result in redundant systems or somponents being inoperable.
Upon entering LCO a.a.a, 1 hour is allowed to prepare for an orderly shutdown before initiating a shange in unit operation. This insludes time to permit the operator to soordinate the redustion in eleotrisal generation with the load dispatsher to ensure the stability and availability of the eleotrioal grid. The time limits spesified to reash lower MODES of operation permit the shutdo'IAlfl to proseed in a sontrolled and orderly manner that is well within the spesified maximum sooldo1.vn rate and v.rithin the sapabilities of the unit, assuming that only tho minimum required equipment is OPERABLE. This reduses thermal stresses on somponents of the Roaster Coolant System and the potential for a plant upset that eould ehallenge safety systems under sonditions to whish this Spesifisation applies. The use and interpretation of spesified times to somplete the astions of LCO a.a.a are oonsistent with the dissussion of Scotian 1.a, Completion Times.
ITSCR-183           ~
                                                                            ~continue~
DAEC                               B 3.0-3                              ~       dm

LCO Applicability B 3.0 BASES Lco a.a.a     A unit sRutdown required in aaaordanae witR LCO a.a.a R1ay be (aontinued) terminated and LCO a.a.a exited if any of tRe following oaaurs:
a:-     TRe LCO is nov, met.
e... A Condition exists for wRiGR tRe Required Aations Rave now been performed.
              &.      ACTIONS exist tRat do not Rave expired CoRlpletion Times. TRese Completion Times are appliaable from tRe point in time tRat tRe Condition is initially entered and not from tRe time LCO a.a.a is exited.
TRe time limits of Speaifiaation a.a.a allmu 37 Rours for tRe unit to be in MODE 4 wRen a sRutdown is required during MODE 1 operation. If tRe unit is in a lmver MODE of operation wRen a sRutdown is required, tRe time limit for reaaRing tRe next lower MODE applies. If a lower MODE is reaaRed in less time tRan allowed, Rowever, tRe total allowable time to reaaR MODE 4, or otRer appliaable MODE, is not reduaed. For example, if MODE 2 is reaaRed in 2 Rours, tRen tRe time allowed for reaoRing MODE 3 is tRe next 11 Rours, beaause tRe total time for reaaRing MODE 3 is not reduaed from tRe allov.*able limit of 13 Rours. TRerefore, if remedial measures are 00R1pleted tRat would permit a return to MODE 1, a penalty is not inaurred by Raving to reasR a lower MODE of operation in less tRan tRe total time allowed.
In MODES 1, 2, and 3, LCO a.a.a provides astions for Conditions not severed in otRer Spesifisations. TRe requireRlents of LCO a.a.a do not apply in MODES 4 and 5 beaause tRe unit is already in tRe most restristive Condition required by LCO a.a.a.
TRe requirements of LCO a.a.a do not apply in otRer spesified aonditions of tRe Appliaability (unless in MODE 1, 2, or 3) beaause tRe ACTIO~rn of individual Spesifiaations s1:1ffisiently define tRe remedial measures to be taken.
Exaeptions to LCO a.a.a are provided in instanses wRere requiring a unit sRutdovm, in assordanse witR LCO a.a.a, would not provide appropriate remedial R1easures for tRe assosiated sondition of tRe unit. An example of tRis is in LCO 3.7.8, "Spent Fuel Storage Pool 'Nater Level." LCO 3.7.8 Ras an Applisability of "During moveR1ent of irradiated fuel assemblies in tRe spent fuel
                                                                !TSCR-183            !
                                                                         ?continued)
DAEC                            B 3.0-4                              ,i:    dment'

LCO Applicability B 3.0 BASES LGO 3.0.3            storage 13001." Therefore, this LGO oan be a1313lioable in any or all (eontinued)      MODES. If the LGO and the Required /\otions of LGO 3.7.8 are not met while in MODE 1, 2, or 3, there is no safety benefit to be gained by 13laoing the l*:IRit in a shutdovm eondition. The Required Aetion of LGO 3.7.8 of "Sus13end movement of irradiated fuel assemblies in the s13ent fuel storage 13001" is the a1313ro13riate Required Aetion to eom13lete in lieu of the aetions of LGO 3.0.3.
These mme13tions are addressed in the individual S13eeifieations.
   -----------------=facility L------''"-------'
LCO 3.0.4            LCO 3.0.4 establishe limitations on changes in MODES or other specified conditions
* the Applicability when an LCO is not met.
It allows placing the ~ in a MODE or other specified condition
     -fa-c-il-ity----~stated in that Applicability (e.g., the Applicability desired to be E~L_----~eein1tteerere!CIT'Wh~~Ht-*conditions are such that the requirements of the LCO would not be met, in accordance with LCO 3.0.4.a, LCO 3.0.4.b, or LCO 3.0.4.c. the facility to be LCO 3.0.4.a allows entry into a M"29'Y-l:=-9lF-elifllef=
in the Applicability with the LC ACTIONS to be entered permit Bel~tMe-EHH*!~~
or other specified condition in the        plicability for an unlimited period of time. Compliance with squired Actions that 13ermit eontinbled 013eration of the unit for an unlimited 13eriod of time in a
!facility           ~MODE or other s13eeified eondition provides an acceptable level of L------''"---------'        et for eontinued 013eration. This is without regard to the status oft -l:ffHt before or              MODE change. Therefore, in such specified condition            ,    y mto  a MODE       or other specified condition in the Applicability may be made in accordance with the provisions of the Required Actions.
LCO 3.0.4.b allows entry into a MODE or ot~er specified condition in the Applicability with the LCO not met after performance of a risk assessment addressing inoperable systems and components, consideration of the results, determination of the acceptability of entering the MODE or other specified condition in the Applicability, and establishment of risk management actions, if appropriate.
The risk assessment may use quantitative, qualitative, or blended approaches, and the risk assessment will be conducted using the plant program, procedures, and criteria in place to implement
                                                                                     !183 (contin~ed)
                                                                                                ~
DAEC                                  B 3.0-5                                         TSCR-Ge4

LCO Applicability B 3.0 BASES LCO 3.0.4      10 CFR 50.65(a)(4), which requires that risk impacts of (continued) maintenance activities be assessed and managed. The risk assessment, for the purposes of LCO 3.0.4.b, must take into account all inoperable Technical Specification equipment regardless of whether the equipment is included in the normal 10 t
CFR 50.65(a)(4) risk assessment scope. The risk assessments will be conducted using the procedures and guidance endorsed by Regulatory Guide 1.160, "Monitoring the Effectiveness of Maintenance at Nuclear Power Plants." Regulatory Guide 1.160 endorses Revision 4A of NUMARC 93-01 dated April 2011, "Industry Guideline for Monitoring the Effectiveness of Maintenance at Nuclear Power Plants." These documents address general guidance for conduct of the risk assessment, quantitative and qualitative guidelines for establishing risk management actions, and example risk management actions.
These include actions to plan and conduct other activities in a manner that controls overall risk, increased risk awareness by shift and management personnel, actions to reduce the duration specified condition of the condition, actions to minimize the magnitude of risk increases (establishment of backup success paths or compensatory measures), and determination that the proposed MODe change is acceptable. Consideration should also be given to the probability of completing restoration such that the requirements of the LCO would be met prior to the expiration of ACTIONS Completion Times that would require exiting the Applicability.
LCO 3.0.4.b may be used with single, or multiple systems and components unavailable. NUMARC 93-01 provides guidance relative to consideration of simultaneous unavailability of multiple systems and components.
The results of the risk assessment shall be considered in determining the acceptability of entering the MODe or other specified condition in the Applicability, and any corresponding risk management actions. The LCO 3.0.4.b risk assessments do not have to be documented.
The Teshnisal gpesifisations allmu sontinued operation with equiprnent unavailable in MODe 1 for the duration of the Gornpletion Tirne. Sinse this is allowable, and sinse in general the risk irnpast in that partisular MODe bounds the risk of transitioning into the through the applisable MODeg or other spesified sonditions in the /\pplisability of the LGO, the use of the LGO d.0.4 .b allowanse should be generally asseptable, as long as the
                                                                                ~!18_3_ _ _ ___,
(contini DAEC                             B 3.0-6                                   TSC

LCO Applicability B 3.0 BASES LCO 3.0.4            risk is assesseel aRel FRaRageel as stateel above. However, there is (continued)       a sFRall subset of systeFRs aRel ooFRpoRents that ha1,e been eleterFRineel to be FRore iFRportant to risk anel use of the LCO 3.0.4 .b allowanoe is prohibiteel. The LCOs governing these systeFRs anel ooFRponents oontain Notes prohibiting the use of LCO 3.0.4 .b by stating that LCO 3.0.4 .b is not applioable.
LCO 3.0.4.c allows entry into a MODE or other specified condition in the Applicability with the LCO not met based on a Note in the Specification which states LCO 3.0.4.c is applicable. These specific allowances permit entry into MODES or other specified conditions in the Applicability when the associated ACTIONS to be entered do not provide f
* eontinueel operation for an unlimited period of time a            1sk assessment has not been performed. This allowa            ay apply to all the ACTIONS or to a specific Required the facility      .__-,-,..... ion of a Specification. The risk assessments performed to justify remaining in the       the use of LCO 3.0.4.b usually only consider systems and condition              components. For this reason, LCO 3.0.4.c is typically applied to Specifications which describe values and parameters (e.g., Roaster Coolant SysteFR Speeifie Aetivity), and may be applied to other Specifications based on NRC plant-specific approval.
The provisions of this Specification should not be interpreted as endorsing the failure to exercise the good practice of restoring systems or components to OPERABLE status before entering an associated MODE or otl:mr specified condition in the Applicability.
The provisions of LCO 3.0.4 shall not prevent changes in MODES or other specified conditions in the Applicability that are required to comply with ACTIONS. In aelelition, the provisions of LCO 3.0.4 shall not prevent ehanges in MODES or other speoifieel oonelitions in the Applieability that result from any unit shutelm".'n. In this oontext, a unit shutelown is elefineel as a ohan&sect;le in MODE or other speoifieel oonelition in the Applioability assooiateel 1,.vith transitionin&sect;I from MODE 1 to MODE 2 or MODE 3, MODE 2 to MODE 3, anel MODE 3 to MODE 4.
Upon entry into a MODE or other specified condition in the Applicability with the LCO not met, LCO 3.0.1 and LCO 3.0.2 require entry into the applicable Conditions and Required Actions until the Condition is resolved, until the LCO is met, or until the~
is not within the Applicability of the Technical Specification.
facility l183 (continue~
Jt DAEC                                     B 3.0-7                                       TSCR-Qe4

LCO Applicability B 3.0 BASES LCO 3.0.4 (continued)
Surveillances do not have to be performed on the associated inoperable equipment (or on variables outside the specified limits),
as permitted by SR 3.0.1. Therefore, utilizing LCO 3.0.4 is not a violation of SR 3.0.1 or SR 3.0.4 for any Surveillances that have not been performed on inoperable equipment. However, SRs
                                                                                              +
must be met to ensure OPERABILITY prior to declaring the associated equipment OPERABLE (or variable within limits) and restoring compliance with the affected LCO.
LCO 3.0.5    LCO d.0.5 establishes the allowanoe for restoring equipment to servioe under administrative oontrols when it has been removed from servioe or deolared inoperable to oomply with ACTIONS. The Deleted.             sole purpose of this Speoifioation is to provide an mcoeption to LCO d.0.2 (e.g., to not oomply *.vith the applioable Required Aotion(s)) to allm.v the performanoe of required testing to demonstrate:
The OPERABILITY of the equipment being returned to servioe; or The OPERABILITY of other equipment.
The administrative oontrols ensure the time the equipment is returned to servioe in oonfliot VJith the requirements of the ACTIONS is limited to the time absolutely neoessary to perform the required testing to demonstrate OPERABILITY. This 8pesifioation does not provide time to perform any other preventive or oorreotive maintenanoe.
An example of demonstrating the OPERABILITY of the equipment being returned to servioe is reopening a oontainment isolation valve that has been olosed to oomply with Required Aotions and must be reopened to perform the required testing.
An example of demonstrating the OPERABILITY of other equipment is taking an inoperable ohannel or trip system out of the tripped oondition to prevent the trip funotion from ooourring during the performanoe of required testing on another ohannel in the other trip system. A similar example of demonstrating the OPERABILITY of other equipment is taking an inoperable shannel or trip system out of the tripped oondition to permit the log is to funotion and indioate the appropriate response during the performanoe of required testing on another ohannel in the same trip system.
* 11_8_3 (continueJ I.?
DAEC                              B 3.0-8                                   TSCR..Qe4

LCO Applicability B 3.0 BASES LCO 3.0.6   LCO 3.0.6 establishes an exception to LCO 3.0.2 for support systems that have an LCO specified in the Technical Specifications (TS). This exception is provided because LCO 3.0.2 would require that the Conditions and Required Actions of the associated inoperable supported system LCO be entered solely due to the inoperability of the support system. This facility       ception is justified because the actions that are required to ensure      fHBfH is maintained in a safe condition are specified in the support system LCO's Required Actions. These Required Actions may include entering the supported system's Conditions and Required Actions or may specify other Required Actions.
When a support system is inoperable and there is an LCO specified for it in the TS, the supported system(s) are required to be declared inoperable if determined to be inoperable as a result of the support system inoperability.
However, it is not necessary to enter into the supported systems' Conditions and Required Actions unless directed to do so by the support system's Required Actions. The potential confusion and inconsistency of requirements related to the entry into multiple support and supported systems' LCOs' Conditions and Required Actions are eliminated by providing all the actions that are
          , necessary to ensure the~
* maintained in a safe condition in the support system's Required Ac
* s. facility However, there are instances where a support system's Required Action may either direct a supported system to be declared inoperable or direct entry into Conditions and Required Actions for the supported system. This may occur immediately or after some specified delay to perform some other Required Action.
Regardless of whether it is immediate or after some delay, 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.
Specification 5.5.11, "Safety Function Determination Program (SFDP)," ensures loss of safety function is detected and appropriate actions are taken. Upon entry into LCO 3.0.6, an evaluation shall be made to determine if loss of safety function exists. Additionally, other limitations, remedial actions, or
                                                                     !183 DAEC                          B 3.0-9                                  TSCR-004

LCO Applicability B 3.0 BASES LCO 3.0.6     compensatory actions may be identified as a result of the support (continued) system lnoperability and corresponding exception to entering supported system Conditions and Required Actions. The SFDP implements the requirements of LCO 3.0.6.
Cross division checks to identify a loss of safety function for those support systems that support safety systems are required. The cross division check verifies that the supported systems of the redundant OPERABLE support system are OPERABLE, thereby ensuring safety function is retained.
:         I A loss of safety function may exist when a support system is inoperable, and:
A. A required system redundant to system(s) supported by the inoperable support system is also inoperable; or (EXAMPLE B3.0.6-1)
B. A required system redundant to system(s) in turn supported by the inoperable supported system is also inoperable; or (EXAMPLE B3.0.6-2)
C. A required system redundi;rnt to support system(s) for the supported systems (a) and (b) above is also inoperable.
(EXAMPLE B3.0.6-3)
EXAMPLE B3.0.6-1 If System 2 of Train A is inoperable, and System 5 of Train B is operable, a loss of safety function exists in supported System 5.
EXAMPLE B3.0.6-2 If System 2 of Train A is inoperable, and System 11 of Train B is inoperable, a loss of safety function exists in System 11 which is in turn supported by System 5.
EXAMPLE B3.0.6-3 If System 2 of Train A is inoperable, and System 1 of Train B is inoperable, a loss of safety function exists in Systems 2, 4, 5, 8, 9, 10, and 11.                                               -
If this evaluation determines that a loss of safety function exists, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered.
                                                                  !183 (co&inued)
Si DAEC                            B 3.0-10                                  TSCR-004

LCO Applicability B 3.0 BASES LCO 3.0.6 (continued)
EXAMPLES System 8                                        System 8 I                                               I System4                                          System4 I       System 9                                 I      System 9
      -    System 2                                    -    System 2 System 10                                       System 10 I                                                 I System 5                                         System 5 I      System 11                                  I    System 11 System 1 System 1 System 12                                       System 12 I                                                I System 6                                         System6 I      System 13                                 I     System 13
      ~
System 3                                    -    System 3 System 14                                       System 141*
I                                                I System 7                                         System7 I      System 15                                 I     System 15
                                                                      !183
.DAEC                                 B 3.0-11                                TSC~

LCO Applicability B 3.0 BASES LCO 3.0.6    This loss of safety function does not require the assumption of (continued) additional single failures or loss of offsite power. Since operation is being restricted in accordance with the ACTIONS of the support system, any resulting temporary loss of redundancy or single failure protection is taken into account. Similarly, the ACTIONS for inoperable offsite circuit(s) and inoperable diesel generator(s) provide the necessary restriction for cross train inoperabilities.
This explicit cross train verification for inoperable AC electrical power sources also acknowledges that supported system(s) are not declared inoperable solely as a result of inoperability of a normal or emergency electrical power source (refer to the definition of OPERABILITY).
When a loss of safety function is determined to exist, and the SFDP requires entry into the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists, consideration must be given to the specific type of function affected. Where a loss of function is solely due to a single Technical Specification support system (e.g., loss of automatic start due to inoperable instrumentation, or loss of pump suction source due to low tank level) the appropriate LCO is the LCO for the support system. The ACTIONS for a support system LCO adequately addresses the inoperabilities of that system without reliance on entering its supported system LCO. When the loss of function is the result of multiple support systems, the appropriate LCO is the LCO for the supported system.
LCO 3.0.7    Tl=ieFe am sertaiR spesial tests aRd opemtioRs Fequirnd to be perioFR1ed at vaFious tiR1es oveF tl=ie lif.e of tl=ie UR it. Tl=iese spesial tests aRd opeFatioRs am Resessar:y to demoRstmte selest URit Deleted.              perioFR1aRse sl=iamstmistiss, to per:foFR1 spesial R1aiRteRaRse astivities, aRd to pOFfoFR1 spesial evolutioRs. apesial Oper=atioRs LG Os iR aestioR d.1 O allov, spesified Ta FequirnR1eRts to be el=iaRged to peFR1it perioFR1aRees of tl=iese speeial tests a Rd opemtiORS, WRiGR otROFWise Gould Rot be perioFR1ed if rnquirnd to 00R1ply with the rnquirnR1eRts of these Ta. UR less otl=imwise spesified, all tl=ie otheF Ta FOquiFeR1eRts FeR1aiR uRsl=iaRged. This will eRsuFe all appmpFiate rnq1:1irnR1eRts of the MODE OF otheF spesified soRditioR Rot dirnstly assosiated witl=i OF rnquirnd to perioFR1 the speeial test OF opemtioR 'Nill FeR1aiR iR off.est.  ~!18_3_ _ _ ___,
DAEC                           B 3.0-12                                          TSCR-Q.79

LCO Applicability B 3.0 BASES LCO d.0.7       The Applisability of a Spesial Operations LCO FepFOsents a (sontimied)    eondition not nesessaFily in eomplianse 1,uith the noFmal mquiFements of the TS. Complianse with Speeial Operations LCOs is optional. A spesial operation may be peFfOFmed eitheF undOF the prnvisions of the apprnpriate apeeial Operations LCO OF under the otheF applisable Ta mquiFOments. If it is desiFOd to peFform the spesial operation under the prnvisions of the Spesial Operations LCO, the requirements of the Spesial Operations LCO shall be followed. \'Vhen a apesial Operations LCO requires another LCO to be met, only the requirements of the LCO statement are required to be met regardless of that LC O's Applieability (i.e., should the requirements of this other LCO not be met, the ACTIONS of the apesial Operations LCO apply, not the ACTIO~Jg of the other LCO). Flo'Ne\*er, there are instanees
                     'Nhere the Spesial Operations LCO's ACTIONS may direst the other LC O's ACTIONS be met. The aurveillanees of the other LCO are not required to be met, unless speoified in the Speoial Operations LCO. If oonditions exist suoh that the Applioability of any other LCO is met, all the othOF LCO's requirements (ACTIONS and SRs) are FOquiFed to be met oonourrent with the requirements of the Speoial Operations LCO.
* LCO 3.0.8       LCO d.0.8 establishes oonditions under whioh systems aFe oonsidered to remain oapable of peFforming their intended safety funotion 1,uhen assooiated snubbers are not oapable of prnviding Deleted.             their assooiated support funotion(s). This LCO states that the supported system is not oonsidered to be inoperable solely due to one or more snubbOFs not oapable of peFforming their assooiated support funotion(s). This is apprnpriate beoause a limited length of time is allm.ved for maintenanoe, testing, or repair of one or more snubbeFs not oapable of peFforming their assooiated support funotion(s) and appropriate oompensatory meas1:1res are speoified in the sn1:1bber req1:1irements, whioh are looated 01:1tside of the Teohnioal apeoifioations (Ta) 1:1nder lioensee oontrnl. The sn1:1bber req1:1irements do not meet the oritOFia in 10 ci;R 50.de(o)(2)(ii), and, as s1:1oh, are appropriate for oontrol by the lioensee.
If the allowed time expires and the snubber(s) are 1:1nable to peFform their assooiated s1:1pport f1:1notion(s), the affeoted
* s1:1pported system's LCO(s) must be deolared not met and the Conditions and Req1:1ired Aotions entered in aooordanoe with LCO
                     ~
                                                                               !183 DAEC                             B 3.0-13 J
TSCR-Q.79

LCO Applicability B 3.0 BASES LCO 3.0.8    LCO a.Q.8.a applies wheA eAe er FAere smibbers are Aet oa13able ef providiAg their asseoiated support fuAstieA(s) te a siAglo traiA or subsystem ef a multiple train er subsystem supported system or te a single train er subsystem su13pertod system. LCO a.Q.Ra allevls 72 heurs te restore tho snubbor(s) before doolaring tho su1313ertod system ino13erablo. The 72 hour Completion Time is roasoAablo based on tho low 13robability ef a seismio event oonourrent with an event that would require operation of the supported system ooourring while tho snubbor(s) are Rot oapablo of porforFAing their assooiatod sup13ort funotion and duo to tho availability of tho redundant train of tho supported system.
LCO a.Q.8.b applies 111hoA one or more snubbers are not oa13ablo of 13roviding their assooiated sup13ort funstion(s) to more than one traiA or subsystem of a multiple train or subsystem supported system. LCO 3.Q.8.b allows 12 hours to restore tho snubbor(s) before doolaring tho su13ported system inoperable. Tho 12 hour Completion Time is reasonable based on the low probability of a soismio event oonourrent with an event that would require operation of tho supported system ooourring while the snubber(s) are not oapablo of performing their assooiatod support funotion.
LCO 3.0.8 requires that risk be assessed and managed .. Industry and ~RC guidanoe on the implementation of 10 CPR 50.65(a)(4)
(the Maintenanoe Rule) does not address seismio risk. Hmve1Jer, use of LCO 3.0.8 should be oonsidered v1ith respeot to other plant maintenanse asti1Jities, and integrated into the existing Maintenanse Rule prosess to the extent possible so that maintenanse on any unaffeoted train or subsystem is properly sontrolled, and emergent issues are properly addressed. The risk assessment need not be quantified, but may be a qualitati1Je a1Nareness of the 1Julnerability of systems and oornponents '!.'hen one or more snubbers are not able to perform their assooiated support funotion.
LCO 3.0.9 (oontinued)
LCO 3.0.9 establishes conditions under which systems described in the Technical Specifications are considered to remain OPERABLE when required barriers are not capable of providing t
their related support function(s).
(continued) 183 DAEC                          B 3.0-13A                                       TSCR~

LCO Applicability B 3.0 BASES LCO 3.0.9          Barriers are doors, walls, floor plugs, curbs, hatches, installed structures (continued)      or components, or other devices, not explicitly described in Technical Specifications, that support the performance of the safety function of systems described in the Technical Specifications. This LCO states that the supported system is not considered to be inoperable solely due to required barriers not capable of performing their related support function(s) under the described conditions. LCO 3.0.9 allows 30 days before declaring the supported system(s) inoperable and the LCO(s) associated with the supported system(s) not met. A maximum time is placed on each use of this allowance to ensure that as required barriers are found or are otherwise made unavailable, they are restored.
However, the allowable duration may be less than the specified maximum time based on the risk assessment.
If the allowed time expires and the barriers are unable to perform their related support fLinction(s), the supported system's LCO(s) must be declared not met and the Conditions and Required Actions entered in accordance with LCO 3.0.2.
This provision does not apply to barriers which support ventilation systems or to fire barriers. The Technical Specifications for ventilation systems provide specific Conditions for inoperable barriers. Fire barriers are addressed by other regulatory requirements and associated
!facility            ~ 'f3'laR-l: programs. This provision does not apply to barriers which are not
......__..___ _ _ __. required to support system OPERABILITY (see NRC Regulatory Issue Summary 2001-09, "Control of Hazard Barriers," dated April 2, 2001).
The provisions of LCO 3.0.9 are justified because of the low risk
                      . associated with required barriers not being capable of performing their related support function. This provision is based on consideration of the following initiating event categories:
* Loss of eoolant aeeidents;
* l=ligh energy line breaks;
* Feedwater line breaks;
* Internal flooding;
* External flooding;
* Turbine rnissile e1ostion; and
* Tornado or high wind.
(continued)
DAEC                                 B 3.0-138                                      TSCR-~
                                                                      ,__!18_3_ _ ____,~

LCO Applicability B 3.0 BASES Leo 3.0.9      The risk impact of the barriers which cannot perform their related (continued)    support function(s) must be addressed pursuant to the risk assessment and management provision of the Maintenance Rule, 10 CFR 50.65 (a)(4), and the associated implementation guidance, Regulatory Guide 1.160, "Monitoring the Effectiveness of Maintenance at Nuclear Power Plants." Regulatory Guide 1.160 endorses Revision 4A of NUMARC 93-01 dated April 2011, "Industry Guideline for Monitoring the Effectiveness t
of Maintenance at Nuclear Power Plants." This guidance provides for the consideration of dynamic plant configuration issues, emergent conditions, and other aspects pertinent to plant operation with the barriers unable to perform their related support function(s). These considerations may result in risk management and other compensatory actions being required during the period that barriers are unable to perform their related support function(s).
LCO 3.0.9 may be applied to one or more trains or subsystems of a system supported by barriers that cannot provide their related support function(s), provided that risk is assessed and managed (inoluding oonsideration of tt:ie effeots on Large Early Release and froFR mc4ernal events). If applied concurrently to more than one trairl or subsystem of a multiple train or subsystem supported system, the barriers supporting each of these trains or subsystems must provide their related support function(s) for different categories of initiating events. For example,,
LCO 3.0.9 may be applied for up to 30 days for more than one train of a multiple train supported system if the affected barrier for one train protects against internal flooding and the affected barrier for the other train protects against tornado missiles. In this example, the affected barrier may be the same physical barrier but serve different protection functions for each train.
Tt:ie FIPCI (Fligt:i Pressure Coolant lnjeotion) and RCIC (Roaster Core Isolation Cooling) systeFRs are single train systeFRs for injeoting FRakeup water into tt:ie roaster during an aooident or transient event Tt:ie RCIC systeFR is not a safety systeFR, nor required to operate during a transient, tt:ierefore, it does not t:iave to FReet tt:ie single failure oriterion. Tt:ie FIPCI systeFR wovides eaokup in ease of a RCIC systeR'l failure. Tt:ie ADS (AutoFRatio Depressurization SysteFR) and lm.v pressure EGGS ooolant injeotion pro11ide tt:ie sore oooling funotion in tt:ie event of failure of tt:ie HPCI systeFR during an aooident Tt:ius, for tt:ie purposes of LCO a.O.Q, tt:ie FIPGI systeFR, tt:ie RCIC systeFR, and tt:ie ADS are oonsidered independent suesysteFRs of a single systeFR and LCO a.0.9 oan ee used on tt:iese single train systeFRs in a FRanner siFRilar to FRultiple train or
* suesysteFR systeFRs.
(continued)
                                                                          !183 DAEC                            B 3.0-13C
                                                                                       ~
TSCR~

LCO Applicability B 3.0 BASES LCO 3.0.9   If during the time that LCO 3.0.9 is being used, the required OPERABLE (continued) train or subsystem becomes inoperable, it must be restored to OPERABLE status within 24 hours. Otherwise, the train(s) or subsystem(s) supported by barriers that cannot perform their related support function(s) must be declared inoperable and the associated LCOs declared not met. This 24 hour period provides tiRle to respond to eR1ergent oonditions that would othervvise likely lead to entry into LCO a.a.a and a rapid plant shutdown, whioh is not justified given the low probability of an initiating event whioh would require the barrier(s) not oapable of perforRling their related support funotion(s). During this 24 hour period, the plant risk associated with the existing conditions is assessed and managed in accordance with 10 CFR 50.65(a)(4).
                                                                     !183 DAEC                         B 3.0-13D                                      TSC'-;.--rn

SR Applicability B 3.0 B 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY BASES SRs              SR 3.0.1 through SR 3.0.4 establish the general requirements applicable to all Specifications in Sections 3.1 through 3.10 and apply at all times, unless otherwise stated.
SR 3.0.1         SR 3.0.1 establishes the requirement that SRs must be met during the MODEg or otl:ier specified conditions in the Applicability for which the requirements of the LCO apply, unless otherwise specified in the individual SRs. This Specification is to ensure that Surveillances are performed to verify the OPERABILITY of systems and components, and that variables are within specified limits.
Failure to meet a Surveillance within the specified Frequency, in accordance with SR 3.0.2, constitutes a failure to meet an LCO.
Surveillance may be performed by means of any series of sequential, overlapping, or total steps provided the entire Surveillance is performed within the specified Frequency.
Additionally, the definitions related to instrument testing (e.g.,
CHANNEL CALIBRATION) specify that these tests are performed by means of any series of sequential, overlapping, or total steps.
Systems and components are assumed to be OPERABLE when the associated SRs have been met. Nothing in this Specification, however, is to be construed as implying that systems or components are OPERABLE when:
: a. The systems or components are known to be inoperable, although still meeting the SRs; or
: b. The requirements of the Surveillance(s) are known to be not met between required Surveillance performanc~
Surveillances do not have to be performed when the HM~ i n ~
MODE or otl:ier specified .condition for which the requirements of the associated LCO are not applicable, unless otherwise specified. Tl:ie SRs assooiated witl:i a Speoial Operations LCO are only applioable wl:ien tl:ie Speoial Operations LCO is used as an allowable mcoe13tion to the reeiuirernents of a S13eoifioation.
Surveillances, including Surveillances invoked by Required Actions, do not have to be performed on inoperable equipment because the ACTIONS define the remedial measures that apply.
Surveillances have to be met and performed in accordance with SR 3.0.2, prior to returning equipment to OPERABLE status.
(continued)
DAEC                             B 3.0-14                                    TSCR~
r--!18--3----~

SR Applicability B 3.0 BASES SR 3.0.1      Upon completion of maintenance, appropriate post maintenance (continued) testing is required to declare equipment OPERABLE. This includes ensuring applicable Surveillances are not failed and their most recent performance is in accordance with SR 3.0.2. Post maintenance testing may not be possible in the current MODe or etRef specified conditions in the Applicability due to the necessary facility
* parameters not having been established. In these situations, the equipment may be considered OPERABLE provided testing has been satisfactorily completed to the extent possible and the equipment is not otherwise believed to be incapable of performing its function. This will allow operation to proceed to a MODe or etRef-specified condition where other necessary post maintenance tests can be completed.
Some examples of this prooess are:
Control Rod Drive maintenanoe during refueling that requires soram testing at > 800 psi. l=lowever, if other appropriate testing is satisfaotorily oompleted, the oontrol rod ean be oonsidered OPeRABLE This allmus startup to proeeed to reaeh 800 psi to perform other neeessary testing.
l=ligh pressure ooolant injeotion (l=IPCI) maintenanee during shutdm.vn that requires system funetional tests at a speeified pressure. Provided other appropriate testing is satisfaetorily eompleted, startup ean proeeed with l=IPGI oonsidered OPeRABLe. This allows operation to reaoh the speoified pressure to oomplete the neoessary post maintenanoe testing.
SR 3.0.2      SR 3.0.2 establishes the requirements for meeting the specified Frequency for Surveillances and any Required Action with a Completion Time that requires the periodic performance of the Required Action on a "once per ... " interval.
SR 3.0.2 permits a 25% extension of the interval specified in the Frequency. This extension facilitates Surveillance scheduling and conside~ plant operating conditions that may not be suitable for
  !facility      conducting the Surveillance (e.g., transient conditions or other ongoing Surveillance or maintenance activities).
                                                                    !183
(~tinued)
                                                                                ~
DAEC                            B 3.0-15                                  TSCR~

SR Applicability B 3.0 BASES SR 3.0.2      The 25% extension does not significantly degrade the reliability (continued) that results from performing the Surveillance at its specified Frequency. This is based on the recognition that the most probable result of any particular Surveillance being performed is the verification of conformance with the SRs. The exceptions to SR 3.0.2 are those Surveillances for which the 25% extension of the interval specified in the Frequency does not apply. These exceptions are stated in the individual Specifications. The requirements of regulations take precedence over the TS.
Therefore, when a test interval is specified in the regulations, the test interval cannot be extended by TS, and the SR includes a Note in the Frequency stating, "SR 3.0.2 is not applicable."
As stated in SR 3.0.2, the 25% extension also does not apply to the initial portion of a periodic Completion Time that requires performance on a "once per... " basis. The 25% extension applies to each performance after the initial performance. The initial performance of the Required Action, whether it is a particular Surveillance or some other remedial action, is considered a single action with a single Completion Time. One reason for not allowing the 25% extension to this Completion Time is that such an action usually verifies that no loss of function has occurred by checking the status of redundant or diverse components or accomplishes the function of the inoperable equipment in an alternative manner.
The provisions of SR 3.0.2 are not intended to be used repeatedly merely as an operational convenience to extend Surveillance intervals (other than those consistent with refueling intervals) or periodic Completion Time intervals beyond those specified.
SR 3.0.3      SR 3.0.3 establishes the flexibility to defer declaring affected equipment inoperable or an affected variable outside the specified limits when a Surveillance has not been completed within the specified Frequency. A delay period of up to 24 hours or up to the limit of the specified Frequency, whichever is greater, applies from the point in time that it is discovered that the Surveillance has not been performed in accordance with SR 3.0.2, and not at the time that the specified Frequency was not met.
                                                                  !183 (cdqtinued)
DAEC                            B 3.0-16
                                                                          ' 'Si rscR~

SR Applicability
                                                                                                - B 3.0 BASES SR 3.0.3                     This delay period provides adequate time to complete (continued)                  Surveillances that have been missed. This delay period permits the completion of a Surveillance before complying with Required Actions or other remedial measures that might preclude completion of the Surveillance.                              .-!fa_c_il-ity-------,1 The basis for this delay period includes consideration of-1:1-A#     ~
conditions, adequate planning, availability of personnel, the time required to perform the Surveillance, the safety significance of the delay in completing the required Surveillance, and the recognition that the most probable result of any particular Surveillance being performed is the verification of conformance with the
                           . requirements.
                             'Nf:len a Surveillanse witf:l a FFequensy based not on time intervals, but upon spesified unit sonditions, opemting situations, OF Fequimments of Fegulations (e.g., pFioF to enteFing MODE 1 afteF easf:l fuel loading, OF in assoFdanse witf:l 10 CH~ 50, Appendi* cl, as modified by apprnved e*emptions, ets.) is dissoveFed to not f:lave been pOFfoFmed v:f:len spesified, SR 3.0.3 allows foF tf:le full delay pOFiod of up to tf:le spesified Froquensy to peFfoFm tf:le Surveillanse. r4oweveF, sinse tf:lern is not a time interval spesified, tf:le missed Surveillanse sf:lould be peFfOFmed at tf:le fiFst Feasonable opportunity. SR 3.0.3 prnvides a time limit foF, and allowanses foF tf:le peFfoFmanse of, Surveillanses tf:lat besome applisable as a sonsequense of IVIODE sf:langes imposed by Requirod Astions.
Failure to comply with specified Frequencies for SRs is expected to be an infrequent occurrence. Use of the delay period established by SR 3.0.3 is a flexibility which is not intended to be used as an operational convenience to extend Surveillance intervals. While up to 24 hours or the limit of the specified Frequency is provided to perform the missed Surveillance, it is expected that the missed Surveillance will be performed at the first reasonable opportunity. The determination of the first reasonable opportunity should include consideration of the impact I                          1 ~ f:H8'fH risk (from delaying the Surveillance as well as any f:H8'fH
             . . ._ _ _ _ _1C6nfiguraton changes required or sf:lutting tf:le plant down to
~fa_c_i_lit. Y perform the Surveillance) and impact on any analysis assumptions, in addition t'f'-1:1-A# conditions, planning, availability of ltacility            I
                                                                                        !183 (conti~ued)
                                                                                                   ~
DAEC                                           B 3.0-17                                      TSCR~

SR Applicability B 3.0 BASES SR 3.0.3              personnel, and the time required to perform the Surveillance. This (continued)           risk impact should be managed through the program in place to implement 10 CFR 50.65(a)(4) and its implementation guidance, NRC Regulatory Guide 1.160, "Monitoring the .Effectiveness of Maintenance at Nuclear Power Plants." This Regulatory Guide addresses consideration of temporary and aggregate risk impacts, determination of risk management action thresholds, and risk management action up to and including plant shutdown. The missed Surveillance should be treated as an emergent condition as discussed in the Regulatory Guide. The risk evaluation may use quantitative, qualitative, or blended methods. The degree of depth and rigor of the evaluation should be comhlensurate with the importance of the component Missed Surveillances for important components should be analyzed quantitatively. If the results of the risk evaluation determine the risk increase is significant, this evaluation should be used to determine the safest course or'action. All missed Surveillances will be placed in the Corrective Action Program.
If a Surveillance is not completed within the allowed delay period, then the equipment is considered inoperable or the variable is considered outside the specified limits and the Completion Times of the Required Actions for the applicable LCO Conditions begin immediately upon expiration of the delay period. If a Surveillance is failed within the delay period, then the equipment is inoperable, or the variable is outside the specified limits and the Completion Times of the Required Actions for the applicable LCO Conditions begin immediately upon the failure of the Surveillance.
Completion of the Surveillance within the delay period allowed by this Specification, or within the Completion Time of the ACTfONS, restores compliance with SR 3.0.1.
I SR 3.0.4
* SR 3.0.4 establishes the requirement that all applicable SRs must be met before entry into a MODE or other specified condition in the Applicability.
This Specification ensures that system and component OPERABILITY requirements and variable limits are met before entry into MODES or other specified conditions in the Applicability for which these systems and components ensure s            operation oft~~-
L                                  maintenance
            !facility l183 (cont~ued)
DAEC                                   B 3.0-18

SR Applicability B 3.0 BASES SR 3.0.4    The provisions of this Specification should not be interpreted as (continued) endorsing the failure to exercise the good practice of restoring systems or components to OPERABLE status before entering an associated MODE or other specified condition in the Applicability.
A provision is included to allow entry into a MODE or other specified condition in the Applicability when an LCO is not met due to Surveillance not being met in accordance with LCO 3.0.4.
However, in certain circumstances, failing to meet an SR will not result in SR 3.0.4 restricting a MODE shange or other specified condition change. When a system, subsystem, division, component, device, or variable is inoperable or outside its specified limits, the associated SR(s) are not required to be performed per SR 3.0.1, which states that Surveillances do not have to be performed on inoperable equipment. When equipment is inoperable, SR 3.0.4 does not apply to the associated SR(s) since the requirement for the SR(s) to be performed is removed.
Therefore, failing to perform the Surveillance(s) within the specified Frequency does not result in an SR 3.0.4 restriction to changing MODES or other specified conditions of the Applicability.
However, since the LCO is not met in this instance, LCO 3.0.4 will govern any restrictions that may (or may not) apply to MODE or ether-specified condition changes. SR d.0.4 does not restrist shanging MODES or other spesified sonditions of the Applisability when a Surveillanoe has not been performed within the speoified Frequenoy, provided the requirement to deolare the LGO not met has been delayed in aooordanoe with SR d.0.d The provisions of SR 3.0.4 shall not prevent changes in MODES or other specified conditions in the Applicability that are required to comply with ACTIONS. In addition, the provisions of SR d.0.4 shall not prevent ohanges in MODES or other speoified oonditions in the Applioability that result from any unit shutdov.m. In this oontmct, a unit shutdown is defined as a ohange in MODE or other speoified oondition in the Applisability assooiated with transitioning from MODE 1 to MODE 2 or MODE d, MODE 2 to MODE d, and MODE d to MODE 4.                                                       J
                                                                 !183 (con~ued)
                                                                              ~
DAEC                        B 3.0-19                                    TSCR~

SR Applicability B 3.0 BASES SR 3.0.4    The precise requirements for performance of SRs are specified (continued) such that exceptions to SR 3.0.4 are not necessary. The specific time frames and conditions necessary for meeting the SRs are specified in the Frequency, in the Surveillance, or both. This allows performance of Surveillances when the prerequisite condition(s) specified in a Surveillance procedure require entry into the MODe or other specified condition in the Applicability of the associated LCO prior to the performance or completion of a Surveillance. A Surveillance that could not be performed until after entering the LCO's Applicability would have its Frequency specified such that it is not "due" until the specific conditions needed are met. Alternately, the Surveillance may be stated in the form of a Note, as not required (to be met or performed) until a particular event, condition, or time has been reached. Further discussion of the specific formats of SRs' annotation is found in Section 1.4, Frequency.
                                                                     !183 DAEC                        B 3.0-20                                     TSCR~

SFU System Instrumentation B 3.3.7.1 B 3.3 INSTRUMENTATION B 3.3. 7.1 Standby Filter Unit (SFU) System Instrumentation personnel                    facility BASES BACKGROUND            The SFU System is esigned to provide a ra
* logically controlled environment to ensu the habitability oft control room for the safety of control room operatoFS under all         conditions. Two independent SFU subsystems are each capable of fulfilling the stated safety function. The instrumentation and controls for the SFU System automatically initiate action to pressurize the control building envelope to minimize the consequences of radioactive material in the control building envelope.
In the event of a Control Building Intake Area Radiation - High signal, the SFU System is automatically started. The outside air is then passed through the charcoal filter and mixed with recirculated air to maintain the control building envelope slightly pressurized with respect to the atmosphere.
The SFU System instrumentation has two trip systems, with each trip system dedicated to its corresponding SFU. Each trip system receives input from the Control Building Intake Area Radiation -
High Function, and is arranged in a one-out-of-one logic. The channels include electronic equipment (e.g., radiation monitors) that compare measured input signals with pre-established setpoints. When the setpoint is exceeded, the channel output relay actuates, which then outputs a SFU System initiation signal and a Control Building Ventilation System isolation signal to the initiation logic. the Fuel Handling Accident APPLICABLE            The ability of the SFU System to maintain the ha *tability of the SAFETY                control building envelope is explicitly assumed fo sertaiR ANALYSES,             aooieleRts as discussed in the UFSAR safety analyses (Refs. 1          y LCO, and              and 2). SFU System operation ensures that the radiation               -,
APPLICABILITY         exposure of control room personnel, through the duration of aRy oRe of the postulated accidents, does not exceed the limits of 10 CFR 50.67.
SFU System instrumentation satisfies Criterion 3 of 10 CFR 50.36(c)(2)(ii).
                                                                          !183 (col;nued)
                                                                                     $i DAEC                                   B 3.3-209                                TSCR 044A

SFU System Instrumentation B 3.3.7.1 BASES APPLICABLE           The OPERABILITY of the SFU System instrumentation is SAFETY               dependent upon the OPERABILITY of the Control Building Intake ANALYSES,            Area Radiation - High channel Function. Each SFU must have LCO, and             one OPERABLE channel, with the radiation monitor setpoint APPLICABILITY        within the specified Allowable Value. A channel is inoperable if its (continued)        actual trip setpoint is not within its required Allowable Value. The actual setpoint is calibrated consistent with applicable setpoint methodology assumptions.                              previously applicable This Allowable Value (AV) is derived from th Analytical Limit (AL) used in the radiological dose analyses of the tlesign basis LOGA Loss of Coolant            (Ref. 1) and ensures that doses to control room personnel remain          f within the limits of 10 CFR 50.6       Operation with a trip setpoint Accident (LOCA).
less conservative th          nominal trip setpoint, but within its Allowabl          , is acceptable. Trip setpoints are those Although the LOCA               etermined values of output at which an action should take is no longer              place. The setpoints are compared to the actual process applicable to the         parameter (e.g., control building intake area radiation level), and when the measured output value of the process parameter permanently shut exceeds the setpoint, the associated device (e.g., radiation down and defueled         monitor output) changes state.
DAEC, the analysis remains valid and         The Applicable Safety Analyses, LCO, and Applicability bounding.                 discussion for the Control Building Intake Area Radiation - High Function follows.
Control Building Intake Area Radiation -       High The control building intake area radiation monitors measure radiation levels exterior to the intake ducting of the control B1:1ilding. A high radiation level may pose a threat to control room
 !building           l----71personnel; thus, this function automatically initiates the SFU
 .....__--=-_ _ _____. System and places the Control Building Ventilation System in the isolation mode.
The Control Building Intake Area Radiation - High Function consists of two independent monitors. Two channels of Control Building Intake Area Radiation - High are available and are required to be OPERABLE to ensure that no single instrument failure can preclude SFU System initiation. The Allowable Value was selected to ensure protection of the control room personnel.
                                                                              !183 (cfuntinued)
                                                                                            ~
DAEC                                 B 3.3-210                                   TSCR 044A

SFU System Instrumentation B 3.3.7.1 BASES APPLICABLE      Control Building Intake Area Radiation -       High (continued)
SAFETY ANALYSES,       The Control Building Intake Area Radiation - High Function is LCO, and        required to be OPERABLE in MOQEg 1, 2, and d and during APPLICABILITY   GORE ALTERATIQNg and movement of irradiated fuel                         {-
assemblies in the secondary containment, to ensure that control room personnel are protected during a LOGA, fuel handling event, or vessel draindown event. D1:1ring MOQEg 4 and 5, 1Nhen these s,aesified sonditions are not in ,arogress (e.g., GORE ALTERATIO~Jg), the ,arobability of a LOGA or fuel damage is lm*J; thus, the i;unstion is not required.
ACTIONS         A Note has been provided to modify the ACTIONS related to SFU System instrumentation channels. Section 1.3, Completion Times, specifies that 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.
Section 1.3 also specifies that Required Actions of the Condition continue to apply for each additional failure, with Completion Times based on iniUal entry into the Condition. However, the Required Actions for inoperable SFU System instrumentation channels provide appropriate compensatory measures for separate inoperable channels. As such, a Note has been
* provided that allows separate Condition entry for each inoperable SFU System instrumentation channel.
A.1, and A.2 With a Control Building Intake Area Radiation-High Channel inoperable, the initiation capability of the associated SFU subsystem is lost. Therefore, the associated SFU subsystem(s) must be declared inoperable within 1 hour per Required Action A.1, or must be placed in the isolation mode of operation, (i.e., the SFU in operation and the Control Building Ventilation System isolated, within 1 hour per Required Action A.2. Placing the subsystem in the isolation mode ensures that control room personnel will be protected in the event of a Design Basis Fuel Handling       Assident. The method used to place the SFU subsystem(s) in Accident (FHA)      operation must provide for automatically re-initiating th~
subsystem(s) upon restoration of power following a loss of power to the SFU subsystem(s).                                             *
                                                               !TSCR-183
                                                                           \     (continued)
DAEC                            B 3.3-211                                Amendment d05

si=u System    Instrumentation B 3.3.7.1 BASES ACTIONS      A.1, and A.2 (continued)
The 1 hour Completion Time is intended to allow the operator time to place the SFU subsystem(s) in the isolation mode of operation, and is acceptable because it minimizes risk while allowing time for restoration of channels, or for placing the associated SFU in its safety mode, or for entering the applicable Conditions and Required Actions for the inoperable SFU subsystem(s).
SURVEILLANCE The Surveillances are modified by a Note to indicate that when a ,
REQUIREMENTS 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 hours, provided the other channel is OPERABLE. Upon completion of the Surveillance, or expiration of the 6 hour allowance, the channel must be returned to OPERABLE status or the applicable Condition entered and Required Actions taken. This Note is based on the reliability analysis (Refs. 4 and 5) assur:nption of the average time required to perform channel surveillance. That analysis demonstrated that the 6 hour testing allowance does not significantly reduce the probability that the SFU System will initiate when necessary.
SR 3.3.7.1.1 Performance of the CHANNEL CHECK ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK f
is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the instrument channels could be an indication of excessive instrument drift in one of the channels or something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
(continued)
                                                        !183                  ~
                                                        ,___~~~-TS-CR~
DAEC                         B 3.3-212

SFU System Instrumentation B 3.3.7.1 BASES SURVEILLANCE SR 3.3.T 1.1 (continued)
REQUIREMENTS Agreement criteria are determined by the plant staff, based on a combination of the channel instrument uncertainties, including indication arid readability. If a channel is outside the criteria, it may be an indication that the instrument has drifted outside its limit.
The Surveillance Frequency is controlled under the Surveillance              J, Frequency Control Program. The Frequency is based upon                      'I operating experience that demonstrates channel failure is rare.
The CHANNEL CHECK supplements less formal, but more frequent, checks of channel status during normal operatioRal use of the displays associated with channels required by the LCO.
SR 3.3.7.1.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least oRoe per refueliRg iRterval v1ith applioable exteRsioRs.
The Surveillance Frequency is controlled under the Surveillance           ~
Frequency Control Program. The Frequency is based on the                 1 reliability analyses of References 4 and 5.
SR 3.3.7.1.3 A CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive calibrations consistent with the plant specific setpoint methodology.
The Surveillance Frequency is controlled under the Surveillance           J.,
Frequency Control Program. The Frequency is based upon the               'I equipment drift in the setpoint analysis.
                                                                !183 (c6Q..tinued)
DAEC                         B 3.3-213                                    TSC~

SFU System Instrumentation B 3.3.7.1 BASES SURVEILLANCE  SR 3.3.7.1.4 REQUIREMENTS (continued) The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required initiation logic for a specific channel. The system functional testing performed in LCO 3. 7.4, "Standby Filter Unit (SFU) System," overlaps this Surveillance to provide complete testing of the assumed safety function.
The Surveillance Frequency is controlled under the Surveillance       J...
Frequency Control Program. The Frequency is based on                  -I operating experience that has shown these components usually pass the Surveillance when performed at this Frequency.                t REFERENCES    1. UFSAR, Section 15.2.
: 2. UFSAR, Section 6.4.4.
: 3.     [Deleted]
: 4. GENE-770-06-1, "Bases for Changes to Surveillance Test Intervals and Allowed Out-of-Service Times for Selected Instrumentation Technical Specifications," February 1991.
: 5. NEDC-31677P-A, "Technical Specification Improvement Analysis for BWR Isolation Actuation Instrumentation,"
July 1990.
                                                                !183 DAEC                         B 3.3-214 C:
TSCR-~

LOP Instrumentation B 3.3.8.1 B 3.3 INSTRUMENTATION B 3.3.8.1 Loss of Power (LOP) Instrumentation BASES BACKGROUND          Successful operation of the required safety functions ef.tAe Emergeney Gore Cooling Systems (EGGS) is dependent upon the availability of adequate power sources for energizing the various components such as pump motors, motor operated valves, and the associated control components. The LOP instrumentation monitors the 4.16 kv emergency bus voltages and the Startup and Standby Transformer secondary winding voltages. Offsite power is the preferred source of power for the 4.16 Kv emergency buses.
If the monitors determine that insufficient power is available, the buses are disconnected from the offsite power sources and connected to the onsite Diesel Generator (DG) power sources.
The monitors also provide start permissive signals ror the low press1:1re EGGS p1:1mps and inp1:1ts to vario1:1s load shedding sire1:1its.
Each 4.16 kV emergency bus has its own independent LOP instrumentation and associated trip logic. Each bus is monitored at two different voltage levels, which can be considered as two different undervoltage Functions: 4.16 kV Emergency Bus Loss of Voltage and 4.16 kV Emergency Bus Degraded Voltage. A third LOP Function monitors the voltages of the secondary windings of both the Startup and Standby Transformers (4.16 kV Emergency Transformer Supply Undervoltage). Each of these Functions provide inputs to various required actions such as: bus transfers, load sheds, or DG starts. Each emergency bus is monitored for the Loss of Voltage Function by a single undervoltage relay. Each bus is monitored for the Degraded Voltage Function by four relays whose contacts form a coincidence logic matrix such that either of the A 1 or A2 contacts and either of the B 1 or B2 contacts must close to initiate the required actions in the associated division (i.e.,
one-out-of-two taken twice). For the Emergency Transformer Supply Undervoltage Function, the secondary winding of the                 t t
Standby Transformer is monitored by two channels. One channel 1 provides an input to initiate the required actions in one division, while the other channel provides input to initiate the required actions in the other division. Each channel of the Emergency Transformer Supply Undervoltage Function includes two relays.
Both of the secondary windings of the Startup Transformer (i.e., a separate secondary winding is associated with each division) are (continued)
DAEC                                B 3.3-215                  .--~~~~T~S=...CR-GG&sect;
                                                               ...._!18_3_ _ _____.~

LOP Instrumentation B 3.3.8.1
*BASES BACKGROUND     monitored by a single relay for this Function; the relay that (continued)  monitors the winding associated with each division provides an input to initiate the required actions in that division. The initiation logic for each division receives inputs from both the Startup and Standby Transformers secondary windings (i.e., two-out-of two relay logic). The various channels include monitoring equipment (i.e., current transformers or voltage transformers) and relays that compare measured input signals with pre-established setpoints.
When the setpoint is exceeded, the channel output relay actuates, which then outputs a LOP signal to its associated trip logic.
APPLICABLE    The LOP instrumentation is required for eRgiReered Safety SAFETY         Features (eSF) to function in any accident with a loss of offsite ANALYSES,      power. The required channels of LOP instrumentation ensure that LCO, and      the eGGS aRd other assumed systems powered from the DGs, APPLICABILITY provide plant protection in the event of any of the Reference 1, ~
               ~ analyzed accidents in which a loss of offsite power is assumed. The LOP instrumentation also serves to provide protection for the eSF from damage that could occur due to prolonged degraded voltage conditions on the grid. The iRitiatioR of the DGs OR a LOP or LOG/\ sigRal, aRd ooRourreRt iRitiatioR of the eGGS OR a LOG/\ sigRal eRsure that the fuel peak oladdiRg temperature remaiRs belm.v the limits of 10 GFR 50.46.
DisGORReotiRg the emergeRGY buses from the offsite souroes aRd startiRg the DGs *.vheR a proloRged degraded voltage ooRditioR exists eRsures that the eSF (e.g., large pump motors) are Rot damaged due to startiRg with iRsuffieieRt voltage preseRt.
Accident analyses credit the loading of the DG based on the loss of offsite power duriRg a LOG/\. The diesel starting and loading times have been included in the delay time associated with each safety system component requiring DG supplied power following a loss of offsite power.
The LOP instrumentation satisfies Criterion 3 of 10 CFR 50.36(c)(2)(ii).
The OPERABILITY of the LOP instrumentation is dependent upon the OPERABILITY of the individual instrumentation channel Functions specified in Table 3.3.8.1-1. Each Function mt,1st have a required number of OPERABLE channels per 4.16 kV emergency bus, with their setpoints within the specified Allowable Values. The actual setpoint is calibrated consistent with applicable setpoint methodology assumptions.
(continued)
DAEC                             B 3.3-216                                  TSCR-OOa r--!18-3---~~

LOP Instrumentation B 3.3.8.1 BASES APPLICABLE    The Allowable Values are specified for each Function in the- Table.
SAFETY        Nominal trip setpoints are specified in the setpoint cal_culations.
ANALYSES,     The nominal setpoints are selected to ensure that the setpoints do LCO, and      not exceed the Allowable Value between CHANNEL APPLICABILITY CALIBRATIONS. Operation with a trip setpoint less conservative (continued) than the nominal trip setpoint, but within the Allowable Value, is acceptable. A channel is inoperable if its actual trip setpoint is not within its required Allowable Value. Trip setpoints are those predetermined values of output at which an action should take place. The setpoints are compared to the actual process parameter (e.g., degraded voltage), and when the measured output value of the process parameter exceeds the setpoint, the associated device (e.g., relay) changes state. Analytical Limits are the limiting values of the process parameters for use in safety analysis. Margin is provided between the Allowable Value and the Analytical Limits to allow for process, calibration (i.e., M&TE) and some instrument uncertainties. Additional margin is provided between the Allowable Value and the trip setpoint to allow for the remaining instrument uncertainties (e.g., drift). The trip setpoints derived in this manner provide adequate protection because instrumentation uncertainties, process effects, calibration tolerances, instrument drift, and severe environment errors (for channels that must function in harsh environments as defined by 10 CFR 50.49) are accounted for.
The specific Applicable Safety Analyses, Leo, and Applicability discussions are listed below on a Function by Function basis.
: 1. 4.16 kV Emergency Bus Undervoltage (Loss of Voltage)
Loss of voltage on *a 4.16 kV emergency bus indicates that offsite power has been completely lost to the respective emergency bus and is unable to supply sufficient power for proper operation of the applicable equipment. Therefore, the power supply to the bus is transferred from offsite power to DG power and the various loads connected to the emergency bus are load shed when the voltage on the bus drops below the Loss of Voltage Function Allowable Values. This ensures that adequate power will be available to the required equipment.
(continued)
DAEC                         B 3.3-217 TSCR-183

LOP Instrumentation B 3.3.8.1 BASES APPLICABLE    1. 4.16 kV Emergency Bus Undervoltage (Loss of Voltage)
SAFETY        (continued)
: ANALYSES, LCO, and      The Bus Undervoltage Allowable Values are low enough to APPLICABILITY prevent power supply transfer and load shedding unless offsite power has truly been lost, but high enough to ensure that power is available to the required equipment.
One channel of 4.16 kV Emergency Bus Undervoltage (Loss of Voltage) Function per associated emergency bus is only required to be OPERABLE iR MODES 1, 2, d, aRd when the associated DG is required to be OPERABLE by LCO 3.8.2, to ensure that no single instrument failure can preclude the DG function. (One channel provides input to the initiation logic for its respective division.) Refer to LCO d.8.1, "AG S01:1rses OperatiRg," aRd 3.8.2, "AC Sources ShutdowR," for Applicability Bases for the DGs.
: 2. 4.16 kV Emergency Bus Undervoltage (Degraded Voltage)
A reduced voltage condition on a 4.16 kV emergency bus indicates that, while offsite power may not be completely lost to the respective emergency bus, available power may be insufficient for starting large EGGS motors without risking damage to the motors that sould disable the EGGS fuRstioR. Therefore, power supply to the bus is transferred from offsite power to onsite DG power when the voltage on the bus drops below the Degraded Voltage Function Allowable Values (degraded voltage with a time delay). This ensures that adequate power will be available to the required equipment.
The Bus Undervoltage Allowable Values are low enough to prevent inadvertent power supply transfer, but high enough to ensure that sufficient power is available to the required equipment. The Time Delay Allowable Values are long enough to provide time for the offsite power supply to recover to normal voltages, but short enough to ensure that sufficient power is available to the required equipment.
(continued)
DAEC                          B 3.3-218 .__ _ _ _ _ ___.* -11 AmeRdmeRt 22d
                                           !TSCR-183           !-'
* LOP Instrumentation B 3.3.8.1 BASES APPLICABLE    2. 4.16 kV Emergency Bus Undervoltage (Degraded Voltage)
SAFETY        (continued)
: ANALYSES, LCO, and      Four channels of 4.16 kv Emergency Bus Undervoltage APPLICABILITY (Degraded Voltage) Function per associated bus are only required to be OPERABLE in MODES 1, 2, and 3, and when the associated DG is required to be OPERABLE by LCO 3.8.2, to ensure that no single instrument failure can preclude the DG function. Refer to LCO 3.8.1 and LGO 3.8.2 for Applicability Bases for the DGs.
: 3. 4.16 kV Emergency Transformer Supply Undervoltage An undervoltage condition on either the Startup Transformer secondary winding or the Standby Transformer secondary winding indicates that offsite power may be lost and is unable to supply sufficient power for proper operation of the applicable equipment.
This Function is similar to Function 1, except whereas Function 1 monitors each emergency bus voltage, Function 3 monitors the voltage of the offsite sources directly via the secondary windings of the two transformers associated with the two offsite sources.
Therefore, when an undervoltage condition exists on an individual transformer, the supply breakers from that transformer to the emergency buses are tripped open. If an undervoltage condition exists on both transformers, then the supply breakers from both transformers to the emergency buses are tripped open and a start signal is sent to the associated DG. This ensures that adequate power will be available to the required equipment.
The Emergency Transformer Supply Undervoltage Allowable Values are low enough to prevent inadvertent power supply transfer, but high enough to ensure that power is available to the required equipment.
(continued)
DAEC                          B 3.3-219                           ~ment' IT_SC_R_-_18_3
                                              .....         _ ___.1---7

LOP Instrumentation B 3.3.8.1 BASES APPLICABLE        3. 4.16 kV Emergency Transformer Supply Undervoltage SAFETY            (continued)
: ANALYSES, LCO, and         Two channels of 4.16 kv Emergency Transformer Supply AP PLI CAB ILITY  Undervoltage Function (one channel from the secondary winding of the Startup Transformer and one channel from the secondary winding of the Standby Transformer) per associated emergency bus are only required to be OPERABLE in MODea 1, 2, and 3, aA4-when the associated DG is required to be OPERABLE by LCO 3.8.2, to ensure that no single failure can preclude the DG function. Refer to LGO 3.8.1 and LCO 3.8.2 for Applicability Bases for the DGs.
ACTIONS          A Note has been provided to modify the ACTIONS related to LOP instrumentation channels. Section 1.3, Completion Times, specifies that 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. Section 1.3 also specifies that Required Actions of the Condition continue to apply for each additional failure, with Completion Times based on initial entry into the Condition. However, the Required Actions for inoperable LOP instrumentation channels provide appropriate compensatory measures for separate inoperable channels. As such, a Note has been provided that allows separate Condition entry for each inoperable LOP instrumentation channel.
With one or more channels of Function 1 or 3 inoperable, the Function is not capable of performing the intended function.
Therefore, only 1 hour is allowed to restore the inoperable channel to OPERABLE status. If the inoperable channel canno-t---.
be restored to OPERABLE status within the allowable out of           and service time, the channel must be placed in the tripped co tlition per Required Action A.1. Placing the inoperable chann in trip would conservatively compensate for the inoperability, estore capability to accommodate a single failure (within the LOP instrumentation), and allow operation to sontinue. Alternately, if it is not desired to place the channel in trip (e.g., as in the case where placing the channel in trip would result in a DG (continued)
DAEC                            B 3.3-220 j...-T-SC-R---18_3_ _ ___,&#xb5; Amendment 223

LOP Instrumentation B 3.3.8.1 BASES ACTIONS A.1 (continued) initiation), Condition C must be entered and its Required Action taken. The Completion Time is intended to allow the operator time to evaluate and repair any discovered inoperabilities. The 1 hour Completion Time is acceptable because it minimizes risk while allowing time for restoration or tripping of channels.
8.1 and 8.2 With certain combinations of multiple Function 2 channels inoperable, the ability of the 4.16 kv Emergency Bus Undervoltage (Degraded Voltage) Function to separate the emergency buses from the offsite sources and to start the DG(s) may be lost.
Required Action 8.1 is intended to ensure that appropriate actions are taken if multiple, inoperable, untripped channels of Function 2 result in automatic initiation capability being lost in one or both divisions. If initiation capability is lost, the associated DG(s) must be declared inoperable within 1 hour from discovery of loss of            t initiation capability for feature(s) in one or both divisions. This      /I requires entry into applicable Conditions and Required Actions of LCO 3.8.1 or LGO 3.8.2, which provide appropriate actions for the inoperable DG(s).
With one Function 2 channel inoperable, or with certain combinations of multiple Function 2 channels inoperable, the ability of the 4.16 kv Emergency Bus Undervoltage (Degraded Voltage) Function to initiate the required actions in either or both divisions is maintained by the remaining OPERABLE channels. In this situation, the requirement to place a channel in trip within 1 hour as in Required Action A.1, or to immediately declare the associated DG inoperable, is overly conservative. The 24 hour Completion Time of Required Action 8.2 is intended to allow the operator time to evaluate and repair any discovered inoperabilities. The 24 hour Completion Time is acceptable because it minimizes risk while allowing time for restoration or tripping of channels.
(continued)
B 3.3-221 DAEC 18_3_ _ _
                                                      ,--!             __,f-?r TSCR-Gee

LOP Instrumentation B 3.3.8.1 BASES ACTIONS      C.1 (continued)
If the Required Action and associated Completion Time is not met, the associated Function is not capable of performing the intended function. Therefore, the associated DG(s) is declared inoperable immediately. This requires entry into applicable Conditions and Required Actions of LCO a.8.1 and LGO 3.8.2, which provide appropriate actions for the inoperable DG(s).
SURVEILLANCE As noted at the beginning of the SRs, the SRs for each LOP REQUIREMENTS instrumentation Function are located in the SRs column of Table 3.3.8.1-1.
The Surveillances are modified by a Note to indicate that 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 2 hours provided the associated Function maintains DG initiation capability. Upon completion of the Surveillance, or expiration of the 2 hour allowance, the channel must be returned to OPERABLE status or the applicable Condition entered and Required Actions taken.
SR 3.3.8.1.1 and SR 3.3.8.1.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least onse per refueling interval with applisable mctensions.
The Surveillance Frequency is controlled under the Surveillance J,..
Frequency Control Program. The Frequencies is based on                  1 operating experience with regard to channel OPERABILITY and drift, which demonstrates that failure of more than one channel of J;,
a given Function in this interval is a rare event.                       'I (continued)
DAEC                        B 3.3-222                                     TSCR-42-0 18-3----v 1

LOP Instrumentation B 3.3.8.1 BASES SURVEILLANCE   SR 3.3.8.1.3 and SR 3.3.8.1.4 REQUIREMENTS (continued)  A CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive calibrations consistent with the plant specific setpoint methodology. Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology.                     . are Frequencies              ~re The Surveillance
* controlled unde he Surveillance Frequency Control Program. The Frequencies -is based upon the magnitude of equipment drift in the setpoint analysis.
t SR 3.3.8.1.5 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required actuation logic for a specific channel. The system functional testing performed in LGO a.8.1 aR1-LCO 3.8.2 overlaps this Surveillance to provide complete testing of the assumed safety functions.
The Surveillance Frequency is controlled under the Surveillance        l--
Frequency Control Program. The Frequency is based on the             'I neea to perform this aurveillance unaer the conditions that apply during a plant outage ana the potential for an unplannea transient if the aurveillance were performed with the reactor at power.
Operating experience has shown these components usually pass the Surveillance when performed at this Frequency.                     1' REFERENCES     1.      UFaAR, aection 6.2.
              ~        UFaAR, aection 6.a.
UFSAR, Chapter 15.
DAEC                           B 3.3-223                                 TSCR-42G
                                                          -118-3---~~

SFU System B 3.7.4 B 3. 7 PLANT SYSTEMS B 3.7.4 Standby Filter Unit (SFU) System facility
                                                                                                  +
BASES BACKGROUND            The SFU System provides             rotected environment from which occupants can control the
* following an uncontrolled release of radioactivity, hazardous chemicals or smoke.
i The safety related function of the SFU System includes two independent and redundant high efficiency air filtration subsystems for emergency treatment of outside supply air and a 1
Control Building Envelope (CSE) boundary that limits the inleakage of unfiltered air. Each SFU subsystem consists of a             * .
demister, an electric heater, a high efficiency particulate air (HEPA) filter, an activated charcoal adsorber section, a second HEPA filter, a fan, and the associated ductwork, valves or f
dampers, doors, barriers, and instrumentation. Demisters remove water droplets from the airstream. HEPA filters remove particulate matter, which may be radioactive. The charcoal adsorbers provide a holdup period for gaseous iodine, allowing time for decay .
. facility ,
The BE is the area within the confines of the CBE boundary that contain t e spaces that control building occupants inhabit to control t tlfl-i.t during normal and accident conditions. This area, encompasses the control building, and may encompass other non-critical areas to which frequent personnel access or continuous occupancy is not necessary in the event of an accident. The CBE is protected during normal operation, natural events, and accident conditions. The CBE boundary is the combination of walls, floor, roof, ducting, doors, penetrations and equipment that physically form the CSE. The OPERABILITY of the CBE boundary must be maintained to ensure that the inleakage of unfiltered air into the CBE will not exceed the inleakage assumed in the licensing basis analysis of design basis accident (OBA) consequences to CBE occupants. The CBE and
* its boundary are defined in the Control Building Envelope Habitability Program.
The SFU System is a standby system, parts of which also operate during normal unit operations to maintain the CSE. Upon receipt of the initiation signal (indicative of conditions that could result in radiation exposure to CBE occupants), the SFU System t
automatically starts and a system of dampers isolates the CBE to minimize infiltration of contaminated air into the CSE. Outside air is taken in at the normal ventilation intake and is passed through (continued)
DAEC                                     B 3.7-18                                    TSCR~
                                                                      ,--!18-3----,&#xb5;

SFU System B 3.7.4 BASES BACKGROUND   one of the charcoal adsorber filter subsystems for removal of (continued) airborne radioactive particles before being mixed with the recirculated air. The air (outside and/or recirculated) is cooled by Air Conditioning (AC) units supplied by the Control Building Chillers (CBCs). The SFUs and AC units share common ductwork such that either SFU may supply outside air to either AC unit.
However, the CBCs and AC units are addressed as part of LCO 3.7.5, "Control Building Chiller System."
The SFU System is designed to maintain a habitable environment in the CBE for a 30 day continuous occupancy after a OBA t
without exceeding 5 rem total effective dose equivalent (TEDE).
A single SFU subsystem operating at a flow rate of 1000 cfm
             +/-10% will pressurize the control room to ~ 0.1 inches water gauge t
pressure above atmospheric pressure, under calm wind conditions (i.e. less than 5 mph wind speed) relative to the Reactor Building and outside atmosphere. A single SFU subsystem operating at a flow rate of 1000 cfm +/-10% will also pressurize the CBE to a positive pressure above atmospheric pressure, under calm wind conditions (i.e. less than 5 mph wind speed) relative to external areas adjacent to the CBE boundary.
This will minimize infiltration of air from all surrounding areas adjacent to the CBE boundary.
Other areas in the CBE that directly communicate with the CBE via HVAC system ductwork or doors are also required to maintain a positive pressure relative to the adjacent areas outside the CBE.
This will assure that leakage is from the CBE to the adjacent areas or outdoors. SFU System operation in maintaining a habitable environment in the CBE is discussed in the UFSAR, Sections 6.4 and 9.4.4, (Refs. 1 and 2, respectively).
APPLICABLE   The ability of the SFU System to maintain the habitability of the       l ..
SAFETY ANALYSES CBE is an explicit assumption for the safety analyses presented in the UFSAR, Sections 6.4 and 15.2 (Refs. 1 and 3, respectively).
The SFU System is assumed to operate in the isolation mode following a OBA. The radiological doses to the CBE occupants as a result of the variolts DBAs afe summarized in Reference 3. No t
1 single active failure will cause ! ~ CBE habitability.
(continued)
DAEC                          B 3.7-19                   .--~~~----'"T~S""""'CR~
                                                         .__!18_3_ _ _    __,&#xb5;

SFU System B 3.7.4 BASES APPLICABLE   There are no offsite or onsite hazardous chemicals that would SAFETY       pose a credible threat to CSE habitability (Ref. 7). Consequently, ANALYSES     engineered controls for the CSE are not required to ensure (continued) habitability against a chemical threat.
The evaluation of a smoke challenge demonstrated that smoke will not result in the inability of the CSE occupants to control the reactor either from the control room or from the remote shutdown system (Ref. 7). The assessment verified that a fire or smoke event anywhere within the plant would not simultaneously render the remote shutdown system and the CSE uninhabitable, nor would it prevent access from the CSE to the remote shutdown system in the event remote shutdown is required. No automatic SFU actuation is required for hazardous chemical releases or smoke and no Surveillance Requirements are required to verify OPERABILITY in cases of hazardous chemicals or smoke ..
The SFU System satisfies Criterion 3 of 10 CFR 50.36(c)(2)(ii).
LCO          Two redundant subsystems of the SFU System are required to be OPERABLE to ensure that at least one is available, if a single
* active failure disables the other subsystem. Total SFU System failure, such as from a loss of both ventilation subsystems or from an inoperable CSE boundary, could result in exceeding a dose of 5 rem TEDE to the CSE occupants in the event of a OBA.
Each SFU subsystem is considered OPERABLE when the individual components necessary to limit CSE occupant exposure
                                                                                     +
are OPERABLE. A subsystem is considered OPERABLE when its associated:
: a.      Fan is OPERABLE;
: b.      HEPA filter and charcoal adsorbers are not excessively restricting flow and are capable of performing their filtration functions; and
: c.      Heater, demister, ductwork, valves, and dampers are OPERABLE, and air circulation can be maintained.
(continued)
DAEC                           B 3.7-20                                  TSCR-482:
                                                       -118-3----~

SFU System B 3.7.4 BASES -
LCO              In o der for the SFU subsystems to be considered OPERABLE, (continued)    the BE boundary must be maintained such that the CBE In addition, the       oc pant dose from a large radioactive release does not exceed necessary portions of  th alculated dose in the licensing basis consequence analyses for BAs. In the event of an inoperable GBE bmmdary in MODES the River Water 1, 2, or a, mitigating astions aro required to ensure GBE Supply system and ossupants are protested from hm!:ardous shemisals and smol"e.
the Ultimate Heat Sink, Emergency          AEC does not have automatic SFU actuation for hazardous Service Water          chemicals or smoke. Current practices at DAEC do not utilize System, and Control    chemicals in sufficient quantity to present a chemical hazard to Building/Standby Gas   the CBE. Smoke is not considered in the DAEC safety analysis.
Treatment Instrument   Therefore, there are no specific limits at DAEC for hazardous Air System are also    chemicals or smoke.
required to provide The LCO is modified by a Note allowing the CBE boundary to be controlling air to the opened intermittently under administrative controls. This Note SFU System.            only applies to openings in the CBE boundary that can be rapidly restored to the design condition, such as doors, hatches, floor plugs, and access panels. For entry and exit through the doors the administrative control of the opening is performed by the person(s) entering or exiting the area. For other openings these controls should be proceduralized and consist of stationing a dedicated individual at the opening who is in continuous communication with the operators in the CBE. This individual will have a method to rapidly close the opening and to restore the CBE boundary to a condition equivalent to the design condition when a need for CBE isolation is indicated.
APPLICABILITY    In MODES 1, 2, and a, the S~U System must be OPERABLE to ensure that the GBE will remain habitable during and following a DM, siRes 1~0 D!!A 00"1~ lea~ 10 a fissi0R ~rn~":1eThe
:::=.t:!:~::=:{;:::,=:.
in these MODES. Therefore, maintaining th;FU System OPERABLEM*H*l~~ree--+R--1&#xa5;1-Y-1::Je--4-e~-*see~~~
during movement of irradiated fuel assemblies in the secondary containment.
(continued)
DAEC                              B 3.7-21          _ _ _ _ _ ___,~endment 305
                                                        !TSCR-183

SFU System B 3.7.4 BASES APPLICABILITY         During GORE ALTERATIONS; and (eontinued)
During movement of irradiated fuel assemblies in the seeondary eontainment.
ACTIONS With one SFU subsystem inoperable, for reasons other than an inoperable CBE boundary, the inoperable SFU subsystem must be restored to OPERABLE status within 7 days. With the unit in this condition, the remaining OPERABLE SFU subsystem is adequate to perform the CBE occupant protection function.
However, the overall reliability is reduced because a failure in the OPERABLE subsystem could result in loss of the SFU System function. The 7 day Completion Time is based on the low probability of a OBA occurring during this time period, and that the remaining subsystem can provide the required capabilities.
B.1, B.2, and B.3 If the unfiltered inleakage of potentially sontaminated air past the GBE boundary and into the GBE san result in GBE oesupant radiologieal dose greater than the ealsulated dose of the lieensing basis analyses of OBA eonsequenees (allowed to be up to 5 rem TEDE), the GBE boundary is inoperable. As diseussed in the Applieable Safety Analyses seetion, the DAEG lieensing basis identifies that CBE inleakage limits for ha:z:ardous ehemieals and smoke are not neeessary to protest the GBE oeeupants. Allm.ving verifieation by administrative means for ha:z:ardous ehemieals and smoke is eonsidered aeseptable, sinee the limit established for radiologieal events is the limiting value for determining entry into Condition B for an inoperable GBE boundary. These administrative eontrols eonsist of the following:
* Verifieation that the periodie shook of onsite and offsite ha:z:ardous ehemieal sourses has been performed v:ithin the last year; and
                   *  \lerifieation that the smol~e analysis of Referense 7 remains valid and surrent.
(continued)
DAEC                            B 3.7-22 TSCR-183

SFU System B 3.7.4 BASES ACTIONS      B.1, B.2, and   Ra   (sontinued)
(continued)
             /\ periodis shesk of onsite and offsite hazardous shemisal sourses tal~os plase onse per year to ensure no onsite or offsite sourses of hazardous shemisals exist that sould present a shemisal hazard to CBE osupants. r>Jo onsite or offsite sourses of hazardous shemisals surrently exist that sould present a shemisal hazard to CBE ossupants.
             /\etions must be taken to restore an OPERABLE CBE boundary within QO days.
During the period that the CBE boundary is eonsidered inoperable, aetion must be initiated to implement mitigating astions to lessen the effest on CBE oseupants from the potential hazards of a radiologisal or shemisal event or a shallenge from smoke. /\stions must be taken within 24 hours to verify that in the event of a DB/\, the mitigating astions ,r.:ill ensure that CBE ossupant radiologisal exposures *.viii not exseed the ealsulated dos-e of the lisensing basis analyses of OBA sonsequenses.
These mitigating astions (i.e., astions that are taken to offset the sonsequenses of the inoperable CBE boundary) should be preplanned for implementation upon entry 'into the sondition, regardless of whether entry is intentional or unintentional.
The 24 hour Completion Time is reasonable based on the low probability of a DB/\ ossurring during this time period, and the use of mitigating astions. The QQ day Completion Time is reasonable based on the determination that the mitigating aetions will ensure proteetion of CBE ossupants within analyzed limits while limiting the probability that CBE ossupants will have to im'plement proteetive measures that may adversely affest their abilit,y to sontrol the roaster and maintain it in a safe shutdovm sondition in the event of a DB/\. In addition, the QO day Completion Time is a reasonable time to diagnose, plan and possibly repair, and test most problems with the CBE boundary.
C.1 and C.2 In MODE 1, 2, or a, if the inoperable SP:U subsystem or the CBE boundary sannot be restored to OPERABLE status *.vithin the required Completion Time, the unit must be plased in a MODE t
that minimizes assident risk. To ashieve this status, the unit must be plased in at least MODE a within 12 t:iours and in MODE 4 within a@ hours. The allowed Completion Times are reasonable, based on operating experiense, to reash the required unit (continued)
DAEC                          B 3.7-23
                                                        -118_3_ _ _TSCR~   _  &#xb5;

SFU System B 3.7.4 BASES ACTIONS           C.1 and C.2 (sontim1ed)
(continued) oonditions fFom full poweF sonditions in an oFdeFly manneF and without shallenging unit systems.
             ~f).1,D.2.1,and~                                                                  f LCO d.0.d is not applisable in MODe 4 oF 5. l=lowevm, sinse iFmdiated fuel assembly move,ment oan oosuF in MODe 1, 2, OF d, the RequiFed Astions of Condition D am modified by a Note indisating that LCO d.0.a does not apply. If mo1Jing iFJadiated fuel assemblies while in MODe 1, 2, OF d, the fuel mo1Jement is independent of mastoF operations. ThemfoFe, inabilit,y to suspend mo1Jement of iFFadiated fuel assemblies is not suffisient mason to mquim a FeastOF shutdov.m.
During movement of irradiated fuel assemblies in the secondary containment OF duFing CORe ALTeRATIO~JS, if the inoperable                    -f SFU subsystem cannot be restored to OPERABLE status within the required Completion Time, the OPERABLE SFU subsystem may be placed in the isolation mode (i.e., one SFU subsystem in operation with the control building isolated). This action ensures that the remaining subsystem is OPERABLE, that no failures that wou.ld prevent automatic actuation will occur, and tl:lat any active failure will be readily detected. An alternative to Hequired Acuo~f).1 is to immediately suspend activities that present a potential for releasing radioactivity that might require isolation of the CSE. This places the
* in a condition that minimizes the accident risk.                           facility If applicable, CORe /\LTeRATIONS and movement of irradiated fuel assemblies in the secondary containment must be suspended immediately. Suspension of these activities shall not preclude completion of movement of a component to a safe position.                      t E1 If both SrU subsystems am inopemble in MODe 1, 2, OF d foF masons otheF than an inopemble CBe boundaf)' (i.e.,
Condition B), the SrU System may not be sapable of peFfoFming the intended funstion and the unit is in a sondition outside of the assident analyses. Thmefom, LCO d.0.d must be enteFed immediately.
(continued)
DAEC                               B 3.7-24        . - - - - - - - - . Amendment d05 IT_SC_R_-_18_3
                                                   .....         _ __ . ~

SFU System B 3.7.4 BASES ACTIONS (continued)
                 .1 and F".2                                                          f LCO a.a.a is not applisable in MODE 4 or 5. l=lowever, sinse irradiated R:Jel assembly movement san ossur in MODE 1, 2, or a, the Required Astions of Condition F" are modified by a Note indisating that LCO a.a.a does not apply. If moving irradiated fuel assemblies vvhile in MODE 1, 2, or a, the fuel movement is independent of roaster operations. Therefore, inability to suspend movement of irradiated fuel assemblies is not suffisient reason to require a roaster shutdown.
During movement of irradiated fuel assemblies in the secondary containment or during CORE ALTERATIO~Ja, with two SFU                   ,r subsystems inoperable, or with one or more SFU subsystems inoperable due to an inoperable CBE boundary, action must be taken immediately to suspend activities that present a potential for releasing radioactivity that might require isolation of the CBE.
* This places t -1:1-Rff in a condition that minimizes the accident risk.
If appli    le, CORE ALTERATIO~Ja and movement of irradiated fuel semblies in the secondary containment must be suspended
* mediately. Suspension of these activities shall not preclude facility completion of movement of a component to a safe position. +f applisable, astion must be initiated immediately to suspend OPDRVs to minimize the probability of a vessel draindown and subsequent potential for fission produst release. Astion must sontim:10 until the OPDR\ls are suspended.
SURVEILLANCE  SR 3.7.4.1 REQUIREMENTS Operating each SFU subsystem for~ 15 minutes ensures that both subsystems are OPERABLE and that all associated controls are functioning properly. It also ensures that blockage or fan or motor failure, can be detected for corrective action. Since the SFU charcoal is tested at a Relative Humidity~ 95%, extended operation of the electric heaters is not required. Thus, each subsystem need only be operated for~ 15 minutes to demonstrate the function of each subsystem. The function of the SFU electric heaters is to pre-heat incoming air to above 40&deg;F to ensure adsorption occurs within the temperature range that charcoal testing is performed. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The Frequency was developed in consideration of the known reliability of fan motors and controls and the redundancy available in the system.
(continued)
DAEC                           B 3.7-24A                             Amendment    ao5
                                                 .--!TS_C_R---18_3_ _ __,&#xb5;

SFU System B 3.7.4 BASES SURVEILLANCE     SR 3.7.4.2 REQUIREMENTS (continued)    This SR verifies that the required SFU testing is performed in accordance with the Ventilation Filter Testing Program (VFTP).
The VFTP includes testing HEPA filter performance, charcoal adsorber efficiency, minimum system flow rate, and the physical properties of the activated charcoal (general use and following specific operations). Specific test Frequencies and additional information are discussed in detail in the VFTP.
SR 3.7.4.3 This SR verifies that on an actual or simulated initiation signal, each SFU subsystem starts and operates. This SR also ensures that the control building isolates. The LOGIC SYSTEM FUNCTIONAL TEST in LCO 3.3.7.1, "Standby Filter Unit Instrumentation," overlaps this SR to provide complete testing of the safety function. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
t Wl:iile tl:iis Surveillanse san be performed witl:i tl:ie roaster at
                            ,
* xperience has shown that these components usually P-          e Surveillance when performed at
* Frequency.                 -f-Th        ore, the Frequency was found to be acceptab e                   a Operating            eliability standpoint.
the current SR 3.7.4.4 This SR verifies the OPERABILITY of the CBE boundary by testing for unfiltered air inleakage past the CBE boundary and into the CBE. The details of the testing are specified in the Control Building Envelope Habitability Program.
The CBE is considered habitable when the radiological dose to CBE occupants calculated in the licensing basis analyses of OBA consequences is no more than 5 rem TEOE and the CBE occupants are protected from hazardous chemicals and smoke.
For OAEC, there is no automatic SFU actuation for hazardous chemical releases or smoke and there are no Surveillance Requirements that verify OPERABILITY in cases of hazardous chemicals or smoke. This SR verifies that the unfiltered air in leakage into the CBE is no greater than the flow rate assumed in the licensing basis analyses of OBA consequences. When unfiltered air in leakage is greater than the assumed flow rate, Conditi_gij,,B must be entered. Required Aetion B.d allows time to jc ~~ GBE boundary to OPERABLE status provided mitigating astions ean ensure tl:iat tl:ie GBE remains witl:iin tl:ie lisensing basis l:iabitabilit,y limits for tl:ie ossupants following an assident. Compensatory measures are dissussed in Regulatory (continued)
OAEC                               B 3.7-24B
                                                                   -,18_3_ _ _      ......;.....;;;&#xb5; TSCR~

SFU System B 3.7.4 BASES SURVEILLANCE SR 3.7.4.4 (continued)
REQUIREMENTS (continued) Guide 1.196, Seetion G.2.7.3, (Ref. <I) 1Nhieh endorses, with exeeptions, j').Jel QQ 03, Seetion 8.<l and Appendix r (Ref. 5).
These eompensatory measures may also be used as mitigating aetions as required by Required Aetion B.2. Temporary analytisal methods may also be used as eompensatory measures to restore OPeRABILITY (Ref. 6). Options for restoring the CBE boundary to OPERABLE status include changing the licensing basis OBA consequence analysis, repairing the CBE boundary, or a combination of these actions. Depending upon the nature of the problem and the corrective action, a full scope inleakage test may not be necessary to establish that the CBE boundary has been restored to OPERABLE status.
REFERENCES   1. UFSAR, Section 6.4.
: 2. UFSAR, Section 9.4.4.
: 3. UFSAR, Section 15.2.
: 4. Regulatory Guide 1.196.
: 5. NEI 99-03, "Control Room Habitability Assessment," June 2001.
: 6. Letter from Eric J. Leeds (NRC) to James W. Davis (NEI) dated January 30, 2004, "NEI Draft White Paper, Use of Generic Letter 91-18 Process and Alternative Source Terms in the Context of Control Room Habitability."
(ADAMS Accession No. ML040300694).
: 7. Letter from Mark A. Peifer (NMC, LLC) to Document Control Desk (USNRC) dated January 28, 2005, "Generic Letter 2003-01: Control Room Habitability - Design Bases, Licensing Bases and lnleakage Testing Results." (ADAMS Accession No. ML050390308).
                                                                      !183 DAEC                         B 3.7-24C                                  TSCR~
i

CBC System B 3.7.5 B 3.7 PLANT SYSTEMS B 3.7.5 Control Building Chiller (CBC) System BASES BACKGROUND            The CBC System provides temperature control for the control building HVAC system under both normal and accident conditions.
The CBC System consists of two independent, redundant subsystems that provide cooling of recirculated control room air.
Each subsystem consists of cooling coils, fans, a chiller, a compressor, ductwork, dampers, and instrumentation and controls to provide for control room temperature control. The CBCs receive water from both the ESW System and the Well Water System. Only the ESW System is required by this LCO.
The CBC System is designed to provide a controlled environment under both normal and accident conditions. Because the source of control room air is common with the air distributed to the remainder of the control building, no special means of isolating just the control room is provided. A single subsystem provides the required temperature control to maintain a suitable control building environment. The design conditions for the control room environment are 75&deg;F dry bulb and 50% relative humidity. The CBC System operation in maintaining the control room temperature is discussed in the UFSAR, Section 9.4.4.2 (Ref. 1).
APPLICABLE           The design basis of the CBC System is to maintain the control SAFETY                room temperature for a 30 day continuous occupancy.
ANALYSES The CBC System components are arranged in redundant safety related subsystems. During emergency operation, the CBC System maintains a habitable environment and ensures the OPERABILITY of components in the control room. A single failure of a component of the CBC System, assuming a loss of offsite power, does not impair the ability of the system to perform its design function. Redundant detectors and controls are provided for control room temperature control. The CBC System is designed in accordance with Seismic Category I requirements.
The CBC System is capable of removing sensible and latent heat loads from the control room, including consideration of equipment heat loads and personnel occupancy requirements to ensure equipment OPERABILITY.
The CBC System satisfies Criterion 3 of 10 CFR 50.36(c)(2)(ii).
(continued)
DAEC                                  B 3.7-25                        "7! Amendment 223 LjTSCR-183               !

CBC System B 3.7.5 BASES (continued)
LCO                 Two independent and redundant subsystems of the CBC System are required to be OPERABLE to ensure that at least one is available, assuming a single failure disables the other subsystem.
In addition, the                 Total system failure could result in the equipment operating necessary portions of            temperature exceeding limits.
the River Water Supply System and the                   The CBC System is considered OPERABLE when the individual Ultimate Heat Sink,              components necessary to maintain the control building Emergency Service                temperature are OPERABLE in both subsystems. These Water System, and                components include the cooling coils, fans, chillers, compressors, Control Building/                ductwork, dampers, and associated instrumentation and controls.
A CBC is considered inoperable if it trips and cannot be promptly Standby Gas Treatment restarted. Therefore, a CBC that spuriously trips and can Instrument Air System            subsequently be restarted in a reasonable period of time, is not are also required to             considered inoperable. In addition, during oonditions in MODEa provide appropriate              other than MODEa 1, 2, and 3 v:hen the CBC aystem is required cooling, ventilation             to be OPERABLE (e.g., during GORE ALTERATIO~Ja), the flowpath, and                    neaessary portions of the Ea'N aystem, Rl..'Va aystem, and the temperature control for           Ultimate
                                       . l=leat a ink are also .required as part of the OPERABILITY the CBC System.
APPLICABILITY In MODEa 4 and 5, the probability and aonsequenaes of a Design Basis /\aaident (DB/\) are reduaed due to the pressure and temperature limitations in these MODER Therefore, maintaining the CBC aystem OPERABLE is not required in MODE 4 or 5, mcaept for the following situations under whiah signifiaant radioaative releases aan be postulated:
During GORE /\LTER/\TIONa; and During movement of irradiated fuel assemblies in the seaondary aontainment.
The CBC System must be OPERABLE t
during movement of irradiated *fuel assemblies in the secondary containment.
(continued)
DAEC                                 B 3.7-26                              ~ndment305 TSCR-183

CBC System B 3.7.5 BASES (continued)
ACTIONS With one CBC subsystem inoperable, the inoperable CBC subsystem must be restored to OPERABLE status within 30 days.
With the unit in this condition, the remaining OPERABLE CBC subsystem is adequate to perform the control building air conditioning function. However, the overall reliability is reduced because a single failure in the OPERABLE subsystem could result in loss of the control building air conditioning function. The 30 day Completion Time is based on the low probability of an event occurring requiring control building isolation, the consideration that the remaining subsystem can provide the required protection, and the availability of alternate cooling methods.
B.1 and B.2 If both CBC subsystems are inoperable, the CBC System may not be capable of performing its intended function. Therefore, the control building area temperatures are required to be monitored to ensure that temperatures are being maintained low enough that equipment in the control building is not adversely affected. To ensure temperatures in the control building are maintained low enough, temperatures are required to be monitored in the control room as well as both essential switchgear rooms. Although design conditions for the control room environment are 75&deg;F dry bulb and 50% relative humidity, maintaining control room area temperatures less than 90&deg;F during the 72 hour Completion Time assures that safety-:-related equipment will remain less than the maximum operating temperature of 104&deg;F. With the control building temperatures being maintained within the temperature limit, 72 hours is allowed to restore a CBC subsystem to OPERABLE status. This Completion Time is reasonable considering that the control building area temperatures are being maintained within limits and the low probability of an event occurring requiring control building isolation.
G.1 and C.2 In MODE 1, 2, or d, if tt:ie inoperable CBC s1:1bsystem(s) sannot be restored to OPHV\BLE stat1:1s within the assosiated Completion Time, the 1:1nit m1:1st be plased in a MODE that minimizes risk. To ashieve this stat1:1s, the 1:1nit m1:1st be plased in at least MODE d v,ithin 12 ho1:1rs and in MODE 4 within de ho1:1rs. The allovi.<<ee Completion Times are reasonable, based on operating experiense, to reash the req1:1ired 1:1nit sonditions from f1:1II pmver sonditions in an orderly manner and witho1:1t shallenging 1:1nit systems.
(continued)
DAEC                                B 3.7-27                                      TSCR~
                                                                                     ~

CBC System B 3.7.5 BASES
               \?
r8            =fcl1---------
                               ~
ACTIONS      .Q.1, ~      and .Q.2.~
(continued)
LCO 3.0.3 is not applisable in MODE 4 or 5. l=lm.vever, sinse irradiated fuel assembly movement ean ossur in MODE 1, 2, or 3, the Required Astions of Condition D are modified by a ~Joto indisating that LCO a.a.a does not apply. If moving irradiated fuel assemblies *.vhile in MODE 1, 2, or 3, the fuel mmmment is independent of roaster operations. Therefore, inability to suspend movement of irradiated fuel assemblies is not suffisient reason to require a roaster shutdo*.vn.
During movement of irradiated fuel assemblies in the secondary containment or during CORE ALTER/\TIO~Ja, if Required Action A.1 cannot be completed within the required Completion Time, the               *
                                                                                          -r OPERABLE CBC subsystem may be placed immediately in operation.
This action ensures that the remaining subsystem is OPERABLE, that no failures that would prevent actuation will occur, and that any active failure will be readily detected.. ~
An alternative to Required Action .Q.1 is to immediately suspend activities that present a potential for releasing radioactivity that might
   /
require isolation of the control room. This places the
* in a condition that minimizes risk.                           facility If applicable, CORE AJ.-TER/\TIO~rn and movement of irradiated fuel assemblies in the secondary containment must be suspended immediately. Suspension of these activities shall not preclude                L, completion of movement of a component to a safe position.
1 E.1 and E.2                                                                  {
LCO a.a.a is not applisable in MODE 4 or 5. l=lowever, sinse irradiated fuel assembly movement san ossur in MODE 1, 2, or 3, the Required Aotions of Condition E are modified by a ~Joto indioating that LCO a.a.a does not apply. If moving irradiated fuel assemblies while in MODE 1, 2, or 3, the fuel movement is independent of roaster operations. Therefore, inability to suspend movement of irradiated fuel assemblies is not a suffisient reason to require a reaotor shutdown.
ITSCR-183             ~
:ontinued!
DAEC                          B 3.7-28                           ~n:ienta

CBC System B 3.7.5 BASES ACTIONS        .1 aRd E.2 (GORtiRl:IOd)
I
!continued During movement of irradiated fuel assemblies in the secondary containment or d1:1riRg GORE ALTERATIONS, if Required Actions             -+-
B.1 and B.2 cannot be met within the required Completion Times, action must be taken to immediately suspend activities that present a potential for releasing radioactivity that might require isolation of the control building. This places the -HfHt in a condition that minimizes risk.       !facility            ~
If applieable, GORE ALTER/\TIO~JS aRd haRdliRg fuel in the secondary containment must be suspena immediately. Suspension of .these activities shall not p elude completion of movement of a component to a safe positio .
        -------------------------Movement SURVEILLANCE SR 3.7.5.1 REQUIREMENTS This SR verifies that the heat removal capability of the system is sufficient to remove available control building heat load. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The Frequency is appropriate since significant degradation of the CBC System is not expected over this time period.
REFERENCES   1.      UFSAR, Section 9.4.4.2.
z.
                                                                       !TSCR 183              !
DAEC                         B 3.7-29                                        eat3Q6

Spent Fuel Storage Pool Water Level B 3.7.8 B 3.7 PLANT SYSTEMS B 3. 7.8 Spent Fuel Storage Pool Water Level BASES BACKGROUND           The minimum water level in the spent fuel storage pool meets the assumptions of iodine decontamination factors following a fuel handling accident.
A general description of the spent fuel storage pool design is found in the UFSAR, Section 9.1.2 (Ref. 1). The assumptions of the fuel handling accident are found in the UFSAR, Section 15.2.5       l (Ref. 2).                                                             1 APPLICABLE           The water level above the irradiated fuel assemblies is an explicit SAFETY               assumption of the fuel handling accident. A fuel handling accident ANALYSES             is evaluated to ensure that the radiological consequences (calculated whole body and thyroid doses at the exclusion area and low population zone boundaries) are well below the guideline limits of 10 CFR 50.67 (Ref. 3) and meet the exposure guidelines of Regulatory Guide 1.183 (Ref. 4). A fuel handling accident could release a fraction of the fission product inventory by breaching the fuel rod cladding as discussed in UFSAR, Section        J..-
15.2.5 (Ref. 2).                                                      -1 The fuel handling accident is evaluated for the dropping of an irradiated fuel assembly onto the reactor core. The consequences of a fuel handling accident over the spent fuel storage pool are no more severe than those of the fuel handling accident over the reactor core, as discussed in the UFSAR, Section 15.2.5 (Ref. 2).     -f The water level in the spent fuel storage pool provides for absorption of water soluble fission product gases and transport delays of soluble and insoluble gases that must pass through the water before being released to the secondary containment atmosphere. This absorption and transport delay reduces the potential radioactivity of the release during a fuel handling accident.
The spent fuel storage pool water level satisfies Criterion 2 of 10 CFR 50.36(c)(2)(ii).
_!1_83~~~~~~~ntinued)
                                                                                   ~
DAEC                                 B 3.7-37                                 TSCR 044/\

i Spent Fuel Storage Pool Water Level B 3.7.8 BASES (continued)
LCO                The specified water level preserves the assumptions of the fuel handling accident analysis (Ref. 2). As such, it is the minimum required for fuel movement within the spent fuel storage pool.
APPLICABILITY     This LCO applies during movement of irradiated fuel assemblies in the spent fuel storage pool since the potential for a release of fission products exists.
ACTIONS LGO d.0.d is Rot applisable iR MODE 4 er 5. ~ov,ever, siRse irradiated fuel assembly movemeRt saR ossur iR MODE 1, 2, or d, required AetioR /\.1 is modified by a ~Joto iRdieatiRg tl:iat LGO d.0.d does Rot apply. If moviRg irradiated fuel assemblies wl:iile iR MODE 1, 2, or d, tl:ie fuel movemeRt is iRdepeRdeRt of roaster operatioRs. Tl:ierefore, iRability to suspeRd movemeRt of irradiated fuel assemblies is Rot a suffieieRt reasoR to require a roaster sl:iutdovvR.
When the initial conditions for an accident cannot be met, action must be taken to preclude the accident from occurring. If the spent fuel storage pool level is less than required, the movement of irradiated fuel assemblies in the spent fuel storage pool is
* suspended immediately. Suspension of this activity shall not preclude completion of movement of an irradiated fuel assembly to a safe position. This effectively precludes a spent fuel handling accident from occurring.
SURVEILLANCE      SR 3.7.8.1 REQUIREMENTS
                                                                                            *t This SR verifies that sufficient water is available in the event of a fuel handling accident. The water level in the spent fuel storage pool must be checked periodically. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
The Frequency is acceptable, based on operating experience, considering that the water volume in the pool is normally stable, and all water level changes are controlled by unit procedures .
                                                      ._!T_S_C_R_-1_8_3_ _~~ (continued)
DAEC                               B 3.7-38                                 \J TSGE 120

Spent Fuel Storage Pool Water Level B 3.7.8 BASES (continued)
REFERENCES        1. UFSAR, Section 9.1.2.
: 2. UFSAR, Section 15.2.5.
: 3. 10 CFR 50.67.
: 4. Regulatory Guide 1.183.
                                                            !183 DAEC                        B 3.7-39 C:
TSCR 044/\

AC Sources       ghutdown B 3.8.2 B 3.8 ELECTRICAL POWER SYSTEMS
           .B 3.8.2 AC Sources     Shutdovm BASES BACKGROUND         /\ description of the /\C sources is provided in the Bases for LCO 3.8.1, "/\C Sources          Operating."
INSERT 83.8.2-1 APPLICABLE          The OPERABILITY of the minimum AC sources during MODES 4 SAFETY              and 6 and during movement of irradiated fuel assemblies in the ANALYSES            secondary containment ensures~t_ ..,
adequate Sufficient instrurnentation and control capability is available for rnonitoring and rnaintaining the 1,mit status; and G,,     /\EleEf uate AC electrical power is provided to mitigate Ia postulated                        )events postulated during shutdown, such as a fuel handling {
accident.               *                     '
In general, v1hen the unit is shutdown the Technical Specifications reEfuireFRents ensure that the unit has the capability to rnitigate the conseEfuences of postulated accidents. r4owover, assurning a single failure and concurrent loss of all offsite or loss of all onsite power is not reEf uired. The rationale for this is based on the fact that rnany Design Basis Accidents (DB/\s) that are analyzed in MODES 1, 2, and 3 have no specific analyses in MODES 4 and 5.
                               'Norst case bounding events are deerned not credible in MODES 4 and 5 because the energy contained within the reactor pressure boundary, reactor coolant ternperature and pressure, and corresponding stresses result in the probabilities of occurrences significantly reduced,or elirninated, and rninimal conseEf uences. These deviations frorn DB/\ analysis assumptions and design reEf uirements during shutdown conditions are allowed by the LCO for reEf uired systems.
During MODES 1, 2, and 3, *1arious deviations from the analysis assurnptions and design reEf uirernents are allm.\*ed within th,e TSCR-183 DAEC                                  B 3.8-26

INSERT 83.8.2-1 Page 1 of 1 The unit Class 1E AC Electrical Power Distribution System AC sources consist of the offsite power sources (preferred and alternate preferred), and the onsite standby power sources (Diesel Generators (DGs) 1G-31 and 1G-21 ). As discussed in UFSAR Section 3.1.2.2.8 (Ref. 1), the design of the AC Electrical Power System provides independence and redundancy to ensure an available source of power to the essential buses 1A3 and 1A4.
The Class 1E AC Distribution System is divided into redundant load groups, so loss of any one group does not prevent the minimum safety functions from being performed. Each load group has connections to two preferred offsite power supplies and a single DG.
Offsite power is supplied to the 161 kV and 345 kV switchyards from the transmission network by six transmission lines. The 345 kV switchyard and the 161 kV switchyard are connected via the autotransformer, and both sections of the switchyard are connected to the transmission grid by at least two independent lines. From the 161 kV switchyard preferred power source breakers CB5550 and/or CB5560, a single overhead transmission line feeds the startup transformer. From the startup transformer, dual isolated secondary windings provide feeds to the 4160 volt essential buses, 1A3 and 1A4, through separate bus supply lines and circuit breakers. The startup transformer is sized to supply all facility power (both essential and non-essential loads). From the 161 kV switchyard alternate preferred power source breaker CB8490, a single 34.5 kV underground line feeds the standby transformer. From the standby transformer, a single 4160 volt line feeds both essential buses through separate bus supply circuit breakers. A detailed description of the offsite power network and circuits to the onsite Class 1E essential buses is found in the UFSAR, Sections 8.2.1.3 and 8.3.1.1.5 (Reference 2).
An offsite circuit consists of all breakers, transformers, switches, interrupting devices, cabling, and controls required to transmit power from the offsite transmission network to the onsite Class 1E essential bus or buses. Startup transformer (1X3) provides the normal source of power to the essential buses 1A3 and 1A4. If either 4.16 kV essential bus loses power, an automatic transfer from the startup transformer to the standby transformer (1X4) occurs.
The startup transformer and standby transformer are both sized to accommodate the starting of all required loads on receipt of an accident signal.
The onsite standby power source for 4.16 kV essential buses 1A3 and 1A4 consists of two DGs. DGs 1G-31 and 1G-21 are dedicated to essential buses 1A3 and 1A4, respectively. A DG starts automatically on an essential bus degraded voltage or undervoltage signal. After the DG has started, it automatically ties to its respective bus after offsite power is tripped as a consequence of essential bus undervoltage or degraded voltage. Following the trip of offsite power, non emergency loads powered from essential buses are load shed.
In the event of a loss of both the preferred power source and the alternate preferred power source, the required electrical loads are automatically connected to the DGs in sufficient time to mitigate the consequences of a Design Basis Accident (OBA) such as a FHA.
Ratings for the DGs satisfy the intent of Safety Guide 9 as discussed in UFSAR Section 1.8.9 (Ref. 3).
DGs 1G-31 and 1G-21 have the following ratings:
: a.      2850 kW continuous,
: b.      3000 kW 2000 hours, and
: c.      3250 kW 300 hours.

AC Sources       ShutElown B 3.8.2 BASES APPLICABLE     ACTIONS. This allov,ance is in Fecognition that certain testing
* SAFETY         anEI maintenance activities must ee conElucted, prnviEled an ANALYSES       acceptaele level of Fisk is not exceeded. DLIFing MODES 4 anEI 5, (continued)  peFformanse of a signifisant numl:>oF of roquimd testing and maintenanse astivities is also required. In MODES 4 and 5, tho astivities are generally planned and administrati'Joly controlloEl.
Relaxations from typical MODES 1, 2, and a LCO requirements are ascepfaelo during shutdov,n MODES, easoEl on:
a..       The fact that time in an outage is limited. This is a risk pFuelent goal as well as a utility esonomis consideFation .
              .e,.,. Requiring appropriate compensatory measures for sortain conditions. These may insludo administrative sontrnls, relianse on systems that do not necessarily meet typical design requirements applied to systems credited in operation MODE analyses, or eoth.
              &:-        Pr1:1dont utility consiEleration of the risk associated with multiple activities that soulel affect multiple systems.
4         Maintaining, to the extent prastical, tho ability to perform required functions (even if not meeting MODES 1, 2, anEI         a OPERABILITY requirements) *11ith systems assumed to function eluring an event.
In tho event of an accielent Eluring shutElown, this LCO ensures the sapaeility of supporting systems nesessary for avoiEling immediate diffic1:1lty, assblming either a loss of all offsito po*ner or a loss of all onsito (Diesel Generator (DG)) pm".'er.
The AC Sources             Shutdown satisfy Criterion 3 of 10 CFR 50.36(c)(2)(ii).
LCO           One offsite circuit capable of supplying the onsite Class 1E power distribution subsystem(s) of LCO 3.8.8, "Distribution Systems -
Shutdown," ensures that all required loads are powered from offsite power. An OPERABLE DG, associated with Distribution System essential bus required OPERABLE by LCO 3.8.8, ensures that a diverse power source is available for providing electrical power support assuming a loss of the offsite circuit. Together, OPERABILITY of the required offsite circuit and DG ensures the availability of sufficient AC sources to opera;:,j>laRI in a safe
                                             !facility (continued)
DAEC                              B 3.8-27

AC Sources         gh1:1tdown B 3.8.2 BASES LCO                manner and to mitigate the consequences oist"lal0~ s*,eals (continued)    d1:1Fing sh1:1tdovm (e.g., fuel handling accident.st. Automatic initiation of the required DG d1:1ring sh1:1tdown sonditions is specified in LCO 3.3.8.1, "LOP lnstrumentatioo!!..            f *i*t
[8                                                  7             ac11y The qualified offsite circuit(s) must be capable of m intaining rated frequency and voltage while connected to thei respective essential bus(es), and of accepting required loads d ring an accident. Qualified offsite circuits are those that are scribed in the UFSAR and are part of the licensing basis for the 4ffi..it. The required offsite circuit consists of either: 1) either the incoming circuit breaker (1400) and disconnects (1401 and 1402) or incoming circuit breaker (2690) and disconnects (2691 and 2692),
the overhead 161 kV buswork, circuit breaker (1590) and disconnect (1591 ), the Reserve Auxiliary Transformer (1 X5},
circuit breaker (8490) and disconnect (8491 ), the underground 34.5 kV line, the standby transformer (1X4), the 4160 volt supply line and the two supply circuit breakers (1A301 and 1A401) to essential buses 1A3 and 1A4, respectively, or 2) the incoming circuit breaker (5550 or 5560) and disconnect (5551 or 5555, respectively), the overhead 161 kV line, the startup transformer (1X3), one of the two 4160 volt supply lines and one of the two supply circuit breakers (1A302 or 1A402) to essential buses 1A3 or 1A4, respectively, if required by LCO 3.8.8.
The required DG must be capable of starting, accelerating to rated speed and voltage, connecting to its respective essential bus on detection of bus undervoltage, and accepting required loads. This sequence must be accomplished within 10 seconds. Each DG must also be capable of accepting required loads within the assumed loading sequence intervals, and must continue to In addition, the             operate until offsite power can be restored to the essential buses.
necessary portions           The necessary portions of Emergency Service Water are also of the River Water           required to provide appropriate cooling to each required DG.
Supply System and Ultimate Heat Sink           Proper sequencing of loads, including non-essential load and Emergency                shedding capability, is a required function for DG OPERABILITY.
Service Water System are also              In addition, proper timed logic sequence operation, is an integral part of offsite circuit OPERABILITY since its inoperability could required to provide impact the ability to start and maintain energized loads required appropriate cooling          OPERABLE by LCO 3.8.8. No automatic transfer capability is for the DG.                  required for offsite circuits to be considered OPERABLE during (continued)
DAEC                                 B 3.8-28                      CAmendment 305
                                                                   !TSCR-183             !

AC Sources        Shutdown B 3.8.2 BASES (continued)
APPLICABILITY     The AC sources are required to be OPERABLE in MODES 4 and 5 and during movement of irradiated fuel assemblies in the secondary containment to provide assurance that;.
Systems that provide core cooling are a'lailablo; systems
                              ~~fm7',1eeded to mitigate a fuel handling accident are available;-
                    &:-        Systems necessarf to mitigate the effects of events that can lead to core Elamage Eluring shutElown are available; aRG 4          Instrumentation and control capability is available for monitoring anEI maintaining the unit in a colEI shutElovm condition or refueling conElition.
AC power requirements for MODES 1 , 2, anEI         a are co'lereEI in LCO a_g_1.
ACTIONS           LCO a.a.a is not applicable 'tlhile in MODE 4 OF 5. Ho'NO'leF, since irradiated fuel assembly movement can occur in MODE 1, 2, or a, tho Actions !:lave boon modified by a Note stating tl:lat LCO a.a.a is not applicable. If moving irraEliatoEI fl:Jol assemblies 1,r.ihilo in MODE 4 or 5, LCO a.a.a woulEI not specify any action. If moving irradiatoEI fuel assemblies while in MODE 1, 2, or a, the fl:Jol movement is inElepenElent of reactor operations. Therefore, in either case, inability to suspend movement of irraEliatod HJel assemblies woulEI not so sufficient reason to require a reactor shutElov~n.
An offsite circuit is considered inoperable if it is not available to supply power to either of the essential buses. If both essential 4.16 kV buses are required per LCO 3.8.8, one division with offsite power available may be capable of supporting sufficient required features to allow continuation of CORE ALTERATIO~JS                L afld....fuel movement. By the allowance of the option to declare          1 required (continued)
DAEC                                 B 3.8-29                          [3: AmenElment 305
                                                              !TSCR-183             !

AC Sources              el:u:-.1tdown B 3.8.2
                                                                                                \
BASES (continued)
ACTIONS           A.1 (continued) features inoperable that are not powered from offsite power, appropriate restrictions can be implemented in accordance with the affected required feature(s) LCOs' ACTIONS.
Required features remaining powered from a qualified offsite power circuit, even if that circuit is considered inoperable because it is not powering other required features, are not declared inoperable by this Required Action.
A.24; A.2.2, /\.2.3, 8.1, 8.2, and 8.3,      ~1.::::*=an=d====B=.1=---_ __J With the required offsite circuit not available to either division, the option still exists to declare all affected required features inoperable per required Action A 1. Since this option may involve undesired administrative efforts, the allowance for sufficiently conservative actions is made. With the required DG inoperable, the minimum required diversity of AC power sources is not available. It is, therefore, required to suspend CORE ALTER/\TIO~rn and movement of irradiated fuel assemblies in the secondary containment.
                                                                                                        -r Suspension of these activities shall not preclude completion of actions to establish a safe conservative condition. These actions minimize the probability of the occurrence of postulated events. t is f1:1rther req1:1ired to Immediately initiate astion to FOstore the req1:1ired /\C so1:1rses and to sontin1:10 this astion 1:1ntil restoration is assomplished in order to provide the nesossary /\C pm.'l.'er to the plant safety systems.
The Completion Time of Immediately is consistent with the required times for ACTIONS requiring prompt attention. The restoration of the required AC electrical power sources should be completed as quickly as possible in order to minimize the time (continued)
DAEC                                 B 3.8-30                             p: Amendment 305
                                                            !TSCR-183                    !

AC Sources             Sh1:1telmvn B 3.8.2 facility                 , and B.1 BASES ACTIONS                                                                                         t during which the             safety systems may be without sufficient power. Pursuant to LCO 3.0.6, the Distribution System ACTIONS would not be entered even if all AC sources to it are inoperable, resulting in de-energization. Therefore, the Required Actions of Condition A have been modified by a Note to indicate that when Condition A is entered with no AC power to any required essential bus, ACTIONS for LCO 3.8.8 must be Immediately entered. This Note allows Condition A to provide requirements for the loss of the offsite circuit whether or not a division is de-energized. LCO 3.8.8 provides the appropriate restrictions for the situation involving a de-energized division.
SURVEILLANCE SR 3.8.2.1 REQUIREMENTS INSERT 83.8.2-2 This    ~m. is moelifieel by two ~Jatos. The reason for ~Joto 1 is to presl1:1ele req1:1iring the OPERABLE DG(s) from being paralleleel v.*ith the offsite po\\'OF neR.vork or other\vise rendered inoperable el1:1ring the performanse of SRs, anel to presl1:1ele eleenergizing a req1:1ired 4160 V essential b1:1s or diseonneeting a req1:1ired of:fsite sire1:1it et1:1ring performanee of SRs. VVith limited AG so1:1rees available, a single e1Jent eo1:1lel eompromise both the req1:1ireet sire1:1it anel the DG. It is the intent that these SRs m1:1st still be sapable of being met, b1:1t aet1:1al performanse is not req1:1ireet el1:1ring perioels 'Nhen the DG anel of:fsite sirs1:1it is req1:1ireel to be OPERABLE.
Note 2 states that SR 3.8.1.13 is eonsidered to be met witho1:1tthe EGGS initiation signals OPERABLE when the EGGS initiation signals are not req1:1ireel to be OPERABLE per Table 3.3.5.1 1.
This SR elemonstrates the DG response to an EGGS signal (either alone or in son11:1nstion with a loss of power signal). This is sonsistent with the EGGS instr1:1mentation req1:1irements of Table 3.3.5.1 1 that do not req1:1ire the EGGS signals to be OPERABLE in MODES 4 anel 5 when EGGS is not req1:1ireel to be OPERABLE.                    f' REFERENCES    ~Jone. JC.<:,__---i!lnsert 3.8.2-3 DAEC                               B 3.8-31                        cAmenelment 305
                                                          !TSCR-183                 !

INSERT B 3.8.2-2 Page 1 of 9 SURVEILLANCE     The AC sources are designed to permit inspection and testing of REQUIREMENTS     all important areas and features, especially those that have a standby function, in accordance with UFSAR Section 3.1.2.2.9 (Ref. 1). Periodic component tests are supplemented by extensive functional tests (under simulated accident conditions).
The SRs for demonstrating the OPERABILITY of the DGs are largely in accordance with the recommendations of Safety Guide 9 as discussed in UFSAR Section 1.8.9 (Ref. 2),
Regulatory Guide 1.108 (Ref. 3), and Regulatory Guide 1.137 (Ref. 4) or as addressed in the UFSAR.
Where the SRs discussed herein specify voltage and frequency tolerances, the following summary is generally applicable. The minimum steady state output voltage of 3744 Vis approximately 90% of the nominal 4160 Voutput voltage. This value, which is specified in ANSI C84.1, allows for voltage drop to the terminals of 4000 V motors whose minimum operating voltage is specified as 90% or 3600 V. It also allows for voltage drops to motors and other equipment down through the 120 V level where minimum operating voltage is also usually specified as 90% of name plate rating. This value also provides a large margin of safety, since safety related motors are capable of accelerating their loads at 70% of rated voltage (2912 V or 322 V). The specified maximum steady state output voltage of 4576 V or 110% of 4160 V is less than the maximum operating voltage specified for 4000 V motors (4756 V), and therefore also provides ample margin. It ensures that for a lightly loaded distribution system, the voltage at the terminals of 4000 V motors is no more than the maximum rated operating voltages. The specified minimum and maximum frequencies of the DG are 59.5 Hz and 60.5 Hz, respectively.
These values are approximately equal to +/- 1% of the 60 Hz nominal frequency and are conservative with respect to the recommendations found in Regulatory Guide 1.9 (Ref. 5).

INSERT B 3.8.2-2 Page 2 of 9 BASES SURVEILLANCE       SR 3.8.2.1 REQUIREMENTS (continued)      This SR ensures proper circuit continuity for the offsite AC electrical power supply to the onsite distribution network and availability of offsite AC electrical power. The breaker alignment verifies that at least the minimum required offsite power supply breakers are in their correct position to ensure that distribution buses and loads are connected to either the preferred power source or the alternate preferred power source and that appropriate independence of offsite circuits is maintained. This can be accomplished by verifying that an essential bus is energized, and that the status of offsite supply breakers that are displayed in the control room are correct. The status of manual disconnects is verified administratively. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The Frequency is adequate since breaker position is not likely to change without the operator being aware of it and because its status is displayed in the control room.
SR 3.8.2.2 and SR 3.8.2.7 These SRs help to ensure the availability of the standby electrical power supply to mitigate a FHA and maintain the facility in a safe condition.
To minimize the wear on moving parts that do not get lubricated when the engine is not running, these SRs have been modified by a Note to indicate that all DG starts for these Surveillances may be preceded by an engine prelube period and (for SR 3.8.2.2 only) followed by a warmup prior to loading.

INSERT B 3.8.2-2 Page 3 of 9 BASES SURVEILLANCE        SR 3.8.2.2 and SR 3.8.2.7 (continued)
REQUIREMENTS For the purposes of this testing, the required DG is manually
                  . started from standby conditions. Standby conditions for a DG mean that the diesel engine coolant and oil are being continuously circulated and temperature is being maintained consistent with manufacturer recommendations.
In order to reduce stress and wear on diesel engines during testing, the manufacturer of the DGs installed at the DAEC recommends a modified start in which the starting speed of the DG is limited, warmup is limited to this lower speed, and the DGs are gradually accelerated to synchronous speed prior to loading.
These start procedures are the intent of Note 2 (SR 3.8.2.2).
SR 3.8.2.7 requires that the required DG starts from standby conditions and achieves required voltage and frequency (i.e. -
voltage::::: 3744 V and frequency::::: 59.5 Hz) within 10 seconds; and achieves steady state voltage ::::: 3744 V and ~ 4576 V and frequency::::: 59.5 Hz and ~ 60.5 Hz. The 10 second start requirement supports the assumptions in the accident analysis of UFSAR, Section 15.2.1 (Ref. 6). If a modified start is not used, the 10 second start requirement of SR 3.8.2.7 applies. In addition to the SR requirements, the time for the DG to reach steady state operation, unless the modified DG start method is employed, is periodically monitored and the trend evaluated to identify degradation of governor and voltage regulator performance.
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The normal Frequency for SR 3.8.2.2 is consistent with Safety Guide 9. The Frequency for SR 3.8.2. 7 is a reduction in cold testing consistent with Generic Letter 84-15 (Ref. 7). These Frequencies provide adequate assurance of DG OPERABILITY, while minimizing degradation resulting from testing.

INSERT B 3.8.2-2 Page 4 of 9 BASES SURVEILLANCE       SR 3.8.2.3 REQUIREMENTS (continued)      This Surveillance verifies that the required DG is capable of synchronizing and can be manually loaded to ~ 2750 kW and
                   ~ 2950 kW, providing a 200 kW range centered on the continuous duty rating of the DG of 2850 kW. This range ensures that the DG is tested at a load above the maximum expected accident load. A minimum run time of 60 minutes is required to stabilize engine temperatures, while minimizing the time that the DG is connected to the offsite source.
Although no power factor requirements are established by this SR, the DG is normally operated at a power factor greater than 0.9 iagging. While a value of 0.8 is the design rating of the machine, the machine is operated at power factors greater than 0.9 for normal operations and greater than 0.8 for surveillance testing. The load limit is provided to avoid routine overloading of the DG. Routine overloading may result in more frequent teardown inspections in accordance with vendor recommendations in order to maintain DG OPERABILITY.
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The normal Frequency for this Surveillance is consistent with Safety Guide 9.
The reason for Note 1 is to preclude requiring the OPERABLE DG from being paralleled with the offsite power network or otherwise rendered inoperable during performance of the Surveillance, and to preclude deenergizing a required 4160 V essential Bus or disconnecting a required offsite circuit during performance of SRs.
With limited AC sources available, a single event could compromise both the required circuit and the DG. It is the intent that this SR must still be capable of being met, but actual performance is not required during periods when the DG and offsite circuit is required to be OPERABLE. Note 2 modifies this Surveillance to indicate that diesel engine runs for this Surveillance may include gradual loading, as recommended by the manufacturer, so that mechanical stress and wear on the diesel engine are minimized. Note 3 modifies this Surveillance by stating that momentary transients because of changing bus loads do not invalidate this test. Similarly, momentary power factor transients above the limit do not invalidate the test.
Note 4 indicates that this Surveillance should be conducted on only one DG at a time in order to avoid common cause failures that might result from offsite circuit or grid perturbations.
Note 5 stipulates a prerequisite requirement for performance of this SR. A successful DG start must precede this test to credit satisfactory performance.

INSERT B 3.8.2-2 Page 5 of 9 BASES SURVEILLANCE       SR 3.8.2.4 REQUIREMENTS (continued)      This SR provides verification that the level of fuel oil in the day tank is at or above the level at which the day tank low level alarm is annunciated. This low level alarm should only be received if the automatic fuel oil transfer instrumentation is not functioning properly. The level is expressed as an equivalent volume in gallons, and is selected to ensure adequate fuel oil for a minimum of approximately one hour of DG operation at full load, considering a conservative fuel consumption rate. Verification that at least a one hour supply of fuel oil exists in a day tank provides assurance that a DG can operate continuously, and also allows the operating crew sufficient time to take corrective action should the automatic fuel oil transfer system not function properly.
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The Frequency is adequate to ensure that a sufficient supply of fuel oil is available, since low level alarms are provided and facility operators* would be aware of any large uses of fuel oil during this period.
SR 3.8.2.5 Microbiological fouling is a major cause of fuel oil degradation.
There are numerous bacteria that can grow in fuel oil and cause fouling, but all must have a water environment in order to survive.
Testing for water content and removal of water from the fuel oil in the required day tank as necessary, eliminates the necessary environment for bacterial survival. This is the most effective means of controlling midrobiological fouling. In addition, it eliminates the potential for water entrainment in the fuel oil during DG operation. Water may come from any of several sources, including condensation, ground water, rain water, contaminated fuel oil, and breakdown of the fuel oil by bacteria. Frequent checking for and removal of accumulated water, as necessary, minimizes fouling and provides data regarding the watertight integrity of the fuel oil system. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
The Surveillance Frequencies meet the intent of Regulatory Guide 1.137 (Ref. 10). This SR is for preventive maintenance.
The presence of water does not necessarily represent a failure of this SR provided that accumulated water is removed during performance of this Surveillance.

INSERT B 3.8.2-2 Page 6 of 9 BASES SURVEILLANCE       SR 3.8.2.6 REQUIREMENTS (continued)      This Surveillance demonstrates that each required fuel oil transfer pump operates and transfers fuel oil from its associated storage tank to its associated day tank. It is required to support continuous operation of standby power sources. This Surveillance provides assurance that the fuel oil transfer pump is OPERABLE, the fuel oil piping system is intact, the fuel delivery piping is not obstructed, and the controls and control systems for manual fuel transfer systems are OPERABLE. Additional assurance of fuel oil transfer pump OPERABILITY is provided by meeting the testing requirements for pumps that are contained in the ASME Code (Ref. 8). The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.8.2.7 See SR 3.8.2.2.

INSERT B 3.8.2-2 Page 7 of 9 BASES SURVEILLANCE       SR 3.8.2.8 REQUIREMENTS (continued)      Each DG is provided with an engine overspeed trip to prevent damage to the engine. Recovery from the transient caused by the loss of a large load could cause diesel engine overspeed, which, if excessive, might result in a trip of the engine. This Surveillance demonstrates the DG load response characteristics and the capability to reject the largest single load and return to the
* required voltage and frequency (i.e. - voltage ~ 37 44 V and :::; 4576 V and frequency~ 59.5 Hz and :::; 60.5 Hz) within predetermined periods of time (i.e., 1.3 seconds for voltage and 3.9 seconds for frequency) while maintaining an acceptable margin to the overspeed trip. This Surveillance may be accomplished by tripping its associated single largest post-accident load with the DG solely supplying the bus.
As specified by IEEE-308 (Ref. 9), the load rejection test is acceptable if the increase in diesel speed does not exceed 75% of the difference between synchronous speed and the overspeed trip setpoint, or 15% above synchronous speed, whichever is lower.
For both DGs, this represents 64.5 Hz, equivalent to 75% of the difference between nominal speed and the overspeed trip setpoint.
This SR is modified by a Note. The reason for the Note is to preclude requiring the OPERABLE DG from being paralleled with the offsite power network or otherwise rendered inoperable during performance of the Surveillance, and to preclude deenergizing a required 4160 V essential Bus or disconnecting a required offsite circuit during performance of SRs. With limited AC sources available, a single event could compromise both the required circuit and the DG. It is the intent that this SR must still be capable of being met, but actual performance is not required during periods when the DG and offsite circuit is required to be OPERABLE.
The time, voltage, and frequency tolerances specified in the Bases for this SR are derived from UFSAR Table 8.3-1 (Ref. 10) recommendations for response during load sequence intervals.
The voltage and frequency are consistent with the design range of the equipment powered by the DG. SR 3.8.2.8.a corresponds to the frequency excursion, while SR 3.8.2.8.b and SR 3.8.2.8.c are the steady state voltage and frequency to which the system must recover following load rejection within a predetermined time period. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

INSERT B 3.8.2-2 Page 8 of 9 BASES SURVEILLANCE        SR 3.8.2.9 REQUIREMENTS (continued)       This Surveillance demonstrates that DG non-critical protective functions (e.g., high jacket water temperature and low lubricating oil pressure) are bypassed and critical protective functions (engine overspeed and generator differential current) trip the DG to avert substantial damage to the DG unit. The non-critical trips are bypassed during DBAs and LOOPs and provide an alarm on an abnormal engine condition. This alarm provides the operator with sufficient time to react appropriately. The DG availability to mitigate the OBA is more critical than protecting the engine against minor problems that are not immediately detrimental to emergency operation of the DG.
This SR is modified by a Note. The reason for the Note is to preclude requiring the OPERABLE DG from being paralleled with the offsite power network or otherwise rendered inoperable during performance of the Surveillance, and to preclude deenergizing a required 4160 V essential Bus or disconnecting a required offsite circuit during performance of SRs. With limited AC sources available, a single event could compromise both the required circuit and the DG. It is the intent that this SR must still be capable of being met, but actual performance is not required during periods when the DG and offsite circuit is required to be OPERABLE.
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The Frequency is based on engineering judgment and takes into consideration plant conditions required to perform the Surveillance. Operating experience has shown that these components usually pass the SR when performed at this Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
SR 3.8.2.10 As specified by Regulatory Guide 1.108 (Ref. 3), paragraph 2.a.(6), this Surveillance ensures that the manual synchronization and load transfer from the DG to the offsite source can be made and that the DG can be returned to ready-to-load status when offsite power is restored. The DG is considered to be in ready-to-load status when the DG is at rated speed and voltage, the output breaker is open and can receive an auto-close signal on bus undervoltage, and the individual pump timers are reset.

INSERT B 3.8.2-2 Page 9 of 9 This SR is modified by a Note. The reason for the Note is to
                    . preclude requiring the OPERABLE DG from being paralleled with the offsite power network or otherwise rendered inoperable during performance of the Surveillance, and to preclude deenergizing a required 4160 V essential Bus or disconnecting a required offsite circuit during performance of SRs. With limited AC sources available, a single event could compromise both the required circuit and the DG. It is the intent that this SR must still be capable of being met, but actual performance is not required during periods when the DG and offsite circuit is required to be OPERABLE.
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

INSERT 3.8.2-3
: 1. UFSAR, Section 3.1.2.2.9
: 2. UFSAR, Section 1.8.9.
: 3. Regulatory Guide 1.108.
: 4. Regulatory Guide 1.137.
: 5. Regulatory Guide 1.9.
: 6. UFSAR, Section 15.2.1
: 7. Generic Letter 84-15.
: 8. ASME Code for Operation and Maintenance of Nuclear Power Plants.
: 9. IEEE Standard 308.
: 10. UFSAR, Table 8.3-1.

Diesel Fuel Oil, Lube Oil, and Starting Air Although the LOCA is no            B 3.8.3 longer applicable to the B 3.8 ELECTRICAL POWER SYSTEMS permanently shut B 3.8.3 Diesel Fuel Oil, Lube Oil, and Starting down and defueled DAEC, the fuel oil capacity,-,
requirement remains valid BASES                                            and boundinq.
BACKGROUND           The Diesel Generators (DGs) are provided with a storage t a
having fuel oil capacity sufficient to operate one DG for a of 7 days while the DG is supplying maximum post Loss of Coolant Accident (LOCA) load demand *
* 8estion 9.5.4 (Ref. 1) and Regulatory Guide 1.1 ~H (Ref. 2). he {'
maximum load demand is calculated using the assumption that only one DG is available. This onsite fuel oil capacity is sufficient to operate the DGs for longer than the time to replenish the onsite supply from outside sources.
Fuel oil is transferred from storage tank to the day tanks by either of two transfer pumps. Redundancy of pumps and piping precludes the failure of one pump, or the rupture of any pipe or valve, to result in the loss of more than one DG. The outside tanks, pumps, and piping are located underground.
For proper operation of the standby DGs, it is necessary to ensure the proper quality of the fuel oil. Regulatory Guide 1.137 (Ref. 2) addresses the recommended fuel oil practices as supplemented by ANSI N195 (Ref. 3). The fuel oil properties governed by these SRs are the water and sediment content, the kinematic viscosity (or Saybolt Universal Viscosity), specific gravity (or API gravity),
and total particulate contamination.
The DG Lubrication System is designed to provide sufficient lubrication to permit proper operation of its associated DG under all loading conditions. The system is required to circulate the lube oil to the diesel engine working surfaces and to remove excess heat generated by friction during operation. The DG Lube Oil System is designed to provide automatic lube oil makeup to the DG crankcase for a minimum of 7 days of operation per UFSAR Section 8.3.1 (Ref. 7). This supply is sufficient to allow the operator to replenish lube oil from outside sources.
Each DG has two independent starting air supply systems each with adequate capacity for five successive normal start attempts per air receiver without recharging. A minimum of fifteen normal DG starts are provided for each DG per UFSAR (continued)
DAEC                                  B 3.8-32                 .--~~~~-T~SCR-4e4
                                                               .__!18_3_ _ _____.~

Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES BACKGROUND    Section 8.3.1 (Ref. 7).
(continued)
APPLICABLE    The initial conditions of Design Basis Accident (OBA) and SAFETY        transient analyses in UFSAR, Chapter 15 (Ref. 5), assume ANALYSES      Engineeffid Safety Feature (ESF) Systems are OPERABLE. The DGs are designed to provide sufficient capacity, capability, -
redundancy, and reliability to ensure the availability of necessary power ~ syste required to ensure safe storage of spent  Since diesel fuel oil, lube oil, and starting air subsystem support fuel.             the operation of the standby AC power sources, they satisfy Criterion 3 of 10 CFR 50.36(c)(2)(ii).
the facility LCO           Stored diesel fuel oil is required to have sufficient supply fo 7 days of full load operation. It is also required to meet sp cific standards for quality. Additionally, sufficient lube oil suppl must be available to ensure the capability to operate at full load for 7 days. This requirement, in conjunction with an ability to obtain replacement supplies wi_thin 7 days, supports the availa * *ty of DGs required to shut dov:n the reactor and to maintain -it in a safe condition for an Abnormal Operational Transient or a postulated OBA with loss of offsite power. DG day tank fuel oil requirements, as well as transfer capability from the storage tank to the day tanks, are addressed in LCO 3.8.1, "AC Sources           Operating,"
a.RG-LCO 3.8.2, "AC Sources         Shutdm.*JR. 11   ,
The starting air system is required to have a minimum capacity for five successive normal DG start attempts without recharging the air start receivers.
(continued)
DAEC                           B 3.8-33                                     TSCR--08a
                                                            -118-3----~

Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 the facility BASES (continued)
APPLICABILITY      The AC sources (                     LCO 3.8.2) are required to ensure the availabil of the required power to sh1,1t Elown the FeastoF anEI maintain +tin a safe sh1,:ltE10*:m condition after aR
                   /\bnOFmal OpeFational Trnnsient or a postulated OBA. Because stored diesel fuel oil, lube oil, and starting air subsystem support LCO 3Jt1 anEI LCO 3.8.2, stored diesel fuel oil, lube oil, and starting air are required to be within limits when the associated DG is required to be OPERABLE.
ACTIONS            The ACTIONS Table is modified by a Note indicating that separate Condition entry is allowed for each DG for Conditions B, E, and F. This is acceptable, since the Required Actions for each Condition provide appropriate compensatory actions for each inoperable DG subsystem. Complying with the Required Actions for one inoperable DG subsystem may allow for continued operation, and subsequent inoperable DG subsystem(s) governed by separate Condition entry and application of associated Required Actions.
In this Condition, the 7 day fuel oil supply for a DG is not available. However, the Condition is restricted to fuel oil level reductions that maintain at least a 6 day supply. The fuel oil level equivalent to a 6 day supply is 32,689 gallons. These
                                                                                             +-
circumstances may be caused by events such as:
: a.      Full load operation required for an inadvertent start while at minimum required level; or
: b.      Feed and bleed operations that may be necessitated by increasing particulate levels or any number of other oil quality degradations.
This restriction allows sufficient time for obtaining the requisite
                  ,replacement volume and performing the analyses required prior to addition of the fuel oil to the tank. A period of 48 hours is considered sufficient to complete restoration of the required level prior to declaring the DG inoperable. This period is acceptable based on the remaining capacity (> 6 days), the fact that procedures will (continued)
DAEC                                B 3.8-34                                     TSCR~
                                                               ,18-3-------,~

Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES ACTIONS A.1 (continued) be initiated to obtain replenishment, and the low probability of an event during this brief period.
In this Conditions, the 7 day lube oil inventory, i.e., sufficient lube oil to support 7 days of continuous DG operation at full load conditions is not available. However, the Condition is restricted to lube oil level reductions that maintain at least a 6 day supply. The lube oil inventory equivalent to a 6 day supply is 221 gallons. This restriction allows sufficient time for obtaining the requisite replacement volume. A period of 48 hours is considered sufficient to complete restoration of the required volume prior to declaring the DG inoperable. This period is acceptable based on the remaining capacity(> 6 days), the low rate of usage, the fact that procedures will be initiated to obtain replenishment, and the low probability of an event during this brief period.
This Condition is entered as a result of a failure to meet the acceptance criterion for particulates. Normally, trending of particulate levels allows sufficient time to correct high particulate levels prior to reaching the limit of acceptability. Poor sample procedures (bottom sampling), contaminated sampling equipment, and errors in laboratory analysis can produce failures that do not follow a trend. Since the presence of particulates does not mean failure of the fuel oil to burn properly in the diesel engine, since particulate concentration is unlikely to change significantly between Surveillance Frequency intervals, and since proper engine performance has been recently demonstrated (within 31 days), it is prudent to allow a period prior to declaring both DGs inoperable. The 30 day Completion Time starts when initial analysis results are known and allows for further evaluation, resampling, and re-analysis of the DG fuel oil.
D.1 With the new fuel oil properties defined in the Bases for SR 3.8.3.3 not within the required limits, a period of 30 days is allowed for restoring the stored fuel oil properties. This period provides sufficient time to test the stored fuel oil to determine that (continued)
DAEC                     B 3.8-35                                     TSCR~
                                                    ~!18-3----~

Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES ACTIONS 0.1 (continued) the mixture of new fuel oil and previously stored fuel oil remains acceptable, or to restore the stored fuel oil properties. If testing of the new fuel oil reveals fuel oil properties are not within limits, those properties not within limits must be tested, or restored to within limits. This restoration may involve feed and bleed procedures, filtering, or combination of these procedures. Even if a DG start and load was required during this time interval and the fuel oil properties were outside limits, there is high likelihood that the DG would still be capable of performing its intended function.
Note that when the entire inventory of stored fuel oil is replaced with new fuel oil, the new fuel oil properties must be within specification prior to declaring the DGs OPERABLE.
E.1 With all starting air receivers associated with a DG with pressure
        < 150 psig, sufficient capacity for five successive DG start attempts may not exist. However, as long as any one receiver's pressure is~ 75 psig, there is adequate capacity for at least one start attempt (as shown during initial plant startup testing when successful DG starting was demonstrated with air receiver pressure as low as 50 psig), and the DG can be considered OPERABLE while the air receiver pressure is restored to the required limit. A period of 48 hours is considered sufficient to complete restoration to the required pressure prior to declaring the DG inoperable. This period is acceptable based on the remaining air start capacity, the fact that most DG starts are accomplished on the first attempt, and the low probability of an event during this brief period.
Ll With a Required Action and associated Completion Time not met, or the stored diesel fuel oil, lube oil, or starting air subsystem not within limits for reasons other than addressed by Conditions A through E, the associated DG may be incapable of performing its intended function and must be immediately declared inoperable.
(continued)
DAEC                     B 3.8-36                                     TSCR-4a4
                                                      .__118_3_ _ ____.~

Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES SURVEILLANCE SR 3.8.3.1 REQUIREMENTS This SR provides verification that there is an adequate inventory of fuel oil in the storage tank to support a single DG's operation for 7 days at full load. The fuel oil level equivalent to a 7 day supply is 37,967 gallons when calculated in accordance with References 2            f and 3. The required fuel storage volume is determined using the most limiting energy content of the stored fuel. Using the known correlation of diesel fuel oil absolute specific gravity or API gravity to energy content, the required diesel output, and the corresponding fuel consumption rate, the onsite fuel storage volume required for 7 days of operation can be determined. SR 3.8.3.3 requires new fuel to be tested to verify that the absolute specific gravity or API gravity is within the range assumed in the diesel fuel oil consumption calculations. The 7 day period is sufficient time to place th -l:1-R-it in a safe shutdovm condition and to bring in re I
* ent fuel from an offsite location.
facility The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The Frequency is adequate to ensure that a sufficient supply of fuel oil is available, since low level alarms are provided and~ operators would be aware of any large uses of fuel oil durin         is period.
facility SR 3.8.3.2 This Surveillance ensures that sufficient lubricating oil inventory is available to support at least 7 days of full load operation for each DG. The lube oil inventory equivalent to a 7 day supply is 257 gallons and is based on the DG manufacturer's consumption values for the run time of the DG. Implicit in this SR is the requirement to verify the capability to transfer the lube oil from the lube oil makeup tank to the DG. The requirement is considered to be fulfilled by observing that the DG lube oil sump level is maintained in the normal band by the lube oil sump level controller.
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. A Frequency is adequate to ensure that a sufficient lube oil supply is onsite, since DG starts and run time are closely monitored by the plant staff.
(continued)
DAEC                          B 3.8-37                                      TSCR-472.
                                                             ....._l18_3_ _ _  ~V

Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES SURVEILLANCE  SR 3.8.3.3 REQUIREMENTS (continued) The tests listed below are a means of determining that the new and stored fuel oil has not been contaminated with substances that would have an immediate detrimental impact on diesel engine combustion. If results from these tests are within acceptable -
limits, the fuel oil may be added to the storage tank without concern for contaminating the entire volume of fuel oil in the storage tank. These tests are to be conducted prior to adding the new fuel to the storage,tank, but in no case is the time between receipt of new fuel and conducting the tests to exceed 31 days.
The tests, limits, and applicable ASTM Standards are as follows:
: a.       Sample the new fuel oil in accordance with ASTM           0975-77 (Ref. 6);
: b.      Verify in accordance with the tests specified in ASTM 01298-85 (Ref. 6) that the sample has an absolute specific gravity at 60/60&deg;F of;:::,: 0.83 and ::; 0.89 or an API gravity at, 60&deg;F of~ 28&deg; and ::; 38&deg;;
: c.      Verify in accordance with ASTM 0975-77, using ASTM Test Method 088-81, that viscosity at 100&deg;F is~ 32.6 and::;
40.1 Saybolt Universal Seconds;
: d.      Verify that water and sediment are within limits when tested in accordance with ASTM 0975-77 (Ref. 6).
Failure to meet any of the above limits is cause for rejecting the new fuel oil, but does not represent a failure to meet the LCO concern since the fuel oil is not added to the storage tank.
Within 31 days following the initial new fuel oil sample, the fuel oil is analyzed to establish that the other properties specified in Table 1 of ASTM 0975-77 (Ref. 6) are met for new fuel oil when tested in accordance with ASTM 0975-77 (Ref. 6), except that a cloud point limit of 0&deg;C has been selected due to fuel oil being stored underground and below the frost line, and that flash point and cetane number are not required. The 31 day period is acceptable because the fuel oil properties of interest, even if they were not within stated limits, would not have an immediate
                                                         !TSCR-183             h
                                                         ,____ _ _ _ _~(confiQued)
                                                                                     ~
OAEC                           B 3.8-38                                  Amendment 223

Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES SURVEILLANCE   SR 3.8.3.3 (continued)
REQUIREMENTS effect on DG operation. This Surveillance ensures the availability of high quality fuel oil for the DGs.
Fuel oil degradation during long term storage shows up as an increase in particulate, mostly due to oxidation. Tlie presence of particulate does not mean that the fuel oil will not burn properly in a diesel engine. The particulate can cause fouling of filters and fuel oil injection equipment, however, which can cause engine failure.
Particulate concentrations should be determined in accordance with ASTM D2276-89 (Ref. 6), Method A2 or A3. These methods involve a gravimetric determination of total particulate concentration in the fuel oil and have a limit of 10 mg/I. It is acceptable to obtain a field sample for subsequent laboratory testing in lieu of field testing.
The Frequency of this test takes into consideration fuel oil degradation trends that indicate that particulate concentration is unlikely to change significantly between Frequency intervals.
SR 3.8.3.4 This Surveillance ensures that, without the aid of any refill compressor, sufficient air start capacity for each DG is available.
The system design requirements provide for a minimum of five engine start cycles per air receiver without recharging. The pressure specified in this SR is intended to reflect a conservative value for which the five starts can be accomplished, assuming only one air start receiver is pressurized.
The Surveillance Frequency is controlled under the Surveillance          L, Frequency Control Program. The Frequency takes into account             1 the capacity, capability, redundancy, and diversity of the AC
                                                          ~
sources and the Air ~tart System for each DG.
                                                                   !183 (cb_nued)
                                                                                  'Si DAEC                            B 3.8-39                                     TSCR~
             \

Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES SURVEILLANCE  SR 3.8.3.5 REQUIREMENTS (continued) Microbiological fouling is a major cause of fuel oil degradation.
There are numerous bacteria that can grow in fuel oil and cause fouling, but all must have a water environment in order to survive.
Checking for the presence of water, and removing water, as             f' necessary, eliminates the necessary environment for bacterial survival. This is the most effective means of controlling microbiological fouling. In addition, it eliminates the potential for water entrainment in the fuel oil during DG operation. Water may come from any of several sources, including condensation, ground water, rain water, contaminated fuel oil, and from breakdown of the fuel oil by bacteria. Frequent checking for and removal of water minimizes fouling and provides data regarding the watertight integrity of the fuel oil system. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The Surveillance Frequencies are consistent with those
                                                                                     +
recommended and established by Regulatory Guide 1.137 (Ref. 2). This SR is for preventive maintenance. The presence of water does not necessarily represent failure of this SR, provided the water is removed during performance of the Surveillance.
REFERENCES    1.      UFSAR, Section 9.5.4. ~=[D_e_l_et_e_d.c,..]_ _ _......
: 2.      Regulatory Guide 1.137.
: 3. ANSI N195, 1976.
: 4.     [Deleted]
: 5.      UFSAR, Chapter 15.
: 6. ASTM Standards: D975-77, D1298:-85 and D2276-89.
: 7. UFSAR, Section 8.3.1.
                                                                        !183 DAEC                           B 3.8-40                                     TSCR~
J

DC Sources         ghbltdown B 3.8.5 B 3.8 ELECTRICAL POWER SYSTEMS B 3.8.5 DC Sources     ghbltdown BASES A dessription of the DC soblrses is pro11ided in the Bases for Insert 83.8.5-1                LCO 3.8.4, "DC goblrses           Operating."
APPLICABLE          The initial sonditions of Design Basis Assident and transient SAFETY             analyses in the ui;::gAR, Chapter 15 (Ref. 1), assblme that ANALYSES            Engineered gafety Feat1:Jre gystems are OPERABLE. The 125 VDC Electrical Power System provides normal and emergency DC electrical power for the Diesel Generators (DGs), emergency auxiliaries, and control and switching during all MODEg of operation and d1:Jring movement of irradiated fuel assemblies in the Secondary Containment.
The OPERABILITY of the DC subsystems is consistent with the initial assumptions of the accident analyses and the requirements for the supported systems' OPERABILITY.
The OPERABILITY of the minimum DC electrical power sources during MODEg 4 and 5 and d1:Jring movement of irradiated fuel assemblies in the secondary containment ensures that.;.
a:-      The fasility san be maintained in the shbltdm.\'n or ref1:Jeling sondition for e*tended perioEls; g1:Jffisient instF1:Jmentation anEI sontrol sapability is a'.'ailable a
for monitoring and maintaining the 1:Jnit statbls; and        &sect;]
dequate DC electrical power is provided to mitigate ~
events postulated dblring sh1:Jtdovm, s1:Jsh as a fuel handling {
accident.
The DC sources satisfy Criterion 3 of 10 CFR 50.36(c)(2)(ii).
TSCR-183 (continued)
DAEC                                   B 3.8-52

INSERT 83.8.5-1 Page 1 of 2 BACKGROUND      The DC Electrical Power System provides the AC Emergency Power System with control power. It also provides both motive and control power to selected safety related equipment. As discussed in UFSAR Section 3.1.2.2.8 (Ref. 1), the DC Electrical Power System is designed to have sufficient independence, redundancy, and testability to perform its safety functions, assuming a single failure. The DC Electrical Power System also conforms to the intent of the recommendations of Safety Guide 6, as discussed in UFSAR Section 1.8.6. (Ref. 2) and IEEE-308 (Ref. 3).
The DC power sources provide both motive and control power to selected safety related equipment, as well as circuit breaker control power for some of the 4160 V, and all 480 V and lower, AC Distribution Systems. Each 125 VDC subsystem is energized by one 125 V station service battery and two 125 V battery chargers (one normally inservice charger and one swing charger that is able to separately charge either 125 VDC divisional battery).
Each battery is exclusively associated with a single 125 V bus.
The normal chargers are supplied from the same essential AC load groups for which the associated DC subsystem supplies the control power, while the swing 125 VDC charger can be supplied from either essential AC division. The loads between the redundant 125 VDC subsystems are not transferable. The 125 VDC subsystems also provide control and instrumentation power for their respective DG.
During normal operation, the DC loads are powered from the battery chargers with the batteries floating on the system, acting as a voltage regulator. If a battery is disconnected from its distribution bus and only a charger is supplying bus voltage, the associated Distribution System shall be considered inoperable, as it cannot supply the peak power required for some event scenarios.
In case of loss of power to any battery charger, the DC loads are automatically powered from the battery until the redundant charger or swing charger is placed in service by operator action.
The DC Power Distribution System is described in more detail in Bases for LCO 3.8.8, "Distribution System."
Each 125 voe battery (with a minimum of 59 cells) has adequate storage capacity to carry the control and essential instrumentation power continuously for approximately 4 hours and the emergency loads for their required length of time.

INSERT 83.8.5-1 Page 2 of 2 BACKGROUND      Each DC battery is separately housed in a ventilated room apart (continued)   from its charger and distribution centers. Each subsystem is located in an area separated physically and electrically from the other subsystems to ensure that a single failure in one subsystem does not cause a failure in a redundant subsystem. There is no sharing between redundant Class 1E subsystems such as batteries, battery chargers, or distribution panels except for the swing 125 VDC battery charger which is mechanically interlocked to prevent being simultaneously connected to both distribution buses with double isolation circuit breakers.
The batteries for DC electrical power subsystems are sized to produce required capacity at 80% of nameplate rating, corresponding to warranted capacity at the end of a nominal 20 year service cycle. The expected life of the batteries may exceed 20 years and will be adjusted based on engineering evaluations of each battery's capacity trend data as the batteries age. The minimum design voltage limit is 105V for the 125 VDC subsystems.
Each battery charger of DC electrical power subsystem has ample power output capacity for the steady state operation of connected loads required during normal operation, while at the same time maintaining its battery bank fully charged. Each station service battery charger has sufficient capacity to restore the battery from the design minimum charge to its fully charged state while supplying normal steady state loads (Ref. 10).

DC Sources        Sh1:1tdown B 3.8.5 BASES (continued)                                                      (1(i.e.,   I LCO               The DC electrical power subsystems           *Nith: JDivision I and Division II 125 VDC subsystems each consisting of one 125 V battery, the associated battery charger or the swing battery charger and the corresponding control equipment and necting cabling supply power to the associated distribution y       , and, the 250 VDC s1:1bsystem sonsisting of the 250V battery, one of the ti.vo battery shaFQOFS and the sorresponding sontrol eq1:1ipment and intersonnesting sabling s1:1ffisient to provide elestrisal power to the 01:1tboard Rl=IR SOC s1:1stion isolation valve (MO 1QOQ), are required to be OPERABLE to support required DC distribution subsystems required OPERABLE by LCO 3.8.8,                    a "Distribution Systems Sh1:1tdovm." This requirement ensure the availability of sufficient DC electrical power sources to oper. e the
!facility           ~-HfHt in a safe manner and to mitigate the consequences of
.....___.'--_ _ ____. postulated events d1:1ring sh1:1tdown (e.g., fuel handling accident51. f-APPLICABILITY     The DC electrical power sources required to be OPERABLE -iff MODES 4 and 5 and during movement of irradiated fuel assemblies in the secondary contai             provide ass1:1ranse that:
to ensure that required                    Req1:1ired feat1:1Fes to provide sore sooling are available;       t Req1:1ired features needed to mitigate a fuel handling accident are available+
Req1:1ired feat1:1res nesessary to mitigate the effests of events that san lead to sore damage d1:1ring sh1:1tdown are available; and lnstF1:1mentation and sontrol sapability is available for monitoring and maintaining the 1:1nit in a sold sh1:1tdown sondition or ref1:1eling sondition.
The DC elestrisal p9'.&#xa5;er req1:1irements for MODES 1, 2, and d are sovered in LCO d.8.4.
ITSCR-183              '.
J   (conti~ued)
DAEC                                B 3.8-53                              ~mendmen

DC Sources       ghutdm*m B 3.8.5 BASES (continued)
ACTIONS           LCO 3.0.3 is not applicable while in MODE 4 or 5. HmNever, since irradiated f1:1el assembly movement can occur in MODE 1, 2, or 3, the Actions have been modified by a fl,Jote stating that LCO 3.0.3 is not applisable. If moving irradiated fuel assemblies 'Nhile in MODE 4 or 5, LCO 3.0.3 wo1:1ld not specify any action. If moving irradiated fuel assemblies while in MODE 1, 2, or 3, the fuel movement is independent of reastor operations. Therefore, in either case, inability to s1:1spond movement of irradiated fuel assemblies 'NOl:lld not be suffiqient reason to require a reastor shu~and            I A.1, A.2-4; A.2.2, and A.2.3                                           {
If more than one DC distribution subsystem is required according to LCO 3.8.8, the DC electrical power subsystems remaining OPERABLE with one or more DC electrical power subsystems inoperable may be capable of supporting sufficient required features to allow continuation of CORE AL TERATIQfl,Jg and fuel         1-,
movement. By allowance of the option to declare required               *1 features inoperable with associated DC electrical power subsystems inoperable, appropriate restrictions are implemented in accordance with the affected system LCOs' ACTIONS.
However, in many instances, this option may involve undesired administrative efforts. Therefore, the allowance for sufficiently conservative action*s is made (i.e., to suspend CORE
                  /\L TER,A,TIOti,Jg and movement of irradiated fuel assemblies in         y the secondary containment).                                            1 Suspension of these activities shall not preclude completion of actions to establish a safe conservative condition. These actions minimize the probability of the occurrence of postulated events. -U is further required to immediately initiate action to restore the required DC elestrical pov.1er subsystems and to continue this action until restoration is accomplished in order to provide tho necessary DC elestrical power to tho plant safety systems.
                                                                  !TSCR-183            !
: (continued)
DAEC                               B 3.8-54                             ~    ndmont~

DC Sources      Shutdm.\'n B 3.8.5 jand                  I
::~:N:continued) A.1   i.2+. A.2.2, A.2.~. aa~ A.2.4 (continued)
The Completion Time of immediately is consistent with the required times for actions requiring prompt attention. +Re restoration of the required DC electrical pov,er subsystems should be sompleted as quiskly as possible in order to minimize the time during 'Nhish the plant safety systems may be 'Nithout suffisiont pO'v'JOF.
SURVEILLANCE      SR 3.~L5.1 REQUIREMENTS SR 3.8.5.1 requires performance of all Surveillanses required by SR 3.8.4.1 throu9h SR 3.8.4.8. Therefore, see the sorresponding INSERT 83.8.5-2      Bases for LCO 3.8.4 for a discussion of eash SR This SR is modified by a Note. The reason for tho ~Jots is to preclude requiring the OPERABLE DC sourses from being disshar9ed below their sapability to provide tho required po*uer supply or otherwise rendered inoperable durin9 the performance of SRs. It is the intent that those SRs must still be capable of being met, but actual performanse is not required.
RE~ERENCES UFS/\R, Chapter 15.
                                                                           !183 DAEC                               B 3.8-55
                                                                                    '1t TSCR 044.t\

INSERT 83.8.5-2 Page 1 of 5 SURVEILLANCE       SR 3.8.5.1 REQUIREMENTS Verifying battery terminal voltage while on float charge for the batteries helps to ensure the effectiveness of the charging system and the ability of the batteries to perform their intended function.
Float charge is the condition in which the charger is supplying the continuous charge required to overcome the internal losses of a battery (or battery cell) and maintain the battery (or a battery cell) in a fully charged state. The voltage requirements are based on the nominal design voltage of the battery and are consistent with the manufacturer's minimum float voltage recommendations (Ref. 4). The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The Frequency is consistent with manufacturer recommendations and with the intent of IEEE-450 (Ref. 7).
SR 3.8.5.2 Visual inspection to detect corrosion of the battery cells and connections, or measurement of the resistance of each inter-cell, inter-rack, inter-tier, and terminal connection, provides an indication of physical damage or abnormal deterioration that could potentially degrade battery performance.
The connection resistance limits established for this SR must be no more than 20% above the resistance as measured during installation or not above the ceiling value established by the manufacturer. The resulting limits are 5.0 E-5 ohms for inter-cell connections and 1.4 E-4 ohms for inter-rack connections, inter-tier connections and terminal connections. The Frequency for these inspections, which can detect conditions that can cause power losses due to resistance heating, is controlled under the Surveillance Frequency Control Program. This Frequency is considered acceptable based on operating experience related to detecting corrosion trends.
SR 3.8.5.3 Visual inspection of the battery cells, cell plates, and battery racks provides an indication of physical damage or abnormal deterioration that could potentially degrade battery performance.
The presence of physical damage or deterioration does not necessarily represent a failure of this SR, provided an evaluation determines that the physical damage or deterioration does not affect the OPERABILITY of the battery (its ability to perform its design function).
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The Frequency for this SR is consistent with the intent of IEEE-450 (Ref. 7), which recommends detailed visual inspection of cell condition and rack integrity.

INSERT 83.8.5-2 Page 2 of 5 SURVEILLANCE       SR 3.8.5.4 and SR 3.8.5.5 REQUIREMENTS       Visual inspection and resistance measurements of inter-cell, (continued)        inter-rack, inter-tier, and terminal connections provide an indication of physical damage or abnormal deterioration that could indicate degraded battery condition. The anti-corrosion material is used to help ensure good electrical connections and to reduce terminal deterioration. The visual inspection for corrosion is not intended to require removal of and inspection under each terminal connection.
The removal of visible corrosion is a preventive maintenance SR.
The presence of visible corrosion does not necessarily represent a failure of this SR, provided visible corrosion is removed during performance of this Surveillance. The connection resistance limits for this SR must be no more than 20% above the resistance as measured during installation, or not above the ceiling value established by the manufacturer. The resulting limits are 5.0 E-5 ohms for inter-cell connections and 1.4 E-4 ohms for inter-rack connections, inter-tier connections and terminal connections.
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The Frequency of these SRs is consistent with the intent of IEEE-450 (Ref. 7), which recommen~s detailed visual inspection of cell condition and inspection of cell to cell and terminal connection resistance.
SR 3.8.5.6 Battery charger capability requirements are based on the design capacity of the chargers (Ref. 3). According to the recommendations of Regulatory Guide 1.32 (Ref. 8), the battery charger supply is required to be based on the largest combined demands of the various steady state loads and the charging capacity to restore the battery from the design minimum charge state to the fully charged state, irrespective of the status of the facility during these demand occurrences. The minimum required amperes ensures that these requirements can be satisfied. The minimum required voltage ensures that the requirements are satisfied at the minimum float voltage that the battery chargers are normally set for. Charger operation at an output greater than the minimum required voltage and amperage, such as during equalize mode, demonstrates the battery charger meets, and exceeds, the Surveillance Requirements.
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The Frequency is acceptable, given the facility conditions required to perform the test and the other administrative controls existing to ensure adequate charger performance during these interva.ls.

INSERT B3.8.5-2 Page 3 of 5 SURVEILLANCE       SR 3.8.5.7 REQUIREMENTS (continued)        A battery service test is a special test of the battery's capability, as found, to satisfy the design requirements (battery duty cycle) of the DC electrical power system. The discharge rate and test length corresponds to the design duty cycle requirements as specified in Reference 4. The voltage of each cell shall be determined after the discharge. Following discharge, battery cell parameters must be restored in accordance with LCO 3.8.6. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
This SR is modified by two Notes. Note 1 allows the performance of a performance discharge test in lieu of a service test. Note 2 precludes requiring the OPERABLE DC sources from being discharged below their capability to provide the required power supply or otherwise rendered inoperable during the performance of SRs. It is the intent that this SR must still be capable of being met, but actual performance is not required.
The modified performance discharge test is a simulated duty cycle consisting of just two rates; the one minute rate published for the battery or the largest current load of the duty cycle, followed by the test rate employed for the performance test, both of which envelope the duty cycle of the service test. Since the ampere-hours removed by a rated one minute discharge represents a very small portion of the battery capacity, the test rate can be changed to that for the performance test without compromising the results of the performance discharge test. The battery terminal voltage for the modified performance discharge test should remain above the minimum battery terminal voltage specified in the battery service test for the duration of time equal to that of the service test.
A modified discharge test is a test of the battery capacity and its ability to provide a high rate, short duration load (usually the highest rate of the duty cycle). This will often confirm the battery's ability to meet the critical period of the load duty cycle, in addition to determining its percentage of rated capacity. Initial conditions for the modified performance discharge test should be identical to those specified for a service test.

INSERT 83.8.5-2 Page 4 of 5 SR 3.8.5.8 SURVEILLANCE REQUIREMENTS       A battery performance discharge test is a test of constant current (continued)        capacity of a battery, normally done in the as found condition, after having been in service, to detect any change in the capacity determined by the acceptance test. The test is intended to determine overall battery degradation due to age and usage.
A battery modified performance test is described in the Bases for SR 3.8.5.7. Either the battery performance discharge test or the modified performance discharge test is acceptable for satisfying SR 3.8.5.8; however, only the modified performance discharge test may be used to satisfy SR 3.8.5.8 while satisfying the requirements of SR 3.8.5.7 at the same time.
This SR is modified by a Note. The reason for the Note is to preclude requiring the OPERABLE DC sources from being discharged below their capability to provide the required power supply or otherwise rendered inoperable during the performance of SRs. It is the intent that this SR must still be capable of being met, but actual performance is not required.
The acceptance criteria for this Surveillance is consistent with IEEE-450 (Ref. 7) and IEEE-485 (Ref. 9). These references recommend that the battery be replaced if its capacity is below 80% of the manufacturer's rating. A capacity of 80% shows that the battery rate of deterioration is increasing, even if there is ample capacity to meet the load requirements. The Frequency for this test is normally controlled under the Surveillance Frequency Control Program. However, if the battery shows degradation, or if the battery has reached 85% of its expected life and capacity is
                  < 100% of the manufacturer's rating, the Surveillance Frequency is reduced to 12 months. However, if the battery shows no degradation but has reached 85% of its expected life, the Surveillance Frequency is only reduced to 24 months for batteries that retain capacity~ 100% of the manufacturer's rating.
Degradation is indicated, according to IEEE-450 (Ref. 7), when the battery capacity drops by more than 10% relative to its capacity on the previous performance test or when it is 10% below the manufacturer's rating. All these Frequencies are consistent with the recommendations in IEEE-450 (Ref. 7).

INSERT B3.8.5-2 Page 5 of 5 REFERENCES
: 1.          UFSAR, Section 3.1.2.2.8.
: 2.          UFSAR, Section 1.8.6.
: 3.          IEEE Standard 308, 1971.
: 4.          Calculation: CAL-E08-008, latest approved revision.
: 5.          UFSAR, Chapter 15.
: 6.          Not used.
: 7.          IEEE Standard 450, 1980.
: 8.          Regulatory Guide 1.32, February 1977.
: 9.          IEEE Standard 485, 1983.
: 10.         UFSAR, Section 8.3.2

Battery Cell Parameters B 3.8.6 B 3.8 ELECTRICAL POWER SYSTEMS B 3.8.6 Battery Cell Parameters BASES BACKGROUND            This LCO delineates the limits on electrolyte temperature, level, float voltage, and specific gravity for the DC electrical power subsystems batteries. A discussion of these batteries and their OPERABILITY requirements is provided in the Bases for LCO 3.8.4, "DC So1:JFGes       Operating," and LCO 3.8.5, "DC Sources        Sh1:Jtdov:n."
APPLICABLE             The initial oonditions of Design Basis Assident (OBA) and SAFETY                transient analyses in UFSAR, Chapter 15 (Ref. 2), ass1:Jme ANALYSES               Engineered Safety Feat1:Jre Systems are OPERABLE. The DC electrical power subsystems provide normal and emergency DC electrical power for the Diesel Generators (DGs), emergency auxiliaries, and control and swit
* d1:JFing all MODES of operation when associated DC electrical power          The OPERABILITY of the DC subsystems is consistent with the subsystems are               initial assumptions of the accident analyses and is based upon required to be               meeting the design basis of the -t::ffiff: as discussed in the Bases for OPERABLE.                    LCO 3.8.4 and LCO 3.8.5.                ~facility                 I Since battery cell parameters support the operation of the DC electrical power subsystems, they satisfy Criterion 3 of 10 CFR 50.36(c)(2)(ii).
LCO                   Battery cell parameters must remain within acceptable limits to ensure availability of the required DC power to sh1:Jt down the roaster and maint
* ft in a safe condition after an Abnormal tJf:~~:B:all-ffaR!:He!M-ff-a postulated OBA. Electrolyte limits are the facility                   ervatively established, allowing continued DC electrical system function even with Category A and B limits not met.
                                                                                     !183 (con~nued)
                                                                                                ~
DAEC                                   B 3.8-56                                    TSCR 044/\

Battery Cell Parameters B 3.8.6 BASES (continued)
APPLICABILITY     The battery cell parameters are required solely for the support of the associated DC electrical power subsystem. Therefore, parameters for required battery cells are only required to be within limits when the associated DC electrical power subsystem is required to be OPERABLE. Refer to the Applicability discussions in Bases for LGO 3.8.4 and LCO 3.8.5.
ACTIONS           A.1, A.2, and A.3 With parameters of one or more cells in one or more batteries not within limits (i.e., Category A limits not met or Category B limits not met, or Category A and B limits not met) but within the Category C limits specified in Table 3.8.6-1, the battery is degraded but there is still sufficient capacity to perform the intended function. Therefore, the affected battery is not required to be considered inoperable solely as a result of Category A or B limits not met, and continued operation is permitted for a limited t
period.
The pilot cell electrolyte level and float voltage are required to be verified to meet the Category C limits within 1 hour (Required Action A.1 ). This check provides a quick indication of the status of the remainder of the battery cells. One hour provides time to inspect the electrolyte level and to confirm the float voltage of the pilot cell. One hour is considered a reasonable amount of time to perform the required verification.
Verification that the Category C limits are met for required battery cells (Required Action A.2) provides assurance that during the time needed to restore the parameters to the Category A and B f
limits, the battery is still capable of performing its intended function. A period of 24 hours is allowed to complete the initial verification because specific gravity measurements must be obtained for each connected cell. Taking into consideration both the time required to perform the required verification and the assurance that the battery cell parameters are not severely
                                                                              !183 DAEC                               B 3.8-57                                     TSCR-448

Battery Cell Parameters B 3.8.6 BASES (continued)
ACTIONS           A.1, A.2, and A.3 (continued) degraded, this time is considered reasonable. The verification is repeated at 7 day intervals until the parameters are restored to Category A and B limits.
Continued operation is only permitted for 31 days before parameters for required battery cells must be restored to within Category A and B limits. Taking into consideration that, while t
battery capacity is degraded, sufficient capacity exists to perform the intended function and to allow time to fully restore the battery cell parameters to normal limits, this time is acceptable for operation prior to declaring the DC batteries inoperable.
When any battery parameter is outside the Category C limit for any connected (required) cell, sufficient capacity to supply the t
maximum expected load requirement is not ensured and the corresponding DC electrical power subsystem must be declared inoperable. Additionally, other potentially extreme conditions, such as any Required Action of Condition A and associated Completion Time not met or average electrolyte temperature of representative cells~ 65&deg;F, also are cause for immediately declaring the associated DC electrical power subsystem inoperable.
SURVEILLANCE      SR 3.8.6.1 REQUIREMENTS This SR verifies that Category A battery cell parameters are consistent with IEEE-450 (Ref. 3), which recommends regular battery inspections (at least one per month) including voltage, specific gravity, and electrolyte temperature of pilot cells.
                                                                           !183 DAEC                              B 3.8-58                                    TSCR-4,4g

Battery Cell Parameters B 3.8.6 BASES SURVEILLANCE   SR 3.8.6.1 (continued)
REQUIREMENTS The SR should only be performed when the battery is on a float charge to allow obtaining meaningful, consistent, trendable readings. If the battery is on equalize charge or has been on equalize charge anytime during the previous 72 hours when the SR is due, performance of the SR should be delayed until the battery has been off equalize charge for 72 hours, utilizing the allowance of SR 3.0.2. If it is expected that a battery will need to be on equalize charge whe*n the SR is due and past the extension time allowed by SR 3.0.2, the SR should be performed early before the battery is placed on equalize charge. The Surveillance Frequency is controlled under the Surveillance Frequency Control t
Program.
* SR 3.8.6.2 The periodic inspection of specific gravity and voltage is consistent with IEEE-450 (Ref. 3). The actual Surveillance
             . Frequency is controlled under the Surveillance Frequency Control t
Program. In addition, within 24 hours of a battery discharge
               < 110 V for 125 V aRE1, ~ 220 V for 260 V or a battery overcharge
               > 150 V for 125 V aRE1, 7 300 V for 260 V, the battery must be demonstrated to meet Category B limits. Transients, such as motor starting transients, which may momentarily cause battery voltage to drop to ~ 110 V for 125 V aM ~ 220 V for ~60 V, do not constitute a battery discharge provided the battery terminal voltage and float current return to pre-transient values. This inspection is also consistent with IEEE-450 (Ref. 3), which.
recommends special inspections following a severe discharge or overcharge, to ensure that no significant degradation of the battery occurs as a consequence of such discharge or overcharge.
SR 3.8.6.3 This Surveillance that verifies the average temperature of         - {
representative cells is within limits is consistent with a recommendation of IEEE-450 (Ref. 3) that states that the temperature of electrolytes in representative cells should be determined on a routine basis. The Surveillance Frequency is           I_
controlled under the Surveillance Frequency Control Program.          f Lower than normal temperatu'res act to inhibit or reduce battery capacity. This SR ensures that the operating temperatures remain within an acceptable operating range. This limit is based on manufacturer's recommendations.
(continued)
DAEC                           B 3.8-59                                     TSCR-42Q 1
                                                                       !183

Battery Cell Parameters  ,
B 3.8.6 BASES SURVEILLANCE  Table 3.8.6-1 REQUIREMENTS (continued) This Table delineates the limits on electrolyte level, float voltage, and specific gravity for three different categories. The meaning of each category is discussed below.
Category A defines the normal parameter limit for each designated pilot cell iri each battery. The cells selected as pilot cells are those whose temperature, voltage, and electrolyte specific gravity approximate the state of charge of the entire battery.
The Category A limits specified for electrolyte level are based on manufacturer's recommendations and are consistent with the guidance in IEEE-450 (Ref. 3), with the extra% inch allowance above the high water level indication for operating mc;1rgin to account for temperature and charge effects. In addition to this allowance, footnote (a) to Table 3.8.6-1 permits the electrolyte level to be temporarily above the specified maximum level during an equalizing charge, provided it is not overflowing. It is acknowledged that, following completion of an equalizing charge, electrolyte level may temporarily be above the specified limit, but not overflowing, for a short period of time. The recovery time for electrolyte level after the equalizing charge is considered part of the equalizing process. These limits ensure that the plates suffer no physical damage, and that adequate electron transfer capability is maintained in the event of transient conditions. ,
IEEE-450 (Ref. 3) recommends that electrolyte level readings should be made only after the battery has been at float charge for at least 72 hours.
The Category A limit specified for float voltage is;:;:-: 2.13 V per cell.
This value is based on the recommendation of IEEE-450 (Ref. 3),
which states that prolonged operation of cells below 2.13 V can reduce the life expectancy of cells. The Category A limit specified for specific gravity for each pilot cell is ;:;:,: 1.195 (0.015 below the manufacturer's fully charged nominal specific gravity or a battery charging current that had stabilized at a low value). This value is characteristic of a charged cell with adequate capacity. According to IEEE-450 (Ref 3), the specific gravity readings are based on a temperature of 77&deg;F (25&deg;C).
(continued)
DAEC                          B 3.8-60                           ~ --)-+ Amendment 22d, 1
                                                !TSCR-183

Battery Cell Parameters B 3.8.6 BASES SURVEILLANCE Table 3.8.6-1 (continued)
REQUIREMENTS The specific gravity readings are corrected for actual electrolyte temperature and level. For each 3&deg;F (1.67&deg;C) above 77&deg;F (25&deg;C),
1 point (0.001) is added to the reading; 1 point is subtracted for each 3&deg;F below 77&deg;F. The specific gravity of the electrolyte in a cell increases with a loss of water due to electrolysis or evaporation. Level correction will be in accordance with manufacturer's recommendations.
Category B defines the normal parameter limits for each connected cell. The term "connected cell" excludes any battery cell that may be jumpered out.
* The Category B limits specified for electrolyte level and float voltage are the same as those specified for Category A and have been discussed above. The Category B limit specified for specific gravity for each connected cell is ;::: 1.190 (0.020 below the manufacturer's fully charged, nominal specific gravity) with the average of all connected cells 1.200 (0.010 below the manufacturer's fully charged, nominal specific gravity). These values are based on manufacturer's recommendations. The minimum specific gravity value required for each cell ensures that the effects of a highly charged or newly installed cell do not mask overall degradation of the battery.
Category C defines the limits for each connected cell. These values, although reduced, provide assurance that sufficient capacity exists to perform the intended function and maintain a margin of safety. When any battery parameter is outside the Category C limits, the assurance of sufficient capacity described above no longer exists, and the battery must be declared inoperable.
The Category C limit specified for electrolyte level (above the top of the plates and not overflowing) ensures that the plates suffer no physical damage and maintain adequate electron transfer capability. The Category C Limit for voltage is based on IEEE-450 (Ref. 3), which states that a cell voltage of 2.07 V or below, under float conditions and not caused by elevated temperature of the cell, indicates internal cell problems and may require cell replacement.
(continued)
DAEC                          B 3.8-61                     .-
1
                                                             ->-   /\meREimeRt 223
                                                !TSCR-183

Battery Cell Parameters B 3.8.6 BASES SURVEILLANCE Table 3.8.6-1 (continued)
REQUIREMENTS The Category C limit on average specific gravity~ 1.190, is based on manufacturer's recommendations (0.020 below the manufacturer's recommended fully charged, nominal specific gravity). In addition to that limit, it is required that the specific gravity for each connected cell must be no less than 0.020 below the average of all connected cells. This limit ensures that the effect of a highly charged or new cell does not mask overall degradation of the battery.
The footnotes to Table 3.8.6-1 that apply to specific gravity are applicable to Category A, B, and C specific gravity. Footnote (b) of Table 3.8.6-1 requires the above mentioned correction for electrolyte level and temperature, with the exception that level correction is not required when battery charging current, while on float charge, is< 2 amps for station service batteries. This current provides, in general, an indication of overall battery condition.
Because of specific gravity gradients that are produced during the recharging process, delays of several days may occur while waiting for the specific gravity to stabilize. A stabilized charger current is an acceptable alternative to specific gravity measurement for determining the state of charge of the designated pilot cell. This phenomenon is discussed in IEEE-450 (Ref. 3). Footnote (c) to Table 3.8.6-1 allows the float charge current to be used as an alternate to specific gravity for up to 7 days following a battery recharge. Within 7 days, each connected cell's specific gravity must be measured to confirm the state of charge. Following a minor battery recharge (such as equalizing charge that does not follow a deep discharge) specific gravity gradients are not significant, and confirming measurements may be made in less than 7 days.
REFERENCES   1.      [Deleted]
: 2.      UFSAR, Chapter 15.
: 3.      IEEE Standard 450, 1987.
                                                                        !183 DAEC                         B 3.8-62 J
TSCR 044A

Distribution Systems       Shutdovm B 3.8.8 B 3.8 ELECTRICAL POWER SYSTEMS B 3.8.8 Distribution Systems       Shutdown BASES BACKGROUND            A dessription of the AG and DC Elestrisal Pm.tJer Distribution System is provided in the Bases for LGO d.8.7, "Distribution INSERT 3.8.8-1                 Systems       Operating."
APPLICABLE            The initial sonditions of Design Basis Aseident and transient SAFETY                analyses in the UFSAR, Chapter 15 (Ref. 1), assume Engineered ANALYSES              Safety feature (ESF) Systems are OPERABLE. The AC arid DC Electrical Power Distribution Systems are designed to provide sufficient capacity, capability, redundancy, and reliability to ensure the availability of necessa              ESF Systems so that the systems required to mitigate the consequences of a         The OPERABILITY of the AC and DC Electrical Power FHA.                      Distribution System is consistent with the initial assumptions of the accident analyses and the requirements for the supported systems' OPERABILITY.
The OPERABILITY of the minimum AC and DC electrical power sources and associated power distribution subsystems during MODES 4 and 5, and during movement of irradiated fuel assemblies in the secondary containment ensures that.;.
a:,     The faeility ean be maintained in the shutdown or refueling eondition for extended periods;
                               ~       Suffieient instrumentation and eontrol eapability is available for monitoring and maintaining the unit~status;   and     a
               !adequate           ~ ,
               '-----'-----&.-.---     ~ o w e r is provided to mitigat                  postulated during shutdown, sueh as a fuel handling accident.              ,r The AC and DC electrical power distribution systems satisfy Criterion 3 of 10 CFR 50.36(c)(2)(ii).
                                                                              !TSCR-183             !
:   (continued)
DAEC                                   B 3.8-74                           ~      ndment~

INSERT 83.8.8-1 The onsite Class 1E AC and DC electrical power distribution Page 1 of 1     system is divided into redundant and independent AC and DC essential bus electrical power distribution subsystems.
The primary AC Distribution System consists of two 4.16 kV essential buses each having an offsite source of power as well as a dedicated onsite Diesel Generator (DG) source. Each essential bus is normally connected to the startup transformer (1X3).
During a loss of the normal offsite power source to the essential buses, the alternate supply breaker from the standby transformer (1X4) attempts to close. If all offsite sources are unavailable, the onsite emergency DGs supply power to the essential buses.
The secondary distribution system includes 480 VAC emergency buses 183 and 184 and associated load centers, and transformers.
There are two independent 125 VDC electrical power distribution subsystems that support the necessary power for required safety functions.
The list of required distribution buses is presented in Table 8 3.8.8-1.

Distribution Systems    Shutdown B 3.8.8 BASES (continued)
LCO                  Various combinations of subsystems, equipment, and components are required OPERABLE by other LCOs, depending on the specific plant condition. Implicit in those requirements is the required OPERABILITY of necessary support required features. This LCO explicitly requires energization of the portions of the Electrical Distribution System necessary to support OPERABILITY of Technical Specifications required systems, equipment, and components - both specifically addressed by their own LCO, and implicitly required by the definition of OPERABILITY. In addition, it is acceptable for required buses to be cross-tied during shutdown sonditions, permitting a single source to supply multiple redundant buses, provided the source is capable of maintaining proper frequency (if required) and voltage.
maintain the facility r-~~~~~!~~~~~~~:~~
Maintaining e                   the Distribution System energized ensures the availability of sufficien po         operate the plant in a safe manner to mitigate the consequences of~ostu~d events during shutdovim (e.g., fuel handling accident5J.~
APPLICABILITY        The AC and DC electrical power distribution subsystems required to be OPERABLE in MODES 4 and 5 and during movement of irradiated fuel assemblies in the secondary containment provide assurance that-:-
Systems that provide sore sooling; systems
                                ~~~needed to mitigate a fuel handling accident are available+
                        &:-     Systems nesessary to mitigate the effests of events that san lead to sore damage during shutdmvn are available; aHa 4       Instrumentation and sontrol sapability is available for monitoring and maintaining the unit in a sold shutdown sondition or refueling sondition.
TSCR-183 DAEC                                  B 3.8-75

Distribution Systems       Sht:1tdown B 3.8.8 BASES (continued)
AP PLI CAB ILITY  The AG and DC electrical power distribt:1tion st:1bsystem (continued)     reqt:1irements for MODeS 1, 2, and a are severed in LGO a.8.7.
ACTIONS           LGO a.a.a is not applicable while in MODE <1 or 5. However, since irradiated ft:1el assembly movement can occt:1r in MODE 1, 2, or a, the Actions have been modified by a Note stating that LGO a.a.a is not applicable. If moving irradiated ~el assemblies while in MODE <1 or 5, LGO a.a.a 'Not:1ld not specify any action. If moving irradiated ft:1el assemblies while in MODE 1, 2, or a, the ft:1el movement is independent of reactor operations. Therefore, in either case, inability to st:1spend movement of irradiated ft:1el assemblies wot:1ld not be st:1fficient reason to reqt:1ire a reactor sht:1tdown.
                  ~
A.1., A.2-4; A.2.2, A.2.a, and A.2.<1                                     f' Although redundant required features may require redundant Divisions of electrical power distribution subsystems to be OPERABLE, one OPERABLE distribution subsystem division may be capable of supporting sufficient required features to allow continuation of GORE ALTERATIO~JS and fuel movement. By                   f-allowing the option to declare required features associated with an inoperable distribution subsystem inoperable, appropriate restrictions are implemented in accordance with the affected distribution subsystem LCO's Required Actions. In many instances this option may invo,lve undesired administrative efforts.
Therefore, the allowance for sufficiently conservative actions is made, (i.e., to suspend GORE ALTERATIONS t:tnd movement of irradiated fuel assemblies in the secondary containment).                {'
DAEC                              B 3.8-76

Distribution Systems        Sh1,1tElown B 3.8.8
                  !and      h BASES (continued)           /
ACTIONS           A.1.?.'2.1, /\.2.2, A.2.3, anEI /\.2.4 (continued)
Suspension of these activities shall not preclude completion of actions to establish a safe conservative condition. These actions minimize the probability of the occurrence of postulated events . .J.t is f1,1rther req1,1ireEI to immeEliately initiate astion to restore the req1,1ireEI /\C anEI DC elestrisal pm.ver Elistrib1,1tion s1,1bsystems anEI to sontin1,1e this astion 1,1ntil restoration is assomplisheEI in orEler to pro1JiEle the nesessary pmNer to the plant safety systems.
Not withstanEling periormanse of the abo1Je sonservati1Je Req1,1ireEI Astions, a req1,1ireEI ResiE11,1al Heat Remo1Jal ah1,1tElown Cooling *
(RHR aDC) s1,1bsystem may be inoperable. In this sase, Req1,1ireEI Astions /\.2.1 thro1,1gh A.2.3 Elo not aEleq1,1ately aEIElress the              ,r sonserns relating to soolant sirs1,1lation anEI heat remo1Jal.
P1,1rs1,1ant to LCO 3.0.6, the RHR SOC ACTIONa wo1,1IEI not be entereEI. Therefore, Req1,1ireEI Astion A.2.4 is pro1JiEleEI to Elirest         ,r Eleslaring RHR aDC inoperable, whish res1,1lts in taking the appropriate RHR aDC ACTIONS.
The Completion Time of immediately is consistent with the required times for actions requiring prompt attention. +Re restoration of the req1,1ireEI Elistrib1,1tion s1,1bsystems sho1,1IEI be sompletea as q1,1iokly as possible in orEler to minimize the time the plant safety systems may be witho1,1t power.
                                                                         !TSCR-183              !
:ontinued)
DAEC                                   B 3.8-77                               ~ment~

Distribution Systems     Shutdown B 3.8.8 BASES (continued)
SURVEILLANCE      SR 3.8.8.1 REQUIREMENTS This Surveillance verifies that the AC and DC electrical power distribution subsystems are functioning properly, with the correct circuit breaker alignment. The correct circuit breaker alignment ensures power is available to each required bus. The verification of energization of the buses ensures that the required power is readily available for motive as well as control functions for critical system loads connected to these buses. The Surveillance                }
Frequency is controlled under the Surveillance Frequency Control Program. The Frequency takes into account the redundant capability of the electrical power distribution subsystems, as well as other indications available in the control room that alert the operator to subsystem malfunctions.
REFERENCES        1.      UFSAR, Chapter 15.
INSERT 3.8.8-2 DAEC                              B 3.8-78
                                                                                ~
TSCR-42:G

INSERT 83.8.8-2 Page 1 of 1 Table B 3.8.8-1 (page 1 of 1)
AC and DC Electrical Power Distribution Systems TYPE              VOLTAGE             DIVISION 1(a)            DIVISION 2(a)
AC safety           4160V           Essential Bus 1A3        Essential Bus 1A4 buses 480V             Load Centers              Load Centers 183,189                 184, 1820 480V              Motor Control            Motor Control Centers                  Centers 1832, 1834               1842, 1844 125 voe buses            125 V          Distribution Panels        Distribution 1D10, 1D11,               Panels I        1D13               1D20, 1D21, 1D23 (a) Each division of the AC and DC electrical power distribution systems is a subsystem.}}