ML14316A606

PPL Susquehanna, LLC, Unit 1 & Unit 2 Proposed Technical Specification Amendment for Adoption of Task Force Traveler TSTF-425, Rev. 3, Relocate Surveillance Frequencies to Licensee Control Risk Informed Technical Specification Task Force...

ML14316A606
Person / Time
Site:	Susquehanna
Issue date:	10/27/2014
From:	Susquehanna
To:	Office of Nuclear Reactor Regulation
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ML14317A052	List: ML14316A605 ML14316A606 PLA-7119, PPL Susquehanna, LLC, Unit 1 & Unit 2 Proposed Technical Specification Amendment for Adoption of Task Force Traveler TSTF-425, Rev. 3, Relocate Surveillance Frequencies to Licensee Control Risk Informed Technical Specification Task Force...
References
PLA-7119 TSTF-425, Rev. 3
Download: ML14316A606 (429)

Text

Attachment 1 to PLA-7119 PPL Susquehanna, LLC, Unit 1 and Unit 2 Proposed Technical Specification Amendment for Adoption of Task Force Traveler TSTF-425, Revision 3, "Relocate Surveillance Frequencies to Licensee Control--Risk Informed Technical Specification Task Force (RITSTF) Initiative 5" 1. DESCRIPTION

2. PROPOSED CHANGES 3. BACKGROUND

4. TECHNICAL ANALYSIS 5. REGULATORY SAFETY ANALYSIS 5.1 No Significant Hazards Consideration Determination 5.2 Applicable Regulatory Requirements/Criteria

6. ENVIRONMENTAL CONSIDERATIONS

7. REFERENCES Attachment 1 to PLA-7119 Page 1 of 10 1.0 DESCRIPTION The proposed amendments would modify Susquehanna SES Units 1 and 2 Technical Specifications (TS) by relocating specific surveillance frequencies to a licensee-controlled program with the adoption of Technical Specification Task Force (TSTF)-425, Revision 3, "Relocate Surveillance Frequencies to Licensee Control--Risk Informed Technical Specification Task Force (RITSTF) Initiative 5." Additionally, the change would add a new program, the Surveillance Frequency Control Program, to TS Section 5.0, Administrative Controls.The changes are consistent with NRC approved Industry/TSTF STS change TSTF-425, Revision 3, (Rev. 3) (ADAMS Accession No. ML080280275).

The Federal Register notice published on July 6, 2009 announced the availability of this TS improvement.

2.0 PROPOSED CHANGES The proposed change relocates all periodic Surveillance Frequencies from the Technical Specifications and places the Frequencies under licensee control in accordance with a new program, the Surveillance Frequency Control Program. All Surveillance Frequencies are relocated except: " Frequencies that reference other approved programs for the specific interval (such as the Inservice Testing Program or the Primary Containment Leakage Rate Testing Program);" Frequencies that are purely event driven (e.g., "Each time the control rod is withdrawn to the 'full out' position");" Frequencies that are event-driven but have a time component for performing the surveillance on a onetime basis once the event occurs (e.g., "within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after thermal power reaching > 95% RTP"); and" Frequencies that are related to specific conditions (e.g., battery degradation, age, and capacity) or conditions for the performance of a surveillance requirement (e.g., "drywell to suppression chamber differential pressure decrease").

The definition of "Staggered Test'Basis" in Section 1.1, "Definitions," is deleted.A new Administrative Controls Program is added as Specification 5.5.15. The program is called the Surveillance Frequency Control Program and describes the requirements for a program to control changes to the relocated Surveillance Frequencies.

The Bases for each Surveillance are revised to state that the Frequency is set in accordance with the Surveillance Frequency Control Program. These Bases changes Attachment 1 to PLA-7119 Page 2 of 10 reflect the changes made to the Technical Specifications and do not substantially contribute to the understanding of the implementation of the proposed Technical Specification requirements.

Various editorial changes are made to the Bases as needed to facilitate the addition of the Bases changes.3.0 BACKGROUND The NRC has been reviewing and granting improvements to the Improved Standard Technical Specifications (ISTS) based, at least in part, on probabilistic risk analysis insights.

Typically, the proposed improvements involved a relaxation of one or more Completion Times or Surveillance Frequencies in the TS.In August 1995, the NRC adopted a final policy statement on the use of probabilistic risk assessment (PRA) methods, which included the following regarding the expanded use of PRA.* The use of PRA technology should be increased in all regulatory matters to the extent supported by the state of the art in PRA methods and data and in a manner that complements the NRC's deterministic approach and supports the NRC's traditional defense-in-depth philosophy.

• PRA and associated analyses (e.g., sensitivity studies, uncertainty analyses, and importance measures) should be used in regulatory matters, where practical within the bounds of the state of the art, to reduce unnecessary conservatism associated with current regulatory requirements, regulatory guides, licensee commitments, and staff practices.

Where appropriate, PRA should be used to support the proposal of additional regulatory requirements in accordance with 10 CFR 50.109 (Backfit Rule). Appropriate procedures for including PRA in the process for changing regulatory requirements should be developed and followed.

It is understood that the intent of this policy is that existing rules and regulations shall be complied with unless these rules and regulations are revised.PRA evaluations in support of regulatory decisions should be as realistic as practicable and appropriate supporting data should be publicly available for review.The Commission's safety goals for nuclear power plants and subsidiary numerical objectives are to be used with appropriate consideration of uncertainties in making regulatory judgments on need for proposing and backfitting new generic requirements on nuclear power plant licensees.

Attachment 1 to PLA-7119 Page 3 of 10 In its approval of the policy statement, the Commission articulated its expectation that implementation of the policy statement will improve the regulatory process in three areas: foremost, through safety decision making enhanced by the use of PRA insights; through more efficient use of agency resources; and through a reduction in unnecessary burdens on licensees.

4.0 TECHNICAL ANALYSIS The control of changes to the relocated Surveillance Frequencies will be in accordance with the Surveillance Frequency Control Program. That 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. In addition, 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.The referenced document, NEI 04-10, provides a detailed description of the process to be followed when considering changes to a Surveillance Frequency.

NEI 04-10 has been reviewed and approved by the NRC.Some Surveillance Frequencies are performed at a given periodicity on a STAGGERED TEST BASIS and are written similar to "18 months on a STAGGERED TEST BASIS." The phrase "on a STAGGERED TEST BASIS" is also relocated to the Surveillance Frequency Control Program and the defined term, which would no longer be used in the TS, is removed from Section 1.1. The purpose of specifying certain Surveillances to be performed on a STAGGERED TEST BASIS is to increase the reliability of the tested system by identifying common mode failures more quickly. Relocating the Frequency requirement to perform Surveillances on a STAGGERED TEST BASIS along with the periodicity allows licensees the flexibility to adjust the Frequency based on operational experience and risk assessment results.For example, a Frequency may be extended but include a new requirement to perform the Surveillance on a STAGGERED TEST BASIS to reflect a higher risk associated with common mode failures.

Conversely, a Frequency may be changed to eliminate a

Attachment 1 to PLA-7119 Page 4 of 10 requirement to perform the Surveillance on a STAGGERED TEST BASIS due to a lower risk or operational experience associated with common mode failure. NEI 04-10 contains information to support the correct risk modeling of Surveillance Frequencies with and without a requirement to perform the Surveillance on a STAGGERED TEST BASIS.The relocation of the specified Surveillance Frequencies to licensee control is consistent with Regulatory Guides 1. 174 and 1.177. Regulatory Guide 1.177 provides guidance for changing Surveillance Frequencies and Completion Times. However, for allowable risk changes associated with Surveillance Frequency extensions, it refers to Regulatory Guide 1.174, which provides quantitative risk acceptance guidelines for changes to core damage frequency (CDF) and large early release frequency (LERF).Regulatory Guide 1.174 provides additional guidelines that have been adapted in the risk-informed methodology for controlling changes to Surveillance Frequencies.

Regulatory Guide 1.174 identifies five key safety principles to be met for all risk-informed applications and to be explicitly addressed in risk-informed plant program change applications.

1. The proposed change meets the current regulations unless it is explicitly related to a requested exemption or rule change.10 CFR 50.36(c) provides that TS will include items in the following categories:

"(3) Surveillance requirements.

Surveillance requirements are requirements relating to test, calibration, or inspection to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met." This change proposes to relocate various Frequencies for the performance of the Surveillance Requirements to a licensee-controlled program using an NRC approved methodology for control of the Surveillance Frequencies.

The Surveillance Requirements themselves will remain in TS. This is consistent with other NRC approved TS changes in which the Surveillance Frequencies are not under NRC control, such as Surveillances that are performed in accordance with the Inservice Testing Program or the Primary Containment Leakage Rate Testing Program, where the Frequencies vary based on the past performance of the subject components.

Thus, this proposed change meets criterion 1 above.2. The proposed change is consistent with the defense-in-depth philosophy.

As described in Position 2.2.1.1 of Regulatory Guide 1.174, consistency with the defense-in-depth philosophy is maintained if:

Attachment 1 to PLA-7119 Page 5 of 10 a. A reasonable balance is preserved among prevention of core damage, prevention of containment failure, and consequence mitigation.

b. Over-reliance on programmatic activities to compensate for weaknesses in plant design is avoided.c. System redundancy, independence, and diversity are preserved commensurate with the expected frequency, consequences of challenges to the system, and uncertainties (e.g., no risk outliers).

d. Defenses against potential common cause failures are preserved, and the potential for the introduction of new common cause failure mechanisms is assessed.e. Independence of barriers is not degraded.f. Defenses against human errors are preserved.

g. The intent of the General Design Criteria in 10 CFR Part 50, Appendix A is maintained.

These defense-in-depth objectives apply to all risk-informed applications, and for some of the issues involved (e.g., no over-reliance on programmatic activities and defense against human errors), it is straightforward to apply them to this proposed change. The use of the multiple risk metrics of CDF and LERF and controlling the change resulting from the implementation of this initiative would maintain a balance between prevention of core damage, prevention of containment failure, and consequence mitigation.

Redundancy, diversity, and independence of safety systems are considered as part of the risk categorization to ensure that these qualities are not adversely affected.

Independence of barriers and defense against common cause failures are also considered in the categorization.

The improved understanding of the relative importance of plant components to risk resulting from the development of this program promotes an improved overall understanding of how the SSCs contribute to the plant's defense-in-depth.

3. The proposed change maintains sufficient safety margins.Conformance with this principle is assured since SSC design, operation, testing methods, and acceptance criteria specified in the Codes and Standards or alternatives approved for use by the NRC will continue to be met as described in the plant licensing basis (e.g., FSAR, or Technical Specifications Bases). Also, the safety analysis acceptance criteria in the licensing basis (e.g., FSAR, supporting analyses, etc.) are met with the proposed change.4. When proposed changes result in an increase in core damage frequency or risk, the increases should be small and consistent with the intent of the Commission's Safety Goal Policy Statement.

Attachment 1 to PLA-7119 Page 6 of 10 NEI 04-10, "Risk-Informed Method for Control of Surveillance Frequencies," requires that changes in core damage frequency or risk are small and consistent with the intent of the Commission's Safety Goal Policy.5. The impact of the proposed change should be monitored using performance measurement strategies.

NEI 04-10 requires that changes in Surveillance Frequencies be monitored using performance management strategies.

Therefore, the proposed change is consistent with the guidance in Regulatory Guide 1.174.5.0 REGULATORY SAFETY ANALYSIS 5.1 No Si2nificant Hazards Consideration Determination PPL has reviewed the proposed no significant hazards consideration determination (NSHC) published in the Federal Register July 6, 2009 (74 FR 31996 -32006). PPL has concluded that the proposed NSHC presented in the Federal Register notice is applicable to Susquehanna Steam Electric Station Units 1 and 2 and is provided below.Description of Amendment Request: The change requests the adoption of an approved change to the standard technical specifications (STS) for General Electric Plants, BWR/4 (NUREG-1433), to allow relocation of specific TS surveillance frequencies to a licensee-controlled program. The proposed change is described in Technical Specification Task Force (TSTF) Traveler, TSTF-425, Revision 3 (Rev. 3) (ADAMS Accession No.ML080280275) related to the Relocation of Surveillance Frequencies to Licensee Control--RITSTF Initiative 5b and was described in the Notice of Availability published in the Federal Register on July 6, 2009 (74 FR 31996 -32006).The proposed changes are consistent with NRC-approved Industry/Technical Specification Task Force (TSTF) Traveler, TSTF-425, Rev. 3, "Relocate Surveillance Frequencies to Licensee Control--RITSTF Initiative 5b." The proposed change relocates surveillance frequencies to a licensee-controlled program, the SFCP. This change is applicable to licensees using probabilistic risk guidelines contained in NRC-approved NEI 04-10, "Risk-Informed Technical Specifications Initiative 5b, Risk-Attachment 1 to PLA-7119 Page 7 of 10 Informed Method for Control of Surveillance Frequencies," (ADAMS Accession No. 071360456).

Basis for proposed no significant hazards consideration:

As required by 10 CFR 50.91 (a), the PPL analysis of the issue of no significant hazards consideration is presented below: 1. Does the proposed change involve a significant increase in the probability or consequences of any accident previously evaluated?

Response:

No.The proposed change relocates the specified frequencies for periodic surveillance requirements to licensee control under a new Surveillance Frequency Control Program. Surveillance frequencies are not an initiator to any accident previously evaluated.

As a result, the probability of any accident previously evaluated is not significantly increased.

The systems and components required by the technical specifications for which the surveillance frequencies are relocated are still required to be operable, meet the acceptance criteria for the surveillance requirements, and be capable of performing any mitigation function assumed in the accident analysis.

As a result, the consequences of any accident previously evaluated are not significantly increased.

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 previously evaluated?

Response:

No.No new or different accidents result from utilizing the proposed change.The changes do not involve a physical alteration of the plant (i.e., no new or different type of equipment will be installed) or a change in the methods governing normal plant operation.

In addition, the changes do not impose any new or different requirements.

The changes do not alter assumptions made in the safety analysis.

The proposed changes are consistent with the safety analysis assumptions and current plant operating practice.Therefore, the proposed changes do not create the possibility of a new or different kind of accident from any accident previously evaluated.

Attachment 1 to PLA-7119 Page 8 of 10 3. Does the proposed change involve a significant reduction in the margin of safety?Response:

No.The design, operation, testing methods, and acceptance criteria for systems, structures, and components (SSCs), specified in applicable codes and standards (or alternatives approved for use by the NRC) will continue to be met as described in the plant licensing basis (including the final safety analysis report and bases to TS), since these are not affected by changes to the surveillance frequencies.

Similarly, there is no impact to safety analysis acceptance criteria as described in the plant licensing basis. To evaluate a change in the relocated surveillance frequency, PPL will perform a risk evaluation using the guidance contained in NRC approved NEI 04-10, Rev. 1 in accordance with the TS SFCP. NEI 04-10, Rev. 1, methodology provides reasonable acceptance guidelines and methods for evaluating the risk increase of proposed changes to surveillance frequencies consistent with Regulatory Guide 1.177.Therefore, the proposed changes do not involve a significant reduction in a margin of safety.Based upon the reasoning presented above, PPL concludes that the requested change does not involve a significant hazards consideration as set forth in 10 CFR 50.92(c), Issuance of Amendment.

5.2 Applicable Regulatory Requirements/Criteria Section 182a of the Atomic Energy Act of 1954, as amended (the Act)requires applicants for nuclear power plant operating licenses to include the TS as part of the license. The Commission's regulatory requirements related to the content for the TS are set forth in 10 CFR 50.36. That regulation requires that the TS include items in eight specific categories.

The categories are: (1) safety limits, limiting safety system settings, and limiting control settings; (2) limiting conditions for operation; (3)surveillance requirements; (4) design features; (5) administrative controls;(6) decommissioning; (7) initial notification; and (8) written reports.However, the regulation does not specify the particular requirements to be included in a plant's TS.The proposed change is consistent with other Surveillance Frequencies in the ISTS. In several instances, the ISTS do not specify a particular Attachment 1 to PLA-7119 Page 9 of 10 surveillance Frequency but rather state the Frequency as "In accordance with the Inservice Testing Program." The Inservice Testing (IST) Program referencesSection XI of the ASME Boiler and Pressure Vessel Code for the surveillance intervals.

The surveillance intervals are based on the plant's IST Program, which implements the ASME Code. Within the IST program, the actual surveillance intervals vary based on the performance of the individual components.

In other instances, the TS again do not specify a particular surveillance Frequency but instead require that the surveillance be performed "in accordance with the Primary Containment Leakage Rate Testing Program." The Primary Containment Leakage Rate Testing Program references 10 CFR 50, Appendix J, Option B, which allows performance based testing. The surveillance Frequency varies based on the past performance of the subject components.

The proposed TS changes are administrative in nature. Relocation of the Surveillance Frequencies from the TS to a licensee-controlled program does not affect the plant design, hardware, or system operation and will not affect the ability of the plant to perform its design function in mitigating the consequences of a postulated design basis accident.

Therefore, the proposed change does not adversely affect nuclear safety or plant operations.

In conclusion, 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 approval of the proposed change will not be inimical to the common defense and security or to the health and safety of the public.6.0 ENVIRONMENTAL CONSIDERATION A review has determined that the proposed change 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 change 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 change meets the eligibility criterion for categorical exclusion set forth in 10 CFR 51.22(c)(9).

Therefore, pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the proposed change.

7.0 REFERENCES

Attachment 1 to PLA-7119.Page 10 of 10 7.1. USNRC, "Use of Probabilistic Risk Assessment Methods in Nuclear Activities:

Final Policy Statement," Federal Register, Vol. 60, p. 42622, August 16, 1995.7.2. Regulatory Guide 1.174, Revision 1, "An Approach for using Probabilistic Risk Assessment in Risk-Informed Decisions On Plant-Specific Changes to the Licensing Basis," November 2002.7.3. Regulatory Guide 1.177, "An Approach for Plant-Specific Risk-Informed Decisionmaking:

Technical Specification," August 1998.

Attachment 2 to PLA-7119 Documentation of PRA Technical Adequacy SUSQUEHANNA PRA TECHNICAL ADEQUACY ASSESSMENT Attachment 2 to PLA-7119 Page 2 of 69 TABLE OF CONTENTS 1.0 O V ER V IE W .....................................................................................................

3 2.0 PRA TECHNICAL ADEQUACY .......................................................................

5 2.1 PRA REPRESENTS THE AS-BUILT, AS-OPERATED PLANT ................

5 2.2 PERMANENT PLANT CHANGES NOT INCORPORATED IN THE PRA.. 7 2.3 IDENTIFICATION OF KEY ASSUMPTIONS AND APPROXIMATIONS..

7 2.4 IDENTIFICATION OF PARTS OF PRA NOT MEETING CAPABILITY C A T E G O R Y II ................................................................................................

7 2.5 ADDITIONAL PEER REVIEW FACTS AND OBSERVATIONS

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

9 3.0 EVALUATION OF CHANGES FOR EXTERNAL EVENTS A N D SH U TD O W N ..............................................................................................

9 4 .0 SU M M A R Y ...........................................................................................................

12 5.0 R E FE R E N C E S .......................................................................................................

12 Attachment 2 to PLA-7119 Page 3 of 69 1.0 OVERVIEW The implementation of the Surveillance Frequency Control Program (also referred to as Tech Spec Initiative 5b) at Susquehanna will follow the guidance provided in NEI 04-10, Revision 1 [Ref. 1] in evaluating proposed surveillance test interval (STI) changes.The following steps of the risk-informed STI revision process are common to proposed changes to all STIs within the proposed licensee-controlled program." Review each candidate STI revision to determine whether there are any NRC or other commitments that may prohibit changing the interval.

If there are no related commitments, or if it is determined that the commitments may be changed using an approved commitment change process, then evaluation of the candidate STI revision may proceed. If a commitment exists and the commitment change process does not permit the change, then the candidate STI revision may not be implemented." Perform a qualitative analysis that involves applicable considerations as explained in NEI 04-10, Revision 1." Perform a risk assessment in accordance with NEI 04-10.When possible use the Probabilistic Risk Assessment (PRA)to quantify the effect of the candidate STI revision.

The results are compared to the acceptance criteria in NEI 04-10.Also, the cumulative impact of all risk-informed STI revisions is compared to the acceptance criteria in NEI 04-10. For those cases where the STI cannot be modeled in the plant PRA or where a particular PRA model does not exist for a given hazard group, a qualitative or bounding analysis is performed to determine if justification for the acceptability of the proposed test interval change can be provided." Conduct an Integrated Decision Making Panel (IDP) review.The IDP is an expert panel consisting of the Maintenance Rule Expert Panel with the addition of specialists with experience in surveillance tests and system or component reliability.

The STI revision may be implemented with IDP approval.

Attachment 2 to PLA-7119 Page 4 of 69* Performance monitoring is conducted as recommended by the IDP. The performance monitoring is intended to identify if the STI revision results in unintentional degraded reliability.

In some cases no additional monitoring may be necessary beyond that already conducted under the Maintenance Rule." The IDP conducts periodic reviews of the performance monitoring results. If it is determined that a STI extended under this process is a factor in unsatisfactory surveillance results, the IDP returns the STI back to the previous STI.The NEI 04-10 methodology endorses the guidance provided in Regulatory Guide 1.200, "An Approach for Determining the Technical Adequacy of Probabilistic Risk Assessment Results for Risk-Informed Activities," [Ref. 2]. The guidance in RG- 1.200 indicates that the following steps should be followed when performing PRA assessments:

1. Identify the parts of the PRA used to support the application

-SSCs, operational characteristics affected by the application and how these are implemented in the PRA model.-A definition of the acceptance criteria used for the application.

2. Identify the scope of risk contributors addressed by the PRA model-If not full scope (i.e. internal and external), identify appropriate compensatory measures or provide bounding arguments to address the risk contributors not addressed by the model.3. Summarize the risk assessment methodology used to assess the risk of the application

-Include how the PRA model was modified to appropriately model the risk impact of the change request.4. Demonstrate the Technical Adequacy of the PRA-Address the need for the PRA model to represent the as-built, as-operated plant.-Identify permanent plant changes (physical or operational practices) that have an impact on the PRA but have not been incorporated in the baseline PRA model.-Identify key assumptions and approximations relevant to the results used in the decision-making process.

Attachment 2 to PLA-7119 Page 5 of 69-Document that the parts of the PRA required to produce the results used in the decision are performed consistently with the ASME/ANS PRA standard [Ref. 3] as endorsed in the appendices of Regulatory Guide 1.200. This includes the identification of the use of parts to the PRA that conform to capability categories lower than deemed required for a given application.

-Document additional peer review facts and observations that are applicable to the parts of the PRA required for the application, and for those that have not yet been addressed justify why the significant contributors would not be impacted.Because of the broad scope of potential Initiative 5b applications and the fact that the parts and scope of the PRA differs from application to application, each of the issues encompassed in Items 1 through 3 will be covered with the preparation of each individual PRA assessment made in support of the individual STI interval requests.

The purpose of the remaining portion of this report is to address the requirements identified in item 4 above. An overview of the planned approach for addressing external events and shutdown risk is also provided.2.0 PRA TECHNICAL ADEQUACY This portion of the assessment addresses the items identified in RG-1.200 to demonstrate the technical adequacy of the PRA. This includes the following items:* PRA represents the as-built, as operated plant* Permanent plant changes not incorporated in the PRA* Identification of key assumptions and approximations

• Identification of parts of PRA not meeting Capability Category II* Additional peer review facts and observations Each of these items is discussed in turn.2.1 PRA REPRESENTS THE AS-BUILT, AS-OPERATED PLANT The JUL 12R 1 update to the Susquehanna PRA model is the most recent evaluation of the risk profile at Susquehanna for internal event challenges

[Ref.10]. The Susquehanna PRA model is highly detailed, including a wide variety of initiating events, modeled systems, operator actions, and common cause events.The PRA model quantification process used for the Susquehanna PRA is based on the event tree/fault tree methodology, which is a well-known methodology in the Attachment 2 to PLA-7119 Page 6 of 69 industry.

PPL employs a structured approach to establishing and maintaining the technical adequacy and plant fidelity of the PRA model for both Susquehanna operating units. This approach includes both a proceduralized PRA maintenance and update process, and the use of self-assessments and independent peer reviews.The following information describes this approach as it applies to the Susquehanna PRA.PRA Maintenance and Update The PPL PRA maintenance and update process ensures that the applicable PRA model remains an accurate reflection of the as-built and as-operated plants. This process is defined in PPL administrative procedure NDAP-QA-1002

[Ref. 9] and a subordinate implementing procedure.

PPL procedure NFP-QA-201, "Internal Events At Power PRA Model Update and Configuration Control Process," delineates the responsibilities and guidelines for updating the full power internal events PRA model for Susquehanna Units 1 and 2 [Ref. 8]. The overall model update process, including NFP-QA-201, defines the process for implementing regularly scheduled and interim PRA model updates, for tracking issues identified as potentially affecting the PRA models (e.g., due to changes in the plant, errors or limitations identified in the model, industry operating experience), and for controlling the model and associated computer files. To ensure that the current PRA model remains an accurate reflection of the as-built, as-operated plants, the following activities are routinely performed:

o Design changes and procedure changes are reviewed for their impact on the PRA model.o New engineering calculations and revisions to existing calculations are reviewed for their impact on the PRA model.o Maintenance unavailabilities are captured, and their impact on CDF is assessed.o Plant specific initiating event frequencies, failure rates, and maintenance unavailabilities are updated at least every 6 years.In accordance with this guidance, regularly scheduled PRA model updates occur at least every six years with more frequent updates occurring based on the risk significance of permanent changes, initiating events, and failure data such that the PRA continues to adequately represent the as-built, as-operated plant.PPL implemented the JUL 12R1 update to the Susquehanna PRA in January 2014.This update incorporated resolution of comments received from the industry peer review of the Susquehanna PRA conducted in October 2012.

Attachment 2 to PLA-7119 Page 7 of 69 2.2 PERMANENT PLANT CHANGES NOT INCORPORATED IN THE PRA PPL's PRA maintenance and update process requires permanent plant changes to be assessed for model impacts. A risk model impact evaluation (RMIE) is created for all issues that are identified that could impact the PRA model. Each RMIE and assessment is tracked in the RMIE database.

As of this submittal, there are no modifications or procedure changes which will require a PRA change. As part of the PRA evaluation for each STI change request, a review of open items in the RMIE database will be performed and an assessment of the impact on the results of the application will be made prior to presenting the results of the risk analysis to the IDP. If a non-trivial impact is expected, then this may include performance of additional sensitivity studies or model changes to confirm the impact on the risk analysis.2.3 IDENTIFICATION OF KEY ASSUMPTIONS AND APPROXIMATIONS The overall Initiative 5b process is a risk-informed process with the PRA model results providing one of the inputs to determine if an STI change is warranted.

The methodology recognizes that a key area of uncertainty for this application is the standby failure rate utilized in the determination of the STI extension impact.Therefore, the NEI 04-10 methodology requires the performance of selected sensitivity studies on the standby failure rate of the component(s) of interest for the STI assessment.

The results of the standby failure rate sensitivity study plus the results of any additional sensitivity studies identified during the performance of the reviews for each STI change assessment will be documented and included in the results of the risk analysis submitted to the IDP. These additional sensitivity studies are identified through a review of identified gaps to Capability Category II as required by NEI 04-10, Steps 5 and 14, and a review of the sources of uncertainty identified in the PRA model quantification summary notebook [Ref. 10].2.4 IDENTIFICATION OF PARTS OF PRA NOT MEETING CAPABILITY CATEGORY II PPL has had PRA Peer Reviews performed in 2003 and in 2012. The 2012 peer review was performed in October 2012 using the NEI 05-04 process, the ASME PRA Standard (ASME/ANS RA-Sa-2009), and Regulatory Guide 1.200, Revision 2. The 2012 Susquehanna PRA Peer Review was a full-scope review of the technical elements of the internal events and internal flooding, at-power PRA.The 2012 peer review resulted in 284 (89%) Supporting Requirements (SRs)meeting Capability Category II or higher, and 35 (11%) of the SRs not meeting Capability Category (CC) II or higher. Note that of the 35 SRs not meeting CC II Attachment 2 to PLA-7119 Page 8 of 69 or higher, 24 were associated with the internal flooding technical element.Therefore, excluding internal flooding, more than 95% of the SRs met CC II or higher. Table 1 lists all the SRs that do not meet CC II or higher and lists the SR, F&O gap with Significance, Resolution, and PRA Model Impact.PRA Impact from Internal Events The peer review model and documentation were revised as described in the"Resolution" column. The revised model has been renamed JUL 12R I [Ref. 10].Upon completion of the JUL12R I model, excluding the internal flooding SRs, there are only 4 open item SRs, that do not meet CC II or higher. These SRs are HR-C3, DA-C6, DA-C12, and DA-C13. As noted in Table 1, these SRs have been evaluated and determined to be documentation enhancements and/or have negligible effect on the technical aspects or quantification of the risk model.Additionally, it is noteworthy that there were ten best practices provided by the peer review team indicating the high level of quality of the Susquehanna PRA model.PRA Impact from Internal Flooding As noted in Table 1, several of the internal flooding SRs did not meet Category II requirements.

However, internal flooding is not a significant contributor to CDF and LERF for Susquehanna.

The PRA Quantification Summary Notebook [Ref.10] lists internal flooding as contributing 4.6% to CDF and 1.9% to LERF and provides a comparison to Limerick Generating Station. Limerick is a very similar two-unit plant design but with the following notable hardware and operational differences.

• Limerick has four EDGs per unit whereas Susquehanna has four shared EDGs.0 Susquehanna has a spare 'E' EDG and also maintains the Blue Max portable DG.a Limerick has procedural direction to cross-tie the 4.kV buses to get power from available EDGs to the safeguard buses as needed.0 Susquehanna does not inhibit ADS in non-ATWS scenarios whereas Limerick does direct inhibiting ADS in non-ATWS scenarios (both sites direct inhibiting ADS in ATWS scenarios).

a ECCS pump cooling and ECCS room cooling are normally supplied by SW at Limerick with backup provided by ESW. ECCS pump and room cooling is only provided by ESW at Susquehanna.

Attachment 2 to PLA-7119 Page 9 of 69 Other than the major differences highlighted above, the sites are very similar. The two sites are dual unit sites and have General Electric BWR/4 reactors.

Bechtel was the architect engineer for both sites and the two sites are similar architecturally.

Therefore, with the plant layouts being similar, similar internal flooding results can be expected.

Limerick's flooding contribution to CDF and LERF as 5.9% and 3.6% respectively, which is comparable to Susquehanna's flooding contribution.

It should also be noted that Limerick had only a few flooding SRs not meeting Capability Category II [Ref. 11]. Based on this industry comparison and small contribution of internal flooding to overall CDF and LERF, the Susquehanna internal flooding PRA can be applied to support the STI frequency change program. While the JUL 12R1 PRA model supports this application, PPL is addressing the internal flooding F&Os through a focused model update.2.5 ADDITIONAL PEER REVIEW FACTS AND OBSERVATIONS Table 2 lists all the SRs meeting CC II or higher for which an F&O was written.Similar to Table 1, it also lists the SR, F&O gap with Significance, Resolution, and PRA Model Impact. As can be seen, all of the remaining facts and observations have been closed, or have otherwise been determined to have no or negligible impact on the PRA model results.3.0 EVALUATION OF CHANGES FOR EXTERNAL EVENTS AND SHUTDOWN The SSES PRA is a Level 1 and 2 model that includes internal events and internal floods. For external events such as fire, seismic, and other external events, the risk assessments from the IPEEE [4] can be used for insights on changes to surveillance intervals.

The status of available information for external events (internal fires, seismic, and other external hazards) as well as shutdown risk is provided below. The proposed use of this information in the context of the surveillance frequency change evaluations is then also provided.3.1 INTERNAL FIRES The SSES plant risk due to internal fires was evaluated in 1994 as part of the SSES Individual Plant Examination for External Events (IPEEE) submittal

[4].The results were amended based on the NRC audit of the IPEEE. PPL document PLA-4983 [5] summarizes the results of the audit on the fire analysis in addition to the updated conclusions of the seismic analysis.

Attachment 2 to PLA-7119 Page 10 of 69 The SSES fire analysis was performed using the methodology prescribed in the PRA Procedures Guide [6], which produced results similar to those yielded by the IPE internal events analysis.

While the fire analysis did yield a CDF, the intent of the analysis was to identify the most risk significant fire areas in the plant using a screening process and by calculating conservative core damage frequencies for fire scenarios.

Additionally, the analysis at the time was based on PRA modeling techniques that have since been upgraded to more acceptable standards.

As such, the accident sequence frequencies calculated for the SSES fire PRA are not a best estimate calculation of plant fire risk and are not acceptable for integration with the best estimate SSES internal events PRA results.In summary, the use of the available fire risk information from the IPEEE is limited, but the NEI 04-10 methodology allows a qualitative screening or bounding analysis to provide justification for acceptability of proposed surveillance frequency changes as described in Section 3.5 below.3.2 SEISMIC RISK The SSES seismic risk analysis was perfornmed as part of the IPEEE [4]. SSES performed a seismic margins assessment (SMA) following the guidance of EPRI NP-6041 [7]. The SMA is a deterministic evaluation process that does not calculate risk on a probabilistic basis. No core damage frequency sequences were quantified as part of the seismic risk evaluation.

The final results of the seismic analysis are documented in the SSES response to audit issues on the IPEEE submittal

[5]. While many of the same results were provided in the IPEEE submittal, the SSES Response to Audit Issues provides a more complete description of the actions taken by PPL to close out the seismic related issues at the site.3.3 OTHER EXTERNAL EVENTS RISK In addition to internal fires and seismic events, the SSES IPEEE Submittal analyzed a variety of other external hazards:* High Winds/Tornadoes

• External Floods* Transportation and Nearby Facility Accidents The SSES IPEEE analysis of high winds, tornadoes, external floods, transportation accidents, and nearby facility accidents was accomplished by reviewing the plant environs against regulatory requirements regarding these hazards. Based upon this review, it was concluded that SSES meets the applicable NRC Standard Review Attachment 2 to PLA-7119 Page 11 of 69 Plan requirements and therefore has an acceptably low risk with respect to these hazards.3.4 SHUTDOWN RISK SSES does not maintain a shutdown PRA model. Consistent with the NEI 04-10, Revision 1 guidance, qualitative information must be developed that supports the acceptability of the STI change with respect to the shutdown risk or it must be screened as not having an impact on the CDF and LERF metrics.3.5 SURVEILLANCE FREQUENCY CHANGE EVALUATIONS PPL is committed to evaluating changes to surveillance frequencies in accordance with the guidance provided in NEI 04-10, Revision 1. The NEI 04-10 methodology allows a qualitative screening or bounding analysis to provide justification for acceptability of proposed surveillance frequency changes. Since the SSES PRA model does not currently include shutdown conditions, internal fires, and other external events, the NEI 04-10 guidance will be used to evaluate the potential risk impact of shutdown conditions and external events associated with the surveillance frequency changes. Specifically, external event information from the SSES IPEEE report will be reviewed and qualitatively assessed based on engineering judgment to determine the impact of the external events on proposed surveillance frequency changes. If the qualitative information is deemed not to be sufficient then a bounding analysis will be performed.

PPL will perform bounding analysis in accordance with Step 10b, Bounding Analysis (below 1E-07/yr CDF and 1E-08/yr LERF), of NEI 04-10 Revision 1, which states, in part: If the ACDF and ALERF values have been demonstrated to be very small from an internal events perspective based on detailed analysis of the impact of the SSC being evaluated for the STI change, and if it is known that the CDF or LERF impact from external events (or shutdown events as applicable) is not specifically sensitive to the SSC being evaluated (by qualitative reasoning), then the detailed internal events evaluations and associated required sensitivity cases can be used to bound the potential impact from external events and shutdown PRA model contributors.

As another example, if the ACDF and ALERF values have been demonstrated to be very small from an internal events perspective based on detailed analysis of the impact of the SSC being evaluated for the STI change, and if it is known that the plant CDF and LERF results of the external event or shutdown PRA are much smaller than the corresponding values for the internal event full power PRA, (that is, less than 10%), then the results of the internal events analysis alone would suffice for the STI consideration.

Attachment 2 to PLA-7119 Page 12 of 69 This example is likely to be applicable for a situation where the SSC associated with the STI change is modeled in the internal event full power PRA, but not in the external event or shutdown PRA.Information regarding the external events and shutdown risk impacts will be summarized in the documented PRA assessments for each STI change and provided to the IDP.4.0

SUMMARY

The Susquehanna PRA maintenance and update processes and technical capability evaluations described above provide a robust basis for concluding that the PRA is suitable for use in risk-informed processes such as that proposed for the implementation of a Surveillance Frequency Control Program. As indicated above, in addition to the standard set of sensitivity studies required per the NEI 04-10 methodology, open items for changes at the site and remaining gaps to specific requirements in the PRA standard will be reviewed to determine which, if any, would merit application-specific sensitivity studies in the presentation of the application results.

5.0 REFERENCES

[1] Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies, Industry Guidance Document, NEI 04-10, Revision 1, April 2007.[2] Regulatory Guide 1.200, An Approach for Determining the Technical Adequacy of Probabilistic Risk Assessment Results for Risk Informed Activities, Revision 2, March 2009.[3] American Society of Mechanical Engineers, Standard for Probabilistic Risk Assessment for Nuclear Power Plant Applications, (ASME RA-Sa-2009), Addenda to ASME/ANS RA-S-2008, Standard for Level 1/Large Early Release Frequency Probabilistic Risk Assessment for Nuclear Power Plant Applications, February 2009.[4] PPL (Pennsylvania Power and Light), Susquehanna Steam Electric Station Individual Plant Examination for External Events, June 1994.[5] PPL (Pennsylvania Power and Light), Susquehanna Steam Electric Station Response to Audit Issues on IPEEE Submittal Units ] and 2, PLA-4983, October 1998.[6] Hickman, J. W., et al., PRA Procedures Guide, NUREG/CR-2300, January 1983.

Attachment 2 to PLA-7119 Page 13 of 69[7] EPRI (Electric Power Research Institute), A Methodology for Assessment of Nuclear Power Plant Seismic Margin, EPRI NP-6041 Revision 1, August 1991.[8] NFP-QA-201, "Internal Events at Power PRA Model Update and Configuration Control Process," Rev. 0.[9] NDAP-QA- 1002, "Maintenance and Update of the Susquehanna PRA," Rev. 1.[10] EC-RISK- 1164, Rev. 0, "Summary Notebook for the JUL12R1 PRA Model."[11] Limerick Generating Station Units 1 and 2, License Amendment Request Supplemental Information, Proposed Changes to Technical Specifications Sections 3.5.1, 3.6.2.3, 3.7.1.1, 3.7.1.2, and 3.8.1.1 to Extend Allowed Outage Times, ML101670319, June 16, 2010.

Attachment 2 to PLA-7119 Page 14 of 69 TABLE 1 SUPPORTING REQUIREMENTS NOT MEETING CAPABILITY CATEGORY II OR GREATER SUPPORTING F&O #, DESCRIPTION OF GAP, AND RESOLUTION MODEL REQUIREMENT SIGNIFICANCE IMPACT IE-A5 4-4: It appears that some maintenance Each system had None, gap has (Met Cat I) rule systems may need to be evaluated in been evaluated but been closed for order to complete the systematic the documentation the JUL 12R1 evaluation of each system, including was not specifically model.support systems, to assess the possibility included.of an initiating event occurring due to a Therefore, a failure of the system. Maintenance Rule This is a finding because the SR requires System Table and that all systems must be evaluated.

Initiating Event evaluation was The requirement is to perform a eviledtin w systematic evaluation of EACH system, Section 2.8 of the including support systems, to assess the IE Notebook possibility of an initiating event occurring due to a failure of the system.Not all maintenance rule plant systems appear to be identified as having been evaluated.

IE-A5 6-29: A systematic approach to identify Additional None, gap has (Met Cat I) initiating events is documented in Section discussion about been closed for 2.4-5 and appears to be reasonably loss of 13.8 and 4 the JUL12R1 complete.

However, no discussion on the kV transformers model.effects of a loss of a single 13.8/4.16kw was added to transformer was found in the initiating Section 2.4.5 of the events notebook.

IE Notebook to Refer to Section 2.4 of the IE Notebook address this F&O.for systems reviewed.

It appears that some maintenance rule systems may need to be evaluated and therefore it does not meet CCII. However, a qualitative evaluation was performed to determine the systems that cause initiating events, but some systems were not explicitly addressed.

This is a suggestion as discussions with Susquehanna PRA staff indicate that loss of a trnaformer would not result in a plant trip or need for a shutdown.

Attachment 2 to PLA-7119 Page 15 of 69 TABLE 1 SUPPORTING REQUIREMENTS NOT MEETING CAPABILITY CATEGORY II OR GREATER SUPPORTING F&O #, DESCRIPTION OF GAP, AND RESOLUTION MODEL REQUIREMENT SIGNIFICANCE IMPACT SC-A5 1-12: There was no evidence presented To address this None, gap has (Not Met) that would indicate that an evaluation F&O, a new section been closed for was performed to determine if certain 2.1.17 was added to the JUL12R1 accident sequences should be extended the event tree and model.beyond 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. Such an evaluation success criteria should include: notebookoutlining A) Instances where there will be an the dominant eventual depletion of finite inventory considerations injection sources (RWST/CST).

contributing to the 3) Justification for why room cooling 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> PRA ID Jmission time. The dependencies are not necessary for cases where room temperatures will exceed outineso equipment functionality or isolation sytem se temperatures after 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. sy lstems/equipment with less than a 24 C) Justification for not extending the hour mission time.mission times for systems that are required to support long term DHR beyond the 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> mark.This is a finding because the SR is considered to be not met.SC-A5 1-23: The EDG mission time is 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. This open item (Not Met) This is conservative compared to many Open item is a provided plants which use the convolution integral suggestion for method to justify a much shorter mission possible time. This is helpful for the improvement enhancement of MSPI margin, and does not by This is a suggestion because it is a itself result in modeling enhancement.

SCA5 not being met.Therefore, there is no model impact Attachment 2 to PLA-7119 Page 16 of 69 TABLE 1 SUPPORTING REQUIREMENTS NOT MEETING CAPABILITY CATEGORY II OR GREATER SUPPORTING F&O #, DESCRIPTION OF GAP, AND RESOLUTION MODEL REQUIREMENT SIGNIFICANCE IMPACT SC-A5 (Not Met)1-24: Since the failure to start and run for 1 st hour have been combined in the data, the fail to run events with a mission time of 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> actually give the PRA a mission time of 25 hours2.893519e-4 days <br />0.00694 hours <br />4.133598e-5 weeks <br />9.5125e-6 months <br />.The treatment is conservative and adds a very small increase in the failure probability, so it is presented as a suggestion.

Per the peer review team proposed resolution, the existing data was reviewed.

It was determined and documented in the Component Data Notebookthat the use of 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> for the failure to run portion is slightly conservative and acceptable.

Therefore, the total time represented is one hour for failure to start, and 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> for failure to run.Negligible as the model is slightly conservative as is. The gap has been closed for the JUTL12R1 model Attachment 2 to PLA-7119 Page 17 of 69 TABLE 1 SUPPORTING REQUIREMENTS NOT MEETING CAPABILITY CATEGORY II OR GREATER SUPPORTING F&O #, DESCRIPTION OF GAP, AND RESOLUTION MODEL REQUIREMENT SIGNIFICANCE IMPACT SY-C3 (Not Met)Related SRs QU-E1 (Met Cat 1/11/111)AS-C3 (Met Cat I/11I/I)DA-E3 (Met Cat 1/11/111)HR-13 (Met Cat 1/11/111)LE-F3 (Met Cat I/I/I1I)IE-D3 (Met Cat I/I/11)SC-C3 (Met Cat I/MI/IMI)1-18: Plant specific sources of modeling uncertainty are also addressed in the Summary Notebook Appendix D.However, there are only 4 candidate sources of uncertainty identified.

Given the large number of modeling assumptions in the system notebooks (28 in the RHR system notebook alone) a more thorough evaluation of plant specific sources of uncertainty should be performed.

This is a finding because it relates directly to a standard requirement.

All of the system notebook assumptions were reviewed for applicability as potential sources of model uncertainty.

The large majority of the listed assumptions were determined to be standard assumptions or fell under the umbrella of level of detail issues. The few remaining items were added to Table D-2 in Appendix D of the Summary Notebook for further discussion.

None, gap has been closed for the JUL12R1 model.

Attachment 2 to PLA-7119 Page 18 of 69 TABLE 1 SUPPORTING REQUIREMENTS NOT MEETING CAPABILITY CATEGORY II OR GREATER SUPPORTING F&O #, DESCRIPTION OF GAP, AND RESOLUTION MODEL REQUIREMENT SIGNIFICANCE IMPACT HR-B2 (Not Met)7-4: Table F-1 in Attachment F lists identified pre-initiator HEP basic events which include CCF basic events. However, section 4.1.2.1 of the Human Reliability Notebook, Systems Review, says that due to staggered testing/maintenance practices, like components in different divisions are generally not susceptible to restoration error and "common mode" errors are screened.Common mode errors cannot be screened in this manner. Typically a plant's work planning process that prohibits cross divisional maintenance during normal operations are typically not in effect during plant shutdowns.

The modeling of pre-initiator HFEs needs to include activities that occur during plant shutdowns.

This is a finding because it is desired to not screen errors that can affect multiple trains of a redundant system or diverse systems.This item was determined to be a documentation and terminology issue and the manner that SR HR-A3 redundant systems was treated in the HRA notebook, specifically the systems review in section 4.1.2.1.After further review, SR HR-A3 identifies that only single activities that simultaneously disable redundant trains or diverse systems require the development of events. Separate procedures/maintenanc e acts on different divisions or systems (even if they are performed in an outage) are NOT required in the development of events. The statement"Due to staggered testing/maintenance practices, like components in different divisions are generally n'ot susceptible to restoration errors and'common mode' errors are screened" is no longer applicable and was removed from the HRA notebook.Therefore, the potential condition described in the peer review comment is no longer applicable.

None, gap has been closed for the JUL12RI model.

Attachment 2 to PLA-7119 Page 19 of 69 TABLE 1 SUPPORTING REQUIREMENTS NOT MEETING CAPABILITY CATEGORY II OR GREATER SUPPORTING F&O #, DESCRIPTION OF GAP, AND RESOLUTION MODEL REQUIREMENT SIGNIFICANCE IMPACT HR-C3 (Not Met)7-1: Section 4.1.2.1 of the HRA Notebook provides guidance towards the identification of restoration errors and miscalibration errors. In the subsection for Identification of Miscalibration Errors, Item 4 says: Identify I&C components the miscalibration of which will impact redundant system trains or redundant system components.

Miscalibrations that impact a single component may be screened from further consideration.

The Susquehanna HRA analysis assumes that miscalibration is included in the component failure rate data. However miscalibrations are not included in the failure rate data of NUREG-6928 and therefore there are potential failures that may have an adverse impact on equipment that has not been assessed in the Susquehanna HRA.Further in Section 4.1.4 of NUREG-1792, Good Practices for Implementing Human Reliability Analysis (HRA) it says: In practice it is best to include pre-initiator human actions even if the associated failure already may be included in the failure data for the affected equipment item (e.g., in the failure-to-start data). This is because it is often hard to determine if the failure databases include such human failures since data bases are typically insufficiently documented to know if the potential pre-initiator failure is already included.

Generally, unless the failure can affect multiple equipment items, either missing the failure or double-counting the failure have small effects on the outcome of the PRA. Potential double-counting is the most conservative approach and yet typically does not result in a serious overestimation of the failure's significance.

In addition, including all identified pre-initiators gives analysts the opportunity to identify the significance of potentially problematic actions such as those with procedural or training problems, those that do not require appropriate checks, etc.This is a finding. The impacts of miscalibration must be included as a mode of failure of initiation of standby systems and cannot be screened.Open item As indicated in the finding discussion from NUREG-1792,"Generally, unless the failure can effect multiple items; either missing the failure or double-counting the failure have small effects on the outcome of the PRA." Therefore, adding this level of detail for single component miscalibration events is not warranted.

The HRA documentation clarifies that these events are not included because they are low contributors.

When this issue is fully addressed, it may be possible to use SR SY-A15 to demonstration that single sensor miscalibrations can be excluded.Negligible effect on model results as per the provided resolution.

Attachment 2 to PLA-7119 Page 20 of 69 TABLE 1 SUPPORTING REQUIREMENTS NOT MEETING OR GREATER CAPABILITY CATEGORY II SUPPORTING F&O #, DESCRIPTION OF GAP, AND RESOLUTION MODEL REQUIREMENT SIGNIFICANCE IMPACT HR-F1 1-2: There are few HRA events that are Redefined the risk None, gap has (Not Met) grouped together into a single HFE. significant MAN- been closed for However, the most risk significant OPSPCINJL-O the JUL12R1 example is MANOP SPCINJL-O.

into three new model.Related SRs This event represents-the opening of HEPs MAN-HR-G3 several valves related to the SPC OPSPCE-O, (Met Cat II & III) function.

The degree of difficulty of MAN-OP SPC L-opening these valves is not necessarily 0, and MAN-the same nor are the performance shaping OP_INJ L-O, and factors. There is little documentation in performed detailed the HRA documentation or HRA evaluations for calculator to justify this grouping.

Also, each.the value for this HRA grouping appears to be extremely low for an in-field operator action 6.9E-4).This is a finding because this issue causes the SR HR-F l to be 'Not Met.'HR-F1 1-3: For HRA MAN-OPSPCINJL-O, Detailed timing None, gap has (Not Met) there is no analysis of how many "turns" evaluation added as been closed for that it takes to manually operate the part of the the JUL12R1 valves that are to be operated.

The valves evaluation of the model.within this grouped HEP are within large new HEPs MAN-diameter piping segments with varying OPSPC E-O, diameters and stroke characteristics.

MAN-OP SPC L-These characteristics can significantly 0, and MAN-affect the manipulation time. OPINJL-O.This is a finding, since it directly References were involves the manipulation time added to the evaluation of a risk significant operator Timing and action. Assumptions sections of the three MAN-OP calculations in the HRA notebook.

Attachment 2 to PLA-7119 Page 21 of 69 TABLE 1 SUPPORTING REQUIREMENTS NOT MEETING CAPABILITY CATEGORY II OR GREATER SUPPORTING F&O #, DESCRIPTION OF GAP, AND RESOLUTION MODEL REQUIREMENT SIGNIFICANCE IMPACT HR-G6 (Not Met)7-9: While Table 5.1-2 does lists the actions by decreasing HEP value and includes comparison comments execution location, execution stress, performance shaping factors, timing information, the comparison comments are really directed more towards an internal assessment of the HFE itself, rather than it's comparison between events that have a similar HEP. However, the standard requires that a check of HEP values relative to each other be performed.

It does not appear that this was done. This is evidenced by the fact that there are some local actions (with potentially negative performance shaping factors and lower likelihood of success) that have HEP values roughly equal to those of a similar in control room action. Examples of this include 159-CNTVNT-O and 159-CNTVNTLOCAL-O, as well as MAN-OP SPCINJL-O compared to other control room actions).Further, there is no discussion to relate location; timing, PSFs, etc. relative to each other and the values within a HFE range are highly variable.It is understood that the intent of this standard is to assess the HFEs relative to each other, i.e., for all of the HFEs that fall within a specific range, is the expected failure rate of the operators considered reasonable?

For example, are all of the events that have a 1E-1 probability considered more difficult than the HFEs that have probabilities in the 1E-2 range? Similarly all of the HFE's that have probabilities on the IE-3 range should be generally considered to have the same level of difficulties compared to the ones in the IE-2 range.This is a finding because it is not apparent a comparison of events of like values, i.e., those with similar HEPs, has been conducted.

Added text to Section 5.1 to explain that the Table 5.1-2 actions were listed (along with their individual details) in decreasing HEP order in order to facilitate comparison between actions with similar HEPs.Inconsistencies were identified and corrected as needed.There are some local actions, as noted by the reviewer, with potentially negative performance shaping factors that have HEP values roughly equal to those of control room actions, but the similarity is justified in the comments section by stating that the time available for recovery for the ex-MCR action would allow multiple execution attempts and recovery opportunities.

None, gap has been closed for the JULL12R1 model.

Attachment 2 to PLA-7119 Page 22 of 69 TABLE 1 SUPPORTING REQUIREMENTS NOT MEETING OR GREATER CAPABILITY CATEGORY II SUPPORTING F&O #, DESCRIPTION OF GAP, AND RESOLUTION MODEL REQUIREMENT SIGNIFICANCE IMPACT DA-C6 4-9: As shown in Attachment B and Open item Negligible (Not Met) Tables B-8 and B-9 of the Component effect on model Data Notebook, most estimated demands results. This were determined from the MSPI and F&O cites a Related SRs from plant experience.

However, there is lack of DA-C7 no documentation that it is collected in documentation (Cat II/111 met) accordance with the requirements of this that the SR. estimated This is a finding. The basis for collection demands were of plant failure data is not provided collected in except to indicate that the source was accordance from MSPI data. with the SR.DA-C12 4-12: No evidence was found that the Open item Documentation (Not Met) unavailability data obtained from MSPI item.was evaluated for issues of "double Negligible effect counting".

on model results.DA-C13 conig.MSPI (Not Also, there was no consideration given to unavailabilty (Not Met) the handling of unavailability hours that data is by it's occurred online versus during an outage. own program This is a finding because there was no considered for evidence found that this requirement was reactor 'critical' considered.

hours. Unkown potential

'double counting' of MSPI data would be slightly conservative.

Attachment 2 to PLA-7119 Page 23 of 69 TABLE 1 SUPPORTING REQUIREMENTS NOT MEETING CAPABILITY CATEGORY II OR GREATER SUPPORTING F&O #, DESCRIPTION OF GAP, AND RESOLUTION MODEL REQUIREMENT SIGNIFICANCE IMPACT QU-D4 5-7: No evidence of a comparison of Attachment F was None, gap has (Met Cat I) CDF and LERF results with similar added to the been closed for plants was found in the documentation.

quantification and the JUL12Rl CC-I1 requires this comparison and summary notebook model.Related SRs identification of causes for significant which includes a LE-F2 differences.

detailed (Met Cat 1II11I) This is a finding because it causes QU- comparison of the D4 to be a Cat 1. CDF and LERF results with Limerick.Limerick has been considered a sister plant to Susquehanna and is a very similar two unit BWR GE design site. The comparison results were similar and reasonable.

Attachment 2 to PLA-7119 Page 24 of 69 TABLE 1 SUPPORTING REQUIREMENTS NOT MEETING CAPABILITY CATEGORY II OR GREATER SUPPORTING F&O #, DESCRIPTION OF GAP, AND RESOLUTION MODEL REQUIREMENT SIGNIFICANCE IMPACT IFSO-A1 (Not Met)IFSN-A16 (Not Met)Related SRs IFSO-A3 (Not Met)IFSN-A 10 (Not Met)IFSN-A14 (Not Met)IFSN-A 15 (Not Met)IrFQU-A5 (Not Met)IFQU-B3 (Not Met)6-2: Per discussion in Section B.2.1, a rupture of fire protection piping appears to be screened from further analysis, except in a few select areas. The given basis for this is that a fire protection rupture would be quickly identified, diagnosed, and isolated.

However, it may not be an insignificant amount of time for operations to diagnose that a flood is occurring, rather than a fire. Once the flood condition is identified, it may take further time to isolate the flood (typically not able to simply stop the pump in the control room, but rather it must be shut down locally).

It is possible for a significant amount of flooding to occur during this time period. While some flood scenarios are included in the analysis, it is unclear what criteria was used as to whether or not fire protection piping was excluded in a given area, and how much total fire protection piping was excluded.This is a finding because fire protection piping does not appear to be adequately addressed in the analysis.

Floods resulting from fire protection piping ruptures can be significant contributors to CDF.Open item Negligible effect on model results. See PRA Impact from Internal Flooding discussion, which preceeds Table 1.

Attachment 2 to PLA-7119 Page 25 of 69 TABLE 1 SUPPORTING REQUIREMENTS NOT MEETING CAPABILITY CATEGORY II OR GREATER SUPPORTING F&O #, DESCRIPTION OF GAP, AND RESOLUTION MODEL REQUIREMENT SIGNIFICANCE IMPACT IFSO-A1 6-3: Section 2.2.11 indicates that lagged Open item Documentation (Not Met) and insulted piping was not considered as item. No a spray source. There does not appear to impact be any justification for this assumption, and it is typically not used for industry IFPRAs. Furthermore, it is unclear from the documentation if spray effects from fire piping is included or not, based on the discussions in Section B.2.1 about excluding fire piping. Based on discussions with site and contractor personnel, a calculation was produced to demonstrate that lagged piping could not result in a spray impact. Furthermore, there are very few, if any, cases of insulated piping that is not also lagged.Finally, it was confirmed that fire protection piping was considered as a spray source.This is a suggestion to enhance the documentation.

IFSO-A1 6-4: Flood sources appear to be based on Open item. Negligible (Not Met) building elevations rather than individual effect on model flood areas. results. See This is a finding as this SR requires flood PRA Impact sources to be identified on a flood area from Internal basis. Flooding discussion, which preceeds Table 1.

Attachment 2 to PLA-7119 Page 26 of 69 TABLE 1 SUPPORTING REQUIREMENTS NOT MEETING CAPABILITY CATEGORY II OR GREATER SUPPORTING F&O #, DESCRIPTION OF GAP, AND RESOLUTION MODEL REQUIREMENT SIGNIFICANCE IMPACT IFSO-Al 1-35: There is no evidence that a search Open item. Documentation (Not Met) for sources of flooding on the upper level An interim item. No of the control structure (where chiller walkdown was impact units and service water piping is located) performed in and The identified Related SRs which could cause flooding of the control around the class iE gap is a IFSN-A8 room, battery rooms, and/or relay rooms battery and DC suggestion to (Met Cat II) via propagation through ductwork was distribution panel provide considered in the analysis.

Susquehanna areas in the Control additonal personnel looked at drawings during the Structure.

No documentation Peer Review and found no evidence of ductwork was supporting the such a scenario.

However, this should be located in the investigations confirmed by a walkdown.

immediate vicintiy perfromed This is a suggestion, since there is no of class lE during the peer evidence based upon Susquehanna batteries, chargers, review and evaluation during the Peer Review that or distribution additional this is a plausible scenario, panels such that walkdown.direct spray or deluge would cause inoperability.

IFSO-AI 6-41: Section 3.4 of the Internal Flooding Negligible (Not Met) notebook indicates that only >6 in (and in Open item effect on model some cases >4 in) piping results. See was considered for flood scenarios, and it PRA Impact IFSO-A3 appears that smaller diameter piping (in from Internal (Not Met) general) was not considered.

Flooding Flood scenarios have been developed and discussion, IFSN-A15 are listed in Appendix C, and in Table 4- which preceeds (Not Met) 1 of Attachment E, of the Internal Table 1.Flooding notebook.Related SRs However, given the number of inappropriately screened flood sources, a IFSN-AO 10significant number of potential flood (Not Met) scenarios have likely been missed in this analysis.This is a finding as potential flood sources may have been missed or not appropriately assessed, which causes several SRs to be "Not Met."

Attachment 2 to PLA-7119 Page 27 of 69 TABLE 1 SUPPORTING REQUIREMENTS NOT MEETING OR GREATER CAPABILITY CATEGORY II SUPPORTING F&O #, DESCRIPTION OF GAP, AND RESOLUTION MODEL REQUIREMENT SIGNIFICANCE IMPACT IFSO-A4 6-5: Failure modes of components Open item Negligible (Not Met) appears to be included in the pipe rupture effect on model data used, as discussed in Section 2.2.9 results. See of the Internal Flooding Notebook.

PRA Impact Maintenance events are also assumed to from Internal be captured in this data (see also Flooding discussion in Section 3.7 of Attachment discussion, E). Inadvertent actuation of fire which preceeds suppression system is discussed in Table 1.Section B.2.While a review of industry OE was performed for maintenance induced flooding, no plant-specific review is documented.

Furthermore, no review of plant test and maintenance procedures to identify potential errors resulting in a flood appears to have been performed.

This is a finding as the plant-specific potential for maintenance-induced flooding does not appear to be appropriately addressed.

IFSO-A5 6-6: The Reg Guide 1.200 Clarification Open item Negligible (Not Met) states that a range of flow rates must be effect on model considered.

This analysis considers only results.'worst case' failure scenarios.

Bounding This is a finding as a range of flow rates larger break is required per the Reg Guide 1.200 flooding effects clarification, are considered in the model.See PRA Impact from Internal Flooding discussion, which preceeds Table 1.

Attachment 2 to PLA-7119 Page 28 of 69 TABLE 1 SUPPORTING REQUIREMENTS NOT MEETING CAPABILITY CATEGORY II OR GREATER SUPPORTING F&O #, DESCRIPTION OF GAP, AND RESOLUTION MODEL REQUIREMENT SIGNIFICANCE IMPACT IFSO-A5 6-7: Pressure and temperature Open item Negligible (Not Met) information for flood sources was not effect on model found in the documentation.

results. See This is a finding as pressure and PRA Impact temperature information is not included from Internal in the Internal Flooding Analysis.

Flooding discussion, which preceeds Table 1.IFSO-B3 6-20: Assumptions are discussed in Open item Documentation (Not Met) Section 2.2 of the Internal Flooding item.documentation.

Discussion of uncertainty Negligible appears limited to discussion of flood effect on model IFSN-B3 initiator frequencies.

Attachment D results. See (Not Met) includes discussion of pipe failure modes PRA Impact but no other discussion of uncertainty is from Internal IE1V-B3 identified.

No documentation exists for Flooding impacts of various assumptions on model discussion, (Not Met) uncertainty could be found. which preceeds This is a finding as the SR requires a Table 1.IFQU-B3 discussion of model uncertainty.(Not Met)Related SRs IFPP-B3 (Met Cat 1III)

Attachment 2 to PLA-7119 Page 29 of 69 TABLE 1 SUPPORTING REQUIREMENTS NOT MEETING CAPABILITY CATEGORY II OR GREATER SUPPORTING F&O #, DESCRIPTION OF GAP, AND RESOLUTION MODEL REQUIREMENT SIGNIFICANCE IMPACT IFSN-A3 6-9: Automatic and Operator actions Open item Negligible (Not Met) appear to be identified throughout the effect on model notes in Appendix C, as well as the results. See discussion in Section B. However, PRA Impact IFSN-A14 numerous concerns exist with the from Internal (Not Met) approach taken, as discussed below. Flooding There appears to be no justification/basis discussion, IFQU-A5 for crediting these actions. which preceeds For example, a flood in C-604 (page C.2 Table 1.(Not Met) credits operator action to isolate a domestic water pipe rupture prior to equipment damage. What indication exists to alert operations of the flood prior to the occurrence of equipment damage? Furthermore, no consideration is given to the likelihood of operator failure/in-action.

This is a finding since while operator actions are credited to terminate flooding before equipment damage occurs, there appears to be insufficient basis for crediting these actions. This may result in erroneously screening some scenarios, which is non-conservative.

IFSN-A3 6-10: Section 4.2 states that no mitigation Open item Documentation (Not Met) actions credited to limit the impacts from item. No a flood. However, the comments impact contained in Appendix C do appear to Related SRs credit operator action (as well as IFQU-A5 discussion in Section B.2.1 to isolate fire (Not Met) protection piping). This text is confusing/incorrect.

This is a suggestion because it only pertains to documentation and is not an unanalyzed method.

Attachment 2 to PLA-7119 Page 30 of 69 TABLE 1 SUPPORTING REQUIREMENTS NOT MEETING CAPABILITY CATEGORY II OR GREATER SUPPORTING F&O #, DESCRIPTION OF GAP, AND RESOLUTION MODEL REQUIREMENT SIGNIFICANCE IMPACT IFSN-A6 6-14: Susceptibility of SSCs to flood Open item Negligible (Not Met) damage is discussed in Section 2.2 of the effect on model Internal Flood notebook.

This discussion results. See includes spray and submergence PRA Impact I7FQU-A9 considerations.

A qualitative discussion from Internal (Not Met) of additional impacts (jet impingement, Flooding pipe whip, humidity) is required for CC discussion, I/Il per Reg Guide 1.200 clarification, but which preceeds is not included here. Table 1.Since medium and small bore fire protection piping is dismissed from the analysis and since spray sources greater than 10 feet away from the source are typically dismissed, the effects of pipe whip and jet impingement cannot be said to be evaluated in the quantification.

This is a finding. A qualitative discussion of additional impacts (jet impingement, pipe whip, humidity) is required for CC I/11 per Reg Guide 1.200 clarification to meet SR IFSN-A6. An evaluation of medium/small bore piping for pipe whip and jet impingement is required to meet SR IFQU-A9.IFSN-A10 6-42: Flood scenarios have been Open item Negligible (Not Met) developed and are listed in Appendix C, effect on model and in Table 4-1 of Attachment E, of the results. See Internal Flooding notebook.

PRA Impact Related SRs There does not appear to be any from Internal IFSN-A5 consideration to the impact of water Flooding (Met Cat 1II/11I) intrusion on control panels or junction discussion, boxes. This can result in additional which preceeds failures to PRA-credited equipment that Table 1.is otherwise not impacted by the flood.This is a finding as some potential failure modes (grounding of local control panels or junction boxes) were not considered in the analysis.

Attachment 2 to PLA-7119 Page 31 of 69 TABLE 1 SUPPORTING REQUIREMENTS NOT MEETING OR GREATER CAPABILITY CATEGORY II SUPPORTING F&O #, DESCRIPTION OF GAP, AND RESOLUTION MODEL REQUIREMENT SIGNIFICANCE IMPACT IFSN-A13 6-17: Per Section 3.3.5 and Appendix E Open item Negligible (Not Met) of the Internal Flooding documentation, effect on model flood areas were screened if no scram or results. See 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> shutdown was required OR no PRA Impact significant source of water exists in the from Internal room. Flooding This is not sufficient per the standard.

discussion, This is a finding since it causes the which preceeds Table 1.associated SR to be not met.IFSN-A17 1-40: Credited plant walkdowns were Open item Negligible (Not Met) conducted at various times and were effect on model separated by a period of many years. results. See There was not a systematic walkdown PRA Impact IFQU-A11 plan that was applied to this process and from Internal (Not Met) thus the requisite information could not Flooding be gleaned to form the basis for scenario discussion, Related SRs development, which preceeds TFSO-A6 Walkdowns were deemed to not be Table 1.complete with respect to their evaluation (Met Cat I/II/I1I) of flood-induced HRA and (implicit or explicit) screening decisions.

IFQU-B2 This is a finding because it causes SRs to (Met Cat I/II/111) be not met.IFSN-A17 4-17: Qualitative screening of areas is Documentation (Not Met) discussed in Appendices B and C of the Open item item. No Internal Flood notebook.

Flood areas impact appear to screened on the basis of either Related SRs no significant flood sources or no IFSN-A12 mitigation equipment is present in the (Met Cat I/IfI!) flood area. However, except for Table 4-1 for unscreened flood areas, sufficient information is not provided to determine IFSN-B 1 which SSCs are in each flood area and (Met Cat FI/III) what flood heights or spray considerations should have been included.This is a suggestion since it involves documentation.

There is insufficient information provided about the SSCs in each flood area.

Attachment 2 to PLA-7119 Page 32 of 69 TABLE 1 SUPPORTING REQUIREMENTS NOT MEETING CAPABILITY CATEGORY II OR GREATER SUPPORTING REQUIREMENT F&O #, DESCRIPTION OF GAP, AND SIGNIFICANCE RESOLUTION MODEL IMPACT+ -I- I WFSN-B2 (Not Met)6-18: The Internal Flooding notebook discusses propagation pathways, accident mitigation features, assumptions and calculations, flood scenarios considered, screened, and retained, and results of plant walkdowns.

No information was found regarding listing of SSCs in each flood area, height of floor, vulnerability to spray, etc.This is a finding as information used in the analysis is not clearly referenced to verify accuracy.Open item Negligible effect on model results. See PRA Impact from Internal Flooding discussion, which preceeds Table 1.+/- +IFSN-B2 (Not Met)Related SRs IFSO-B2 (Met Cat 1/II/III)6-19: The Internal Flooding notebook discusses propagation pathways, accident mitigation features, assumptions and calculations, flood scenarios considered, screened, and retained, and results of plant walkdowns.

Only limited information was found regarding pipe lengths, diameters, insulation, etc.This is a finding as piping information is required to verify the results of the assessment, including max flow rate and pipe rupture frequencies.

Open item Negligible effect on model results. See PRA Impact from Internal Flooding discussion, which preceeds Table 1.+ + +/-IFSN-B2 (Not Met)Related SRs IFSN-A2 (Met Cat I/I1/III)6-8: Presence of alarms is discussed in individual room analysis in Appendix B of Internal Flooding notebook.

Curbs, drains, sump pumps, etc. appear to be accounted for in calculations in Appendix C. Appendix D lists all water tight doors in plant.Lists/tables of such features in each plant area would aid in review, as well as walkdown verification.

This is a suggestion since while the required information appears to be incorporated in the analysis, including lists of such features for each flood area would be beneficial for review.Open item Documentation item. No impact.

Attachmnent 2 to PLA-7119 Page 33 of 69 TABLE 1 SUPPORTING REQUIREMENTS NOT MEETING CAPABILITY CATEGORY II OR GREATER SUPPORTING F&O #, DESCRIPTION OF GAP, AND RESOLUTION MODEL REQUIREMENT SIGNIFICANCE IMPACT IFSN-B2 6-12: Drains/sumps are discussed Open item Negligible (Not Met) throughout the documentation, but no effect on model indication of drain size or sump pump results. See capacity was found. Drains were not PRA Impact Related SRs credited in hydraulic calculations.

The from Internal IFSN-A4 presence of drains/sumps was credited to Flooding (Met Cat I/II/III) screen out some flood scenarios with low discussion, volume sources in Appendix C. which preceeds The presence of curbs appears to be Table 1.included in hydraulic calculations.

This is a suggestion as floor drains and sumps typically do not have a major impact on flood scenarios.

IFSN-B2 6-13: Table 4-1 of Attachment E of the Open item Negligible (Not Met) Internal Flooding notebook documents effect on model the impacted SSCs. results. See However, it is not always clear what the PRA Impact Related SRs impacted components are, as often times from Internal IFSN-A5 only the System (example, RBCCW or Flooding (Met Cat 1I/IIIII)

HPCI) is identified.

discussion, This is a suggestion as it should not which preceeds impact the results of the model.IFEV-A1 4-14: Per Section B of Internal Flooding Open item Negligible (Not Met) notebook, flood scenarios are mapped to effect on model existing plant initiators or are treated as results. See new initiators.

However, flood-induced PRA Impact LOCAs were not considered a credible from Internal event and were excluded from Flooding consideration LOCAs were addressed in discussion, the Initiating Events notebook.

which preceeds This is a finding since the potential for Table 1.flood-induced LOCAs was not included.

Attachment 2 to PLA-7119 Page 34 of 69 TABLE 1 SUPPORTING REQUIREMENTS NOT MEETING CAPABILITY CATEGORY II OR GREATER SUPPORTING F&O #, DESCRIPTION OF GAP, AND RESOLUTION MODEL REQUIREMENT SIGNIFICANCE IMPACT IFEV-A5 1-42: The pipe rupture frequencies used Open item Negligible (Not Met) for development of the flood initiating effect on model event frequencies did not use the latest results. See data (published in November 2010). PRA Impact Since the Internal Flooding Analysis was from Internal updated in early 2012, it was expected Flooding that justification would be provided to discussion, show that not using latest industry which preceeds frequency data complies with the Table 1.requirements.

Therefore this SR is not met.This is a finding since it causes the SR to be "Not Met." IFEV-A6 1-41: No consideration of material Open item Negligible (Met Cat I) condition, water hammer, or maintenance effect on model induced flooding is included in the results. See analysis.

PRA Impact This is finding since it causes the SR to from Internal be of Cat I only. Flooding discussion, which preceeds Table 1.IFQU-A6 1-30: There are some flooding events Open item Negligible (Not Met) which cause flooding of areas without the effect on model potential for draining the area in greater results. See than four hours. Therefore, this screening PRA Impact criterion is questionable.

from Internal This is a finding because it causes the SR Flooding to be "Not Met." discussion, which preceeds Table 1.IFQU-A6 1-31: There was no consideration given Open item Negligible (Not Met) for increased stress level for both in effect on model control room actions and ex-control room results. See actions that were are not failed by the PRA Impact flooding scenario.

There was no from Internal adjustment of HEPs related to this Flooding finding, discussion, This is a finding because it causes the SR which preceeds to be "Not Met." Table 1.

Attachment 2 to PLA-7119 Page 35 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE IE-A1 (Met Cat I/II/11)4-2: The Manual Shutdown initiator for'unplanned events' was included in the model even though section 2.3.4 clearly states that 'the scope of the PSA is for at-power conditions'.

This F&O is a suggestion.

Planned shutdowns that do not result in failures that would cause an initiating event would not challenge plant safety and would not result in an LER.Therefore, it should not be counted as an initiating event. The current estimate is overly conservative.

Unsuccessful planned shutdowns would be captured in the review of plant events, reviewed for impact and included in the initiating events modeled.The ASME Standard interpretations

1. 5 and #6 indicate that the Manual Shutdown initiator is not included in the PRA, but should be included in transition risk or low power risk models. Interpretation 5 states;"Question:

Is it a requirement to include "non-forced" manual trips which are part of the normal shutdown procedure when counting initiating events.Reply: No, a normal controlled shutdown would not present the same challenges as a trip from full power.This event is more appropriate for a transition model and outside of the scope of the standard".

This position is repeated in Interpretation 6; "Question:

Is it a requirement to include "forced" (e.g., technical specification 3.03 actions) or"non-forced" (e.g., manual shutdowns for refueling) when the resulting shutdown follows normal plant procedures with no off-normal conditions requiring a reactor scram?Reply: No, the risk needs to be captured in a transition risk or low power risk model, which is outside the scope of RA-Sb-2005.

At power conditions for the online PRA risk model is defined to be plant modes 1, 2, and 3. Supporting Requirement IE-Al states to"Identify those initiating events that challenge normal plant operation and that require successful mitigation to prevent core damage using structured, systematic process for identifying initiating events that accounts for plant specific features." As described in the summary notebook, "The manual shutdowns are included in the analysis because of their frequency and because they represent changes in operating state which result in the demand on available equipment to reach a safe shutdown condition.

The manual shutdowns are controlled evolutions that have different characteristics than a SCRAM challenge.

The manual shutdowns generally represent a reduced challenge relative to that of a turbine trip; however, also possible is a manual shutdown resulting from equipment unavailability where accident mitigation capability has been reduced prior to the demand for the shutdown." Therefore, the peer review suggestion is noted, but no changes were made to delete manual shutdowns from the initiating events given any shutdown can on some level challenge normal plant operation.

None, gap has been closed for the JUJL12Rl model.

Attachment 2 to PLA-7119 Page 36 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE IE-A2 1-16: The loss of control room Per discussion with the peer Documentation (Met Cat 1/11/111) ventilation is not considered to be an review evaluator, the item. The gap has initiator in the model. The initiating identified condition can be been closed for events notebook states that this resolved with additional the JUL12RI initiator was dismissed, but there is documentation.

Information model.no detailed discussion why this was regarding the Appendix R done. Upon discussion with fire calculation and loss of Susquehanna personnel, it was control room ventilation determined that there is a basis for was added to the Initiating dismissing this initiator, but it was Events Notebook, Section not documented.

2.4.2, to support that no new This is a suggestion because it is a initiator is needed.documentation concern only.IE-A9 6-28: The process by which LER Per discussion with the Documentation (Met Cat II) reports are searched to identify peer review evaluator, it item. The gap precursors needs to be was desired to have has been closed documented.

additional documentation for the JUL12R1 This is a suggestion because it outlining the LER review, model.involves documentation only. Section 2.3.8 of the Initiating Events Notebook was expanded to provide more detail to the LER review process and whether or not the events described needed to be included in the PRA.IE-C3 4-3: Use of NUREG-0666 The Initiating Events None, gap has (Met Cat 1/11/111) includes a generic recovery Notebook Section 3.5.2 been closed for estimate.

No indication of was revised to remove the JUL12R1 Susquehanna adjustment.

Section credit for DC bus repair model.Related SRs 3.5.2 of the IE Notebook uses the recovery.

Accordingly, IE-C 11 credit for recovery for loss of DC the initiating event (Met Cat I//1/1Il) bus events from NUREG-0666.

frequency was also This is a finding. Use of NUREG- changed in Table 4-1 and 0666 is a very old reference and a in the JUTL12R1 model.more contemporary reference (NUREG-6928) should be used.

Attacunent 2 to PLA-7119 Page 37 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE IE-C6 (Met Cat I/II/III)6-2 1: No potential Initiating Events appear to be screened based on criteria (a) or (b).A loss of River Water intake and Loss of the Spray Pond (UHS) are screened on the basis that it would not result in an immediate plant shutdown.

However, this credits operator actions to remove any debris blocking the intake structure, and states that failure of this action would result in an initiating event similar to a loss of condenser heat sink. Per discussions with PRA staff, debris/fouling/ice are unlikely (no recorded plant events), and there appear to be no common suction lines that would impact multiple systems.A loss of a 13.8 kV bus was screened on the basis that it would appear like a loss of feedwater with some impacts on service water/instrument air. The notebook then states that this IE is screened as it is assumed to be adequately included in as a turbine trip transient initiator with subsequent failure of a 13.8kV AC bus. An estimation of this IE frequency should be made to verify it conforms with the Screening Criteria given in this SR.This is a suggestion as the frequencies of the screened IEs are likely low enough to support their being screened.The proposed resolution from the peer reviewer evaluator was to estimate the frequencies for loss of the river water intake and loss of the 13.8kV bus to confirm that they are appropriately screened out under the guidance of SR IE-C6. The screening determined that these system losses should be added to the risk model.The river water makeup discussion inthe Initiating Events Notebook, section 2.4.5 was revised. The river water makeup system is now an input to the service water initiating event fault tree.CCF screen and pump terms were also added to the model loss of service water support system initiating event fault tree and are documented in the Component Data Notebook.

Also added loss of 13.8 kV buses as special initiators, to the initiating event notebook.None, gap has been closed for the JUJL12R1 model.

Attachment 2 to PLA-7119 Page 38 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE IE-C8 (Met Cat If1/III)Related SRs IE-D1 (Met Cat FII/III)4-1: Section 3.5 of the IE Notebook provides the fault tree method and results of the support system initiating events. The initiating event fault trees were developed from the mitigation fault tree. Only the Service Water tree is found in the system notebook.

The support system dependencies were removed from the mitigation tree to develop the initiating event fault tree. The support system initiating event fault trees developed for loss of off-site power, loss of CIG, loss of SW, loss of IA, loss of TBCCW, and loss of RBCCW are found in the Susquehanna CAFTA fault tree under gates identified for each system. The cutset results are shown in Appendix F of the EE Notebook for each system IE.This is a finding because Appendix F states that the System IE fault trees are located in the respective system notebooks, however, this was not found to be the case for RBCCW, TBCCW, IA and CIG.The peer review finding noted that the special initiating events fault trees described in the initiating events notebook were not located in the referenced individual system notebooks.

The peer review finding specifically questions the documentation of the special initiating events fault trees since the frequency is calculated within the model. The special initiating event fault trees have been added directly to the Initiating Events Notebook in Appendix F.None, gap has been closed for the JUL12R1 model.IE-C14 (Met Cat I/1I)6-25: Appendix H of the Initiating Events notebook addresses the ISLOCA frequency calculation and appears to address most of the items required by this SR. However, no discussion of interlocks of relevant surveillance tests and procedures was found.This is a finding. Consideration of protective interlocks and plant surveillance procedures is required by this SR.Per the referenced possible resolution, Appendix H of the Initiating Events Notebook was updated to address the identified gap. A discussion of surveillances and interlocks has been added to Appendix H for ISLOCAs.None, gap has been closed for the JUL12R1 model.

Attachment 2 to PLA-7119 Page 39 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE IE-D3 6-26: Assumptions are discussed Open item Documentation (Met Cat I/II/I) throughout the IE notebook.

item. No Sources of Uncertainty regarding impact.initiating events are included in the discussion in Section D. 1.4 of the Summary Notebook.A single section/list of all assumptions made was not found, such a list may be beneficial.

This is a suggestion as all assumptions made appear to be captured throughout the documentation.

AS-A9 2-1: Section 2.1.16 of Event Tree / Reference to MAAP None, gap has (Met Cat HI) Success Criteria Notebook, Thermal- limitations have been been closed for Hydraulic Code Limitations, states incorporated in the Event the JUL12RI that MAAP4 does not calculate peak Tree/Success Criteria model.fuel temperature well. However, fuel Notebook.temperature calculated in MAAP is used to define core damage.Analysis and justification for the use of MAAP4 to define core damage is provided in Section 2.1.1 of the, Performance Requirements for Maintaining Core, Vessel, and Containment Integrity During Severe Accidents notebook.Section 2.1.1 of the performance requirements notebook should be referenced in the Event Tree /Success Criteria Notebook to avoid confusion on the use of MAAP4 with the limitation described.

This is a suggestion to clarify documentation in the Event Tree /Success Criteria Notebook.

Attachment 2 to PLA-7119 Page 40 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE AS-B3 1-20: There is no separate success Open item Documentation (Met Cat I/I/II) criteria notebook in the item. No impact Susquehanna documentation.

Rather, the plant uses the event tree notebook for both AS and SC technical elements.

This results in some of the success criteria information being scattered through the event tree sequence descriptions.

This is a suggestion, since it is a potential documentation enhancement.

AS-B5 1-21: Expanded documentation of Open item Documentation (Met Cat I/H/HI) the FFT model top logic would item. No impact facilitate greater understanding of the model by PRA engineers new to the group and would further enhance the scrutinizing of the model.This is a suggestion since it involves model documentation only.

Attachment 2 to PLA-7119 Page 41 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE AS-Cl 1-13: The accident sequence Open item Documentation (Met Cat I/II/lI) model is constructed using a very item. No impact large number of transfers.

This made the model difficult to Related SRs review. It is also constructed in a AS-Al 1 manner such that the CDF tree (Met Cat IIIIII) and the Level 2 tree are integrated.

While there is no evidence from the peer assessment that was performed that the model fails to accurately model the as-built, as-operated plant (the quantification results are reasonable given the operation and design of the plant).However, the event tree structure does not lend itself readily to evaluation.

This should not hamper the ability to pursue PRA applications.

However, as more hazards are added to the spectrum of the PRA (internal fire, seismic, etc.) the event tree structure may become difficult to deal with.This is a suggestion because it primarily addresses potential issues that may arise in the fture.AS-Cl 1-46: Consider the creation of a Open item No impact. The (Met Cat I/11/I1) separate LOOP tree. This would F&O suggests a allow for increased model different method readability and would diminish to model the the need for the use of recoveries.

Loss Of Off-Site This is a suggestion, since the as- Power.built, as-operated plant is effectively represented by the current model.

Attachment 2 to PLA-7119 Page 42 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE SC-A3 3-2: Section 2.6.2 of the Event Open item Documentation (Met Cat I/II/111)

Tree/Success Criteria Notebook item. No impact describes the core protective functions identified in the AS and Related SRs SC Notebook.

Table 3.3.1 SC-Cl through 3.3.11 (LOCA) and Table (Met Cat MIMI/I) 3.4.1 through 3.4.10 AS-A2 (TRANSIENT) provide the functional level SC for the key (Met Cat I/II/III) critical safety functions for each initiator category.

Attachment M provides key results of MAIAP nins to support the SC.However, no similar Tables as LOCA and TRANSIENT key safety functions were found that described the key safety functions for ATWS and ISLOCA.This is a document suggestion.

Attachment 2 to PLA-7119 Page 43 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE SC-A6 3-3: The success criteria given are System flow used for Negligible, the (Met Cat 1/11/I11) consistent with the features MAAP analysis is current analyses described in the system notebook conservative (i.e. lower) are conservative.

document.

The MAAP input deck relative to predicted post- However, using and runs use flows, pressures, and modification system flow. a higher fire other parameters that are Therefore, the current water pump flow consistent with the values credit for fire water has the potential described in the station system makeup based on the to yield success description documents and in the MAAP analyses are for re-flooding PSA system notebooks.

The conservative.

No the core after success criteria are also tied to modeling changes are depressurization.

plant's procedures.

made at this time, but this If this is However, there is a plant should be considered in a successful, the modification on the Fire Water future PRA model fire pump, System to replace a 50 foot 3' update. injection flow inch hose with 200 foot of 5 inch path and hose. System flow is potentially operator action increased, and SC might need to for the fire water be updated to reflect the plant as- injection build condition.

This may alignment would improve the plant over SC as become more well. important.

This a finding since the unanalyzed modification may impact overall model success criteria and implemented logic.SC-B4 2-2: Event Tree / Success Criteria Documentation issue. None, gap has (Met Cat 1/11/Il1)

Notebook Section 2.1.6 describes Reference to been closed for Thermal-Hydraulic Code BWRSAR/MAAP the JUL12R1 Limitations.

comparison was added to model.Related SRs There is no discussion of the the Event Tree/Success AS-A9 MAAP4 limitation concerning its Criteria Notebook section (Met Cat III) use in analysis of large break 2.1.6.LOCAs.This is a suggestion since the large LOCA MAAP calculations were compared to existing BWRSAR calculations and found acceptable for use in the PRA.

Attachment 2 to PLA-7119 Page 44 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE SY-A3 5-4: PRA model system functions Documentation (Met Cat I/II1/11) documented in Section 1.2 of the Open item item. No system notebooks are based on impact.Maintenance Rule functions.

Did not find a reference for the source of these functions (e.g., Maintenance Rule basis document) identified in the system notebooks.

This is a suggestion because it pertains primarily to documentation.

SY-A10 5-3: The effect of variable success Open item Documentation (Met Cat I/II/III) criteria was not clearly item. No documented for three system impact.notebooks RCIC), CRD and CST Related SRs and RWST.HR-F2 For example, success of RWST is (Met Cat III) defined simply as to provide SY-A2 manual makeup to the Unit 1 CST (Met Cat I/IJ!IIl) and the Unit 2 CST. Timing information is found in the event SY-C2 tree notebook for different (Met Cat I/11/111) scenarios.

The evaluation of 037-N-N-RWST-O in the HRA notebook indicates a different timing than found in the event tree notebook.It is not clear from the CRD system notebook what CRD flow is credited and the basis in success criteria.

It would be clearer if this and other success criteria are documented in a separate notebook to tabulate various combinations of criteria applicable to accident scenarios.

This is a suggestion because it applies to documentation only.

Attachment 2 to PLA-7119 Page 45 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE SY-A13 6-3 1: Assumption 2 of Section Open item Documentation (Met Cat 1/11/111) 2.2 (general assumptions) in the item. No System Notebook Template impact.discusses screening potential flow diversion paths if the diameter of the pathway is less than 1/3rd the diameter of the primary pathway.This assumption may not necessarily be true and requires more justification on a system-by-system basis. Per discussion with PRA staff, the general assumption on 1/3rd pipe diameter is not actually used. Flow diversion are analyzed on a system by system basis, and are documented in Section 2.1.3 of each notebook discusses the identified flow paths.This is a suggestion to remove the unused assumption from the notebook.SY-A15 6-32: Per the system notebook Open item Documentation (Met Cat I/RI/III) template, several item. No components/failure modes have impact..been screened (plugging of components, leakage/rupture of a components, etc.). This appears to be in accordance with the requirements of this SR.However, some additional discussion to verify appropriate screening should be added to the documentation.

This is a finding since quantitative criteria were not cited.

Attachment 2 to PLA-7119 Page 46 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE SY-A16 6-33: Discussion of these events Open item Documentation (Met Cat 1/11) was not found in the system item. No notebooks and were expected to impact.be found in Section 2.3.2 (example, discussion of pre-initiator events such as 054-I-AC-PMP-H was not found in the ESW notebook, outside the"copy-paste" of the fault tree and cutsets).This is a suggestion as the pre-initiator events are included in the model and the HRA documentation but are not described in the system notebooks.

SY-A21 1-25: The RHR System Notebook Open item Documentation (Met Cat I/II/II) contains a reference point item. No estimate probability for the R-HR impact.water hammer event that is postulated in NEDO-33150-NP (BE 149-fl-N-H20_PART).

An expanded discussion of this phenomenology should be presented and details of its injection accident sequence model should be presented.

This is a suggestion since it is a documentation enhancement.

Attachment 2 to PLA-7119 Page 47 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE SY-B3 (Met Cat I/II/I1)1-17: Check valve CCF is slightly more than 2 orders of magnitude lower in CCF probability than MOV failures, but less than 2 orders below pump failure to start and failure to run CCF terms.Therefore, it is not appropriate to screen check valve CCF unless there are MOVs (or other high CCF failures) in the system.Of particular concern are check valves which are within injection pathways to the reactor shared by multiple systems (such as one inlection line through with HPCI and FW inject and the opposite injection line inject RCIC and FW) in which the shared lines only have check valves. CCF modeling of such check valves is important to incorporate.

This is a finding because there is a potentially significant common cause failure that was not added to the model.Upon review, it was determined that check valve CCF basic event terms for the HPCI!RCIC Feedwater (FW) injection paths and ESW paths should be included in the risk model. The basic events and CCF data is as documented in the component data notebook.None, gap has been closed for the JUL12R1 model.

Attachment 2 to PLA-7119 Page 48 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE SY-B3 (Met Cat 1/111)6-34: Selection of CCF groups is discussed in Data Notebook Section 3.0. CCF groups follow guidance in NUREG/CR-5485 and are based on similarities in service conditions, environment, design or manufacturer, maintenance.

CCF groups included pumps, MOVs, air compressors, etc.However, per discussion in Section 3 of Data Notebook, some component types, such as filters, check valves, and circuit breakers, were screened due to low probability.

This may not necessarily be true. For example, based on Table 4-1 the probability for 2 of 4 RHR pumps failing to start is 8.4E-7. With a probability of a check valve failing to open of 1E-5 and assuming a Beta factor of 8.5E-3, a probability of 2 of 4 pump discharge check valves failing to open would be -1IE-7, which is less than 2 orders of magnitude lower than the pump failure to start CCF tern. In addition, plugging of strainers/HXs/etc.

can have CCF probabilities that are within an order of magnitude or two less than their independent probabilities.

This is a finding as some CCF terms may have been inappropriately screened from the model.Possible Resolution Demonstrate that screened CCF terms were appropriately screened, or incorporate them into the model.Section 4.3.24 of Component Data Notebook evaluates the CCF for check valves in the RHR, CS and RHRSW systems. The conclusion is the CCF of check valves in these systems is not required since their CCF is more two orders of magnitude lower than the highest failure probability of the other components in the same system train that results in the same effect on system operation.

Strainer (filter) plugging for the RHR and Core Spray Pumps is modeled.The CCF of circuit breakers for motor driven equipment is not modeled since the failure of the circuit breaker for motor driven equipment is included in the failure rate of the driven equipment (NUREG/CR-6928).None, gap has been closed for the JUJL12R1 model.

Attachment 2 to PLA-7119 Page 49 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE SY-B15 (Met Cat I/MI/IUM)5-6: Section 2.3.2 in each of the system notebooks discusses human interactions and lists HRA basic events. Also refer to the HRA notebook.

An example of operator interface dependencies across systems is 037-N-N-XTIE-0, OPERATOR FAILS TO XTIE RWST TO CST, which provide CST makeup from the RWST.This HRA basic event is among the events listed in Section 2.3.2 of the RCIC system notebook, but was not included in Section 2.3.2 of the HPCI and Core Spray system notebooks.

Documentation of operator interface dependencies across systems in the systems notebooks is not complete.This is a suggestion because it only pertains to documentation.

Open item Documentation item. No impact.

Attachment 2 to PLA-7119 Page 50 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE HR-A3 (Met Cat I/I/11)5-2: Statement in Section 4.1.2.1 on page 60: Due to staggered testing/maintenance practices, like components in different divisions are generally not susceptible to restoration errors and "common mode" errors are screened.This is a finding. Need basis for not identifying the work practices identified above (HR-Al, HR-A2) that involve a mechanism that simultaneously affects equipment in either different trains of a redundant system or diverse systems [e.g., use of common calibration equipment by the same crew on the same shift, a maintenance or test activity that requires realignment of an entire system (e.g., SLCS)].This item was determined to be a documentation and terminology issue and the manner that SR HR-A3 redundant systems was treated in the HRA notebook, specifically the systems review in section 4.1.2.1 .After further review of SR HR-A3, it was determined that only single activities that simultaneously disable redundant trains or diverse systems require the development of common mode failure events, as exemplified in SR HR-A3. Maintenance acts that are directed by separate procedures on different divisions or systems, even if they are performed in an outage, are NOT required to be identified as common mode failure events. The identification process used in the SSES pre-initiator HRA is consistent with SR HR-A3. The documentation was updated to provide clarification.

None, gap has been closed for the JUL12R1 model.

Attachment 2 to PLA-7119 Page 51 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE HR-B1 (Met Cat II/III)7-2: Although some screening criteria are identified in selected sentences throughout the document, a succinct section outlining screening criteria is not reiterated in the HRA Notebook.Although Section 4.1.2.1 of the HRA Notebook, largely identifies components that are to be included in the analysis, this section does not succinctly identify the criteria under which components and actions can be screened from the analysis.Note that it is stated in section 4.1.2.1 that "Miscalibrations that impact a single component may be screened from further consideration and assumed to be inherent in the component failure rate." Screening calibration activities on that basis is not a screening criteria of ASEP as identified in this associated supporting requirement:

SR-B 1. Therefore since unique screening criteria have been used in the Susquehanna HRA analysis that is not part of the ASEP process, a succinct and comprehensive listing of all pre-initiator screening criteria is required.Later, Section 4.1.2.5 refers to the procedures used for the pre-initiator analysis of HFEs identified as 'risk-significant', which are listed in Attachment C. It is not noted however, if these procedures provide the post maintenance functional tests that would reveal misalignment It is noted that Attachment F of the HRA notebook defines some screening criteria for pre-initiator identification which presents screening of plant experience related to potential restoration errors or miscalibration errors to identify additional pre-initiator actions worthy of inclusion in the model.This is a finding because a complete set of screening criteria for Type A events was not found in the documentation.

The HRA notebook, Section 4.1.2.1, has been updated to include a specific set of screening criteria.

The text has been updated to clarify what the test needs to do in order for it to be credited (identify the error). The description of the potential recovery mechanisms has also been enhanced to clarify that mechanisms described in section 4.1.2.5 are the same as those listed for each procedure review section.None, gap has been closed for the JUL12R1 model.

Attachment 2 to PLA-7119 Page 52 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE HR-C2 (Met Cat I1/I1)7-5: Restoration errors screened on the basis of an administrative work practice procedure which may not be applicable during all stages of low power and shutdown modes.This is a finding because it is possible to have restoration errors during low power and shutdown modes that affect equipment across system trains.SR HR-C2 is attempting to ensure that specific failure modes are addressed for the unscreened activities.

SSES does not have unscreened common mode misalignment events. In addition, based on the clarification and fuirther review of SR HR-A3, the HR-A3 requirement identifies that only single activities that simultaneously disable redundant trains or diverse systems require the development of events. Separate procedures/maintenance acts on different divisions or systems (even if they are performed in an outage) are NOT required in the development of events. Clarification was provided in the HRA notebook in revision 5.None, gap has been closed for the JUL12R1 model.

Attachment 2 to PLA-7119 Page 53 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE HR-D2 7-7: A detailed analysis has been Expanded and/or None, gap has (Met Cat II) performed for the HFEs that had a corrected discussion was been closed for risk achievement worth (RAW) provided in the HRA the JUL12R1 greater than or equal to 2.0 or a notebook, sections 4.2.3 model.Related SRs risk reduction worth (RRW) and 4.2.1.4.HR-GI greater than or equal to 1.005.(Met Cat II) Consideration should be given to QU-F6 using the FV directly per the ASMIE Standard wording rather (Met Cat I/111111) than indirectly through RRW.This is a suggestion because it pertains to more direct correlation with the standard.

Use the ASME Standard and RG 1.200 parameter of a FV = 0.005 rather than the RRW to avoid confusion.

HR-D2 5-1: The screening criteria and Scoping values of 0.01 None, gap has (Met Cat H) values used need to be more for independent pre- been closed for clearly defined within the initiator events and 0.001 the JUL12R1 Susquehanna HRA as also noted for common cause pre- model.in SR HR-B2. The nominal ASEP initiators are judged as methodology has been used in the reasonable scoping Susquehanna HRA as the detailed estimates as described in methodology.

Section 4.1.2.4 of the This is a suggestion, since there is HRA Notebook.

The 1 E-no direct evidence that important 2 value that SSES contributors have been missed. employed is per the NRC's guidance in NUREG-1792 document.HR-E4 1-1: Simulator observations Open item Negligible, F&O (Met Cat ITf1H' should be conducted to further is a suggestion confirm the validity of that would assumptions in modeled operator enhance the actions. HRA analysis.This is a suggestion, since there is no requirement for such observations if a 'talk-through' was performed.

Attachment 2 to PLA-7119 Page 54 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE HR-F2 1-19: RHRSW is credited for 013-N-N-RHRSWXL-O None, gap has (Met Cat III) external injection past was added to the model as been closed for containment venting. It was a late RHRSW crosstie the JUJL12R1 noted that the injection path must action to maintain alternate model.Related SRs lined up (MOVs opened) before injection after PC venting.AS-B3 venting by procedure.

However, The venting procedure (Met Cat I/II/III) there is no step in the execution steps to open the RHRSW or cognitive portion of the HEP crosstie valves prior to 013 -N-N-RHRSWXTIE venting are included in the execution error. The This is a finding, since it may execution error for both affect the value for the HEP and 013-N-N-RHRSWXTIE the quantification.

and 013-N-N-RHRSWX L-O reflects RHRSW alignment as alternate RPV injection.

HR-G1 1-10: Basic Event 054-01222AB-Open item. Negligible, F&O (Met Cat II) 24AB1-O uses a screening HEP is a suggestion value. While this is by definition that would not a risk significant function by enhance the RAW or FV, the action does HI-RA analysis.appear in some cutsets above 1E-9.This is a suggestion, since screening values are allowed by the standard for non-significant events for Cat II.

Attachment 2 to PLA-7119 Page 55 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE HR-G2 7-8: The combination sum The Peer Review None, gap has (Met Cat 1/111) technique presented in the HRAC suggestion questions the been closed for has no theoretical basis. Although combination sum the JUL12R1 all of the FIFE methodologies technique used in the EPRI model.have limitations, it is more HRA calculator and defensible to choose an industry recormnends consideration reviewed methodology that most of another approach.

It closely models the scenario was detenrnined acceptable according to the known to retain the combined limitations of the methodology method for actions with limited time available for rather than adding the cognitive reov e aus e the errors of two unlike recovery because the error of wo ulikecombined method provides methodologies to compensate for both the detailed timing uncertainties, assessment of the CBDTM This is a suggestion.

While the PSFs and accounts for the HRA Calculator allows this expected increase in Pc if approach, its basis may be subject the time available for to challenge.

recovery is limited. The method is retained because it allows detailed PSF (Performance Shaping Factors) assessment and accounts for the expected increase in cognitive error associated with limited time available for recovery and is allowed within the use of the HRAC HR-G4 1-8: The description for event The title of 013-N-N- None, gap has (Met Cat II) 013-N-N-RHRSWXTIIE-O is RHRSWXTIE-O was been closed for OPERATOR FAILS TO TEE IN corrected in the HRAC the JUL 12R I FIRE MAIN OR database and in the HRA model.RHRSW WITHIN 29 MINUTES. Notebook.The mission time for this event, however, is 100 minutes.This is a suggestion because the timing analysis for the event is correct.

Attachment 2 to PLA-7119 Page 56 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE HR-G5 1-4: There are several instances in The basis for None, gap has (Met Cat II) the HRA Notebook where the manipulation times was been closed for previous HRA analysis carried forward in the the JUJL12R1 (Notebook) is quoted as a HRA Notebook.

model.reference for the manipulation time. The basis for these manipulation times should be carried forward to the new documentation.

This is a suggestion, since there is a basis for the manipulation time and this issue pertains only to documentation.

HR-G5 1-5: There is no documented The manipulation time None, gap has (Met Cat II) basis for the manipulation time for 013-N-N- been closed for for 013-N-N-RHRSWXTIE-O.

RHRSWXTIE-O was the JUL12R1 Note that the utility staff obtained via PPL operator model.subsequently noted an accurate interviews and reference basis for the timing. was. added to the HRA This is a suggestion, since the Notebook.utility stated a basis for the manipulation time.

Attachment 2 to PLA-7119 Page 57 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE HR-G7 (Met Cat I/II/IIl)Related SRs QU-C1 (Met Cat I/I1/I11)1-7: Dependent HEPs MAN-OPSPCINJL-O and 159-CNTVNT-O are found in a dependent HEP Group with three elements.

However, they are not in a dependent HEP Group by themselves (two event combination).

This appears to be inconsistent.

Table 5.3-1 gives an explanation that there is zero dependency between the actions. However, it appears that the timing information for 159-CNTVNT-O in that table does not match that in the HRA Calculator Database.

If the timing in the HRA calculator database for that event is used, it would appear that there is, in fact, some level of dependency between these events. This combination is important to the mitigation of long term DHR related sequences.

This is a finding because it has quantitative impact.The HRA dependency analysis has been completely re-performed with the JULI2R1 model.Additionally, F&O 1-7 has 2 parts: the dependency analysis question with regard to the manual MOV operation with containment venting actions, and the timing differences in the dependency analysis file (DAF) and the HRAC. The second part of the explanation addresses the need for the timing differences between the DAF and the HRAC in order to force the actions into their expected chronological order. The first issue starts with MAN-OPSPCINJL-O which was broken into 2 actions: MAN-OP SPC L-O and MAN-OPINJ L-O. The revised HRA dependency analysis includes a dependent HEP for the new SPC action and both versions of containment venting. The 159-CNTVNT-O action is in Combination 52.Combination 51 has MAN-OP SPC L-O and 159-CNTVNTLOCAL-O.

Additionally, since MAN-OP SPC INJ E-O is not credited due to the timing constraints (i.e., HEP value= 1.0 and it is set to TRUE prior to quantification), there are no dependent HEPs which involve this early action.None, gap has been closed for the JUL12R1 model.

Attachment 2 to PLA-7119 Page 58 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE HR-G7 1-9: The HEP values that are part The processing of the None, gap has (Met Cat I/II/II) of a dependent group are HEPs has been revised, been closed for sometimes assigned and HEP in A JUL12R1 model flag the JUL12Rl the RR file that is arbitrarily high. file has been created to model.After performing the elevate the HEPs prior to quantification, a post processing quantification, and the recovery is applied to these non- real values are maintained dependent HEPs to return them to in the JUL12R1.RR file.their "true" value. Although the true HEP value is seen in the HEP description, it is somewhat confuising to someone not familiar with the model; it can also cause issues when using the RR file to perform query operations for data extraction from the model.This is a suggestion because it does not affect quantification.

HR-H2 1-48: A spot check of several Open item Negligible, this (Met Cat 1/11/111)

HFEs within the Susquehanna F&O is 2011 HRA Update in V 411 used quantitatively with the DAF. HRA file reveals insignificant.

that individual operator actions are selectively credited where appropriate for recovery of potential execution errors.However the dependency values are often not used with the HRA calculator for the cognitive decision trees when a LD is assessed.

While the use of "N/A" produces realistic results in the case of ZD it provides unrealistic low values for cases where a higher dependency is suggested.

This is a suggestion, since it is not deemed to be quantitatively significant.

Attachment 2 to PLA-7119 Page 59 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE HR-12 (Met Cat I/II/II)7-12: The Susquehanna HRA Notebook, PA-B-NA-041, documents the process used to characterize the HFEs used in the model. It is noted however that some documentation is provided within the notebook which does not actually reflect the process used. For example, assessing recovery factors based on time phasing appears not to have been done as is described in Table 4.2.1-11 [INCREMENTAL(l)

CONDITIONAL FAILURE PROBABILITIES (NON-RECOVERY PROBABILITIES WITHIN EACH TIME PHASE)].Rather, the recovery factors that are inherent within the HRA Calculator appear to be used in the actual modeling of the HFEs and such recovery factors do not account for time phasing.This is a suggestion because it relates to updating the documentation within the HRA notebook to reflect only what is done in the system models.Expanded and/or corrected discussion was provided in the HRA notebook, sections 4.2.3 and 4.2.1.4.None, gap has been closed for the JUL12R1 model.DA-Al 4-6: There is no clear statement Documentation was None, gap has (Met Cat 1/11/I11) documenting that the system added to the Component been closed for analysis or the overall model was Data Notebook.

the JUL12R1 used to determine which basic model.Related SRs events were identified that DA-A4 required development of data.(Met Cat I/II/III)

This is a finding since identification of the basic events from the system analysis is required by the ASME standard.

Attachment 2 to PLA-7119 Page 60 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE DA-C4 4-8: The Component Data Added discussion for None, gap has (Met Cat I/I/11) Notebook evaluates the evaluation of failures to been closed for unavailability in Appendix B Section B.4 of the the JUL 12R1 using plant data taken from Component Data model.Maintenance Rule and/or MSPI Notebook and added as shown in Table B-8. Table B- cross-reference to 10 shows the Maintenance Rule categories to the PRA Functional Failure Data that was comments field in Table evaluated for inclusion in the B-10. This revision is in Bayes update. However, there is line with the proposed no clear basis documented in resolution provided by Section B.2 for how events were the peer review team and screened to identify failures to be documents the method included in the model for the data used for analysis of data analysis.

applicability.

This is a finding since the requirement is to provide a clear basis for identification of failures for inclusion in the data analysis.DA-C14 1-22: Coincident maintenance A sensitivity case is now None, gap has (Met Cat 1/11/111) unavailability is well accounted discussed in the been closed for for in the Susquehanna PRA. component data the JUL12R1 However, there is a maintenance notebookSection B.3.3 model.Related SRs combination of risk significant which indicates that this SY-A20 equipment which may occur that additional combination is (Met Cat 1I/11I1) is not accounted for in the PRA not warranted due to very model that is allowed by the 13 low risk impact. Other week schedule.

That combination combinations were not is in Week for of the Table G-1 identified.

work matrix, which is the Blue Max portable diesel generator and the B/D ESW HVAC system.This is a suggestion, since the equipment is not considered to be redundant per strict interpretation of the ASME Standard requirement.

Attachment 2 to PLA-7119 Page 61 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE DA-El 4-7: Sections in the Summary The Component Data None, gap has (Met Cat III//II) Notebook and in the Component Notebookwas revised to been closed for Data Notebook are identified as incorporate the title the JUL12RI"Appendices..." when in fact the Attachment instead of model.Related SRs notebooks identify the Appendix where AS-Cl corresponding sections as appropriate.(Met Cat /1141111) "Attachments".

SY-C1 Table B-I in the Component Data (Met Cat MI/II) Notebook refers to sections of the notebook and to the Systems Notebooks as "Appendix..." when in fact they are identified as"Attachment...".

This is a suggestion since it involves documentation only. The roadmap designation of"Appendix..." led to confusion and difficulty in finding the correct section in the notebook.QU-B7 1-47: There is a general The JUL1IJ2R1 model None, gap has (Met Cat I/I/IIr) discussion regarding the rationale Quantification and been closed for for the combinations in the Summary Notebook, the JUL12R1 mutually exclusive file. However, section A.2 and Table model.the rationale for each combination A.2-1, provide the is not explicitly discussed in the mutually exclusive basic documentation.

event combinations and This is a suggestion because it the basis for exclusion.

pertains to documentation only.

Attachment 2 to PLA-7119 Page 62 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE QU-B9 1-38: It was noted that there are Added 0.0 probability None, gap has (Met Cat I/II/I11) several negated events with a events to flag file as false been closed for probability of 0.0 that appear in to be assigned prior to the JUL12R1 the CDF cutsets (specifically, quantification, model.events like -EFORB). These events, while useful for the cutset readability and debugging, should be set to false in a flag file for"production" quantifications.

This does not have a significant impact on the quantification (it only adds an insignificant conservatism) and therefore is a suggestion.

QU-D1 6-35: Only the top 10 cutsets are listed or This peer review suggestion is None, gap has been (Met Cat IH/IIllI) described in any detail. The percent directed to SR requirements QU- closed for the contribution to total CDF of these cntsets Dl and QU-D5. Requirement JUL12RI model.was not give, although the individual QU-D1 requires reviewing a Related SRs contributions are (the total appears to be sample of the significant accident QU-D5 -30% of CDF). sequences/cutset sufficient to (Met Cat I/I/III) A listing of those cutsets selected for in- determine that the logic is depth review for the non-significant cutset correct. QU-D5 involves review process would enhance the reviewing a sample of non-documentation, significant accident cutsets or sequences to determine they are This is a suggestion as the review of cutsets reasonable and have physical appears to be thorough, based on meaning. Instead of selecting a discussions with PRA staff, random number of cutset to review, the top cutsets contributing

> 1% to the overall CDF/LERF were reviewed.

This constitutes a review of significant cutsets. A sampling of non-significant cutsets was selected for review of reasonableness and meaning. These cutsets and their description were added to the summary notebook where in the past, only conclusion of reasonableness was provided.

Attachment 2 to PLA-7119 Page 63 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE QU-D2 (Met Cat I/II/III)6-38: Section 3.4 of Attachment A of the Summary Notebook discusses dominant core damage sequences and provides a description of why these sequences result in CDF/LERF.However, further review and discussion of the results would help verify model reasonableness.

Section 4 includes a review of basic event importance, initiator contributions to CDF/LERF, and significant operator actions. The discussion is focused on what items changed since the previous revision, rather than the reasonableness of the results (i.e., why is LOOP -50% of CDF when the plant has a 5th diesel and the Blue Max diesel to for charging batteries?).

This is a finding as further documented review and discussion of results is needed to verify the reasonableness of the model.The item identified requests additional discussion and justification to the statements of reasonableness.

The Quantification and Summary Notebook was revised to include additional sequence discussion and justification of reasonableness given plant operation.

Additional discussion for LERF differences found in section 3.5 was also provided.

Section 4.1, important systems, was also enhanced by providing a discussion of the component basic event importances.

In general, where appropriate, additional discussion was added to results sections to better demonstrate statements of reasonableness.

None, gap has been closed for the JUL12R1 model.

Attachment 2 to PLA-7119 Page 64 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE QU-D6 (Met Cat II/HI)6-37: Importance of Operator actions are given in terms of RAW and RRW. However, the quantification process appears to remove dependent HEPs from the cutsets and replace them with a single basic event containing the total dependent failure probability.

No discussion was found regarding how this might impact Importance Measures for HEPs.This is a suggestion as it does not directly impact the model or quantification process, but can distort model results if the effects are not accounted for.The dependent operator action basic event nomenclature that was provided in the JUL12 risk model was determined not complete.During the peer review, the noted operator actions provided to the peer review team were only independent actions.Upon review of the basic events, it was determined that the dependent operator action nomenclature did not include the -O at the end of the basic event name.Therefore, upon data sorting, the complete list of operator actions was not initially provided to the peer review team.The dependent operator actions are identified by a beginning letter Z annotation and now end with a -O annotation.

Therefore any future assessment and search for operator actions and their importance will be complete.

All operator actions both independent and dependent now end with -0.None, gap has been closed for the JUL12RI model.

Attachment 2 to PLA-7119 Page 65 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE QU-D7 6-36: Importance measures for Section 4.1 of the None, gap has (Met Cat 1/11/I11) basic events are given in Table Quantification and been closed for 4.1-1, and appears to be based on Summary the JUL12R1 RRW > 0.1. The Summary Notebookprovides a model.Notebook indicates that these review of results were reviewed and appear component/system basic reasonable.

Importance measures event importance.

The for all basic events are given in importance measures Attachment B for CDF (both reviewed in the notebook units), and Attachment C for were revised to include LERF (both units). Fussell-Vesely and Risk While Table 4.1-1 is titled Achievement Worth'Important Components to (RAW). The listed basic Reduction in Risk (RRW)', this events are those having appears to be a misnomer as the importance measures FV items listed in the table are basic greater than 0.005 and events. No component importance RAW greater than 2. A measures were found in the discussion supporting a documentation.

reasonable results This is a finding as reviewing conclusion was provided.component ismaofince is revwird The results were component importance is required determined to be by this SR. acceptable when considering plant configuration and the changes made to the PRA model during the latest data update.QU-E2 1-44: With the exception of the Open item Documentation (Met Cat I/I/II) system notebooks, assumptions item. No impact tend to be scattered throughout the documents.

Consider consolidating all assumptions into a single section of each technical notebook.This is a suggestion since it applies to documentation only.

Attachment 2 to PLA-7119 Page 66 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE QU-E3 1-26: There are several classes of Error Factors were added None, gap has (Met Cat III) basic events which do not have for all basic events or been closed for associated error factors. These type codes in the risk the JUL12RI include: internal flooding model reliability database model.Related SRs initiators, unavailabilities, and file DA-D3 certain operator actions. This (Met Cat II) causes the distribution calculated by Uncert to be narrower than it would be had error factors been included for these parameters.

This is a finding because it relates to the results of the parametric uncertainty.

QU-E3 1-45: No discussion of the results The JUL12R1 model None, gap has (Met Cat III) of the Parametric Uncertainty uncertainty analysis been closed for Analysis was found. No provided in the the JUL12R1 calculation of the Error Factor Quantification and model.(95%/50%)

was found. No Summary Notebookwas statement regarding the updated to include a full reasonableness of the CAFTA discussion of uncertainty mean value was found. including the provision of This is a finding since it relates to a mean value comparison fundamental information table, additional necessary for most application uncertainty graphs for submittals.

1CDF, 1HE, 2CDF, and 2HE, and a specific conclusion section discussing results, mean, and skewness.QU-F3 6-40: No initiating event pie chart The Quantification and None, gap has (Met Cat IIII) was given for Unit 2 results. The Summary Notebook was been closed for Summary Notebook states that revised to include the JUL12R1 Unit 2 results are similar. No initiating events pie model.importance measures for charts for 1CDF, 2DF, components or systems were 1HBE, and 2HE.given in the documentation.

This is a suggestion to enhance the model documentation.

Attachment 2 to PLA-7119 Page 67 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE LE-CIO (Met Cat II)Related SRs LE-C12 (Met Cat II)3-5: Per discussion with plant staff, although a review of sequences was not performed"after the fact" to try to further reduce LERF. Rather, the event trees were built to credit equipment operation and operator actions as would be warranted given the conditions.

The sequences were reviewed in this process. That is, only actions from the control room and equipment that could be reasonably assumed for success were credited.

In this fashion, no additional engineering analyses were warranted to support continued operation of equipment or operator actions during accident progression that could reduce LERF.It was determined that this process should be documented in the AS/SC notebook.It was determined that documentation of the process that was utilized to evaluate the accident sequence procession is necessary to affirm for PRA applications that an evaluation was performed.

The process for evaluating accident sequence progression was added to the Quantification and Summary Notebook.None, gap has been closed for the JUL I2R1 model.LE-F3 1-43: Understanding LERF Open item Documentation (Met Cat I/lI/III) uncertainty in the Susquehanna item. No model would be improved by impact.having LERF related assumptions were clearly identified and listed in a single place (e.g., a section of the summary notebook or elsewhere).

This is a suggestion because it applies to documentation only.

Attachment 2 to PLA-7119 Page 68 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE LE-G5 2-4: Appendix E, Section E.6 of Section E is related to None, gap has (Met Cat I/II/II1) the Summary Notebook evaluates quantification limitations, been closed for the limitations of the LERF and would not be the JITL12R1 evaluations related to the appropriate for model.quantification process. incorporation of This does not address the limitations due to limitations of the LERF analysis modeling choices., due to assumptions or modeling Therefore, Section 2.10.1 choices. was added to the This is a suggestion to provide a LJUL12R1 Quantification more complete description of the and Summary Notebook morecompete esciptin ofthe for a discussion of LERF analysis limitations for potna imitation ta applications.

potential limitations that could influence LERF results in applications.

IFPP-Al 6-1: Based on discussion in Open item Negligible effect (Met Cat I/II/111)

Section 3.1 and contents of on model results.Appendix C of the Internal See PRA Impact Flooding notebook, flood areas from Internal Related SRs are based on plant rooms, which Flooding IFPP-B 1 appear to be generally discussion, (Met Cat I/11/111) independent of other areas which preceeds regarding flood propagation.

Table 1.Many buildings and structures were eliminated from fuirther consideration on the basis that they do not contain any SSCs modeled in the PRA, as identified in Section 3.1.1.2 However, it is not clear if there exists a potential for a flood in one of these areas to propagate to a building/area that does contain flood susceptible PRA equipment.

Based on discussions with PRA staff and review of the plant layout drawing, only the Radwaste building is connected to the main portion of the plant.This is a suggestion as the list of screened buildings appears reasonable.

Attachment 2 to PLA-7119 Page 69 of 69 TABLE 2 SUPPORTING REQUIREMENTS MEETING CAPABILITY CATEGORY II OR GREATER WITH ASSOCIATED FACTS AND OBSERVATIONS SUPPORTING F&O #, DESCRIPTION OF GAP, RESOLUTION IMPACT REQUIREMENT AND SIGNIFICANCE IFQU-A2 1-28: Consider using the FRANX Open item None, F&O (Met Cat I/1II/I1) or other declarative modeling tool suggests a way for the injection of flooding of adding flood initiators (and other spatially initiators to the oriented initiators, such as model and is an internal fire, or external event enhancement.

initiators such as seismic).This is a suggestion, since there is no requirement to use a declarative modeling technique for injection of flooding initiators.

MU-Cl 1-27: There is no requirement to Open item None, F&O (Met Cat Ill/I/) issue the development model as addresses the the updated model based upon the PRA quantitative impact on PRA Maintenance and Related SRs applications (such as MSPI) in Update MU-E1 the Susquehanna model Procedure.(Met Cat F11/111) maintenance procedures.

This is a finding because it causes the SR to be not met.(This F&O may be a finding however both of the associated SRs were noted as met.)

Attachment 3 to PLA-7119 Markups of Existing Technical Specifications PPL Rev. 2 Definitions 1.1 1.1 Definitions (continued)

RATED THERMAL POWER (RTP)REACTOR PROTECTION SYSTEM (RPS) RESPONSE TIME SHUTDOWN MARGIN (SDM)RTP shall be a total reactor core heat transfer rate to the reactor coolant of 3952 MWt.The RPS RESPONSE TIME shall be that time interval from when the monitored parameter exceeds its RPS trip setpoint at the channel sensor until de-energization of the scram pilot valve solenoids.

The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.SDM shall be the amount of reactivity by which the reactor is subcritical or would be subcritical assuming that: a. The reactor is xenon free;b. The moderator temperature is 68°F; and c. All control rods are fully inserted except for the single control rod of highest reactivity worth, which is assumed to be fully withdrawn.

With control rods not capable of being fully inserted, the reactivity worth of these control rods must be accounted for in the determination of SDM.A S-T.AG-GFERED TEST OASIS shall concist Of the testing of one of the systems, subsystems, channels, or specified by the Sulveillance Frequency, so that all systems, subsystems, channels, or other designated components are tested durIing il Sun.'cilIanco Frequency intervals, where il is the total numnber of systems, subsystems, channels, or other designated comnponents in the aSSOciated function.THERMAL POWER shall be the total reactor core heat transfer rate to the reactor coolant.The TURBINE BYPASS SYSTEM RESPONSE TIME consists of the time from when the turbine bypass control unit generates a turbine bypass valve flow signal (continued)

STAGGERED TEST BRASIS2 THERMAL POWER TURBINE BYPASS SYSTEM RESPONSE TIME I SUSQUEHANNA-UNIT 1 TS / 1.1-6 Amendment 4-94, 24-&

PPL Rev. 4 Control Rod OPERABILITY 3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY 24 hGuFsln accordance with the Surveillance Frequency SR 3.1.3.1 Determine the position of each control rod. trolaProgram Control Progqram SR 3.1.3.2 NOT USED SR 3.1.3.3 -----------------

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

Not required to be performed until 31 days after the control rod is withdrawn and THERMAL POWER is greater than the LPSP of the RWM.In accordance with the Insert each withdrawn control rod at least one Surveillance Frequency notch. Control Pro-gram 1- days SR 3.1.3.4 Verify each control rod scram time from fully In accordance with withdrawn to notch position 05 is < 7 seconds. SR 3.1.4.1, SR 3.1.4.2, SR 3.1.4.3, and SR 3.1.4.4 (continued)

SUSQUEHANNA

-UNIT 1 TS / 3.1-10 Amendment 47-8-,2 PPL Rev. 2 Control Rod Scram Times 3.1.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY In accordance with the SR 3.1.4.2 Verify, for a representative sample, each tested Surv ance Frehuenc control rod scram time is within the limits of Cnrol Program Table 3.1.4-1 with reactor steam dome pressure Control Pro0ram> 800 psig. operati on in M OD E Prior to declaring control rod SR 3.1.4.3 Verify each affected control rod scram time is PrABLE after work on within the limits of Table 3.1.4-1 with any reactor control rod or CRD System steam dome pressure, that could affect scram time SR 3.1.4.4 Verify each affected control rod scram time is Prior to exceeding 40% RTP within the limits of Table 3.1.4-1 with reactor after fuel movement within steam dome pressure > 800 psig. the affected core cell AND Prior to exceeding 40% RTP after work on control rod or CRD System that could affect scram time SUSQUEHANNA

-UNIT 1 TS / 3.1-13 Amendment 479, 237, 249 PPL Rev. 0 Control Rod Scram Accumulators 3.1.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more control rod C.1 Verify all control rods Immediately upon scram accumulators associated with inoperable discovery of charging inoperable with reactor accumulators are fully water header pressure steam dome pressure inserted.

< 940 psig< 900 psig.AND C.2 Declare the associated control 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> rod inoperable.

D. Required Action and D. 1 ---------NOTE-------

associated Completion Not applicable if all inoperable Time of Required Action control rod scram B.1 or C.1 not met. accumulators are associated with fully inserted control rods.Place the reactor mode switch Immediately in the shutdown position.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify each control rod scram In accordance with the Surveillance accumulator nitrogen pressure is Frequency Control Program-7days

> 940 psig.I SUSQUEHANNA

-UNIT 1 TS / 3.1-15 Amendment 178 PPL Rev. 0 Rod Pattern Control 3.1.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Nine or more OPERABLE B.1 ----------

NOTE -------control rods not in Rod worth minimizer (RWM)compliance with BPWS. may be bypassed as allowed by LCO 3.3.2.1.Suspend withdrawal of Immediately control rods.AND B.2 Place the reactor mode 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> switch in the shutdown position.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.1 Verify all OPERABLE control rods comply with In accordance with the BPWS. Surveillance Frequency Control Procqram24-heuFs I SUSQUEHANNA

-UNIT 1 TS / 3.1-18 Amendment47 PPL Rev. 3 SLC SYSTEM 3.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.1 Verify available volume of sodium pentaborate In accordance with the solution is within the limits of Figure 3.1.7-1. Surveillance Frequency Control Proqram24-hours SR 3.1.7.2 Verify temperature of sodium pentaborate solution In accordance with the is within the limits of Figure 3.1.7-2. Surveillance Frequency Control Proqram24-hOUrs SR 3.1.7.3 Verify temperature of pump suction piping is within In accordance with the the limits of Figure 3.1.7-2. Surveillance Frequency Control Proqram24-heuws SR 3.1.7.4 Verify continuity of explosive charge. In accordance with the Surveillance Frequency Control Proqram31 days SR 3.1.7.5 Verify the concentration of sodium pentaborate in Inaccordance with the solution is within the limits of Figure 3.1.7-1. Surveillance Frequency Control Proqram31 days AND Once within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after water or sodium pentaborate is added to solution AND Once within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after solution temperature is restored within the limits of Figure 3.1.7-2 (continued)

I SUSQUEHANNA

-UNIT 1 TS / 3.1-21 Amendment V8,-240-PPL Rev. 3 SLC SYSTEM 3.1.7 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.1.7.6 Verify each SLC subsystem manual and power In accordance with the operated valve in the flow path that is not locked, Surveillance Frequency sealed, or otherwise secured in position is in the Control correct position, or can be aligned to the correct position.SR 3.1.7.7 Verify each pump develops a flow rate 40.0 gpm In accordance with the at a discharge pressure 1250 psig. Inservice Testing Program SR 3.1.7.8 Verify flow through one SLC subsystem pump into In accordance with the reactor pressure vessel. Surveillance Frequency Control Proqram24 menths on a STAGG-ERED TEST BA419 SR 3.1.7.9 Verify all heat traced piping between storage tank In accordance with the and pump suction is unblocked.

Surveillance Frequency Control Proqram24" menths AND Once within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after solution temperature is restored within the limits of Figure 3.1.7-2 SR 3.1.7.10 Verify sodium pentaborate enrichment is Prior to addition to SLC tank.!88 atom percent B-10.SUSQUEHANNA

-UNIT 1 TS / 3.1-22 Amendment 17-8, 2,1 -24G PPL Rev. 4-SDV Vent and Drain Valves 3.1.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.8.1 ------------------

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

Not required to be met on vent and drain valves closed during performance of SR 3.1.8.2.Verify each SDV vent and drain valve is open. In accordance with the Surveillance Frequency Control Proqram31 SR 3.1.8.2 Cycle each SDV vent and drain valve to the fully In accordance with the closed and fully open position.

Surveillance Frequency Control Program2-days SR 3.1.8.3 Verify each SDV vent and drain valve: 24-menthsln accordance with the Surveillance

a. Closes in 30 seconds after receipt of an Frequency Control Program actual or simulated scram signal; and b. Opens when the actual or simulated scram signal is reset.SUSQUEHANNA

-UNIT 1 TS / 3.1-26 Amendment

+76-PPL Rev. 4-APLHGR 3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.1 Verify all APLHGRs are less than or equal Once within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after to the limits specified in the COLR. >_ 23% RTP AND In accordance with the Surveillance Frequency Control Program24 hours thcrfefter AND Prior to exceeding 44% RTP I SUSQUEHANNA

-UNIT 1 TS / 3.2-2 Amendment PPL Rev. 1-MCPR 3.2.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify all MCPRs are greater than or equal to the limits specified in the COLR.Once within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after> 23% RTP AND In accordance with the Surveillance Frequency Control Pro-qram24 hours theroefter AND Prior to exceeding 44% RTP SR 3.2.2.2 Determine the MCPR limits.Once within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after each completion of SRs in 3.1.4 I SUSQUEHANNA-UNIT 1 TS / 3.2-4 Amendment

>718,4469--

PPL Rev. 4 LHGR 3.2.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 Verify all LHGRs are less than or equal to Once within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after the limits specified in the COLR. >_ 23% RTP AND In accordance with the Surveillance Frequency Control Program24 hours thereafter AND Prior to exceeding 44% RTP I SUSQUEHANNA

-UNIT 1 TS / 3.2-6 Amendment 4-7-9, 246-PPL Rev. 3 RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS

---

NOTES.1. Refer to Table 3.3.1.1-1 to determine which SRs apply for each RPS Function.2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the associated Function maintains RPS trip capability.

SURVEILLANCE FREQUENCY SR 3.3.1.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Proqram!2 hGurs SR 3.3.1.1.2 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Proqram24-hewrs SR 3.3.1.1.3

---

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

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after THERMAL POWER _> 23% RTP.Verify the absolute difference between the average In accordance with power range monitor (APRM) channels and the the Surveillance calculated power is _ 2% RTP while operating at Frequency Control23% RTP. Procqram7-4-ays SR 3.3.1.1.4

---

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

Not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after entering MODE 2.Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Proqram7-days (continued)

SUSQUEHANNA

-UNIT 1 TS / 3.3-3 Amendment 174 2aZ49 246-PPL Rev. 3 RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.5 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program -cays SR 3.3.1.1.6 Verify the source range monitor (SRM) and Prior to fully intermediate range monitor (IRM) channels overlap, withdrawing SRMs from the core.SR 3.3.1.1.7

---

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

Only required to be met during entry into MODE 2 from MODE 1.Verify the IRM and APRM channels overlap. In accordance with the Surveillance Frequency Control Program 7-days SR 3.3.1.1.8 Calibrate the local power range monitors.

In accordance with the Surveillance Frequency Control Progqram 1 000 M\AJD/MT aveFage-Gore expesufs SR 3.3.1.1.9

---

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

A test of all required contacts does not have to be performed.

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program 92-days (continued)

I SUSQUEHANNA

-UNIT 1 TS / 3.3-4 Amendment 7-, 24&-Correction Letter Dated PPL Rev. 3 RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.10 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Pro-qram ,2-day..SR 3.3.1.1.11

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

1. Neutron detectors are excluded.2. For Function 1.a, not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after entering MODE 2.Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Procqram 484-dave SR 3.3.1.1.12

---

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

1. For Function 2.a, not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after entering MODE 2.2. For Functions 2.b and 2.f, the CHANNEL FUNCTIONAL TEST includes the recirculation flow input processing, excluding the flow transmitters.

Perform CHANNEL FUNCTIONAL TEST In accordance with the Surveillance Frequency Control Pro.qram,18,4-days (continued)

SUSQUEHANNA

-UNIT 1 TS / 3.3-5 Amendment 172,,*'2*, 2411ý PPL Rev. 3 RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.13 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Pro qram24-menths SR 3.3.1.1.14 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program 24 menthe SR 3.3.1.1.15 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program 24 -me,4h SR 3.3.1.1.16 Verify Turbine Stop Valve-Closure and Turbine In accordance with Control Valve Fast Closure, Trip Oil Pressure-Low the Surveillance Functions are not bypassed when THERMAL Frequency Control POWER is > 26% RTP. Proqram24-menft SR 3.3.1.1.17

---

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

1. Neutron detectors are excluded.2. For Function 5 "n" equals 4 .hanncls for the purpose of deteFrmining the_ STAGGERED TETBSS Frequencyý, 3. For 2."e, "n" equals 8 channelsfo-the purpose of determiningthe TGEE TEST BASIS FrequeGcY. g of APIRM and OPRM outputs, shall alternate.

Verify the RPS RESPONSE TIME is within limits. In accordance with the Surveillance Frequency Control Pro qram24 months on a STAGGERED TEST-(oASine (continued)

I SUSQUEHANNA-UNIT 1 TS / 3.3-6 Amendment

ý1,911, 220, 2$

PPL Rev. 3 RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.18

---

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

1. Neutron detectors are excluded.2. For Functions 2.b and 2.f, the recirculation flow transmitters that feed the APRMs are included.Perform CHANNEL CALIBRATION In accordance with the Surveillance Frequency Control Procqram.24 menths SR 3.3.1.1.19 Verify OPRM is not bypassed when APRM Simulated In accordance with Thermal Power is >- 25% and recirculation drive flow the Surveillance is < value equivalent to the core flow value defined in Frequency Control the COLR. Proqram24 menths SR 3.3.1.1.20 Adjust recirculation drive flow to conform to reactor In accordance with core flow. the Surveillance Frequency Control Proqram24 mneths I SUSQUEHANNA

-UNIT 1 TS / 3.3-6.a Amendment PPL Rev. 0 SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS

---

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

Refer to Table 3.3.1.2-1 to determine which SRs apply for each applicable MODE or other specified conditions.

SURVEILLANCE FREQUENCY SR 3.3.1.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Proqram42 heuFs SR 3.3.1.2.2

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

1. Only required to be met during CORE ALTERATIONS.

2. One SRM may be used to satisfy more than one of the following Verify an OPERABLE SRM detector is located in: In accordance with the Surveillance Frequency Control Progqram 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> a. The fueled region;b. The core quadrant where CORE ALTERATIONS are being performed, when the associated SRM is included in the fueled region; and c. A core quadrant adjacent to where CORE ALTERATIONS are being performed, when the associated SRM is included in the fueled region.(continued)

I SUSQUEHANNA -UNIT 1 TS /3.3-12D; ,,.. IL,. " Amendment 47 PPL Rev. 0 SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.2.3 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Pro-qram24 heu's SR 3.3.1.2.4

---

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

Not required to be met with less than or equal to four fuel assemblies adjacent to the SRM and no other fuel assemblies in the associated core quadrant.Verify count rate is: 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> during CORE ALTERATIONS

a. > 3.0 cps if a signal to noise ratio _> 2:1 AND or In accordance with b. Within the limits of Figure 3.3.1.2-1 the Surveillance Frequency Control Pro-gram 2"4 ,hou SR 3.3.1.2.5 Perform CHANNEL FUNCTIONAL TEST and In accordance with determination of signal to noise ratio. the Surveillance Frequency Control Pro-qram7-dys (continued)

I SUSQUEHANNA

-UNIT 1.I\ TS / 3.3-13 Amendment 1-4&

PPL Rev. 0 SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.2.6

---

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

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after I RMs on Range 2 or below.Perform CHANNEL FUNCTIONAL TEST and In accordance with determination of signal to noise ratio, the Surveillance Frequency Control Procqram,31-days SR 3.3.1.2.7

---

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

1. Neutron detectors are excluded.2. Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after IRMs on Range 2 or below.Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Proqram24 menths I SUSQUEHANNA-UNIT 1 TS / 3.3-13.a Amendment PPL Rev. 2 Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS Ik I -----------------------------------

J JI--------------------------------------------------------

1. Refer to Table 3.3.2.1-1 to determine which SRs apply for each Control Rod Block Function.2. When an RBM channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the associated Function maintains control rod block capability.

SURVEILLANCE FREQUENCY SR 3.3.2.1.1 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Propqram4!4-day,'

SR 3.3.2.1.2

---

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

Not required to be performed until 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after any control rod is withdrawn at _< 10% RTP in MODE 2.Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Proqram42-days SR 3.3.2.1.3

---

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

Not required to be performed until 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after THERMAL POWER is _< 10% RTP in MODE 1.............................................................................

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control ProgramQ2-daya SR 3.3.2.1.4 Verify the RBM: a. Low Power Range -Upscale Function is not bypassed when In accordance with the APRM Simulated Thermal Power is > 28% RTP and <_ Intermediate Surveillance Frequency Power Range Setpoint specified in the COLR. Control Prociram24 MnAIIhs (continued)

SUSQUEHANNA

-UNIT 1 TS / 3.3-18 Amendment 17T,2S 0, 2-PPL Rev. 2 Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE FREQUENCY b. Intermediate Power Range -Upscale Function is not bypassed when APRM Simulated Thermal Power is > Intermediate Power Range Setpoint specified in the COLR and _< High Power Range Setpoint specified in the COLR.c. High Power Range -Upscale Function is not bypassed when APRM Simulated Thermal Power is > High Power Range Setpoint specified in the COLR.SR 3.3.2.1.5 Verify the RWM is not bypassed when THERMAL POWER In accordance with is < 10% RTP. the Surveillance Frequency Control Pro-qram24 months SR 3.3.2.1.6

---

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

Not required to be performed until 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after reactor mode switch is in the shutdown position.Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Procqram24-menths SR 3.3.2.1.7

---

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

Neutron detectors are excluded.In accordance with Perform CHANNEL CALIBRATION the Surveillance Frequency Control Proqram24 menths SR 3.3.2.1.8 Verify control rod sequences input to the RWM are in Prior to declaring conformance with BPWS. RWM OPERABLE following loading of sequence into RWM SUSQUEHANNA

-UNIT 1 TS / 3.3-19 Amendment 1X, 242 Nwl PPL Rev. 4 Feedwater

-Main Turbine High Water Level Trip Instrumentation 3.3.2.2 SURVEILLANCE REQUIREMENTS

---

N OT 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 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided feedwater

-main turbine high water level trip capability is maintained.

SURVEILLANCE FREQUENCY SR 3.3.2.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Proqram24 hourS SR 3.3.2.2.2------------------------------------------

1. A test of all required contacts does not have to be performed.

2. For the Feedwater

-Main Turbine High Water Level Function, a test of all required relays does not have to be performed.

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program92-days SR 3.3.2.2.3 Perform CHANNEL CALIBRATION.

The Allowable In accordance with Value shall be _ 55.5 inches. the Surveillance Frequency Control Program24!

meths SR 3.3.2.2.4 Perform LOGIC SYSTEM FUNCTIONAL TEST including In accordance with valve actuation.

the Surveillance Frequency Control Pro.qram24 mcnths I SUSQUEHANNA

-UNIT 1 TS / 3.3-22 Amendment

+7 PPL Rev. 2 PAM Instrumentation 3.3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Enter the Condition referenced Immediately associated in Table 3.3.3.1-iA for the Completion Time of channel.Condition C not met.E. As required by E.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Required Action D.1 and referenced in Table 3.3.3.1-1.

F. As required by F.1 Initiate action in accordance with Immediately Required Action D.1 Specification 5.6.7.and referenced in Table 3.3.3.1-1.

SURVEILLANCE REQUIREMENTS

---

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

These SRs apply to each Function in Table 3.3.3.1-1.

SURVEILLANCE FREQUENCY SR 3.3.3.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Pro-qram31,-day.

SR 3.3.3.1.2 Not Used.SR 3.3.3.1.3 Perform CHANNEL CALIBRATION for all Functions 24 menthsln except PCIV Position.

accordance with the Surveillance Frequency Control Pro-gram SUSQUEHANNA

-UNIT 1 TS / 3.3-24 Amendment IM, 2 PPL Rev. 4 Remote Shutdown System 3.3.3.2 SURVEILLANCE REQUIREMENTS

---

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

Refer to Table 3.3.3.2-1 to determine which SRs apply for each Remote Shutdown System Function.SURVEILLANCE FREQUENCY SR 3.3.3.2.1 Perform CHANNEL CHECK for each required In accordance with instrumentation channel that is normally energized.

the Surveillance Frequency Control Pro-qram341-da,'

SR 3.3.3.2.2 Verify each required control circuit and transfer In accordance with switch is capable of performing the intended the Surveillance function.

Frequency Control Propqram24-iewths SIR 3.3.3.2.3 Perform CHANNEL CALIBRATION for each In accordance with required instrumentation channel. the Surveillance Frequency Control Procqram24-menths I SUSQUEHANNA

-UNIT 1 TS / 3.3-27 Amendment 148-I PPL Rev. 4 EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS

---

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

SURVEILLANCE FREQUENCY SR 3.3.4.1.1 A test of all required contacts does not have to be performed.

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Proqram92-days SR 3.3.4.1.2 Perform CHANNEL CALIBRATION.

The Allowable Values shall be: In accordance with the Surveillance Frequency Control Proqram24 months TSV-Closure:

<7% closed;and TCV Fast Closure, Trip Oil Pressure-Low:

_> 460 psig.SR 3.3.4.1.3 Perform LOGIC SYSTEM FUNCTIONAL TEST including In accordance with breaker actuation, the Surveillance Frequency Control Proqram24 menths SR 3.3.4.1.4 Verify TSV-Closure and TCV Fast Closure, Trip Oil In accordance with Pressure-Low Functions are not bypassed when the Surveillance THERMAL POWER is 26% RTP. Frequency Control Proqram24 menths (continued)

I SUSQUEHANNA

-UNIT I TS / 3.3-31 Amendment V8, 246-PPL Rev. 4-EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY+SR 3.3.4.1.5-rF--------------------------------------

iJy.IE_Ii------------------------------------

Breaker arc suppression time may be assumed from the most recent performance of SR 3.3.4.1.6.

Verify the EOC-RPT SYSTEM RESPONSE TIME is within limits.In accordance with the Surveillance Frequency Control Proqram24 menths on a ST-AGGERED TEST 13ASS SR 3.3.4.1.6 Determine RPT breaker arc suppression time. In accordance with the Surveillance Frequency Control Proqram60 months I SUSQUEHANNA-UNIT 1 TS /.3.3-32 Amendment 4-7-&

PPL Rev. 0 ATWS-RPT Instrumentation 3.3.4.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One Function with B. 1 Restore ATWS-RPT trip 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> ATWS-RPT trip capability.

capability not maintained.

C. Both Functions with C. 1 Restore ATWS-RPT trip 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> ATWS-RPT trip capability for one Function.capability not maintained.

D. Required Action and D. 1 Remove the associated 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated recirculation pump from service.Completion Time not met.OR D.2 Be in MODE 2. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> SURVEILLANCE REQUIREMENTS

'1I1V J-----------------------------------

IJI I--I----------------------------------------

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

SURVEILLANCE FREQUENCY SR 3.3.4.2.1 Perform CHANNEL CHECK of Reactor Vessel Water In accordance with Level, Low Low, Level 2. the Surveillance Frequency Control Proqram12 heurs (continued)

I SUSQUEHANNA-UNIT 1 TS /-3.3-34 Amendment I-T&

PPL Rev. 0 ATWS-RPT Instrumentation 3.3.4.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.4.2.2 A test of all required contacts does not have to be performed.

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Proqram42-days SR 3.3.4.2.3 Perform CHANNEL CALIBRATION of the Reactor In accordance with Steam Dome Pressure-High.

The Allowable Values shall the Surveillance be_< 1150 psig. Frequency Control Pro.qramQ2-days SR 3.3.4.2.4 Perform CHANNEL CALIBRATION of the Reactor In accordance with Vessel Water Level Low Low, Level 2. The Allowable the Surveillance Values shall be >_ -45 inches. Frequency Control Proqram24-menths SR 3.3.4.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST including In accordance with breaker actuation.

the Surveillance Frequency Control Proqram24-meoths I SUSQUEHANNA

-UNIT 1 TS / 3.3-35 Amendment 17-Er PPL Rev. 3 ECCS Instrumentation 3.3.5.1 SURVEILLANCE REQUIREMENTS

---

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

1. Refer to Table 3.3.5.1-1 to determine which SRs apply for each ECCS Function.2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed as follows: (a) for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for Functions 3.c and 3.e; and (b) for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for Functions other than 3.c and 3.e provided the associated Function or the redundant Function maintains ECCS initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.5.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Prog ram!2 h9urS SR 3.3.5.1.2 A test of all required contacts does not have to be performed.

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Proqram-2-days SR 3.3.5.1.3 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Procram92-4ays SR 3.3.5.1.4 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Proqram24 months SR 3.3.5.1.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control IProram24-mentths SUSQUEHANNA

-UNIT 1 TS / 3.3-41 Amendment 3?8, Z2-6' PPL Rev. 0 RCIC System Instrumentation 3.3.5.2 SURVEILLANCE REQUIREMENTS

---

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

1. Refer to Table 3.3.5.2-1 to determine which SRs apply for each RCIC Function.2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed as follows: (a) for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for Functions 2 and 4 and (b) for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for Functions other than Functions 2 and 4 provided the associated Function maintains RCIC initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.5.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Proqram!2 heuFs SR 3.3.5.2.2 A test of all required contacts does not have to be performed.

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Pro~qram92-days SR 3.3.5.2.3 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Proqram92-dayes SR 3.3.5.2.4 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Proqram2-months SR 3.3.5.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program24-meniths I SUSQUEHANNA

-UNIT 1 TS / 3.3-50 Amendment J;-a-PPL Rev. 4 Primary Containment Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS-NOTES-1. Refer to Table 3.3.6.1-1 to determine which SRs apply for each Primary Containment Isolation Function.2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the associated Function maintains isolation capability.

SURVEILLANCE FREQUENCY SR 3.3.6.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Proqram12 h4nur SR 3.3.6.1.2

1. A test of all required contacts does not have to be performed 2. For Functions 2.e, 3.a, and 4.a, a test of all required relays does not have to be performed Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Proram92 days SR 3.3.6.1.3 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program92 days SR 3.3.6.1.4 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Proqram24 SR 3.3.6.1.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Procqram24 months SUSQUEHANNA

-UNIT 1 TS / 3.3-55 Amendment 17ýT PPL Rev. 4 Primary Containment Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.6.1.6-NOTE -----------------------------

1. For Function 1.b. channel sensors are excluded.2. Response time testing of isolating relays is not required for Function 5.a.Verify the ISOLATION SYSTEM RESPONSE TIME is within limits.In accordance with the Surveillance Frequency Control Procqram2-4 mSnthE, En a SUSQUEHANNA-UNIT 1 TS / 3.3-56 Amendment 19 PPL Rev. 0 Secondary Containment Isolation Instrumentation 3.3.6.2 SURVEILLANCE REQUIREMENTS

---

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

1. Refer to Table 3.3.6.2-1 to determine which SRs apply for each Secondary Containment Isolation Function.2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the associated Function maintains secondary containment isolation capability.

SURVEILLANCE FREQUENCY SR 3.3.6.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Proqram12 heurs SR 3.3.6.2.2 A test of all required contacts does not have to be performed.

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control SR 3.3.6.2.3 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control ProqramQ2-days SR 3.3.6.2.4 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Proqram24 months SR 3.3.6.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control ProEqram24.

months I SUSQUEHANNA-UNIT 1 TS /-3.3-65 Amendment V-8'-

PPL Rev. 0 CREOAS System Instrumentation 3.3.7.1 SURVEILLANCE REQUIREMENTS

---

ILJ r-.% ---------------------------------------------------------

1. Refer to Table 3.3.7.1-1 to determine which SRs apply for each CREOAS 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 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the associated Function maintains CREOAS initiation capability.

up to SURVEILLANCE FREQUENCY SR 3.3.7.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Proqram 12 ho'-S SR 3.3.7.1.2 1. A test of all required contacts does not have to be performed.

2. For Function 8, a test of all required relays does not have to be performed.

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Proqram42-days SR 3.3.7.1.3 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Proqram92-4ays SR 3.3.7.1.4 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Proqram24 months SR 3.3.7.1.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Prociramf2A-gnnnjhg I SUSQUEHANNA

-UNIT 1 TS / 3.3-70 Amendment U&

PPL Rev. 0 LOP Instrumentation 3.3.8,1 CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Declare associated diesel Immediately associated generator (DG) inoperable.

Completion Time of Condition B or C not met.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 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the associated Function maintains DG initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.8.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Prog ram4!2 heUrs SR 3.3.8.1.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program 3-4-days SR 3.3.8.1.3 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program 24 months SR 3.3.8.1.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program 24-mneths I SUSQUEHANNA-UNIT 1 TS / 3.3-73 Amendment 17,e PPL Rev. 0 RPS Electric Power Monitoring 3.3.8.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Initiate action to fully insert all Immediately associated insertable control rods in core Completion Time of cells containing one or more fuel Condition A or B not assemblies.

met in MODE 4 or 5.AND D.2.1 Initiate action to restore one Immediately electric power monitoring assembly to OPERABLE status for inservice power supply(s)supplying required instrumentation.

OR D.2.2 Initiate action to isolate the Immediately Residual Heat Removal Shutdown Cooling System.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.8.2.1

---

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

Only required to be performed prior to entering MODE 2 or 3 from MODE 4, when in MODE 4 for>_ 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Proqram484-day8 (continued)

I SUSQUEHANNA-UNIT 1 TS / 3.3-76 Amendment J.ýý PPL Rev. 0 RPS Electric Power Monitoring 3.3.8.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.8.2.2 Perform CHANNEL CALIBRATION.

The Allowable Values shall be: a. Overvoltage

_< 128.3 Vfor Division A and< 129.5 V for Division B.b. Undervoltage

_> 110.7 V for Division A and> 111.9 V for Division B.c. Underfrequency

_ 57 Hz.In accordance with the Surveillance Frequency Control Proaqram24 meths SR 3.3.8.2.3 Perform a system functional test. In accordance with the Surveillance Frequency Control Proqram24 menths I SUSQUEHANNA

-UNIT 1 TS / 3.3-77 Amendment JW-8--

PPL Rev. 3 Recirculating Loops Operating 3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY i SR 3.4.1.1--------------

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

Not required to be performed until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after both recirculation loops are in operation.

Verify recirculation loop jet pump flow mismatch with both recirculation loops in operation is: a. _< 10 million Ibm/hr when operating at< 75 million Ibm/hr total core flow; and b. < 5 million Ibm/hr when operating at> 75 million Ibm/hr total core flow.In accordance with the Surveillance Frequency Control Proqram24-he9UF SR 3.4.1.2 ----------------

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

Only required to be met during single loop operations.

Verify recirculation pump speed is within the In accordance with the limit specified in the LCO. Surveillance Frequency Control Proqram24-heuws SUSQUEHANNA

-UNIT 1 TS / 3.4-3 A endment 1/78,;T4, 2 Y5, 21-7 PPL Rev. 4 Jet Pumps 3.4.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.2.1 --------------------------

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

1. Not required to be completed until 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> after associated recirculation loop is in operation.

2. Not required to be completed until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after > 23% RTP.Verify at least two of the following criteria (a, In accordance with the b, or c) are satisfied for each operating Surveillance Frequency recirculation loop: Control Proqram24-hours

a. Recirculation loop drive flow versus Recirculation Pump speed differs by_< 10% from established patterns.b. Recirculation loop drive flow versus total core flow differs by _< 10% from established patterns.c. Each jet pump diffuser to lower plenum differential pressure differs by< 20% from established patterns, or each jet pump flow differs by < 10%from established patterns.I SUSQUEHANNA

-UNIT 1 TS / 3.4-7 Amendment 1"d, ;4,T YO PPL Rev. 0 RCS Operational LEAKAGE 3.4.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued)

B.2 Verify source of 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> unidentified LEAKAGE increase is not service sensitive type 304 or type 316 austenitic stainless steel.A. Required Action and C. 1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A AND or B not met.C.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> OR Pressure boundary LEAKAGE exists.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.4.1 Verify RCS unidentified and total LEAKAGE In accordance with the and unidentified LEAKAGE increases are Surveillance Frequency within limits. Control Proqram42 heurs I SUSQUEHANNA

-UNIT 1 TS / 3.4-11 Amendment 1-711ýV--,

PPL Rev. 4 RCS Leakage Detection Instrumentation 3.4.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 Perform a CHANNEL CHECK of required primary In accordance with containment atmospheric monitoring system. the Surveillance Frequency Control Pro qram2-h U'6 SR 3.4.6.2 Perform a CHANNEL FUNCTIONAL TEST of required In accordance with leakage detection instrumentation, the Surveillance Frequency Control Program y SR 3.4.6.3 Perform a CHANNEL CALIBRATION of required In accordance with leakage detection instrumentation, the Surveillance Frequency Control Propqram24-moethe I SUSQUEHANNA

-UNIT 1 TS / 3.4-16 Amendment 17-T PPL Rev.4 RCS Specific Activity 3.4.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued)

B.2.2.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> AND B.2.2.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 -------------------------

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

Only required to be performed in MODE 1.Verify reactor coolant DOSE EQUIVALENT In accordance with the 1-131 specific activity is < 0.2 pCi/gm. Surveillance Frequency Control Proqram7-days I SUSQUEHANNA

-UNIT 1 TS / 3.4-18 Amendment J,76 PPL Rev. 4 RHR Shutdown Cooling System -Hot Shutdown 3.4.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 ----------------------

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

Not required to be met until 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after reactor steam dome pressure is less than the RHR cut in permissive pressure.Verify one RHR shutdown cooling subsystem or In accordance with the recirculation pump is operating.

Surveillance Frequency Control Procqram42 heur-I SUSQUEHANNA-UNIT 1 TS / 3.4-21 Amendment J.7e PPL Rev. 0 RHR Shutdown Cooling System -Cold Shutdown 3.4.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. No RHR shutdown 8.1 Verify reactor coolant 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from discovery of cooling subsystem in circulating by an alternate no reactor coolant operation.

method. circulation AND AND No recirculation pump Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> in operation.

thereafter AND B.2 Monitor reactor coolant Once per hour temperature.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify one RHR shutdown cooling subsystem or In accordance with the recirculation pump is operating.

Surveillance Frequency Control Proqram42 I SUSQUEHANNA

-UNIT 1 TS /13.4-23 Amendment 17T PPL Rev. 2 RCS P/T Limits 3.4.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.10.1-----------------

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

Only required to be performed during RCS heatup and cooldown operations and RCS inservice leak and hydrostatic testing.Verify: a. RCS pressure and RCS temperature are to the right of the most limiting curve specified in Figures 3.4.10-1 through 3.4.10-3; and b. ---------------

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

Only applicable when governed by Figure 3.4.10-2, Curve B, and Figure 3.4.10-3, Curve C.RCS heatup and cooldown rates are< 100OF in any one hour period; and c. ---------------

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

Only applicable when governed by Figure 3.4.10-1, Curve A.RCS heatup and cooldown rates are < 20'F in any one hour period.In accordance with the Surveillance Frequency Control R~Rutes SR 3.4.10.2 Verify RCS pressure and RCS temperature are to Once within 15 minutes the right of the criticality limit (Curve C) specified in prior to control rod Figure 3.4.10-3.

withdrawal for the purpose of achieving criticality (continued)

SUSQUEHANNA

-UNIT 1 TS / 3.4-26 Amendment 2W PPL Rev. 2 RCS P/T Limits 3.4.10 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.10.6 ---------------------

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

Only required to be met in single loop operation when the idle recirculation loop is not isolated from the RPV, and: a. THERMAL POWER 27% RTP; or b. The operating recirculation loop flow< 21,320 gpm.Verify the difference between the reactor coolant Once within 15 minutes temperature in the recirculation loop not in prior to an increase in operation and the RPV coolant temperature is THERMAL POWER or_< 50 0 F. an increase in loop flow.SR 3.4.10.7 ---------------------

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

Only required to be performed when tensioning the reactor vessel head bolting studs.Verify reactor vessel flange and head flange In accordance with the temperatures are _> 70 0 F. Surveillance Frequency Control Pro-qram30 M#vut-es SR 3.4.10.8 ---------------------

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

Not required to be performed until 30 minutes after RCS temperature

_< 80°F in MODE 4.Verify reactor vessel flange and head flange In accordance with the temperatures are > 70 0 F. Surveillance Frequency Control Proqram30 Minutes (continued)

I SUSQUEHANNA-UNIT 1 TS / 3.4-28 Amendment V6, 24&-

PPL Rev. 2 RCS P/T Limits 3.4.10 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.10.9 ---------------------

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

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after RCS temperature

_ '100 0 F in MODE 4.Verify reactor vessel flange and head flange In accordance with the temperatures are _> 70 0 F. Surveillance Frequency Control Proqram4-2 heur-s I SUSQUEHANNA-UNIT 1 TS / 3.4-29 Amendment J.7&

PPL Rev. 0 Reactor Steam Dome Pressure 3.4.11 3.4 REACTOR COOLANT SYSTEM (RCS)3.4.11 Reactor Steam Dome Pressure LCO 3.4.11 APPLICABILITY:

The reactor steam dome pressure shall be _< 1050 psig.MODES 1 and 2.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Reactor steam dome A. 1 Restore reactor steam 15 minutes pressure not within dome pressure to within lim it, lim it.B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 Verify reactor steam dome pressure is In accordance with the_< 1050 psig. Surveillance Frequency V_) h Cnfo m Control Progqram .21-is, I SUSQUEHANNA

-UNIT I TS 1 3.4-31 Amendment 1_7ý PPL Rev. 4 ECCS -Operating 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify, for each ECCS injection/spray subsystem, In accordance with the the piping is filled with water from the pump Surveillance Frequency discharge valve to the injection valve. Control Program34-day.

SR 3.5.1.2 ------------------

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

Low pressure coolant injection (LPCI) subsystems may be considered OPERABLE during alignment and operation for decay heat removal with reactor steam dome pressure less than the Residual Heat Removal (RHR) cut in permissive pressure in MODE 3, if capable of being manually realigned and not otherwise inoperable.

Verify each ECCS injection/spray subsystem manual, power operated, and automatic valve in In accordance with the the flow path, that is not locked, sealed, or Surveillance Frequency otherwise secured in position, and the HPCI flow Control Program 31-days controller are in the correct position.SR 3.5.1.3 Verify ADS gas supply header pressure is In accordance with the135 psig. Surveillance Frequency Control Program_34-days SR 3.5.1.4 Verify at least one RHR System cross tie valve is In accordance with the closed and power is removed from the valve Surveillance Frequency operator.

Control Program 34-days SR 3.5.1.5 Verify each 480 volt AC swing bus transfers In accordance with the automatically from the normal source to the Surveillance Frequency alternate source on loss of power. Control Program 34-days (continued)

I SUSQUEHANNA

-UNIT 1 TS / 3.5-4 Amendment 1-7ý PPL Rev. 4 ECCS -Operating 3.5.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.1.9 -----------------

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

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam pressure and flow are adequate to perform the test.Verify, with reactor pressure _< 165 psig, the HPCI In accordance with the pump can develop a flow rate >_ 5000 gpm against Surveillance Frequency a system head corresponding to reactor pressure.

Control Program 2- menths SR 3.5.1.10 ------------------

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

Vessel injection/spray may be excluded.Verify each ECCS injection/spray subsystem In accordance with the actuates on an actual or simulated automatic Surveillance Frequency initiation signal. Control Program 24-menths SR 3.5.1.11 ------------------

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

Valve actuation may be excluded.Verify the ADS actuates on an actual or simulated In accordance with the automatic initiation signal. Surveillance Frequency Control Program 24 menthe SR 3.5.1.12 ------------------

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

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam pressure and flow are adequate to perform the test.Verify each ADS valve opens when manually In accordance with the actuated.

Surveillance Frequency Control Program 24 months on a STAGGERED TES I BA.SIS for each valve (continued)

I SUSQUEHANNA

-UNIT 1 TS / 3.5-6 Amendment 1-79 PPL Rev. 4 ECCS -Operating 3.5.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.1.13 ---------------

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

Instrumentation response time is based on historical response time data.Verify the ECCS RESPONSE TIME for each In accordance with the ECCS injection/spray subsystem is within limit. Surveillance Frequency Control Pro-gram 24-months I SUSQUEHANNA

-UNIT 1 TS / 3.5-7 Amendment 17-0' PPL Rev. 0 ECCS-Shutdown 3.5.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action C.2 and D.1 Initiate action to restore Immediately associated Completion Time secondary containment to not met. OPERABLE status.AND D.2 Initiate action to restore one Immediately standby gas treatment subsystem to OPERABLE status.AND D.3 Initiate action to restore isolation Immediately capability in each required secondary containment penetration flow path not isolated.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify, for each required low pressure coolant In accordance with the injection (LPCI) subsystem, the suppression pool Surveillance Frequency water level is _> 20 ft 0 inches. Control Proqram12 hGurs (continued)

I SUSQUEHANNA-UNIT 1 TS / 3.5-11 AmendmentJ7 PPL Rev. 0 ECCS-Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY i SR 3.5.2.2 Verify, for each required core spray (CS)subsystem, the: a. Suppression pool water level is>_ 20 ft 0 inches; or b. ----------------

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

Only one required CS subsystem may take credit for this option during OPDRVs.In accordance with the Surveillance Frequency Control Proqram12 hours Condensate storage tank water level is> 49% of capacity.SR 3.5.2.3 Verify, for each required ECCS injection/spray In accordance with the subsystem, the piping is filled with water from the Surveillance Frequency pump discharge valve to the injection valve. Control Pro-qram31 days SR 3.5.2.4 -------------------

NOTE--- --------LPCI subsystems may be considered OPERABLE during alignment and operation for decay heat removal if capable of being manually realigned and not otherwise inoperable.

Verify each required ECCS injection/spray In accordance with the subsystem manual, power operated, and Surveillance Frequency automatic valve in the flow path, that is not locked, Control Program 3-1 days sealed, or otherwise secured in position, is in the correct position.(continued)

I SUSQUEHANNA-UNIT 1 TS / 3.5-11 Amendment_178-PPL Rev. 0 ECCS-Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.5 Verify each required ECCS pump develops the specified flow rate against a system head corresponding to the specified reactor pressure.In accordance with the Inservice Testing Program SYSTEM CS LPCI FLOW RATE_6350 gpm> 12,200 gpm NO. OF PUMPS 2 1 SYSTEM HEAD CORRESPONDING TO A REACTOR PRESSURE OF> 105 psig> 20 psig SR 3.5.2.6 ------------------

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

Vessel injection/spray may be excluded.Verify each required ECCS injection/spray In accordance with the subsystem actuates on an actual or simulated Surveillance Frequency automatic initiation signal. Control Proqram24 menths SR 3.5.2.7 ------------------

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

Instrumentation response time may be assumed to be the historical instrumentation response time.Verify the ECCS RESPONSE TIME for each In accordance with the ECCS injection/spray subsystem is within limit. Surveillance Frequency Control Procqram24 months I SUSQUEHANNA

-UNIT 1 TS / 3.5-11 Amendmentj,7ý PPL Rev. 4 RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 SR 3.5.3.2 Verify the RCIC System piping is filled with water from the pump discharge valve to the injection valve.In accordance with the Surveillance Frequency Control Proqram3-4-aye Verify each RCIC System manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, and the RCIC flow controller are in the correct position.In accordance with the Surveillance Frequency Control Propqram34-days SR 3.5.3.3-NOTE ---------------------------------

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam pressure and flow are adequate to perform the test.Verify, with reactor pressure < 1060 psig and> 920 psig, the RCIC pump can develop a flow rate> 600 gpm against a system head corresponding to reactor pressure.In accordance with the Inservice Testing Program SR 3.5.3.4---------------

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

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam pressure and flow are adequate to perform the test.Verify, with reactor pressure < 165 psig, the RCIC pump can develop a flow rate > 600 gpm against a system head corresponding to reactor pressure.In accordance with the Surveillance Frequency Control Pro.qram-24 met4hs (continued)

I SUSQUEHANNA

-UNIT 1 TS / 3.5-13 Amendment 17 PPL Rev. 4-RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.3.5-NOTE-Vessel injection may be excluded.Verify the RCIC System actuates on an actual or simulated automatic initiation signal.In accordance with the Surveillance Frequency Control Program -24 I SUSQUEHANNA-UNIT 1 TS / 3.5-14 Amendment 17-9 PPL Rev. 0 Primary Containment 3.6.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.1.1 Perform required visual examinations and leakage In accordance with the rate testing except for primary containment air lock Primary Containment testing, in accordance with the Primary Leakage Rate Testing Containment Leakage Rate Testing Program. Program.SR 3.6.1.1.2 Verify that the drywell-to-suppression chamber When performing 10 CFR 50 bypass leakage is less than 0.00535 ft 2 at an initial Appendix J, Type A testing, in differential pressure of _ 4.3 psi. accordance with the Primary Containment Leakage Rate Testing Program.AND-- ---- ------------

Note ----------------

Only required after two consecutive tests fail and continues until two consecutive tests pass In accordance with the Surveillance Frequency Control Program 24-meiths (continued)

I SUSQUEHANNA

-UNIT 1 TS / 3.6-2 Amendment 1.74ý PPL Rev. 0 Primary Containment 3.6.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.1.1.3

---

Note-- -------------

Satisfied by the performance of SR 3.6.1.1.2.

Verify that the total drywell-to-suppression In accordance with the chamber vacuum breaker leakage is less than or Surveillance Frequency equal to .001605 ft 2 and the leakage area for each Control Proqram24 months set of vacuum breakers is less than or equal to.000642 ft 2 at an initial differential pressure of_ 4.3 psi.I SUSQUEHANNA

-UNIT 1 TS / 3.6-3 Amendmentj,7ýff PPL Rev. 0 Primary Containment Air Lock 3.6.1.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met. AND D.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.2.1

---

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

1. An inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test.2. Results shall be evaluated against acceptance criteria acceptable to SR 3.6.1.1.1.

Perform required primary containment air lock In accordance with leakage rate testing in accordance with the the Primary Primary Containment Leakage Rat Testihg Containment Leakage Program. Rate Testing Program SR 3.6.1.2.2 Verify only one door in the primary In accordance with containment air lock can be opened at-a time. the Surveillance Frequency Control Proqram,24 mnths I SUSQUEHANNA-UNIT 1 TS / 3.6-4 Amendment 178-PPL Rev. 3 PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.3.1----------------

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

1. Only required to be met in MODES 1, 2, and3.2. Not required to be met when the 18 and 24 inch primary containment purge valves are open for inerting, de-inerting, pressure control, ALARA or air quality considerations for personnel entry, or Surveillances that require the valves to be open.Verify each 18 and 24 inch primary containment purge valve is closed.In accordance with the Surveillance Frequency Control Proqram31-days j SR 3.6.1.3.2----------------

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

1. Valves and blind flanges in high radiation areas may be verified by use of administrative means.2. Not required to be met for PCIVs that are open under administrative controls.Verify each primary containment isolation manual valve and blind flange that is located outside primary containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed.In accordance with the Surveillance Frequency Control Program 34-days (continued)

I SUSQUEHANNA

-UNIT 1 TS / 3.6-12 Amendment 1,7ýr PPL Rev. 3 PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY 4-SR 3.6.1.3.3-----------------------------

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

1. Valves and blind flanges in high radiation areas may be verified by use of administrative means.2. Not required to be met for PCIVs that are open under administrative controls.Verify each primary containment manual isolation valve and blind flange that is located inside primary containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed.Prior to entering MODE 2 or 3 from MODE 4 if primary containment was de-inerted while in MODE 4, if not performed within the previous.j,4~-.SR 3.6.1.3.4 Verify continuity for each of the traversing incore probe (TIP) shear isolation valve explosive charge.In accordance with the Surveillance Frequency Control Proaram3.-days SR 3.6.1.3.5 Verify the isolation time of each-power operated In accordance and each automatic PCIV, except for MSIVs', is- with the Inservice within limits. Testing Program--(continued)

SUSQUEHANNA

-UNIT I TS / 3.6-13 Amendment 1708,.. ...

PPL Rev. 3 PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.1.3.6------------------

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

Only required to be met in MODES 1, 2 and 3.Perform leakage rate testing for each primary containment purge valve with resilient seals.In accordance with the Surveillance Frequency Control Program 24 morthhe SR 3.6.1.3.7 Verify the isolation time of each MSIV is In accordance

> 3 seconds and < 5 seconds. with the Inservice Testing Program SIR 3.6.1.3.8 Verify each automatic PCIV actuates to the In accordance with isolation position on an actual or simulated the Surveillance isolation signal. Frequency Control Pro-qram24,-,,,,h

&-SR 3.6.1.39 Verify a-representative sample of reactor -in accordance with ihstrumentation line EFCVs actuate to"check flow the Surveilance on a simulated instrument line break. Frequency Control Proqram24.... ........ '- ......,.. ,. "(continued do (otined SUSQUEHANNA

-UNIT 1 TS / 3.6-14 Amendment-143, 2-2T v PPL Rev. 3 PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.1.3.10 Remove and test the explosive squib from each In accordance with shear isolation valve of the TIP System. the Surveillance Frequency Control Proqram24-menth STAGGERED TEST- 1ASIS SR 3.6.1.3.11

---

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

Only required to be met in MODES 1, 2, and 3.Verify the combined leakage rate for all secondary In accordance containment bypass leakage paths is <_ 15 scfh with the Primary when pressurized to _> Pa. Containment Leakage Rate Testing Program.SR 3.6.1.3.12

---

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

Only required to be met in MODES 1, 2, and 3.Verify leakage rate through each MSIV is In accordance

< 100 scfh and 300 scfh for the combined with the Primary leakage including the leakage from the MS Line Containment Drains, when the MSIVs are tested at >_ 24.3 psig Leakage Rate or Pa and the MS Line Drains are tested at Pa. Testing Program.(continued)

SUSQUEHANNA

-UNIT 1 TS / 3.6-15 Amendment 9, 246, 251-PPL Rev. 0 Containment Pressure 3.6.1.4 3.6 CONTAINMENT SYSTEMS 3.6.1.4 Containment Pressure LCO 3.6.1.4 Containment pressure shall be -1.0 to 2.0 psig.APPLICABILITY:

MODES 1,2, and 3.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment pressure not A.1 Restore containment pressure 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> within limit to within limit.B. Required Action and associated Completion Time B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> not met.AND B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY In accordance with the SR 3.6.1.4.1 Verify containment pressure is within limit. Surveillance Frequency Control Program 12 ho-rs I SUSQUEHANNA

-UNIT 1 TS / 3.6-17 Amendment J,7K PPL Rev. 0 Drywell Air Temperature 3.6.1.5 3.6 CONTAINMENT SYSTEMS 3.6.1.5 Drywell Air Temperature LCO 3.6.1.5 Drywell average air temperature shall be < 135 0 F.APPLICABILITY:

MODES 1, 2, and 3.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Drywell average air A.1 Restore drywell average air 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> temperature not within temperature to within limit.limit.B. Required Action and B. 1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.5.1 Verify drywell average air temperature is within limit. In accordance with the Surveillance Frequency Control Program2-4-herss I SUSQUEHANNA

-UNIT 1 TS / 3.6-18 Amendment 1.79 PPL Rev. 0 Suppression Chamber-to-Drywell Vacuum Breakers 3.6.1.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met. AND D.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.6.1

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

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

Not required to be met for vacuum breakers that are open during Surveillances.

Verify each vacuum breaker is closed. In accordance with the Surveillance Frequency Control Proqram44-days AND Within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after discharge of steam to the suppression chamber from safety/relief valve (S/RV) operation.(continued)

I SUSQUEHANNA

-UNIT 1 TS / 3.6-20 Amendment 1_7.&-

PPL Rev. G Suppression Chamber-to-Drywell Vacuum Breakers 3.6.1.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.1.6.2 Perform a functional test of each required vacuum In accordance with breaker. the Surveillance Frequency Control Pro-qram31 day.AND Within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after discharge of steam to the suppression chamber from S/RV operation AND Within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> following an operation that causes any of the vacuum breakers to open SR 3.6.1.6.3 Verify the opening setpoint of each required In accordance with vacuum breaker is > 0.25 and _ .75 psid. the Surveillance Frequency Control Progqram2A .m-..th SUSQUEHANNA

-UNIT 1 TS / 3.6-21 Amendment 198-PPL Rev. 0 Suppression Pool Average Temperature 3.6.2.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Suppression pool average E.1 Depressurize the reactor 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> temperature

> 120)F. vessel to < 200 psig.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.1.1 Verify suppression pool average temperature is In accordance with the within the applicable limits. Surveillance Frequency Control Program heu.AND 5 minutes when performing testing that adds heat to the suppression pool I SUSQUEHANNA

-UNIT 1 TS / 3.6-24 Amendment 17-ýK PPL Rev. 0 Suppression Pool Water Level 3.6.2.2 3.6 CONTAINMENT SYSTEMS 3.6.2.2 Suppression Pool Water Level LCO 3.6.2.2 Suppression pool water level shall be > 22 ft 0 inches and < 24 ft 0 inches.APPLICABILITY:

MODES 1, 2, and 3.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Suppression pool water level A.1 Restore suppression pool 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> not within limits, water level to within limits.B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met.AND B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.2.1 Verify suppression pool water level is In accordance with the Surveillance within limits. Frequency Control Proqram24--he9W I SUSQUEHANNA

-UNIT 1 TS / 3.6-25 Amendment 17.&-

PPL Rev. 0 RHR Suppression Pool Cooling 3.6.2.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.3.1 Verify each RHR suppression pool cooling In accordance with the subsystem manual, power operated, and Surveillance Frequency automatic valve in the flow path that is not locked, Control Pro-qram31 days sealed, or otherwise secured in position is in the correct position or can be aligned to the correct position.SR 3.6.2.3.2 Verify each RHR pump develops a flow rate In accordance with the> 9750 gpm through the associated heat Inservice Testing Program exchanger while operating in the suppression pool cooling mode.I SUSQUEHANNA

-UNIT 1 TS / 3.6-27 Amendment 17.ý PPL Rev. 0 RHR Suppression Pool Spray 3.6.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.4.1 Verify each RHR suppression pool spray In accordance with the subsystem manual, power operated, and Surveillance Frequency automatic valve in the flow path that is not locked, Control Proqram31 days sealed, or otherwise secured in position is in the correct position or can be aligned to the correct position.SR 3.6.2.4.2 Verify each suppression pool spray is In accordance with the unobstructed.

Surveillance Frequency Control Proqram-l-years I SUSQUEHANNA

-UNIT 1 TS / 3.6-29 Amendment 17.&'

PPL Rev. 4 Drywell Air Flow System 3.6.3.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.2.1 Operate each required drywell cooling fan at low In accordance with the speed for > 15 minutes. Surveillance Frequency Control Procqram@2-days I SUSQUEHANNA

-UNIT 1 TS / 3.6-33 Amendment,176 PPL Rev. 0 Primary Containment Oxygen Concentration 3.6.3.3 3.6 CONTAINMENT SYSTEMS 3.6.3.3 Primary Containment Oxygen Concentration LCO 3.6.3.3 The primary containment oxygen concentration shall be < 4.0 volume percent.APPLICABILITY:

MODE 1 during the time period: a. From 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after THERMAL POWER is > 15% RTP following startup, to b. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> prior to reducing THERMAL POWER to _< 15% RTP prior to the next scheduled reactor shutdown.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Primary containment oxygen A.1 Restore oxygen concentration 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> concentration not within limit, to within limit.B. Required Action and B.1 Reduce THERMAL POWER to 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> associated Completion Time <15% RTP.not met.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.3.1 Verify primary containment oxygen concentration In accordance with the is within limits. Surveillance Frequency Control Proqram7-days I SUSQUEHANNA-UNIT 1 TS / 3.6-34 Amendment 17-K PPL Rev. 3 Secondary Containment 3.6.4.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Secondary containment C.1 -----------

NOTE--------

inoperable during movement LCO 3.0.3 is not applicable.

of irradiated fuel assemblies in the secondary containment, during CORE Suspend movement of Immediately ALTERATIONS, or during irradiated fuel assemblies in OPDRVs. the secondary containment.

AND C.2 Suspend CORE Immediately ALTERATIONS.

AND C.3 Initiate action to suspend Immediately OPDRVs.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1.1 Verify secondary containment vacuum is In accordance with the> 0.25 inch of vacuum water gauge. Surveillance Frequency Control Procqram24-heUFe SR 3.6.4.1.2 Verify all required secondary containment In accordance with the removable walls and equipment hatches required Surveillance Frequency to be closed are closed and sealed. Control Proqram34-days (continued)

SUSQUEHANNA

-UNIT 1 TS / 3.6-36 Amendment 1716, Zd4, 226 I PPL Rev. 3 Secondary Containment 3.6.4.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY--------------

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

Single door access openings between required zones within the secondary containment boundary may be opened for entry and exit.SR 3.6.4.1.3 Verify one secondary containment access door in In accordance with the each access opening is closed. Surveillance Frequencv Control Proqram34-days SR 3.6.4.1.4

---

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

NOTE --------The maximum time allowed for secondary Test each configuration at containment draw down is dependent on the least one time every 60 secondary containment configuration.

months.Verify each standby gas treatment (SGT) In accordance with the subsystem will draw down the secondary Surveillance Frequency containment to >_ 0.25 inch of vacuum water gauge Control Program 24 months in less than or equal to the maximum time allowed on a STAGGERED TEST for the secondary containment configuration that is BASIS OPERABLE.SR 3.6.4.1.5

---

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

NOTE --------The maximum flow allowed for maintaining Test each configuration at secondary containment vacuum is dependent on least one time every 60 the secondary containment configuration.

months.Verify each SGT subsystem can maintain In accordance with the_> 0.25 inch of vacuum water gauge in the Surveillance Frequency secondary containment for at least 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> at a flow Control Procqram24 months rate less than or equal to the maximum flow rate on a STAGGERED TEST permitted for the secondary containment BASIS configuration that is OPERABLE.SUSQUEHANNA

-UNIT 1 TS / 3.6-37 Amendment 178, 26, 229-PPL Rev. 0 SCIVs 3.6.4.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.2.1----------------

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

1. Valves and blind flanges in high radiation areas may be verified by use of administrative means.2. Not required to be met for SCIVs that are open under administrative controls.Verify each required secondary containment isolation manual valve and blind flange that is required to be closed during accident conditions is closed.In accordance with the Surveillance Frequency Control Program !4-days SR 3.6.4.2.2 Verify the isolation time of each required In accordance with the automatic SCIV is within limits. Surveillance Frequency Control ProgramQ2-1ays SR 3.6.4.2.3 Verify each required automatic SCIV actuates to In accordance with the the isolation position on an actual or simulated Surveillance Frequency actuation signal. Control Proqram24-menthe I SUSQUEHANNA

-UNIT 1 TS / 3.6-41 Amendment 17 PPL Rev. 4 SGT System 3.6.4.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. Two SGT subsystems F.1 ----------

NOTE--------

inoperable during movement LCO 3.0.3 is not applicable.

of irradiated fuel assemblies in the secondary containment, during CORE Suspend movement of irradiated fuel Immediately ALTERATIONS, or during assemblies in secondary OPDRVs. containment.

AND F.2 Suspend CORE ALTERATIONS.

Immediately AND F.3 Initiate action to suspend Immediately OPDRVs.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.3.1 Operate each SGT filter train for > 10 continuous In accordance with the hours with heaters operating.

Surveillance Frequency Control Proqraml-1 SR 3.6.4.3.2 Perform required SGT filter testing in accordance In accordance with the VFTP with the Ventilation Filter Testing Program (VFTP).SR 3.6.4.3.3 Verify each SGT subsystem actuates on an actual In accordance with the or simulated initiation signal. Surveillance Frequency Control Proqram24 menths SR 3.6.4.3.4 Verify each SGT filter cooling bypass and outside In accordance with the air damper opens and the fan starts on high Surveillance Frequency charcoal temperature.

Control Proaram24 menths SUSQUEHANNA

-UNIT 1 TS / 3.6-44 Amendment 1/8, ýW PPL Rev. 4 RHRSW System and UHS 3.7.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1.1 Verify the water level is greater than or equal to 678 feet In accordance with 1 inch above Mean Sea Level. the Surveillance Frequency Control Procqram12 hecus SR 3.7.1.2 Verify the average water temperature of the UHS is: In accordance with the Surveillance Frequency Control Pro.qram24 hGurs a. ------------------

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

Only applicable with both units in MODE 1 or 2, or with either unit in MODE 3 for less than twelve (12) hours........................................................................

-_< 85 0 F; or b. ------------------

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

Only applicable when either unit has been in MODE 3 for at least twelve (12) hours but not more than twenty-four (24) hours........................................................................

< 87 0 F; or c. ------------------

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

Only applicable when either unit has been in MODE 3 for at least twenty-four (24) hours......................................................................

< 88oF SR 3.7.1.3 Verify each RHRSW manual, power operated, and 31 daysln accordance automatic valve in the flow path, that is not locked, sealed, with the Surveillance or otherwise secured in position, is in the correct position Frequency Control or can be aligned to the correct position.

Program SR 3.7.1.4 Verify that valves HV-01 222A and B (the spray array In accordance with bypass valves) close upon receipt of a closing signal and the Surveillance open upon receipt of an opening signal. Frequency Control Program-2-days (continued)

SUSQUEHANNA

-UNIT 1 TS / 3.7-3 Amendment'W-8, 182 2K6 24e-PPL Rev. 4 RHRSW System and UHS 3.7.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1.5 Verify that valves HV-01224A1 and B1 (the large spray In accordance with array valves) close upon receipt of a closing signal and the Surveillance open upon receipt of an opening signal. Frequency Control Procqram92-dys-SR 3.7.1.6 Verify that valves HV-01 224A2 and B2 (the small spray In accordance with array valves) close upon receipt of a closing signal and the Surveillance open upon receipt of an opening signal. Frequency Control ProcqramQ2 days SR 3.7.1.7 Verify that valves 012287A and 012287B (the spray array In accordance with bypass manual valves) are capable of being opened and the Surveillance closed. Frequency Control Proqram92-d-a'e SUSQUEHANNA

-UNIT 1 TS / 3.7-3a Amendment 206,,Z4e PPL Rev. 0 ESW System 3.7.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1-----------

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

Isolation of flow to individual components does not render ESW System inoperable.

Verify each ESW subsystem manual, power operated, and automatic valve in the flow paths servicing safety related systems or components, that is not locked, sealed, or otherwise secured in position, is in the correct position.In accordance with the Surveillance Frequency Control Program31 ,days In accordance with the SR 3.7.2.2 Verify each ESW subsystem actuates on an Surveillance Frequency actual or simulated initiation signal. Control Procqram24 months I SUSQUEHANNA

-UNIT 1 TS / 3.7-5 Amendment 17-81, PPL Rev. 4-CREOAS System 3.7.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. Two CREOAS subsystems

---

NOTE ----------

inoperable during movement LCO 3.0.3 is not applicable.

of irradiated fuel assemblies in the secondary containment, during CORE F.1 Suspend movement of Immediately ALTERATIONS, or during irradiated fuel assemblies in OPDRVs. the secondary containment.

OR AND One or more CREOAS F.2 Suspend CORE Immediately subsystems inoperable due ALTERATIONS.

to an inoperable CRE boundary during movement of irradiated fuel assemblies AND in the secondary containment, during CORE F.3 Initiate action to suspend Immediately ALTERATIONS, or during OPDRVs.OPDRVs.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 Operate each CREOAS filter train for _> 10 In accordance with the continuous hours with the heaters operable.

Surveillance Frequency Control Procqram34-.ay.

SR 3.7.3.2 Perform required CREOAS filter testing in In accordance with the VFTP accordance with the Ventilation Filter Testing Program (VFTP).SR 3.7.3.3 Verify each CREOAS subsystem actuates on an In accordance with the actual or simulated initiation signal. Surveillance Frequency Control Proqram24-menths (continued)

SUSQUEHANNA

-UNIT 1 TS / 3.7-8 Amendment 2W, ý.ý PPL Rev. 0 Control Room Floor Cooling System 3.7.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Two control room floor -----------------

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

cooling subsystems LCO 3.0.3 is not applicable.

inoperable during movement of irradiated fuel assemblies in the secondary E.1 Suspend movement of Immediately containment, during CORE irradiated fuel assemblies in ALTERATIONS, or during the secondary containment.

OPDRVs.AND E.2 Suspend CORE Immediately ALTERATIONS.

AND E.3 Initiate actions to suspend Immediately OPDRVs.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify each control room floor cooling subsystem In accordance with the has the capability to remove the assumed heat Provqrance mF ntcC load.I SUSQUEHANNA

-UNIT 1 TS /.3.7-12 Amendment 1,76 I PPL Rev. 0 Main Condenser Offgas 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 -----------------

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

Not required to be performed until 31 days after any main steam line is not isolated Verify the radioactivity rate of the specified noble In accordance with the gases is _< 330 mCi/second.

Surveillance Frequency Control Proo ram31-days AND Once within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> after a_> 50% increase in the nominal steady state fission gas release after factoring out increases due to changes in THERMAL POWER level I SUSQUEHANNA

-UNIT 1 TS / 3.7-14 Amendment ix PPL Rev. 2 Main Turbine Bypass System 3.7.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify one complete cycle of each required main In accordance with the turbine bypass valve. Surveillance Frequency Control Program31.-day.

SR 3.7.6.2 Perform a system functional test. In accordance with the Surveillance Frequency Control Propram2,4-menths SR 3.7.6.3 Verify the TURBINE BYPASS SYSTEM In accordance with the RESPONSE TIME is within limits. Surveillance Frequency Control Proq ram.24 mnths SUSQUEHANNA

-UNIT 1 TS / 3.7-16 Amendment 17ý, 2/0, Z$6 PPL Rev. 0 Spent Fuel Storage Pool Water Level 3.7.7 3.7 PLANT SYSTEMS 3.7.7 Spent Fuel Storage Pool Water Level LCO 3.7.7 The spent fuel storage pool water level shall be >_ 22 ft over the top of irradiated fuel assemblies seated in the spent fuel storage pool racks.APPLICABILITY:

During movement of irradiated fuel assemblies in the spent fuel storage pool.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Spent fuel storage pool water A.1 ----------

NOTE---------

level not within limit. LCO 3.0.3 is not applicable.

Suspend movement of Immediately irradiated fuel assemblies in the spent fuel storage pool.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1 Verify the spent fuel storage pool water level is In accordance with the> 22 ft over the top of irradiated fuel assemblies Surveillance Frequency Control seated in the spent fuel storage pool racks. Proqramr-days I SUSQUEHANNA

-UNIT 1 TS/ 3.7-17 Amendment 1 jx PPL Rev. 0 Main Turbine Pressure Regulation System 3.7.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.8.1 Verify that both Main Turbine Pressure Regulators In accordance with the are each capable of controlling main steam Surveillance Frequency pressure.

Control ProqramQ2-days In accordance with the Surveillance Frequency SR 3.7.8.2 Perform a system functional test. Cnrol Frequency Control Progqram2-4 menth;SUSQUEHANNA

-UNIT 1 TS / 3.7-19 Amendment;Aig" PPL Rev. 4 AC Sources -Operating 3.8.1 3.8 Electrical Power Systems ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Two or more E.1 Restore at least three required 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> required DGs DGs to OPERABLE status.inoperable.

F. Required Action F.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and Associated Completion Time of AND Condition A, B, C, D, or E not met. F.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> G. One or more offsite G.1 Enter LCO 3.0.3. Immediately circuits and two or more required DGs inoperable.

OR One required DG and two offsite circuits inoperable.

SURVEILLANCE REQUIREMENTS

---

NO r ------------------------------------------------------------

Four DGs are required and a DG is only considered OPERABLE when the DG is aligned to the Class 1E distribution system. DG Surveillance Requirements have been modified to integrate the necessary testing to demonstrate the availability of DG E and ensure its OPERABILITY when substituted for any other DG. If the DG Surveillance Requirements, as modified by the associated Notes, are met and performed, DG E can be considered available and OPERABLE when substituted for any other DG after performance of SR 3.8.1.3 and SR 3.8.1.7.SURVEILLANCE FREQUENCY i SR 3.8.1.1 Verify correct breaker alignment and indicated power availability for each offsite circuit.In accordance with the Surveillance Frequency Control (continued)

Amendment

/78 SUSQUEHANNA

-UNIT 1 TS / 3.8-4 PPL Rev. 4 AC Sources -Operating 3.8.1 3.8 Electrical Power Systems SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.2 Not Used.SR 3.8.1.3 -------------------

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

1. DG loading may include gradual loading as recommended by the manufacturer.

2. Momentary transients outside the load range do not invalidate this test.3. This Surveillance shall be conducted on only one DG at a time.4. This SR shall be preceded by and immediately follow, without shutdown, a successful performance of SR 3.8.1.7.5. DG E, when not aligned to the Class IE distribution system, may satisfy this SR using the test facility.6. A single test will satisfy this Surveillance for both units if synchronization is to the 4.16 kV ESS bus for Unit 1 for one periodic test and synchronization is to the 4.16 kV ESS bus for Unit 2 for the next periodic test.However, if it is not possible to perform the test on Unit 2 or test performance is not required per SR 3.8.2.1, then the test shall be performed synchronized to the 4.16 kV ESS bus for Unit 1.Verify each DG is synchronized and loaded and operates In accordance with the for >_ 60 minutes at a load _> 3600 kW and < 4000 kW. Surveillance Frequency Control Proqram31day,'(continued)

I SUSQUEHANNA-UNIT 1 TS / 3.8-5 Amendment 17,8-PPL Rev. 4 AC Sources -Operating 3.8.1 3.8 Electrical Power Systems SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.4 Verify each engine mounted day tank fuel oil level is 420 In accordance with the gallons for DG A-D and > 425 gallons for DG E. Surveillance Frequency Control Pro qram3-1 -ys SR 3.8.1.5 Check for and remove accumulated water from each In accordance with the engine mounted day tank. Surveillance Frequency Control Prooram31-days SR 3.8.1.6 Verify the fuel oil transfer system operates to automatically In accordance with the transfer fuel oil from the storage tanks to each engine Surveillance mounted tank. Frequency Control Proqram314-days SR 3.8.1.7 -------------------

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

1. All DG starts may be preceded by an engine prelube period.2. A single test at the specified Frequency will satisfy this Surveillance for both units.Verify each DG starts from standby condition and In accordance with the achieves, in _< 10 seconds, voltage > 3793 V and Surveillance frequency

>_ 58.8, and after steady state conditions are Frequency Control reached, maintains voltage >_ 3793 V and _< 4400 V and Proaram31-days frequency

_ 58.8 Hz and < 61.2 Hz.SR 3.8.1.8 -------------------

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

The automatic transfer of the unit power supply shall not be performed in MODE 1 or 2.Verify automatic and manual transfer of unit power supply In accordance with the from the normal offsite circuit to the alternate offsite Surveillance circuit. Frequency Control Pro-qram24 -months (continued)

SUSQUEHANNA

-UNIT 1 TS / 3.8-6 Amendment IW-'

PPL Rev. 4 AC Sources -Operating 3.8.1 3.8 Electrical Power Systems SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.9----- -------------

NOTE ..............

A single test at the specified Frequency will satisfy this Surveillance for both units.Verify each DG rejects a load greater than or equal to its associated single largest post-accident load, and: a. Following load rejection, the frequency is 64.5 Hz;b. Within 4.5 seconds following load rejection, the voltage is _> 3760 V and _< 4560 V, and after steady state conditions are reached, maintains voltage > 3793 V and _< 4400 V; and c. Within 6 seconds following load rejection, the frequency is _> 58.8 Hz and _< 61.2 Hz.In accordance with the Surveillance Frequency Control Pro-gram24-months SR 3.8.1.10 ------------------

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

A single test at the specified Frequency will satisfy this Surveillance for both units.Verify each DG does not trip and voltage is maintained In accordance with the_ 4560 V during and following a load rejection of Surveillance 4000 kW. Frequency Control Pro-qram24 menths (continued)

I SUSQUEHANNA-UNIT 1 TS / 3.8-7 Amendment 17-&-

PPL Rev. 4 AC Sources -Operating 3.8.1 3.8 Electrical Power Systems SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.11-------------------

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

1. All DG starts may be preceded by an engine prelube period.2. This SR shall be performed for each DG on a rotational test basis and for each 4.16 kV ESS bus at the specified FREQUENCY.

3. This Surveillance shall not be performed in MODE 1, 2 or 3.Verify on an actual or simulated loss of offsite power signal: In accordance with the Surveillance Frequency Control Procqram24-men,49f a.b.C.De-energization of 4.16 kV ESS buses;Load shedding from 4.16 kV ESS buses; and DG auto-starts from standby condition and: 1. energizes permanently connected loads in< 10 seconds, 2. energizes auto-connected shutdown loads through individual load timers, 3. maintains steady state voltage >_ 3793 V and_< 4400 V, 4. maintains steady state frequency

_> 58.8 Hz and< 61.2 Hz, and 5. supplies permanently connected loads for>_ 5 minutes.(continued)

I SUSQUEHANNA

-UNIT 1 TS../_.3.8-8 Amendment J,79 PPL Rev. 4 AC Sources -Operating 3.8.1 3.8 Electrical Power Systems SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.12 ------------------

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

1. All DG starts may be preceded by an engine prelube period.2. DG E, when not aligned to the Class 1 E distribution system, may satisfy this SR for both units by performance of SR 3.8.1.12.a, b and c using the test facility to simulate a 4.16 kV ESS bus. SR 3.8.1.12.d and e may be satisfied with either the normally aligned DG or DG E aligned to the Class 1 E distribution system.In accordance with the Surveillance Frequency Control Propqram24-mef-t.4 Verify, on an actual or simulated Emergency Core Cooling System (ECCS) initiation signal, each DG auto-starts from standby condition and: a. In < 10 seconds after auto-start achieves voltage> 3793 V, and after steady state conditions are reached, maintains voltage >_ 3793 V and _< 4400 V;b. In < 10 seconds after auto-start achieves frequency_> 58.8 Hz, and after steady state conditions are reached, maintains frequency

> 58.8 Hz and 61.2 Hz;c. Operates for >_ 5 minutes;d. Permanently connected loads remain energized from the offsite power system; and e. Emergency loads are energized or auto-connected through the individual load timers from the offsite power system.(continued)

I SUSQUEHANNA

-UNIT 1 TS / 3.8-9 AmendmentPer PPL Rev. 4 AC Sources -Operating 3.8.1 3.8 Electrical Power Systems SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.13--------------

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

1. A single test at the specified Frequency will satisfy this Surveillance for both units.2. DG E, when not aligned to the Class 1 E distribution system, may satisfy this SR for both units by using a simulated ECCS initiation signal.Verify each DG's automatic trips are bypassed on actual or simulated loss of voltage signal on the 4.16 kV ESS bus concurrent with an actual or simulated ECCS initiation signal except: a. Engine overspeed; and b. Generator differential current; and c. Low lube oil pressure.In accordance with the Surveillance Frequency Control Program,24 menth (continued)

I SUSQUEHANNA

-UNIT 1 TS / 3.8-10 Amendment j7-8' PPL Rev. 4 AC Sources -Operating 3.8.1 3.8 Electrical Power Systems SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.14---------------

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

1. Momentary transients outside the load ranges do not invalidate this test.2. A single test at the specified Frequency will satisfy this Surveillance for both units.3. DG E, when not aligned to the Class 1 E distribution system may satisfy this SR by using the test facility.Verify each DG operates for _> 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />s: a. For > 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> loaded >_ 4400 kW and < 4700 kW for DGs A through D and > 5000 kW and < 5500 kW for DG E; and b. For the remaining hours of the test loaded _> 3600 kW and 4000 kW for DGs A through D and > 4500 kW and 5000 kW for DG E.In accordance with the Surveillance Frequency Control Proaqram24 menths (continued)

I SUSQUEHANNA

-UNIT 1 TS / 3.8-11 Amendment 1,78 PPL Rev. 4 AC Sources -Operating 3.8.1 3.8 Electrical Power Systems SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.15 ------------------

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

1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated_> 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> loaded >_: 3800 kW.Momentary transients outside of load range do not invalidate this test.2. All DG starts may be preceded by an engine prelube period.3. A single test at the specified Frequency will satisfy this Surveillance for both units.Verify each DG starts and achieves, in _< 10 seconds, voltage _> 3793 V and frequency

> 58.8 and after steady state conditions are reached, maintains voltage > 3793 V and _< 4400 V and frequency

> 58.8 Hz and _< 61.2 Hz.In accordance with the Surveillance Frequency Control Prog ram24 me.-ths (continued)

I SUSQUEHANNA-UNIT 1 TS / 3.8-12 Amendment J.7-K PPL Rev. 4 AC Sources -Operating 3.8.1 3.8 Electrical Power Systems SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.16 ------------------

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

This SR shall be performed for each DG on a rotational test basis and for each 4.16 kV ESS bus at the specified FREQUENCY.

Verify each DG: In accordance with the Surveillance Frequency Control Program244nGRfth

a. Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power;b. Transfers loads to offsite power source; and c. Returns to ready-to-load operation.(continued)

I SUSQUEHANNA

-UNIT 1 TS / 3.8-13 Amendment JI-fr PPL Rev. 4 AC Sources -Operating 3.8.1 3.8 Electrical Power Systems SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.17 ------------------

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

This SR shall be performed for each DG on a rotational test basis and for each 4.16 kV ESS bus at the specified FREQUENCY.

Verify with a DG operating in test mode and connected to In accordance with the its bus, an actual or simulated ECCS initiation signal Surveillance overrides the test mode by: Frequency Control Pro qram24-meths

a. Returning DG to ready-to-load operation; and b. Automatically energizing the emergency load from offsite power.SR 3.8.1.18 ------------------

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

Load timers associated with equipment that has automatic initiation capability disabled are not required to be OPERABLE.Verify each sequenced load is within required limits of the In accordance with the design interval.

Surveillance Frequency Control Proqram24 months (continued)

I SUSQUEHANNA-UNIT 1 TS / 3.8-14 Amendment 17T PPL Rev. 4 AC Sources -Operating 3.8.1 3.8 Electrical Power Systems SURVEILLANCE REQUIREMENTS (continued)

I SURVEILLANCE FREQUENCY SR 3.8.1.19---------------

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

1. All DG starts may be preceded by an engine prelube period.2. This SR shall be performed for each DG on a rotational test basis and for each 4.16 kV ESS bus at the specified FREQUENCY.

3. This Surveillance shall not be performed in MODE 1, 2 or 3.Verify on an actual or simulated loss of offsite power signal in conjunction with an actual or simulated ECCS initiation signal: a. De-energization of 4.16 kV ESS buses;b. Load shedding from emergency buses; and c. DG auto-starts from standby condition and: 1. energizes permanently connected loads in_ 10 seconds, 2. energizes auto-connected emergency loads through individual load timers, 3. achieves steady state voltage _> 3793 V and4400 V, 4. achieves steady state frequency

>_ 58.8 Hz and_< 61.2 Hz, and 5. supplies permanently connected and auto-connected emergency loads for >_ 5 minutes.In accordance with the Surveillance Frequency Control Proaram24-menths (continued)

I SUSQUEHANNA-UNIT 1 TS / 3.8-15 Amendment 1,7-K PPL Rev. 4 AC Sources -Operating 3.8.1 3.8 Electrical Power Systems SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.20------------------

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

1. All DG starts may be preceded by an engine prelube period.2. This SR does not have to be performed with DG E substituted for any DG.Verify, when started simultaneously from standby condition, each DG achieves, in < 10 seconds, voltage> 3793 V and frequency

_> 58.8 and after steady state conditions are reached, maintains voltage > 3793 V and_< 4400 V and frequency

> 58.8 Hz and < 61.2 Hz.In accordance with the Surveillance Frequency Control Proqram4gleafs I SUSQUEHANNA

-UNIT 1 TS / 3.8-16 Amendment

7 PPL Rev. 0 Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 ACTIONS (continued)

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify each fuel oil storage tank contains In accordance with the 2> 47,570 gallons for DG A-D; Surveillance

>_ 60,480 gallons for DG E. Frequency Control Program31 days SR 3.8.3.2 Verify lube oil sump level is visible in the sight glass. In accordance with the Surveillance Frequency Control Proram34-d..s SR 3.8.3.3 Verify fuel oil properties of new and stored fuel oil are In accordance with tested in accordance with, and maintained within the limits the Diesel Fuel Oil of, the Diesel Fuel Oil Testing Program. Testing Program SR 3.8.3.4 -------------------

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

Not required to be met when DG is operating.

Verify each DG air start receiver pressure is >_ 240 psig. In accordance with the Surveillance Frequency Control Proqram3l days SR 3.8.3.5 Check for and remove accumulated water from each fuel In accordance with the oil storage tank. Surveillance Freauency Control Program31 days SUSQUEHANNA

-UNIT 1 TS / 3.8-22 Amendment 47-8, Jý&T PPL Rev. 3 DC Sources-Operating 3.8.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Diesel Generator E DC E.1 Verify that all ESW valves 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> electrical power associated with Diesel subsystem inoperable, Generator E are closed.when not aligned to the Class 1E distribution system.F. Diesel Generator E DC F.1 Declare Diesel Generator E 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> electrical power inoperable.

subsystem inoperable, when aligned to the Class 1E distribution system.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify battery terminal voltage is greater than or equal to In accordance with the the minimum established float voltage. Surveillance Frequency Control Program7 days SR 3.8.4.2 Verify each required battery charger supplies its In accordance with the associated battery at the following rates for _> 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> at Surveillance greater than or equal to the minimum established float Frequency Control voltages.

Proqram24.

months a. _ 100 amps for the 125V Battery b. _ 300 amps for the 250V Battery c. _ 200 amps for the 125V Diesel Generator E Battery (continued)

SUSQUEHANNA

-UNIT 1 TS / 3.8-24 Amendment 17-8, 2-W, 24-"

PPL Rev. 3 DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued)

~1~SURVEILLANCE FREQUENCY SR 3.8.4.3---------------------------------

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

1. The modified performance discharge test in SR 3.8.6.6 may be performed in lieu of SR 3.8.4.3.2. This Surveillance shall not be Performed in Mode 1, 2, or 3 except for the Diesel Generator E DC electrical power subsystem.

This Surveillance can be performed on the Diesel Generator E DC electrical power subsystem when the Diesel Generator E is not aligned to the Class 1 E distribution system. However, credit may be taken for unplanned events that satisfy this SR.Verify battery capacity is adequate to supply, and maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test.In accordance with the Surveillance Frequency Control Proaram24 menths SUSQUEHANNA

-UNIT 1 TS / 3.8-25 Amendment 1,78, 2.35,2.3&

PPL Rev. 4 Battery Parameters 3.8.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1-----------------

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

Not required to be met when battery terminal voltage is less than the minimum established float voltage of SR 3.8.4.1.Verify each battery float current is 2 amps. In accordance with the Surveillance Frequency Control Program7 days----,.

NOTE The"7 day Fre.q nc -..not applicvable if the batte~y 0- one equalize charge or hqas been en equalize charge at any time duFrig the p~eviws4 days.AND SR 3.8.6.2 Verify each battery pilot cell voltage is 2.07 V. In accordance with the Surveillance Freguency Control Program3-days SR 3.8.6.3 Verify each battery connected cell electrolyte level is In accordance with the greater than or equal to minimum established design Surveillance limits. Frequency Control Program34-day4e SR 3.8.6.4 Verify each battery pilot cell temperature is greater than or In accordance with the equal to minimum established design limits. Surveillance Frequency Control Pro ram3-1 -daV (continued)

SUSQUEHANNA-UNIT 1 TS /13.8-35 Amendment 1/8,2ý PPL Rev. 4 Battery Parameters 3.8.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.6.5 Verify each battery connected cell voltage is _ 2.07 V. In accordance with the Surveillance Frequency Control Proqram.92days SR 3.8.6.6-----------------

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

This Surveillance shall not be Performed in Mode 1, 2, or 3. However, credit may be taken for unplanned events that satisfy this SR.Verify battery capacity is >_ 80% of the manufacturer's rating when subjected to a performance discharge test or a modified performance discharge test.In accordance with the Surveillance Frequency Control Proqram60 menths AND 12 months when battery shows degradation or has reached 85% of expected service life with capacity< 100% of manufacturer's rating AND 24 months when battery has reached 85% of the expected service life with capacity_> 100% of manufacturer's rating SUSQUEHANNA-UNIT 1 TS / 3.8-36 Amendment 1A,2ý PPL Rev. 4-Distribution Systems -Operating 3.8.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct breaker alignments and voltage or In accordance with indicated power availability to required AC and DC the Surveillance electrical power distribution subsystems.

Frequency Control Proq ram7- das I SUSQUEHANNA

-UNIT 1 TS / 3.8-39 Amendment Pe PPL Rev. 4-Distribution Systems -Shutdown 3.8.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Diesel Generator E B.1 Verify that all ESW valves 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> DC electrical power associated with Diesel distribution Generator E are closed.subsystem inoperable, while not aligned to the Class 1 E distribution system.C. Diesel Generator E C.1 Declare Diesel Generator E 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> DC electrical power inoperable.

distribution subsystem inoperable, while aligned to the Class 1 E distribution system.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct breaker alignments and voltage or 74ayln indicated power availability to required AC and DC accordance with the electrical power distribution subsystems.

Surveillance Frequency Control Pro-qram I SUSQUEHANNA-UNIT 1 TS / 3.8-43 Amendmentj-7-K PPL Rev. 0 Refueling Equipment Interlocks 3.9.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Perform CHANNEL FUNCTIONAL TEST on each of the following required refueling equipment interlock inputs: a. All-rods-in, b. Refuel platform position, c. Refuel platform fuel grapple, fuel loaded, d. Refuel platform frame mounted hoist, fuel loaded, e. Refuel platform monorail mounted hoist, fuel loaded.In accordance with the Surveillance Freauencv Control Proqram7-ays I SUSQUEHANNA

-UNIT 1 TS /.3.9-2 Amendment

ý1,79 PPL Rev. 0 Refuel Position One-Rod-Out Interlock 3.9.2 3.9 REFUELING OPERATIONS 3.9.2 Refuel Position One-Rod-Out Interlock LCO 3.9.2 The refuel position one-rod-out interlock shall be OPERABLE.APPLICABILITY:

MODE 5 with the reactor mode switch in the refuel position and any control rod withdrawn.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refuel position one-rod-out A.1 Suspend control rod Immediately interlock inoperable, withdrawal.

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

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Verify reactor mode switch locked in Refuel In accordance with the position.

Surveillance Frequency Control Proqram12 h4eU'(continued)

I SUSQUEHANNA-UNIT 1 TS / 3.9-3 Amendment 17,8"ý PPL Rev. 0 Refuel Position One-Rod-Out Interlock 3.9.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.9.2.2 ------------------

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

Not required to be performed until 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after any control rod is withdrawn.

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Proqram7-days I SUSQUEHANNA

-UNIT 1 TS / 3.9-4 Amendment 17,8' PPL Rev. 0 Control Rod Position 3.9.3 3.9 REFUELING OPERATIONS 3.9.3 Control Rod Position LCO 3.9.3 All control rods shall be fully inserted.APPLICABILITY:

When loading fuel assemblies into the core.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more control rods not A.1 Suspend loading fuel Immediately fully inserted, assemblies into the core.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Verify all control rods are fully inserted.

In accordance with the Surveillance Frequency Control Proqram412 heus I SUSQUEHANNA

-UNIT 1 TS / 3.9-5 Amendment 1-7 11ýY'D PPL Rev. 0 Control Rod OPERABILITY-Refueling 3.9.5 3.9 REFUELING OPERATIONS 3.9.5 Control Rod OPERABILITY-Refueling LCO 3.9.5 Each withdrawn control rod shall be OPERABLE.APPLICABILITY:

MODE 5.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more withdrawn A.1 Initiate action to fully insert Immediately control rods inoperable, inoperable withdrawn control rods.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 ------------------

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

Not required to be performed until 7 days after the control rod is withdrawn.

Insert each withdrawn control rod at least one In accordance with the notch. Surveillance Frequency Control Pro-qram7-days SR 3.9.5.2 Verify each withdrawn control rod scram In accordance with the accumulator pressure is > 940 psig. Surveillance Frequency Control ProgramT-day I SUSQUEHANNA-UNIT 1 TS / 3.9-8 Amendment j,7.&

PPL Rev. 0 RPV Water Level 3.9.6 3.9 REFUELING OPERATIONS 3.9.6 Reactor Pressure Vessel (RPV) Water Level LCO 3.9.6 RPV water level shall be > 22 ft above the top of the RPV flange.APPLICABILITY:

During movement of irradiated fuel assemblies within the RPV, During movement of new or irradiated fuel assemblies or handling of control rods within the RPV, when irradiated fuel assemblies are seated within the RPV.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RPV water level not within A.1 Suspend movement of fuel Immediately limit. assemblies and handling of control rods within the RPV.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify RPV water level is _> 22 ft above the top of In accordance with the the RPV flange. Surveillance Frequency Control Proqram24 hours I SUSQUEHANNA

-UNIT 1 TS / 3.9-9 Amendment 17-T PPL Rev. 0 RHR-High Water Level 3.9.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify one RHR shutdown cooling subsystem is 12 hur4eln accordance with operating.

the Surveillance Frequency Control Program I SUSQUEHANNA

-UNIT 1 TS / 3.9-10 Amendment PT PPL Rev. 0 RHR -Low Water Level 3.9.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.8.1 Verify one RHR shutdown cooling subsystem is In accordance with the operating.

Surveillance Frequency Control Procqram !2 heuFs I SUSQUEHANNA

-UNIT 1 TS / 3.9-15 Amendment ix, PPL Rev. 0 Reactor Mode Switch Interlock Testing 3.10.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)

A.3.1 Place the reactor mode 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> switch in the shutdown position.OR A.3.2 ------NOTE------

Only applicable in MODE 5 Place the reactor mode 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> switch in the refuel position.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.2.1 Verify all control rods are fully inserted in core cells In accordance with the containing one or more fuel assemblies.

Surveillance Frequency Control Proqram42 heurs SR 3.10.2.2 Verify no CORE ALTERATIONS are in progress.

In accordance with the Surveillance Frequency Control I SUSQUEHANNA-UNIT I TS / 3.10-5 Amendment 1.7ý PPL Rev. 0 Single Control Rod Withdrawal

-Hot Shutdown 3.10.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.3.1 Perform the applicable SRs for the required LCOs. According to the applicable SRs SR 3.10.3.2 ----------------------------

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

Not required to be met if SR 3.10.3.1 is satisfied for LCO 3.10.3.d.1 requirements.

Verify all control rods, other than the control rod In accordance with the being withdrawn, in a five by five array centered Surveillance Frequency on the control rod being withdrawn, are disarmed.

Control Proqram24-heue SR 3.10.3.3 Verify all control rods other than the control rod In accordance with the being withdrawn, are fully inserted.

Surveillance Frequency , ContrlPro ram24-heurs I SUSQUEHANNA

-UNIT 1 TS / 3.10-8 Amendment J,76 PPL Rev. 0 Single Control Rod Withdrawal

-Cold Shutdown 3.10.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more of the above B.1 Suspend withdrawal of Immediately requirements not met with the control rod and the affected control rod not removal of associated insertable.

CRD.AND B.2.1 Initiate action to fully Immediately insert all control rods.OR B.2.2 Initiate action to Immediately satisfy the requirements of this LCO.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.4.1 Perform the applicable SRs for the required LCOs. According to the applicable SRs SR 3.10.4.2 ----------------

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

Not required to be met if SR 3.10.4.1 is satisfied for LCO 3.10.4.c.

1 requirements.

Verify all control rods, other than the control rod In accordance with the being withdrawn, in a five by five array centered Surveillance Frequency on the control rod being withdrawn, are Control Proqram24-heur-s disarmed.(continued)

I SUSQUEHANNA-UNIT 1 TS / 3.10-11 Amendment

7-Or PPL Rev. 0 Single Control Rod Withdrawal

-Cold Shutdown 3.10.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.10.4.3 Verify all control rods, other than the control rod In accordance with the being withdrawn, are fully inserted.

Surveillance Frequency Control Program2-he'ris SR 3.10.4.4 -----------------

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

Not required to be met if SR 3.10.4.1 is satisfied for LCO 3.10.4. b. 1 requirements.

Verify a control rod withdrawal block is inserted.

In accordance with the Surveillance Frequency Control Proqram24-heuos I SUSQUEHANNA

-UNIT 1 TS / 3.10-12 Amendment JW-8r PPL Rev. 0 Single CRD Removal -Refueling 3.10.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)

A.2.1 Initiate action to fully Immediately insert all control rods.OR A.2.2 Initiate action to satisfy Immediately the requirements of this LCO.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.5.1 Verify all control rods, other than the control rod In accordance with the withdrawn for the removal of the associated CRD, Surveillance Frequency are fully inserted.

Control Procqram24" he'IF SR 3.10.5.2 Verify all control rods, other than the control rod In accordance with the withdrawn for the removal of the associated CRD, Surveillance Frequency in a five by five array centered on the control rod Control Procqram24 heu'r withdrawn for the removal of the associated CRD, are disarmed.SR 3.10.5.3 Verify a control rod withdrawal block is inserted.

In accordance with the Surveillance Frequency Control Procqram24-heuF6 SR 3.10.5.4 Perform SR 3.1.1.1. According to SR 3.1.1.1 (continued)

I SUSQUEHANNA

-UNIT 1 TS / 3.10-14 Amendment J7-8' PPL Rev. G Single CRD Removal -Refueling 3.10.5 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.10.5.5 Verify no CORE ALTERATIONS are in progress.

In accordance with the Surveillance Frequency Control Pro-qram2.4hews I SUSQUEHANNA

-UNIT 1 TS / 3.10-13 Amendment J,7S PPL Rev. 0 Multiple Control Rod Withdrawal

-Refueling 3.10.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)

A.3.1 Initiate action to fully Immediately insert all control rods in core cells containing one or more fuel assemblies.

OR A.3.2 Initiate action to satisfy Immediately the requirements of this LCO.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.6.1 Verify the four fuel assemblies are removed from In accordance with the core cells associated with each control rod or Surveillance Frequency CRD removed. Control Proqram24-heu-e SR 3.10.6.2 Verify all other control rods in core cells containing In accordance with the one or more fuel assemblies are fully inserted.

Surveillance Frequency Control Proqram24-heurse SR 3.10.6.3 -----------------

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

Only required to be met during fuel loading.Verify fuel assemblies being loaded are in In accordance with the compliance with an approved reload sequence.

Surveillance Frequency Control Proqram24-heuFs I SUSQUEHANNA

-UNIT 1 TS / 3.10-17 Amendment,ýn PPL Rev. 2 SDM Test -Refueling 3.10.8 SURVEILLANCE REQUIREMENTS (continued)

SURVE.ILLANCE FREQUENCY SR 3.10.8.2 ---------------

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

Not required to be met if SR 3.10.8.3 satisfied.

Perform the MODE 2 applicable SRs for LCO According to the applicable 3.3.2.1. Function 2 of Table 3.3.2.1-1.

SRs SR 3.10.8.3 ----------------

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

Not required to be met if SR 3.10.8.2 satisfied.

Verify movement of control rods is in compliance During control rod movement with the approved control rod sequence for the SDM test by a second licensed operator or other qualified member of the technical staff.SR 3.10.8.4 Verify no other CORE ALTERATIONS are in In accordance with the progress.

Surveillance Frequency Control Proqram412 h'-rs (continued)

I SUSQUEHANNA

-UNIT 1 TS / 3.10-22 Amendment 17-K PPL Rev. 2 SDM Test -Refueling 3.10.8 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY i SR 3.10.8.5 Verify each withdrawn control rod does not go to the withdrawn overtravel position.Each time the control rod is withdrawn to "full out" position AND Prior to satisfying LCO 3.10.8.c requirement after work on control rod or CRD System that could affect coupling SR 3.10.8.6 Verify CRD charging water header pressure 940 psig In accordance with the Surveillance Frequency Control Proqram7-days I SUSQUEHANNA

-UNIT 1 TS 13.10-23 Amendment P6 PPL Rev. 6 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.14 Control Room Envelope Habitability Program (continued)

e. The quantitative limits on unfiltered air inleakage into the CRE. These limits shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph

c. The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of DBA consequences.

Unfiltered air inleakage limits for hazardous chemicals must ensure that exposure of CRE occupants to these hazards will be within the assumptions in the licensing basis.f. The provisions of SR 3.0.2 are applicable to the Frequencies for assessing CRE habitability, determining CRE unfiltered inleakage, and measuring CRE pressure and assessing the CRE boundary as required by paragraphs c and d, respectively.

5.5.15 Surveillance Frequency Control Pro-gram This pro-gram 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 Limitinq 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 Freauencies established in the Surveillance Freauencv Control Program.SUSQUEHANNA

-UNIT I TS / 5.0-18C Amendment 2,82 PPL Rev. 3 Definitions 1.1 1.1 Definitions (continued)

RATED THERMAL POWER (RTP)REACTOR PROTECTION SYSTEM (RPS)RESPONSE TIME SHUTDOWN MARGIN (SDM)RTP shall be a total reactor core heat transfer rate to the reactor coolant of 3952 MWt.The RPS RESPONSE TIME shall be that time interval from when the monitored parameter exceeds its RPS trip setpoint at the channel sensor until de-energization of the scram pilot valve solenoids.

The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.SDM shall be the amount of reactivity by which the reactor is subcritical or would be subcritical assuming that: a. The reactor is xenon free;b. The moderator temperature is 68°F; and c. All control rods are fully inserted except for the single control rod of highest reactivity worth, which is assumed to be fully withdrawn.

With control rods not capable of being fully inserted, the reactivity worth of these control rods must be accounted for in the determination of SDM.A STAGGERED TEST BASIS shall conSit of the testing of one of the systems, subsystems, channels, Or ether designated comnpencntc dUring thc interval specified by the Surveillance FrFequency, so that a"l systems, SUbSyStems, channols, Or other designated components aro tested duFrin n Surveillance FrFequency intervals, where n is the total numbero S1-AGGER91Q TF=ST- BASIS systems, SUbsyStems, channels, or other designated components in tho associated functio.THERMAL POWER TURBINE BYPASS SYSTEM RESPONSE TIME THERMAL POWER shall be the total reactor core heat transfer rate to the reactor coolant.The TURBINE BYPASS SYSTEM RESPONSE TIME consists of the time from when the turbine bypass control unit generates a turbine bypass valve flow signal (continued)

I SUSQUEHANNA-UNIT 2 TS / 1.1-6 Amend ment-1 6&,-2-24 PPL Rev. 4 Control Rod OPERABILITY 3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.3.1 Determine the position of each control rod. In accordance with the Surveillance Frequency Control Program 24-heurs SR 3.1.3.2 NOT USED SR 3.1.3.3 -----------------

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

Not required to be performed until 31 days after the control rod is withdrawn and THERMAL POWER is greater than the LPSP of the RWM.Insert each withdrawn control rod at least one In accordance with the notch. Surveillance Frequency Control Program ,1 days SR 3.1.3.4 Verify each control rod scram time from fully In accordance with withdrawn to notch position 05 is:-< 7 seconds. SR 3.1.4.1, SR 3.1.4.2, SR 3.1.4.3, and SR 3.1.4.4 (continued)

SUSQUEHANNA-UNIT2 TS / 3.1-10 Amendment 4&1-, 222119-PPL Rev. 2 Control Rod Scram Times 3.1.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.1.4.2 Verify, for a representative sample, each tested control rod scram time is within the limits of Table 3.1.4-1 with reactor steam dome pressure> 800 psig.In accordance with the Surveillance Frequency Control Program uuulativo epcratien in MODE= 1 SR 3.1.4.3 Verify each affected control rod scram time is Prior to declaring control rod within the limits of Table 3.1.4-1 with any reactor OPERABLE after work on steam dome pressure.

control rod or CRD System that could affect scram time SR 3.1.4.4 Verify each affected control rod scram time is Prior to exceeding 40% RTP within the limits of Table 3.1.4-1 with reactor after fuel movement within steam dome pressure > 800 psig. the affected core cell AND Prior to exceeding 40% RTP after work on control rod or CRD System that could affect scram time SUSQUEHANNA

-UNIT 2 TS / 3.1-13 Amendment 4-54-,244, 2-28 PPL Rev. 0 Control Rod Scram Accumulators 3.1.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more control rod C.1 Verify all control rods Immediately upon scram accumulators associated with inoperable discovery of charging inoperable with reactor accumulators are fully water header steam dome pressure inserted, pressure < 940 psig< 900 psig.AND C.2 Declare the associated control 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> rod inoperable.

D. Required Action and D.1 ----------

NOTE --------associated Completion Not applicable if all inoperable Time of Required Action control rod scram B. 1 or C. 1 not met. accumulators are associated with fully inserted control rods.Place the reactor mode switch Immediately in the shutdown position.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify each control rod scram accumulator In accordance with the nitrogen pressure is > 940 psig. Surveillance Frequency Control Program7-days I SUSQUEHANNA

-UNIT 2 TS / 3.1-17 Amendment 1-5+

PPL Rev. 0 Rod Pattern Control 3.1.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Nine or more OPERABLE B. 1 ---------NOTE ----------

control rods not in Rod worth minimizer (RWM)compliance with BPWS. may be bypassed as allowed by LCO 3.3.2.1.Suspend withdrawal of control Immediately rods.AND B.2 Place the reactor mode switch 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> in the shutdown position.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.1 Verify all OPERABLE control rods comply with In accordance with the BPWS. Surveillance Frequency Control Program24 heurs I SUSQUEHANNA-UNIT2 TS / 3.1-19 Amendment 3-&l PPL Rev. 3 SLC System 3,1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.1 Verify available volume of sodium pentaborate In accordance with the solution is within the limits of Figure 3.1.7-1. Surveillance Frequency Control Proqram24-heurs SR 3.1.7.2 Verify temperature of sodium pentaborate solution In accordance with the is within the limits of Figure 3.1.7-2. Surveillance Frequency Control Proaram24-heu-s SR 3.1.7.3 Verify temperature of pump suction piping is within In accordance with the the limits of Figure 3.1.7-2. Surveillance Frequency Control Proqram24 heur-SR 3.1.7.4 Verify continuity of explosive charge. In accordance with the Surveillance Frequency Control Proqgram,3-1-daye SR 3.1.7.5 Verify the concentration of sodium pentaborate in In accordance with the solution is within the limits of Figure 3.1.7-1. Surveillance Frequency Control Proqram31 days AND Once within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after water or sodium pentaborate is added to solution AND Once within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after solution temperature is restored within the limits of Figure 3.1.7-2 (continued)

I SUSQUEHANNA

-UNIT 2 TS / 3.1-21 Amendment 1 V, 1 2-4-7 PPL Rev. 3 SLC System 3.1.7 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.1.7.6 Verify each SLC subsystem manual and power In accordance with the operated valve in the flow path that is not locked, Surveillance Frequency sealed, or otherwise secured in position is in the Control Program31-days correct position, or can be aligned to the correct position.SR 3.1.7.7 Verify each pump develops a flow rate 40.0 gpm In accordance with the at a discharge pressure >_ 1250 psig. Inservice Testing Program SR 3.1.7.8 Verify flow through one SLC subsystem pump into 24 monthen a reactor pressure vessel. STAGGERED TEST PASISIn accordance with the Surveillance Frequency Control Program SR 3.1.7.9 Verify all heat traced piping between storage tank 24-menthsln accordance with and pump suction is unblocked, the Survellance Frequency Control Program AND Once within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after solution temperature is restored within the limits of Figure 3.1.7-2 SR 3.1.7.10 Verify sodium pentaborate enrichment is > 88 Prior to addition to SLC tank.atom percent B-10.SUSQUEHANNA

-UNIT 2 TS / 3.1-22 Amendment 15ý, 10, 2-t7 PPL Rev. 4 SDV Vent and Drain Valves 3.1.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.8.1 ------------------

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

Not required to be met on vent and drain valves closed during performance of SR 3.1.8.2.In accordance with the Verify each SDV vent and drain valve is open. Surveillance Frequency Control Procqram3l days SR 3.1.8.2 Cycle each SDV vent and drain valve to the fully In accordance with the closed and fully open position.

Surveillance Frequency Control Program In accordance with the SR 3.1.8.3 Verify each SDV vent and drain valve: Surveillance Frequency Control Procqram24 menths a. Closes in : 30 seconds after receipt of an actual or simulated scram signal; and b. Opens when the actual or simulated scram signal is reset.I SUSQUEHANNA

-UNIT 2 TS / 3.1-26 Amendment 1W PPL Rev. 4 APLHGR 3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY i-SR 3.2.1.1 Verify all APLHGRs are less than or equal to the limits specified in the COLR.Once within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after 23% RTP AND In accordance with the Surveillance Freauencv Control Pro pram24 hourc theFrcftef AND Prior to exceeding 44% RTP I SUSQUEHANNA-UNIT2 TS / 3.2-2 Amendment W,,22<

PPL Rev. 4 MCPR 3.2.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify all MCPRs are greater than or equal to the limits specified in the COLR.Once within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after_ 23% RTP AND In accordance with the Surveillance Frequencv Control Propqram24 hours theroafter AND Prior to exceeding 44% RTP SR 3.2.2.2 Determine the MCPR limits. Once within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after each completion of SRs in 3.1.4 I SUSQUEHANNA-UNIT2 TS / 3.2-4 Amendment 151,,W4 PPL Rev. 4-LHGR 3.2.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 Verify all LHGRs are less than or equal to the limits specified in the COLR.Once within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after> 23% RTP AND In accordance with the Surveillance Frequency Control Procqram24 houre thereafte AND Prior to exceeding 44% RTP I SUSQUEHANNA-UNIT2 TS / 3.2-6 Amendment 151, ýý PPL Rev. 3 RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS

---

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

1. Refer to Table 3.3.1.1-1 to determine which SRs apply for each RPS Function.2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the associated Function maintains RPS trip capability.

SURVEILLANCE FREQUENCY SR 3.3.1.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Proqram1!2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> SR 3.3.1.1.2 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program24 hours SR 3.3.1.1.3

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

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

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after THERMAL POWER >_ 23% RTP.Verify the absolute difference between the average power In accordance range monitor (APRM) channels and the calculated power with the is _< 2% RTP while operating at _ 23% RTP. Surveillance Frequency Control Prociram7-1ays (continued)

I SUSQUEHANNA

-UNIT 2 TS / 3.3-3 Amendment 1-54, 207, 220,ý24 PPL Rev. 3 RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.4

---

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

Not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after entering MODE 2.Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Pro-qram7-days SR 3.3.1.1.5 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control ProgramW-days SR 3.3.1.1.6 Verify the source range monitor (SRM) and intermediate Prior to fully range monitor (IRM) channels overlap, withdrawing SRMs from the core.SR 3.3.1.1.7

---

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

Only required to be met during entry into MODE 2 from MODE 1.Verify the IRM and APRM channels overlap. In accordance with the Surveillance Frequency Control Proqram7-days SR 3.3.1.1.8 Calibrate the local power range monitors.

In accordance with the Surveillance Frequency Control Proqram!000 MWDI MT ave~a(eoteFe (continued)

I SUSQUEHANNA-UNIT2 TS / 3.3-4 Amendment 4-54-, 224 PPL Rev. 3 RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.9----------------------

NOTE A test of all required contacts does not have to be performed.

---

Perform CHANNEL FUNCTIONAL TEST.In accordance with the Surveillance Frequency Control ProqramG2-days SR 3.3.1.1.10 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control ProcqramQ2-days SR 3.3.1.1.11

---

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

1. Neutron detectors are excluded.2. For Function 1.a, not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after entering MODE 2.Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Proqram484-day s (continued)

I SUSQUEHANNA-UNIT 2 TS._/L3.3-5 Amendment 444-, 207,2ý PPL Rev. 3 RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.12

---

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

1. For Function 2.a, not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after entering MODE 2.2. For Functions 2.b and 2.f, the CHANNEL FUNCTIONAL TEST includes the recirculation flow input processing, excluding the flow transmitters.

Perform CHANNEL FUNCTIONAL TEST In accordance with the Surveillance Frequency Control Proqraml-84 days SR 3.3.1.1.13 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program24 ment hs SR 3.3.1.1.14 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program24-ment hs SR 3.3.1.1.15 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program24-met hs (continued)

I SUSQUEHANNA

-UNIT 2 TS 1 3.3-6 Amendment 4-66, 207, ý2ý PPL Rev. 3 RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.16 Verify Turbine Stop Valve-Closure and Turbine Control In accordance with Valve Fast Closure, Trip Oil Pressure-Low Functions the Surveillance are not bypassed when THERMAL POWER is Frequency Control>26% RTP. Proqram24-eonths SR 3.3.1.1.17

---

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

1. Neutron detectors are excluded.2. For Function 6, "n" equals channels for the purFpos of deteFrining the STAGGERED TEST- ASIS F~equeney.

3. For Function 2.e, "n" equals 8 channels for the purpose of deterMinin, the STAGGERED TEST SASISTestig of APRM and -PRM outputs sh.ll Verify the RPS RESPONSE TIME is within limits. In accordance with the Surveillance Frequency Control Proqram24 months on a STAGGERED SR 3.3.1.1.18

---

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

1. Neutron detectors are excluded.2. For Functions 2b and 2.f, the recirculation flow transmitters that feed the APRMs are included.Perform CHANNEL CALIBRATION In accordance with the Surveillance Frequency Control Program24 months SR 3.3.1.1.19 Verify OPRM is not bypassed when APRM Simulated In accordance with Thermal Power is > 25% and recirculation drive flow is < the Surveillance value equivalent to the core flow value defined in the Frequency Control COLR. Program24-emths (continued)

I SUSQUEHANNA

-UNIT 2 TS / 3.3-6a Amendment PPL Rev. 3 RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.20 Adjust recirculation drive flow to conform to reactor core In accordance with flow. the Surveillance Frequency Control Prog ram24 m,-,ths I SUSQUEHANNA-UNIT 2 TS / 3.3-6b Amendment PPL Rev. 0 SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS

---

N-NOTE ----------------------------

Refer to Table 3.3.1.2-1 to determine which SRs apply for each applicable MODE or other specified conditions.

SURVEILLANCE FREQUENCY SR 3.3.1.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Proqram12 hours SR 3.3.1.2.2

---

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

1. Only required to be met during CORE ALTERATIONS.

2. One SRM may be used to satisfy more than one of the following.

Verify an OPERABLE SRM detector is located in: In accordance with the Surveillance Frequency Control Progqram!

2 heurs a. The fueled region;b. The core quadrant where CORE ALTERATIONS are being performed, when the associated SRM is included in the fueled region; and c. A core quadrant adjacent to where CORE ALTERATIONS are being performed, when the associated SRM is included in the fueled region.SR 3.3.1.2.3 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Proqram24-heurs (continued)

I SUSQUEHANNA

-UNIT 2 TS / 3.3-12 Amendment LW PPL Rev. 0 SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.2.4 I-----------------

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

Not required to be met with less than or equal to four fuel assemblies adjacent to the SRM and no other fuel assemblies in the associated core quadrant.Verify count rate is: a. >_ 3.0 cps if a signal to noise ratio _ 2:1 or b. Within the limits of Figure 3.3.1.2-1 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> during CORE ALTERATIONS AND In accordance with the Surveillance Frequency Control Program 24-heU-s SR 3.3.1.2.5 Perform CHANNEL FUNCTIONAL TEST and determination of In accordance with the signal to noise ratio. Surveillance Frequency Control Proqram.7-days SR 3.3.1.2.6

---

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

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after IRMs on Range 2 or below.Perform CHANNEL FUNCTIONAL TEST and determination of In accordance with the signal to noise ratio. Surveillance Frequency Control Prograrn,4-day' SR 3.3.1.2.7

---

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

1. Neutron detectors are excluded.2. Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after IRMs on Range 2 or below.Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control aggram24l Months I SUSQUEHANNA

-UNIT 2 TS / 3.3-13 Amendment W

PPL Rev. 4 Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS k ITIt'--------------------------------------

IJII r- ;I% -----------------------------------------------------------1. Refer to Table 3.3.2.1-1 to determine which SRs apply for each Control Rod Block Function.2. When an RBM channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the associated Function maintains control rod block capability.

SURVEILLANCE FREQUENCY SR 3.3.2.1.1 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Proqram8&4 days SR 3.3.2.1.2

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

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

Not required to be performed until 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after any control rod is withdrawn at _ 10% RTP in MODE 2.Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program92-days SR 3.3.2.1.3

---

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

Not required to be performed until 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after THERMAL POWER is 10% RTP in MODE 1.Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control ProqramQ2-days SR 3.3.2.1.4 Verify the RBM: a. Low Power Range -Upscale Function is not bypassed when APRM In accordance with the Simulated Thermal Power is > 28% RTP and 5 Intermediate Power Surveillance Range Setpoint specified in the COLR. Frequency Control Program24 months (continued)

SUSQUEHANNA

-UNIT 2 TS / 3.3-18 Amendment W, 207,,ýM PPL Rev. 4 Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY b. Intermediate Power Range -Upscale Function is not bypassed when APRM Simulated Thermal Power is > Intermediate Power Range Setpoint specified in the COLR and < High Power Range Setpoint specified in the COLR.c. High Power Range -Upscale Function is not bypassed when APRM Simulated Thermal Power > High Power Range Setpoint specified in the COLR.SR 3.3.2.1.5 Verify the RWM is not bypassed when THERMAL POWER In accordance with is < 10% RTP. the Surveillance Frequency Control Proqram24-menths SR 3.3.2.1.6

---

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

Not required to be performed until 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after reactor mode switch is in the shutdown position.Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Propqram24-menthe SR 3.3.2.1.7

---

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

Neutron detectors are excluded.Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Pro-qram24 months SR 3.3.2.1.8 Verify control rod sequences input to the RWM are in Prior to declaring conformance with BPWS. RWM OPERABLE following loading of sequence into RWM SUSQUEHANNA-UNIT2 TS / 3.3-1.9 Amendment I.K 220 PPL Rev. 4 Feedwater

-Main Turbine High Water Level Trip Instrumentation 3.3.2.2 SURVEILLANCE REQUIREMENTS I. I -----------

---

tI IF II-------------------------------------------------------------

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

-main turbine high water level trip capability is maintained.

SURVEILLANCE FREQUENCY SR 3.3.2.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Proqram24-heu-s SR 3.3.2.2.2-------------------------------------------

1. A test of all required contacts does not have to be performed.

2. For the Feedwater

-Main Turbine High Water Level Function, a test of all required relays does not have to be performed.

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Pro-qram92-days SR 3.3.2.2.3 Perform CHANNEL CALIBRATION.

The Allowable Value In accordance with shall be _< 55.5 inches. the Surveillance Frequency Control Pro-qram24 menths SR 3.3.2.2.4 Perform LOGIC SYSTEM FUNCTIONAL TEST including In accordance with valve actuation.

the Surveillance Frequency Control Proqram24 menths I SUSQUEHANNA

-UNIT 2 TS / 3.3-22 Amendment.15<

PPL Rev. 2 PAM Instrumentation 3.3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Enter the Condition referenced in Immediately associated Completion Table 3.3.3.1-1 for the channel.Time of Condition C not met.E. As required by E.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Required Action D.1 and referenced in Table 3.3.3.1-1.

F. As required by F.1 Initiate action in accordance with Immediately Required Action D.land Specification 5.6.7.referenced in Table 3.3.3.1-1.

SURVEILLANCE REQUIREMENTS

---

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

These SRs apply to each Function in Table 3.3.3.1-1.

SURVEILLANCE FREQUENCY SR 3.3.3.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Proqram31 days (continued)

I SUSQUEHANNA-UNIT 2 TS / 3.3-24 Amendment J5-t I PPL Rev. 2 PAM Instrumentation 3.3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.3.1.2 Not Used.SR 3.3.3.1.3 Perform CHANNEL CALIBRATION for all Functions except 24 mntheln PCIV Position.

accordance with the Surveillance Frequency Control Program SUSQUEHANNA

-UNIT 2 TS / 3.3-25 Amendment W, 2-K PPL Rev. 4-Remote Shutdown System 3.3.3.2 SURVEILLANCE REQUIREMENTS

---

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

Refer to Table 3.3.3.2-1 to determine which SRs apply for each Remote Shutdown System Function.SURVEILLANCE FREQUENCY SR 3.3.3.2.1 Perform CHANNEL CHECK for each required In accordance with instrumentation channel that is normally energized.

the Surveillance Frequency Control Proaqram.31,-..

SR 3.3.3.2.2 Verify each required control circuit and transfer switch is In accordance with capable of performing the intended function, the Surveillance Frequency Control Procqram24-menths SR 3.3.3.2.3 Perform CHANNEL CALIBRATION for each required In accordance with instrumentation channel, the Surveillance Frequency Control Procqram24 moeths I SUSQUEHANNA

-UNIT 2 TS / 3.3-28 Amendment 111>P1 PPL Rev. 4 EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS

---

Ij r ------------------------------------------------------------

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

SURVEILLANCE FREQUENCY SR 3.3.4.1.1 A test of all required contacts does not have to be performed.

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Procqram92-days SR 3.3.4.1.2 Perform CHANNEL CALIBRATION.

The Allowable In accordance with Values shall be: the Surveillance Frequency Control Procqram24-menths TSV-Closure:

< 7% closed;and TCV Fast Closure, Trip Oil Pressure-Low:

>_ 460 psig.SR 3.3.4.1.3 Perform LOGIC SYSTEM FUNCTIONAL TEST including In accordance with breaker actuation.

the Surveillance Frequency Control Proqram24-menths SR 3.3.4.1.4 Verify TSV-Closure and TCV Fast Closure, Trip Oil In accordance with Pressure-Low Functions are not bypassed when the Surveillance THERMAL POWER is _ 26% RTP. Frequency Control Proqram24 months (continued)

I SUSQUEHANNA

-UNIT 2 TS / 3.3-32 Amendment 161, 32<

PPL Rev. 4 EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY-t SR 3.3.4.1.5i i-11" r--------------------------

L r"---------------------------------

Breaker arc suppression time may be assumed from the most recent performance of SR 3.3.4.1.6.

Verify the EOC-RPT SYSTEM RESPONSE TIME is within limits.In accordance with the Surveillance Frequency Control Proqram24 menths on a STA GGE=REDI SR 3.3.4.1.6 Determine RPT breaker arc suppression time. In accordance with the Surveillance Frequency Control Propqram60 menths I SUSQUEHANNA-UNIT 2 TS / 3.3-33 Amendment JW, PPL Rev. 0 ATWS-RPT Instrumentation 3.3.4.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One Function with B.1 Restore ATWS-RPT trip capability.

72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> ATWS-RPT trip capability not maintained.

C. Both Functions with C.1 Restore ATWS-RPT trip capability 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> ATWS-RPT trip for one Function.capability not maintained.

D. Required Action and D.1 Remove the associated 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion recirculation pump from service.Time not met.OR D.2 Be in MODE 2. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> SURVEILLANCE REQUIREMENTS

---

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

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

SURVEILLANCE FREQUENCY SR 3.3.4.2.1 Perform CHANNEL CHECK of Reactor Vessel Water In accordance with Level, Low Low, Level 2. the Surveillance Frequency Control Program!2 1heuS (continued)

I SUSQUEHANNA-UNIT 2 TS / 3.3-35 Amendment ilit PPL Rev. 0 ATWS-RPT Instrumentation 3.3.4.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.4.2.2

---

A test of all required contacts does not have to be performed.

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program92 days SR 3.3.4.2.3 Perform CHANNEL CALIBRATION of the Reactor Steam In accordance with Dome Pressure-High.

The Allowable Values shall be the Surveillance

_ 1150 psig. Frequency Control Procqram@2 days SR 3.3.4.2.4 Perform CHANNEL CALIBRATION of the Reactor Vessel In accordance with Water Level Low Low, Level 2. The Allowable Values the Surveillance shall be > -45 inches. Frequency Control Proqram24 menths SR 3.3.4.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST including In accordance with breaker actuation.

the Surveillance Frequency Control Proqram24 menths I SUSQUEHANNA-UNIT 2 TS / 3.3-36 Amendment W

PPL Rev. 4 ECCS Instrumentation 3.3.5.1 SURVEILLANCE REQUIREMENTS

---

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

1. Refer to Table 3.3.5.1-1 to determine which SRs apply for each ECCS Function.2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed as follows: (a) for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for Functions 3.c and 3.e; and (b) for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for Functions other than 3.c and 3.e provided the associated Function or the redundant Function maintains ECCS initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.5.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program42-hours SR 3.3.5.1.2 A test of all required contacts does not have to be performed.

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Pro-gramO2-days SR 3.3.5.1.3 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Proqram82-days SR 3.3.5.1.4 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control P rgarn24-mept-hs SR 3.3.5.1.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Pro gram24 nFieths SUSQUEHANNA

-UNIT 2 TS / 3.3-42 Amendment lZt, N-2 PPL Rev. 0 RCIC System Instrumentation 3.3.5.2 SURVEILLANCE REQUIREMENTS

---

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

1. Refer to Table 3.3.5.2-1 to determine which SRs apply for each RCIC Function.2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed as follows: (a) for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for Functions 2 and 4 and (b) for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for Functions other than Functions 2 and 4 provided the associated Function maintains RCIC initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.5.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program42 hours SR 3.3.5.2.2 A test of all required contacts does not have to be performed.

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control ProgramQ-days SR 3.3.5.2.3 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control SR 3.3.5.2.4 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program24-mePths SR 3.3.5.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Proqram24-mfeIlths I SUSQUEHANNA

-UNIT 2 TS / 3.3-50 Amendment 1,W I PPL Rev. 3 Primary Containment Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS

---

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

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

1. Refer to Table 3.3.6.1-1 to determine which SRs apply for each Primary Containment Isolation Function.2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the associated Function maintains isolation capability.

SURVEILLANCE FREQUENCY SR 3.3.6.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program42-heus SR 3.3.6.1.2

1. A test of all required contacts does not have to be performed 2. For Functions 2.e, 3.a, and 4.a, a test of all required relays does not have to be performed Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Pro..ram92-days SR 3.3.6.1.3 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Proqram92-da.s SR 3.3.6.1.4 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Proqram24-mnaniits SR 3.3.6.1.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program24-meths SUSQUEHANNA

-UNIT 2 TS 1 3.3-55 Amendment W

PPL Rev. 3 Primary Containment Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.6.1.6-------------

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

1. For Function 1.b. channel sensors are excluded.2. Response time testing of isolating relays is not required for Function 5.a.Verify the ISOLATION SYSTEM RESPONSE TIME is within limits.In accordance with the Surveillance Frequency Control Pro qram-24 STAGGERED TEST BASIS SUSQUEHANNA

-UNIT 2 TS / 3.3-56 Amendment 1W I PPL Rev. 0 Secondary Containment Isolation Instrumentation 3.3.6.2 SURVEILLANCE REQUIREMENTS

---

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

1. Refer to Table 3.3.6.2-1 to determine which SRs apply for each Secondary Containment Isolation Function.2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the associated Function maintains secondary containment isolation capability.

SURVEILLANCE FREQUENCY SR 3.3.6.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Pro!ram12 hews S R 3 .3 .6 .2 .2 .------------------------------------------------------------------

..........

A test of all required contacts does not have to be performed.

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

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Proqram92-days SR 3.3.6.2.3 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program2-days SR 3.3.6.2.4 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Proqram24 mneiths SR 3.3.6.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Proqram,24-me.the I SUSQUEHANNA-UNIT 2 TS / 3.3-66 Amendment 154-PPL Rev. G CREOAS System Instrumentation 3.3.7.1 SAGUIAN SURVEILLANCE REQUIREMENTS I r~srr c~-------------------------------------------------------------

I-aUm I I -------------------------------------

1. Refer to Table 3.3.7.1-1 to determine which SRs apply for each CREOAS Function.2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the associated Function maintains CREOAS initiation capability.

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

SURVEILLANCE FREQUENCY SR 3.3.7.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program 42-heu-s S R 3 .3 .7 .1 .2 -------------------------------------------------------------------------------

1. A test of all required contacts does not have to be performed.

2. For Function 8, a test of all required relays does not have to be performed.

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

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program 9 2 days SR 3.3.7.1.3 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program SR 3.3.7.1.4 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program 24 mneths SR 3.3.7.1.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program 24 menths I SUSQUEHANNA-UNIT2 TS / 3.3-70 Amendment j5-V I PPL Rev. 4-LOP Instrumentation 3.3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. As required by Required D.1 Restore the inoperable Channel. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Action A.1 and referenced in Table 3.3.8.1-1.

E. Required Action and E.I Declare associated diesel generator Immediately associated Completion (DG) inoperable.

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

---

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 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the associated Function maintains DG initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.8.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Pro!ram12 hows SR 3.3.8.1.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program3-1 days SR 3.3.8.1.3 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Propram24-meonth SR 3.3.8.1.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Proqram24 moenths SUSQUEHANNA

-UNIT 2 TS / 3.3-73 Amendment 454,>5 1 3W PPL Rev. 0 RPS Electric Power Monitoring 3.3.8.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Initiate action to fully insert all Immediately associated Completion insertable control rods in core cells Time of Condition A containing one or more fuel or B not met in assemblies.

MODE 4 or 5.AND D.2.1 Initiate action to restore one Immediately electric power monitoring assembly to OPERABLE status for inservice power supply(s) supplying required instrumentation.

OR D.2.2 Initiate action to isolate the Immediately Residual Heat Removal Shutdown Cooling System.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.8.2.1

---

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

Only required to be performed prior to entering MODE 2 or 3 from MODE 4, when in MODE 4 for _> 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Procjram-84-days (continued)

I SUSQUEHANNA

-UNIT 2 TS / 3.3-76 Amend ment j--r-7f PPL Rev. 0 RPS Electric Power Monitoring 3.3.8.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.8.2.2 Perform CHANNEL CALIBRATION.

The Allowable Values shall be: In accordance with the Surveillance Frequency Control Pro-qram24 mei~th a. Overvoltage

_< 129.1 V for Division A and _< 130.3 V for Division B.b. Undervoltage

>_ 112.0 V for Division A and _ 112.5 V for Division B.c. Underfrequency

>_ 57 Hz.SR 3.3.8.2.3 Perform a system functional test. In accordance with the Surveillance Frequency Control Program24-menths I SUSQUEHANNA

-UNIT 2 TS / 3.3-77 Amendment 15-f PPL Rev. 3 Recirculation Loops Operating 3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 ----------------

NOTE--- --------Not required to be performed until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after both recirculation loops are in operation.

Verify recirculation loop jet pump flow mismatch with both recirculation loops in operation is: a. < 10 million Ibm/hr when operating at< 75 million Ibm/hr total core flow; and b. < 5 million Ibm/hr when operating at_ 75 million Ibm/hr total core flow.In accordance with the Surveillance Frequency Control Program24-heur-s SR 3.4.1.2 ----------------

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

Only required to be met during single loop operations.

Verify recirculation pump speed is within the In accordance with the limit specified in the LCO. Surveillance Frequency Control Program24 hours SUSQUEHANNA

-UNIT 2 TS / 3.4-3 Amendment -t5t-iý, I%, J9-2, PPL Rev. 4-Jet Pumps 3.4.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.2.1 ----------------

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

1. Not required to be completed until 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> after associated recirculation loop is in operation.

2. Not required to be completed until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after > 23% RTP.Verify at least two of the following criteria (a, In accordance with the b, or c) are satisfied for each operating Surveillance Frequency recirculation loop: Control Proqram24-hGur-a. Recirculation loop drive flow versus Recirculation Pump speed differs by_< 10% from established patterns.b. Recirculation loop drive flow versus total core flow differs by _< 10% from established patterns.c. Each jet pump diffuser to lower plenum differential pressure differs by< 20% from established patterns, or each jet pump flow differs by _< 10%from established patterns.I SUSQUEHANNA

-UNIT 2 TS / 3.4-7 Amendment 181,,224 PPL Rev. 0 RCS Operational LEAKAGE 3.4.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued)

B.2 Verify source of 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> unidentified LEAKAGE increase is not service sensitive type 304 or type 316 austenitic stainless steel.A. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A AND or B not met.C.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> OR Pressure boundary LEAKAGE exists.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.4.1 Verify RCS unidentified and total LEAKAGE In accordance with the and unidentified LEAKAGE increases are Surveillance Frequency within limits. Control Proqram!n2 hO'-S I SUSQUEHANNA-UNIT 2 TS / 3.4-11 Amendment iw PPL Rev. 4-RCS Leakage Detection Instrumentation 3.4.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 Perform a CHANNEL CHECK of required primary In accordance with containment atmospheric monitoring system. the Surveillance Frequency Control h-I.w.SR 3.4.6.2 Perform a CHANNEL FUNCTIONAL TEST of required In accordance with leakage detection instrumentation, the Surveillance Frequency Control___ ___ ___ ___ ___ ___ ___ ___ ___ ___ ___ ___ ___ ___ ___ __ Program314 e SR 3.4.6.3 Perform a CHANNEL CALIBRATION of required In accordance with leakage detection instrumentation, the Surveillance Frequency Control Program24-menthe I SUSQUEHANNA

-UNIT 2 TS / 3.4-16 Amendment,*f PPL Rev. 1-RCS Specific Activity 3.4.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued)

B.2.2.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> AND B.2.2.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 -----------------------

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

Only required to be performed in MODE 1.Verify reactor coolant DOSE EQUIVALENT In accordance with 1-131 specific activity is 0.2 pCi/gm. the Surveillance Frequency Control Program7-days I SUSQUEHANNA

-UNIT 2 TS /,3.4-18 Amendment PPL Rev. 4 RHR Shutdown Cooling System -Hot Shutdown 3.4.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 ----------------------

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

Not required to be met until 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after reactor steam dome pressure is less than the RHR cut in permissive pressure.Verify one RHR shutdown cooling subsystem or In accordance with the recirculation pump is operating.

Surveillance Frequency Control Procqraml-2 hours I SUSQUEHANNA-UNIT 2 TS / 3.4-21 Amendment j,5T PPL Rev. 0 RHR Shutdown Cooling System-Cold Shutdown 3.4.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. No RHR shutdown cooling B.1 Verify reactor coolant 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from discovery subsystem in operation, circulating by an alternate of no reactor coolant method. circulation AND AND No recirculation pump in operation.

Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter AND B.2 Monitor reactor coolant Once per hour temperature.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify one RHR shutdown cooling subsystem or In accordance with the recirculation pump is operating.

Surveillance Frequency Control Procqram12 he'-s I SUSQUEHANNA

-UNIT 2 TS / 3.4-23 Amendment

ý&<

PPL Rev. 3 RCS P/T Limits 3.4.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.10.1----------------

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

Only required to be performed during RCS heatup and cooldown operations and RCS inservice leak and hydrostatic testing.Verify: a. RCS pressure and RCS temperature are to the right of the most limiting curve specified in Figures 3.4.10-1 through 3.4.10-3; and b. --------------

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

Only applicable when governed by Figure 3.4.10-ý2, Curve B, and Figure 3.4.10-3, Curve C.RCS heatup and cooldown rates are< 100°F in any one hour period; and c. -----------------

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

Only applicable when governed by Figure 3.4.10-1, Curve A.In accordance with the Surveillance Frequency Control Proqram3g minutes RCS heatup and cooldown rates are _< 20°F in any one hour period.SR 3.4.10.2 Verify RCS pressure and RCS temperature are to Once within 15 minutes the right of the criticality limit (Curve C) specified in prior to control rod Figure 3.4.10-3.

withdrawal for the purpose of achieving criticality (continued)

SUSQUEHANNA

-UNIT 2 TS / 3.4-26 Amendment V4 PPL Rev. 3 RCS P/T Limits 3.4.10 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.10.6---------------------

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

Only required to be met in single loop operation when the idle recirculation loop is not isolated from the RPV, and: a. THERMAL POWER 27% RTP; or b. The operating recirculation loop flow 21,320 gpm.Verify the difference between the reactor coolant temperature in the recirculation loop not in operation and the RPV coolant temperature is< 50 0 F.Once within 15 minutes prior to an increase in THERMAL POWER or an increase in loop flow.SR 3.4.10.7 ---------------------

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

Only required to be performed when tensioning the reactor vessel head bolting studs.Verify reactor vessel flange and head flange In accordance with the temperatures are _> 70 0 F. Surveillance Frequency Control Proqrame3 miautes SR 3.4.10.8 ---------------------

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

Not required to be performed until 30 minutes after RCS temperature

_< 80°F in MODE 4.Verify reactor vessel flange and head flange In accordance with the temperatures are _> 70 0 F. Surveillance Frequency Control Procqram30 miWtes (continued)

I SUSQUEHANNA-UNIT 2 TS / 3.4-28 Amendment 454, ;24 I PPL Rev. 3 RCS PIT Limits 3.4.10 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.10.9 ---------------------

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

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after RCS temperature

< 1 00°F in MODE 4.Verify reactor vessel flange and head flange In accordance with the temperatures are >_ 70 0 F. Surveillance Frequency Control Proqraml-2 I SUSQUEHANNA

-UNIT 2 TS / 3.4-29 Amendment 15-r PPL Rev. 0 Reactor Steam Dome Pressure 3.4.11 3.4 REACTOR COOLANT SYSTEM (RCS)3.4.11 Reactor Steam Dome Pressure LCO 3.4.11 APPLICABILITY:

The reactor steam dome pressure shall be _< 1050 psig.MODES 1 and 2.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Reactor steam dome A. I Restore reactor steam 15 minutes pressure not within dome pressure to within limit. limit.B. Required Action and B. 1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met.I SUSQUEHANNA

-UNIT 2 TS / 3.4-31 Amendment I i,5*

PPL Rev. 1-ECCS -Operating 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify, for each ECCS injection/spray subsystem, In accordance with the the piping is filled with water from the pump Surveillance Frequency discharge valve to the injection valve. Control Program 314-days SR 3.5.1.2 ------------------

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

Low pressure coolant injection (LPCI) subsystems may be considered OPERABLE during alignment and operation for decay heat removal with reactor steam dome pressure less than the Residual Heat Removal (RHR) cut in permissive pressure in MODE 3, if capable of being manually realigned and not otherwise inoperable.

Verify each ECCS injection/spray subsystem In accordance with the manual, power operated, and automatic valve in Surveillance Frequency the flow path, that is not locked, sealed, or Control Program 34-days otherwise secured in position, and the HPCI flow controller are in the correct position.SR 3.5.1.3 Verify ADS gas supply header pressure is In accordance with the> 135 psig. Surveillance Frequency Control Program 3-1-ays SR 3.5.1.4 Verify at least one RHR System cross tie valve is In accordance with the closed and power is removed from the valve Surveillance Frequency operator.

Control Program SR 3.5.1.5 Verify each 480 volt AC swing bus transfers In accordance with the automatically from the normal source to the Surveillance Frequency alternate source on loss of power. Control Program 34--days (continued)

I SUSQUEHANNA

-UNIT 2 TS / 3.5-4 Amendment JW PPL Rev. 4 ECCS -Operating 3.5.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.1.9 -----------------

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

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam pressure and flow are adequate to perform the test.Verify, with reactor pressure < 165 psig, the HPCI In accordance with the pump can develop a flow rate _> 5000 gpm against a Surveillance Frequency system head corresponding to reactor pressure.

Control Program 24 menths SR 3.5.1.10 ------------------

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

Vessel injection/spray may be excluded.Verify each ECCS injection/spray subsystem In accordance with the actuates on an actual or simulated automatic Surveillance Frequency initiation signal. Control Program 24-menths SR 3.5.1.11 -----------------

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

Valve actuation may be excluded.Verify the ADS actuates on an actual or simulated In accordance with the automatic initiation signal. Surveillance Frequency Control Program 24- nenths SR 3.5.1.12 -----------------

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

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam pressure and flow are adequate to perform the test.Verify each ADS valve opens when manually In accordance with the actuated.

Surveillance Frequency Control Program 24-menth on a STAGGERED TEST BASIS for each valve ,olenoi.(continued)

I SUSQUEHANNA

-UNIT 2 TS / 3.5-6 Amendment IX I PPL Rev. 1-ECCS -Operating 3.5.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.1.13 ---------------

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

Instrumentation response time is based on historical response time data.Verify the ECCS RESPONSE TIME for each In accordance with the ECCS injection/spray subsystem is within limit. Surveillance Frequency Control Proqram 24-menthe I SUSQUEHANNA

-UNIT 2 TS / 3.5-7 Amendment JW PPL Rev. 0 ECCS-Shutdown 3.5.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action C.2 and D.1 Initiate action to restore Immediately associated Completion Time secondary containment to not met. OPERABLE status.AND D.2 Initiate action to restore one Immediately standby gas treatment subsystem to OPERABLE status.AND D.3 Initiate action to restore Immediately isolation capability in each required secondary containment penetration flow path not isolated.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify, for each required low pressure coolant In accordance with the injection (LPCI) subsystem, the suppression pool Surveillance Frequency water level is _> 20 ft 0 inches. Control Program 12 heuF-(continued)

I SUSQUEHANNA-UNIT 2 TS / 3.5-9 Amendment

>:I-PPL Rev. 0 ECCS-Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.2 Verify, for each required core spray (CS)subsystem, the: a. Suppression pool water level is_> 20 ft 0 inches; or b. ---------------

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

Only one required CS subsystem may take credit for this option during OPDRVs.Condensate storage tank water level is >_ 49%of capacity.In accordance with the Surveillance Frequency Control Proqram12 heurs SR 3.5.2.3 Verify, for each required ECCS injection/spray In accordance with the subsystem, the piping is filled with water from the Surveillance Frequency pump discharge valve to the injection valve. Control Program 31 days SR 3.5.2.4 -----------------

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

LPCI subsystems may be considered OPERABLE during alignment and operation for decay heat removal if capable of being manually realigned and not otherwise inoperable.

Verify each required ECCS injection/spray In accordance with the subsystem manual, power operated, and Surveillance Frequency automatic valve in the flow path, that is not locked, Control Program31 days sealed, or otherwise secured in position, is in the correct position.(continued)

I SUSQUEHANNA

-UNIT 2 TS / 3.5-10 Amendment jR-t PPL Rev. 0 ECCS-Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.5 Verify each required ECCS pump develops the specified flow rate against a system head corresponding to the specified reactor pressure.In accordance with the Inservice Testing Program NO. OF SYSTEM FLOW RATE PUMPS SYSTEM HEAD CORRESPONDING TO A REACTOR PRESSURE OF 105 psig> 20 psig CS>_ 6350 gpm 2 1 LPCI _> 12,200 gpm SR 3.5.2.6 -----------------

NOTE--- ---------Vessel injection/spray may be excluded.Verify each required ECCS injection/spray In accordance with the subsystem actuates on an actual or simulated Surveillance Frequency automatic initiation signal. Control Program 24--menthe SR 3.5.2.7 -----------------

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

Instrumentation response time may be assumed to be the historical instrumentation response time.Verify the ECCS RESPONSE TIME for each In accordance with the ECCS injection/spray subsystem is within limit. Surveillance Frequency Control Program24-me4nths I SUSQUEHANNA-UNIT2 TS / 3.5-11 Amendment 1,5 PPL Rev. 4-RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 Verify the RCIC System piping is filled with water from In accordance with the pump discharge valve to the injection valve, the Surveillance Frequency Control Program,3--as SR 3.5.3.2 Verify each RCIC System manual, power operated, and In accordance with automatic valve in the flow path, that is not locked, the Surveillance sealed, or otherwise secured in position, and the RCIC Frequency Control flow controller are in the correct position.

Proqram31-days SR 3.5.3.3 ---------------------

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

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam pressure and flow are adequate to perform the test.Verify, with reactor pressure < 1060 psig and In accordance

> 920 psig, the RCIC pump can develop a flow rate with the Inservice_ 600 gpm against a system head corresponding to Testing Program reactor pressure.SR 3.5.3.4 ----------------------

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

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam pressure and flow are adequate to perform the test.Verify, with reactor pressure < 165 psig, the RCIC pump In accordance with can develop a flow rate > 600 gpm against a system the Surveillance head corresponding to reactor pressure.

Frequency Control Program-24 (continued)

I SUSQUEHANNA

-UNIT 2 TS / 3.5-13 Amendment 1,5f PPL Rev. 4 RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.3.5 ---------------------

NOTE.Vessel injection may be excluded.Verify the RCIC System actuates on an actual or simulated automatic initiation signal.In accordance with the Surveillance Frequency Control Program 24 menthe I SUSQUEHANNA

-UNIT 2 TS 13.5-14 Amendment 1,51 PPL Rev. 0 Primary Containment 3.6.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.1.1 Perform required visual examinations and leakage In accordance with the rate testing except for primary containment air lock Primary Containment testing, in accordance with the Primary Leakage Rate Testing Containment Leakage Rate Testing Program. Program.When performing 10 CFR 50 SR 3.6.1.1.2 Verify that the drywell-to-suppression chamber Appendix J, Type A testing, in bypass leakage is less than 0.00535 ft 2 at an initial accordance with the Primary differential pressure of _4.3 psi. Containment Leakage Rate Testing Program.AND------ ------------

Note ----------------

Only required after two consecutive tests fail and continues until two consecutive tests pass In accordance with the Surveillance Frequency Control Proqram 2,, mnths SUSQUEHANNA

-UNIT 2 TS / 3.6-2 Amendment 17-;r PPL Rev. 0 Primary Containment 3.6.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.1.1.3-Note ------------------------------

Satisfied by the performance of SR 3.6.1.1.2.

Verify that the total drywell-to-suppression chamber vacuum breaker leakage is less than or equal to .001605 ft2 and the leakage area for each set of vacuum breakers is less than or equal to.000642 ft2 at an initial differential pressure of_ 4.3 psi.In accordance with the Surveillance Frequency Control Proqram24-metths I SUSQUEHANNA

-UNIT 2 TS / 3.6-3 Amendmentj5-r PPL Rev. 0 Primary Containment Air Lock 3.6.1.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met. AND D.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.2.1

---

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

1. An inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test.2. Results shall be evaluated against acceptance criteria acceptable to SR 3.6.1.1.1.

Perform required primary containment air lock In accordance with the leakage rate testing in accordance with the Primary Primary Containment Containment Leakage Rate Testing Program. Leakage Rate Testing Program SR 3.6.1.2.2 Verify only one door in the primary containment air In accordance with the lock can be opened at a time. Surveillance Frequency Control Proflram-24 menthe I SUSQUEHANNA-UNIT 2 TS / 3.6-7 Amendment

)151(

PPL Rev. 2 PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.3.1

---

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

1. Only required to be met in MODES 1, 2, and 3.2. Not required to be met when the 18 and 24 inch primary containment purge valves are open for inerting, de-inerting, pressure control, ALARA or air quality considerations for personnel entry, or Surveillances that require the valves to be open.Verify each 18 and 24 inch primary containment In accordance with purge valve is closed, the Surveillance Frequency Control Programl-1 SR 3.6.1.3.2

---

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

1. Valves and blind flanges in high radiation areas may be verified by use of administrative means.2. Not required to be met for PCIVs that are open under administrative controls.In accordance with Verify each primary containment isolation manual the Surveillance valve and blind flange that is located outside Frequency Control primary containment and not locked, sealed, or Procqram 34-days otherwise secured and is required to be closed during accident conditions is closed.(continued)

I SUSQUEHANNA

-UNIT 2 TS_./ 3.6-12 Amendment W

PPL Rev. 2 PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.1.3.3----------------------

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

1. Valves and blind flanges in high radiation areas may be verified by use of administrative means.2. Not required to be met for PCIVs that are open under administrative controls.Verify each primary containment manual isolation valve and blind flange that is located inside primary containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed.Prior to entering MODE 2 or 3 from MODE 4 if primary containment was de-inerted while in MODE 4, if not performed within the previous 92 days~1-SR 3.6.1.3.4 Verify continuity for each of the traversing incore probe (TIP) shear isolation valve explosive charge.In accordance with the Surveillance Frequency Control Prociram34-davs SR 3.6.1.3.5 Verify the isolation time of each power operated In accordance with and each automatic PCIV, except for MSIVs, is the Inservice within limits. Testing Program (continued)

I SUSQUEHANNA

-UNIT 2 TS / 3.6-13 Amendment

ýX PPL Rev. 2 PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.1.3.6-------------------

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

Only required to be met in MODES 1, 2 and 3.Perform leakage rate testing for each primary containment purge valve with resilient seals.In accordance with the Surveillance Frequency Control Pro-gram 184 day- 24 Menthe SR 3.6.1.3.7 Verify the isolation time of each MSIV is In accordance with_3 seconds and _ 5 seconds. the Inservice Testing Program SR 3.6.1.3.8 Verify each automatic PCIV actuates to the In accordance with isolation position on an actual or simulated the Surveillance isolation signal. Frequency Control Pro-qram24 menth SR 3.6.1.3.9 Verify a representative sample of reactor In accordance with instrumentation line EFCVs actuate to check flow the Surveillance on a simulated instrument line break. Frequency Control Proqram24 4nGRthS SR 3.6.1.3.10 Remove and test the explosive squib from each In accordance with shear isolation valve of the TIP System. the Surveillance Frequency Control Program 241 nnthe on a STAGGERED TEST13At&(continued)

SUSQUEHANNA

-UNIT 2 TS / 3.6-14 Amendment 468, ?,00 PPL Rev. 0 Containment Pressure 3.6.1.4 3.6 CONTAINMENT SYSTEMS 3.6.1.4 Containment Pressure LCO 3.6.1.4 Containment pressure shall be -1.0 to 2.0 psig.APPLICABILITY:

MODES 1, 2, and 3.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment pressure not A.1 Restore containment pressure 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> within limit to within limit.B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met.AND B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY In accordance with the SR 3.6.1.4.1 Verify containment pressure is within limit. Surveillance Frequency Control Program 12 heurs I SUSQUEHANNA-UNIT 2 TS / 3.6-17 Amendment 1 r- 4'ýýl I PPL Rev. 0 Drywell Air Temperature 3.6.1.5 3.6 CONTAINMENT SYSTEMS Drywell Air Temperature 3.6.1.5 LCO 3.6.1.5 APPLICABILITY:

Drywell average air temperature shall be _< 135 0 F.MODES 1, 2, and 3.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Drywell average air A. 1 Restore drywell average air 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> temperature not within temperature to within limit.limit.B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met. AND 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> B.2 Be in MODE 4.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.5.1 Verify drywell average air temperature is within In accordance with limit, the Surveillance Frequency Control , proaram24-heuers I SUSQUEHANNA

-UNIT 2 TS / 3.6-18 Amendment 9ý-

PPL Rev. 0 Suppression Chamber-to-Drywell Vacuum Breakers 3.6.1.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met. AND D.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.6.1

---

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

Not required to be met for vacuum breakers that are open during Surveillances.

Verify each vacuum breaker is closed. In accordance with the Surveillance Frequency Control Program44-days AND Within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after discharge of steam to the suppression chamber from safety/relief valve (S/RV) operation.(continued)

I SUSQUEHANNA

-UNIT 2 TS / 3.6-20 Amendment 1 %

PPL Rev. G Suppression Chamber-to-Drywell Vacuum Breakers 3.6.1.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY i SR 3.6.1.6.2 Perform a functional test of each required vacuum breaker.In accordance with the Surveillance Frequency Control Proqram341.-days AND Within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after discharge of steam to the suppression chamber from S/RV operation AND Within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> following an operation that causes any of the vacuum breakers to open SR 3.6.1.6.3 Verify the opening setpoint of each required In accordance with vacuum breaker is _> 0.25 and < .75 psid. the Surveillance Frequency Control Program244mRnthe SUSQUEHANNA

-UNIT 2 TS / 3.6-21 Amendment 17,2r PPL Rev. 0 Suppression Pool Average Temperature 3.6.2.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Suppression pool average E.1 Depressurize the reactor 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> temperature

> 120 0 F. vessel to < 200 psig.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.1.1 Verify suppression pool average temperature is In accordance with the within the applicable limits. Surveillance Frequency Control Program 24-heure AND 5 minutes when performing testing that adds heat to the suppression pool I SUSQUEHANNA

-UNIT 2 TS / 3.6-24 Amendment 1 j--r,*

PPL Rev. 0 Suppression Pool Water Level 3.6.2.2 3.6 CONTAINMENT SYSTEMS 3.6.2.2 Suppression Pool Water Level LCO 3.6.2.2 Suppression pool water level shall be _> 22 ft 0 inches and < 24 ft 0 inches.APPLICABILITY:

MODES 1, 2, and 3.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Suppression pool water level A.1 Restore suppression pool 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> not within limits, water level to within limits.B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met.AND B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.2.1 Verify suppression pool water level is In accordance with the Surveillance within limits. Frequency Control Pro-qram24 hours I SUSQUEHANNA-UNIT 2 TS / 3.6-25 Amendment J5T PPL Rev. 0 RHR Suppression Pool Cooling 3.6.2.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.3.1 Verify each RHR suppression pool cooling In accordance with the subsystem manual, power operated, and Surveillance Frequency automatic valve in the flow path that is not locked, Control Procqram34-da,.

sealed, or otherwise secured in position is in the correct position or can be aligned to the correct position.SR 3.6.2.3.2 Verify each RHR pump develops a flow rate In accordance with the> 9750 gpm through the associated heat Inservice Testing Program exchanger while operating in the suppression pool cooling mode.I SUSQUEHANNA

-UNIT 2 TS.__/3.6-27 Amendment 15+

PPL Rev. 0 RHR Suppression Pool Spray 3.6.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.4.1 Verify each RHR suppression pool spray In accordance with the subsystem manual, power operated, and Surveillance Frequency automatic valve in the flow path that is not locked, Control Proram3a4 days sealed, or otherwise secured in position is in the correct position or can be aligned to the correct position.SR 3.6.2.4.2 Verify each suppression pool spray is In accordance with the unobstructed.

Surveillance Frequency Control Pro-lram40-yeaFs I SUSQUEHANNA

-UNIT 2 TS / 3.6-29 Amendment 1,54-PPL Rev. 1-Drywell Air Flow System 3.6.3.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.2.1 Operate each required drywell cooling fan at low In accordance with the speed for > 15 minutes. Surveillance Frequency Control Pro-qram@2-days I SUSQUEHANNA

-UNIT 2 TS / 3.6-33 Amendment W

PPL Rev. 0 Primary Containment Oxygen Concentration 3.6.3.3 CONTAINMENT SYSTEMS Primary Containment Oxygen Concentration 3.6 3.6.3.3 LCO 3.6.3.3 APPLICABILITY:

The primary containment oxygen concentration shall be < 4.0 volume percent.MODE 1 during the time period: a. From 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after THERMAL POWER is > 15% RTP following startup, to b. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> prior to reducing THERMAL POWER to < 15% RTP prior to the next scheduled reactor shutdown.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Primary containment oxygen A. I Restore oxygen concentration 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> concentration not within limit, to within limit.B. Required Action and B.1 Reduce THERMAL POWER to 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> associated Completion Time <15% RTP.not met.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY R 3.6.3.3.1 Verify primary containment oxygen concentration In accordance with the is within limits. Surveillance Frequency Control Pro-aram7 days I SUSQUEHANNA

-UNIT 2 TS / 3.6-34 Amendment 15t PPL Rev. 3 Secondary Containment 3.6.4.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Secondary containment C. I -----------

NOTE--------

inoperable during movement LCO 3.0.3 is not applicable.

of irradiated fuel assemblies in the secondary containment, during CORE Suspend movement of Immediately ALTERATIONS, or during irradiated fuel assemblies in OPDRVs. the secondary containment.

AND C.2 Suspend CORE Immediately ALTERATIONS.

AND C.3 Initiate action to suspend Immediately OPDRVs.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1.1 Verify secondary containment vacuum is In accordance with the> 0.25 inch of vacuum water gauge. Surveillance Frequency Control Program24-heu-s SR 3.6.4.1.2 Verify all required secondary containment In accordance with the removable walls and equipment hatches required Surveillance Frequency to be closed are closed and sealed. Control Proqram34-days (continued)

SUSQUEHANNA

-UNIT 2 TS / 3.6-36 Amendment 1,1, 291,205 PPL Rev. 3 Secondary Containment 3.6.4.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY----------------

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

Single door access openings between required zones within the secondary containment boundary may be opened for entry and exit.SR 3.6.4.1.3 Verify one secondary containment access door in In accordance with the each access opening is closed. Surveillance Frequency Control Proqram31 days SR 3.6.4.1.4

---

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

NOTE-------

The maximum time allowed for secondary Test each configuration at containment draw down is dependent on the least one time every 60 secondary containment configuration.

months.Verify each standby gas treatment (SGT) In accordance with the subsystem will draw down the secondary Surveillance Frequency containment to _> 0.25 inch of vacuum water gauge Control Proqram 24-months in less than or equal to the maximum time allowed on a STAGGERED TEST for the secondary containment configuration that is BASIS OPERABLE.SR 3.6.4.1.5

---

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

NOTE --------The maximum flow allowed for maintaining Test each configuration at secondary containment vacuum is dependent on least one time every 60 the secondary containment configuration.

months.Verify each SGT subsystem can maintain In accordance with the_> 0.25 inch of vacuum water gauge in the Surveillance Frequency secondary containment for at least 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> at a flow Control Program24-menths rate less than or equal to the maximum flow rate on a STAGGERED TEST permitted for the secondary containment BASIS configuration that is OPERABLE.SUSQUEHANNA

-UNIT 2 TS / 3.6-37 Amendment 1X1, 20-5, P5-PPL Rev. 0 SCIVs 3.6.4.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.2.1----------------

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

1. Valves and blind flanges in high radiation areas may be verified by use of administrative means.2. Not required to be met for SCIVs that are open under administrative controls.Verify each required secondary containment isolation manual valve and blind flange that is required to be closed during accident conditions is closed.In accordance with the Surveillance Frequency Control Program 31 ,days SR 3.6.4.2.2 Verify the isolation time of each required In accordance with the automatic SCIV is within limits. Surveillance Frequency Control Program"2-"ae SR 3.6.4.2.3 Verify each required automatic SCIV actuates to In accordance with the the isolation position on an actual or simulated Surveillance Frequency actuation signal. Control Proqram244Pieths I SUSQUEHANNA-UNIT2 TS / 3.6-41 Amendment j-r-r PPL Rev. 4 SGT System 3.6.4.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. Two SGT subsystems F.1 ----------

NOTE--------

inoperable during movement LCO 3.0.3 is not applicable.

of irradiated fuel assemblies in the secondary containment, during CORE Suspend movement of irradiated fuel Immediately ALTERATIONS, or during assemblies in secondary OPDRVs. containment.

AND F.2 Suspend CORE Immediately ALTERATIONS.

AND F.3 Initiate action to suspend Immediately OPDRVs.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.3.1 Operate each SGT filter train for _> 10 continuous In accordance with the hours with heaters operating.

Surveillance Frequency Control Proqram31-de SR 3.6.4.3.2 Perform required SGT filter testing in accordance In accordance with the VFTP with the Ventilation Filter Testing Program (VFTP).SR 3.6.4.3.3 Verify each SGT subsystem actuates on an actual In accordance with the or simulated initiation signal. Surveillance Frequency Control Program2-4menths SR 3.6.4.3.4 Verify each SGT filter cooling bypass and outside In accordance with the air damper opens and the fan starts on high Surveillance Frequency charcoal temperature.

Control Procqram24 menths SUSQUEHANNA

-UNIT 2 TS / 3.6-44 Amendment 41, M PPL Rev. 3 RHRSW System and UHS 3.7.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1.1 Verify the water level is greater than or equal to 678 feet In accordance with 1 inch above Mean Sea Level. the Surveillance Frequency Control Program!12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SR 3.7.1.2 Verify the average water temperature of the UHS is: a. ------------------

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

Only applicable with both units in MODE 1 or 2, or with either unit in MODE 3 for less than twelve (12) hours.< 85 0 F; or b. ------------------

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

Only applicable when either unit has been in MODE 3 for at least twelve (12) hours but not more than twenty-four (24) hours.<87 0 F; or c. ------------------

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

Only applicable when either unit has been in MODE 3 for at least twenty-four (24) hours.In accordance with the Surveillance Frequency Control Proqram24-heuF-

_< 88°F.SR 3.7.1.3 Verify each RHRSW manual, power operated, and In accordance with automatic valve in the flow path, that is not locked, sealed, the Surveillance or otherwise secured in position, is in the correct position or Frequency Control can be aligned to the correct position.

Proqram34-days In accordance with SR 3.7.1.4 Verify that valves HV-01222A and B (the spray array bypass the Surveillance valves) close upon receipt of a closing signal and open Frequency Control upon receipt of an opening signal. FProqramu Cor (continued)

SUSQUEHANNA

-UNIT 2 TS / 3.7-3 Amendment 454, 1-66, 48W, 224 PPL Rev 3 RHRSW System AND UHS 3.7.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY In accordance with SR 3.7.1.5 Verify that valves HV-01224A1 and B1 (the large spray the Surveillance array valves) close upon receipt of a closing signal and Frequency Control open upon receipt of an opening signal. ProeuramencyC In accordance with SR 3.7.1.6 Verify that valves HV-01224A2 and B2 (the small spray the Surveillance array valves) close upon receipt of a closing signal and Frequency Control open upon receipt of an opening signal. Proqramu2-e1ayC In accordance with SR 3.7.1.7 Verify that valves 01 2287A and 01 2287B (the spray array the Surveillance bypass manual valves) are capable of being opened and Frequency Control closed. Froe Control Program92-day SUSQUEHANNA

-UNIT 2 TS / 3.7-3a Amendment 4-89,224' PPL Rev. 0 ESW System 3.7.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A, B or C not met. AND OR D.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> Both ESW subsystems inoperable for reasons other than Condition A and B.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1 ------------------

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

Isolation of flow to individual components does not render ESW System inoperable.

Verify each ESW subsystem manual, power In accordance with the operated, and automatic valve in the flow paths Surveillance Frequency Control servicing safety related systems or components, Program341-day, that is not locked, sealed, or otherwise secured in position, is in the correct position.SR 3.7.2.2 Verify each ESW subsystem actuates on an In accordance with the actual or simulated initiation signal. Surveillance Frequency Control Proqram24 months I SUSQUEHANNA

-UNIT 2 TS / 3.7-5 Amendment I!W PPL Rev.,A4" CREOAS System 3.7.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. Two CREOAS subsystems

---

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

inoperable during movement LCO 3.0.3 is not applicable.

of irradiated fuel assemblies in the secondary containment, during CORE F.1 Suspend movement of Immediately ALTERATIONS, or during irradiated fuel assemblies in OPDRVs. the secondary containment.

OR AND One or more CREOAS F.2 Suspend CORE Immediately subsystems inoperable due ALTERATIONS.

to an inoperable CRE boundary during movement of irradiated fuel AND assemblies in the secondary containment, during CORE F.3 Initiate action to suspend Immediately ALTERATIONS, or during OPDRVs.OPDRVs.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 Operate each CREOAS filter train for > 10 In accordance with the continuous hours with the heaters operable.

Surveillance Frequency Control Proqram314-d.ys SR 3.7.3.2 Perform required CREOAS filter testing in In accordance with the VFTP accordance with the Ventilation Filter Testing Program (VFTP).In accordance with the SR 3.7.3.3 Verify each CREOAS subsystem actuates on an Sureance Fre actual or simulated initiation signal. Proqramvl-meFnthe (continued)

SUSQUEHANA

-UNIT 2 TS / 3.7-8 A m e n d m e n t 4-7-7,,23-2 PPL Rev. 0 Control Room Floor Cooling System 3.7.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Two control room floor -----------------

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

cooling subsystems LCO 3.0.3 is not applicable.

inoperable during movement of irradiated fuel assemblies in the secondary containment, during CORE E.1 Suspend movement of Immediately ALTERATIONS, or during irradiated fuel assemblies in OPDRVs. the secondary containment.

AND E.2 Suspend CORE Immediately ALTERATIONS.

AND E.3 Initiate actions to suspend Immediately OPDRVs.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify each control room floor cooling subsystem In accordance with the has the capability to remove the assumed heat Surveillance Frequency Control load. Program24 menths I SUSQUEHANNA

-UNIT 2 TS / 3.7-12 Amendment 1,5-r I PPL Rev. 0 Main Condenser Offgas 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 -----------------

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

Not required to be performed until 31 days after any main steam line is not isolated.Verify the radioactivity rate of the specified noble In accordance with the gases is _< 330 mCi/second.

Surveillance Frequency Control Pro ram31-&4...

AND Once within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> after a>_ 50% increase in the nominal steady state fission gas release after factoring out increases due to changes in THERMAL POWER level I SUSQUEHANNA-UNIT 2 TS / 3.7-14 Amendment 154-PPL Rev. 2 Main Turbine Bypass System 3.7.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify one complete cycle of each required main In accordance with the turbine bypass valve. Surveillance Frequency Control Proqram314-da' In accordance with the SR 3.7.6.2 Perform a system functional test. Surveillance Frequency Control Proqram24 menths SR 3.7.6.3 Verify the TURBINE BYPASS SYSTEM In accordance with the Surveillance Frequency Control RESPONSE TIME is within limits. Proqram24r mnthr SUSQUEHANNA

-UNIT 2 TS / 3.7-16 Amendment 1,ýl 1 ý5, 193ý PPL Rev. 0 Spent Fuel Storage Pool Water Level 3.7.7 3.7 PLANT SYSTEMS 3.7.7 Spent Fuel Storage Pool Water Level LCO 3.7.7 The spent fuel storage pool water level shall be > 22 ft over the top of irradiated fuel assemblies seated in the spent fuel storage pool racks.APPLICABILITY:

During movement of irradiated fuel assemblies in the spent fuel storage pool.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Spent fuel storage pool water A.1 ----------

NOTE---------

level not within limit. LCO 3.0.3 is not applicable.

Suspend movement of Immediately irradiated fuel assemblies in the spent fuel storage pool.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1 Verify the spent fuel storage pool water level is In accordance with the_> 22 ft over the top of irradiated fuel assemblies Surveillance Frequency Control seated in the spent fuel storage pool racks. Proqram7-days I SUSQUEHANNA

-UNIT 2 TS / 3.7-17 Amendment 154-PPL Rev. 0 Main Turbine Pressure Regulation System 3.7.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.8.1 Verify that both Main Turbine Pressure Regulators In accordance with the are each capable of controlling main steam Surveillance Frequency pressure.

Control Procqram92-days In accordance with the Surveillance Freqiuency SR 3.7.8.2 Perform a system functional test. Cnrol Frequency Control Program2-4 months SUSQUEHANNA

-UNIT 2 TS 1 3.7-19 Amendment 2-%*-

PPL Rev. 4 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS

---

NOTES-1. Four DGs are required and a DG is only considered OPERABLE when the DG is aligned to the Class 1E distribution system. DG Surveillance Requirements have been modified to integrate the necessary testing to demonstrate the availability of DG E and ensure its OPERABILITY when substituted for any other DG. If the DG Surveillance Requirements, as modified by the associated Notes, are met and performed, DG E can be considered available and OPERABLE when substituted for any other DG after performance of SR 3.8.1.3 and SR 3.8.1.7.2. SR 3.8.1.21 establishes Surveillance Requirements for the Unit 1 AC sources required to support Unit 2.SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated In accordance with the Surveillance Frequency Control power availability for each offsite circuit. Proqram-eilan SR 3.8.1.2 Not Used.(continued)

I SUSQUEHANNA

-UNIT 2 TS___/ 3.8-6 Amendment 1X PPL Rev. 4 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.3 ----------------

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

1. DG loading may include gradual loading as recommended by the manufacturer.

2. Momentary transients outside the load range do not invalidate this test.3. This Surveillance shall be conducted on only one DG at a time.4. This SR shall be preceded by and immediately follow, without shutdown, a successful performance of SR 3.8.1.7.5. DG E, when not aligned to the Class 1 E distribution system, may satisfy this SR using the test facility.6. A single test will satisfy this Surveillance for both units if synchronization is to the 4.16 kV ESS bus for Unit 2 for one periodic test and synchronization is to the 4.16 kV ESS bus for Unit 1 for the next periodic test.However, if it is not possible to perform the test on Unit I or test performance is not required per SR 3.8.2.1, then the test shall be performed synchronized to the 4.16 kV ESS bus for Unit 2.Verify each DG is synchronized and loaded and In accordance with the operates for 60 minutes at a load >_ 3600 kW Surveillance Frequency Control and 4000 kW. Procaram31-dWys (continued)

I SUSQUEHANNA

-UNIT 2 TS / 3.8-7 Amendment W

PPL Rev. 4 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.4 Verify each engine mounted day tank fuel oil In accordance with the level is > 420 gallons for DG A-D and > 425 Surveillance Frequency Control gallons for DG E. Program31-day, SR 3.8.1.5 Check for and remove accumulated water from In accordance with the Surveillance Frequency Control each engine mounted day tank. rra31ds Program31 d~ys SR 3.8.1.6 Verify the fuel oil transfer system operates to In accordance with the automatically transfer fuel oil from the storage Surveillance Frequency Control tanks to each engine mounted tank. Procqram31-das'&

SR 3.8.1.7 ----------------

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

1. All DG starts may be preceded by an engine prelube period.2. A single test at the specified Frequency will satisfy this Surveillance for both units.Verify each DG starts from standby condition In accordance with the and achieves, in < 10 seconds, voltage > 3793 V Surveillance Frequency Control and frequency

> 58.8, and after steady state Proqram31-days conditions are reached, maintains voltage> 3793 V and _< 4400 V and frequency

_> 58.8 Hz and 61.2 Hz.SR 3.8.1.8 ------------------

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

The automatic transfer of unit power supply shall not be performed in MODE 1 or 2.Verify automatic and manual transfer of unit In accordance with the power supply from the normal offsite circuit to the Surveillance Frequency Control alternate offsite circuit. Progqram24 menths (continued)

SUSQUEHANNA

-UNIT 2 TS / 3.8-8 Amendment JW PPL Rev. 4 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.9----------------

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

A single test at the specified Frequency will satisfy this Surveillance for both units.Verify each DG rejects a load greater than or equal to its associated single largest post-accident load, and: a. Following load rejection, the frequency is_ 64.5 Hz;b. Within 4.5 seconds following load rejection, the voltage is _> 3760 V and <_ 4560 V, and after steady state conditions are reached, maintains voltage >_ 3793 V and _ 4400 V;and c. Within 6 seconds following load rejection, the frequency is _> 58.8 Hz and _< 61.2 Hz.In accordance with the Surveillance Freauencv Control Proa ram244RGnthe SR 3.8.1.10 ----------------

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

A single test at the specified Frequency will satisfy this Surveillance for both units.Verify each DG does not trip and voltage is In accordance with the maintained

< 4560 V during and following a load Surveillance Frequency Control rejection of >_ 4000 kW. Proaram24-mReth-(continued)

I SUSQUEHANNA

-UNIT 2 TS / 3.8-9 Amendment 1K PPL Rev. 4 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.11-------------

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

1. All DG starts may be preceded by an engine prelube period.2. This Surveillance shall not be performed in MODE 1,2 or 3.3. This SR shall be performed for each DG on a rotational test basis and for each 4.16 kV ESS bus at the specified FREQUENCY.

Verify on an actual or simulated loss of offsite power signal: a. De-energization of 4.16 kV ESS buses;b. Load shedding from 4.16 kV ESS buses; and c. DG auto-starts from standby condition and: 1. energizes permanently connected loads in _ 10 seconds, 2. energizes auto-connected shutdown loads through individual load timers, 3. maintains steady state voltage>_ 3793 V and< 4400 V, 4. maintains steady state frequency_ 58.8 Hz and < 61.2 Hz, and 5. supplies permanently connected loads for_> 5 minutes.In accordance with the Surveillance Freauencv Control Prograrn24-moi~fth (continued)

I SUSQUEHANNA

-UNIT 2 TS / 3.8-10 Amendment 154-PPL Rev. 4 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.12 ----------------

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

1. All DG starts may be preceded by an engine prelube period.2. DG E, when not aligned to the Class 1E distribution system, may satisfy this SR for both units by performance of SR 3.8.1.12.a, b and c using the test facility to simulate a 4.16 kV ESS bus. SR 3.8.1.12.d and e may be satisfied with either the normally aligned DG or DG E aligned to the Class 1 E distribution system.Verify, on an actual or simulated Emergency In accordance with the Core Cooling System (ECCS) initiation signal, Surveillance Frequency Control each DG auto-starts from standby condition and: Procram24-mGAths

a. In < 10 seconds after auto-start achieves voltage > 3793 V, and after steady state conditions are reached,.

maintains voltage> 3793 V and < 4400 V;b. In < 10 seconds after auto-start achieves frequency

>_ 58.8 Hz, and after steady state conditions are reached, maintains frequency 58.8 Hz and 61.2 Hz;c. Operates for > 5 minutes;d. Permanently connected loads remain energized from the offsite power system; and e. Emergency loads are energized or auto-connected through the individual load timers from the offsite power system.(continued)

I SUSQUEHANNA

-UNIT 2 TS / 3.8-11 Amendment J5T PPL Rev. 4 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.13 ----------------

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

1. A single test at the specified Frequency will satisfy this Surveillance for both units.2. DG E when not aligned to the Class 1 E distribution system may satisfy this SR by using a simulated ECCS initiation signal.Verify each DG's automatic trips are bypassed on In accordance with the actual or simulated loss of voltage signal on the Surveillance Frequency Control 4.16 kV ESS bus concurrent with an actual or Proqram2A4RoRthS simulated ECCS initiation signal except: a. Engine overspeed; and b. Generator differential current; and c. Low lube oil pressure.(continued)

I SUSQUEHANNA

-UNIT 2 TS / 3.8-12 Amendment JRf PPL Rev. 4 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.14 ----------------

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

1. Momentary transients outside the load ranges do not invalidate this test.2. A single test at the specified Frequency will satisfy this Surveillance for both units.3. DG E when not aligned to the Class 1E distribution system may satisfy this SR using the test facility.In accordance with the Surveillance Frequency Control Verify each DG operates for >_ 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />s: SuranceFq yn Program24mnh

a. For > 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> loaded > 4400 kW and< 4700 kW for DGs A through D and> 5000 kW and _< 5500 kW for DG E; and b. For the remaining hours of the test loaded> 3600 kW and < 4000 kW for DGs A through D and _> 4500 kW and < 5000 kW for DG E.(continued)

I SUSQUEHANNA

-UNIT 2 TS / 3.8-13 Amendment JW PPL Rev. 4 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.15 ----------------

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

1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated _> 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> loaded>_ 3800 kW.Momentary transients outside of load range do not invalidate this test.2. All DG starts may be preceded by an engine prelube period.3. A single test at the specified Frequency will satisfy this Surveillance for both units.Verify each DG starts and achieves, in In accordance with the_ 10 seconds, voltage > 3793 V and frequency Surveillance Frequency Control_ 58.8 and after steady state conditions are Prooram24 menths reached, maintains voltage -3793 V and< 4400 V and frequency

> 58.8 Hz and < 61.2 Hz.(continued)

I SUSQUEHANNA

-UNIT 2 TS / 3.8-14 Amendment:ý81 PPL Rev. 4 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.16 ----------------

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

This SR shall be performed for each DG on a rotational basis and for each 4.16 kV ESS bus at the specified FREQUENCY.

Verify each DG: In accordance with the Surveillance Frequency Control Program24 menths a. Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power;b. Transfers loads to offsite power source; and c. Returns to ready-to-load operation.(continued)

I SUSQUEHANNA

-UNIT 2 TS / 3.8-15 Amendment W

PPL Rev. 4 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.17----------------

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

This SR shall be performed for each DG on a rotational basis and for each 4.16 kV ESS bus at the specified FREQUENCY.

Verify with a DG operating in test mode and connected to its bus, an actual or simulated ECCS initiation signal overrides the test mode by: a. Returning DG to ready-to-load operation; and b. Automatically energizing the emergency load from offsite power.In accordance with the Surveillance Frequency Control Proqram24 menthe SR 3.8.1.18 -----------------

NOTE-- ---------Load timers associated with equipment that has automatic initiation capability disabled are not required to be OPERABLE.In accordance with the Verify each sequenced load is within required Surveillance Freiuency Control limits of the design interval.

ProS ram2-a-me t-nhs (continued)

I SUSQUEHANNA

-UNIT 2 TS / 3.8-16 Amendment

ý&T PPL Rev. 4 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.19-------------

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

1. All DG starts may be preceded by an engine prelube period.2. This SR shall be performed for each DG on a rotational test basis and for each 4.16 kV ESS bus at the specified FREQUENCY.

3. This Surveillance shall not be performed in MODE 1,2 or 3.Verify on an actual or simulated loss of offsite power signal in conjunction with an actual or simulated ECCS initiation signal: a. De-energization of 4.16 kV ESS buses;b. Load shedding from emergency buses; and c. DG auto-starts from standby condition and: 1. energizes permanently connected loads in < 10 seconds, 2. energizes auto-connected emergency loads through individual load timers, 3. achieves steady state voltage > 3793 V and 4400 V, 4. achieves steady state frequency58.8 Hz and< 61.2 Hz, and 5. supplies permanently connected and auto-connected emergency loads for_> 5 minutes.In accordance with the Surveillance Freauencv Control Programf2A-minnihm (continued)

I SUSQUEHANNA

-UNIT 2 TS / 3.8-17 Amendment 154' PPL Rev. 4 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.20---------------

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

1. All DG starts may be preceded by an engine prelube period.2. This SR must be met, but does not have to be performed with DG E substituted for any DG.Verify, when started simultaneously from standby condition, each DG achieves, in _< 10 seconds, voltage >_ 3793 V and frequency

>_ 58.8 and after steady state conditions are reached, maintains voltage >_ 3793 V and _< 4400 V and frequency> 58.8 Hz and 61.2 Hz.In accordance with the Surveillance Frequency Control Proqram4g-yea-s SR 3.8.1.21------------

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

When Unit 1 is in MODE 4 or 5, or moving irradiated fuel assemblies in the secondary containment, the Note to Unit 1 SR 3.8.2.1 is applicable.

For required Unit 1 AC sources, the following SRs of Unit 1 Specification 3.8.1 are applicable:

In accordance with applicable SRs SR 3.8.1.1;SR 3.8.1.3;SR 3.8.1.4;SR 3.8.1.5;SR 3.8.1.6;SR 3.8.1.7;SR 3.8.1.9;SR 3.8.1.10;SR 3.8. 1.11;SR 3.8.1.14;SR 3.8.1.15;SR 3.8.1.16;SR 3.8.1.18;SR 3.8.1.19;and SR 3.8.1.8 (when more than one Unit 1 offsite circuit is required)I SUSQUEHANNA

-UNIT 2 TS / 3.8-18 Amendment j5lt PPL Rev. G Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify each fuel oil storage tank contains In accordance with the> 47,570 gallons for DG A-D; Surveillance Frequency Control> 60,480 gallons for DG E. Program3.-day.

SR 3.8.3.2 Verify lube oil sump level is visible in the sight In accordance with the glass. Surveillance Frequency Control Proqram34-4ay".

SR 3.8.3.3 Verify fuel oil properties of new and stored fuel oil In accordance with the are tested in accordance with, and maintained Diesel Fuel Oil Testing within the limits of, the Diesel Fuel Oil Testing Program Program.SR 3.8.3.4 ------------------

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

Not required to be met when DG is operating.

Verify each DG air start receiver pressure is In accordance with the> 240 psig. Surveillance Frequency Control Program34-days SR 3.8.3.5 Check for and remove accumulated water from In accordance with the each fuel oil storage tank. Proran y Control eachfueloilstorge tnk.Program3-11--day SUSQUEHANNA

-UNIT 2 TS 1 3.8-25 Amendment TV, 1,5ý'

PPL Rev. 3 DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS S U RVEI LLANCE FREQUENCY SR 3.8.4.1 Verify battery terminal voltage is greater than or In accordance with the equal to the minimum established float voltage. Surveillance Frequency Control Program7-days SR 3.8.4.2 Verify each required battery charger supplies its In accordance with the associated battery at the following rates for > 4 Surveillance Frequency Control hours at greater than or equal to the minimum Proqram24 months established float voltages: a) > 100 amps for the 125V Battery b) > 300 amps for the 250V Battery c) 200 amps for the125V Diesel Generator E Battery (continued)

SUSQUEHANNA

-UNIT 2 TS / 3.8-28 Amendment 1.51, 21-2, 2?A3 PPL Rev. 3 DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY i SR 3.8.4.3-NOTES --------------------------

1. The modified performance discharge test in SR 3.8.6.6 may be performed in lieu of SR 3.8.4.3.2. This Surveillance shall not be Performed in Mode 1, 2 or 3 except for the Diesel Generator E DC electrical power subsystem.

This Surveillance can be performed on the Diesel Generator E DC electrical power subsystem when the Diesel Generator E is not aligned to the Class 1 E distribution system. However, credit may be taken for unplanned events that satisfy this SR.Verify battery capacity is adequate to supply, and maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test.In accordance with the Surveillance Frequency Control Proqram24-mnnths SR 3.8.4.4-------------

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

When Unit 1 is in MODE 4 or 5, or moving irradiated fuel assemblies in the secondary containment, the Note to Unit 1 SR 3.8.5.1 is applicable.

For required Unit 1 DC electrical power subsystems, the SRs for Unit 1 Specification 3.8.4 are applicable.

In accordance with applicable SRs SUSQUEHANNA

-UNIT 2 TS / 3.8-29 Amendment 1,51, 2,W, 2,16 PPL Rev. 4 Battery Parameters 3.8.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1---------------

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

Not required to be met when battery terminal voltage is less than the minimum established float voltage of SR 3.8.4.1.Verify..each..batte....float.current..is....2.amps...............

Verify each battery float current is _<ý 2 amps.In accordance with the Surveillance Frequency Control Proqram-7-day SR 3.8.6.2 Verify each battery pilot cell voltage is -2.07 V. In accordance with the Surveillance Frequency Control Proaram3-1lda-SR 3.8.6.3 Verify each battery connected cell electrolyte In accordance with the level is greater than or equal to minimum Surveillance Frequency Control established design limits. Proram3.4-days SR 3.8.6.4 Verify each battery pilot cell temperature is In accordance with the greater than or equal to minimum established Surveillance Frequency Control design limits. Prooram3 .-days (continued)

SUSQUEHANNA

-UNIT 2 TS / 3.8-42 Amendment 15yl, Z4-a PPL Rev. 4 Battery Parameters 3.8.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.6.5 Verify each battery connected cell voltage is In accordance with the2.07 V. Surveillance Freauency Control Proqram42--ays SR 3.8.6.6-------------

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

This Surveillance shall not be Performed in Mode 1, 2, or 3. However, credit may be taken for unplanned events that satisfy this SR.Verify battery capacity is _ 80% of the manufacturer's rating when subjected to a performance discharge test or a modified performance discharge test.In accordance with the Surveillance Freauencv Control Proraram60 menths AND 12 months when battery shows degradation or has reached 85% of expected service life with capacity< 100% of manufacturer's rating AND 24 months when battery has reached 85% of the expected service life with capacity >_ 100% of manufacturer's rating SUSQUEHANNA

-UNIT 2 TS / 3.8-43 Amendment t5l,2,1-5 PPL Rev. 4 Distribution Systems-Operating 3.8.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct breaker alignments and voltage or In accordance with the indicated power availability to required AC and Surveillance Frequency DC electrical power distribution subsystems.

Control Proqram7-days I SUSQUEHANNA

-UNIT 2 TS / 3.8-47 Amendment 154ý PPL Rev. 0 Distribution Systems--Shutdown 3.8.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Diesel Generator E DC B.1 Verify that all ESW valves 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> electrical power distribution associated with Diesel subsystem inoperable, while Generator E are closed.not aligned to the Class I E distribution system.C. Diesel Generator E DC C.1 Declare Diesel Generator E 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> electrical power distribution inoperable.

subsystem inoperable, while aligned to the Class 1 E distribution system.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY In accordance with the SR 3.8.8.1 Verify correct breaker alignments and voltage or Surv ance Freque indicated power availability to required AC and Cnrol Frequency DC electrical power distribution subsystems.

I SUSQUEHANNA

-UNIT 2 TS / 3.8-53 Amendment I.&T PPL Rev. 0 Refueling Equipment Interlocks 3.9.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Perform CHANNEL FUNCTIONAL TEST on each In accordance with the of the following required refueling equipment Surveillance Frequency interlock inputs: Control Progcram-days a. All-rods-in, b. Refuel platform position, c. Refuel platform fuel grapple, fuel loaded, d. Refuel platform frame mounted hoist, fuel loaded, e. Refuel platform monorail mounted hoist, fuel loaded.I SUSQUEHANNA-UNIT 2 TS / 3.9-2 Amendment 1,W PPL Rev. 0 Refuel Position One-Rod-Out Interlock 3.9.2 3.9 REFUELING OPERATIONS 3.9.2 Refuel Position One-Rod-Out Interlock LCO 3.9.2 The refuel position one-rod-out interlock shall be OPERABLE.APPLICABILITY:

MODE 5 with the reactor mode switch in the refuel position and any control rod withdrawn.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refuel position one-rod-out A.1 Suspend control rod withdrawal.

Immediately interlock inoperable.

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

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Verify reactor mode switch locked in Refuel In accordance with the position.

Surveillance Frequency Control Proqram12 hFiu, (continued)

I SUSQUEHANNA

-UNIT 2 TS / 3.9-3 Amendment 154ý'

PPL Rev. 0 Refuel Position One-Rod-Out Interlock 3.9.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.9.2.2 ------------------

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

Not required to be performed until 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after any control rod is withdrawn.

Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Proqram7-day I SUSQUEHANNA

-UNIT 2 TS / 3.9-4 Amendment jW PPL Rev. 0 Control Rod Position 3.9.3 3.9 REFUELING OPERATIONS 3.9.3 Control Rod Position LCO 3.9.3 All control rods shall be fully inserted.APPLICABILITY:

When loading fuel assemblies into the core.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more control rods not A.1 Suspend loading fuel Immediately fully inserted, assemblies into the core.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Verify all control rods are fully inserted.

In accordance with the Surveillance Frequency Control Proqram12 heurs I SUSQUEHANNA-UNIT 2 TS_._/ 3. 9-5 Amendment 1,&t PPL Rev. 0 Control Rod OPERABILITY-Refueling 3.9.5 3.9 REFUELING OPERATIONS 3.9.5 Control Rod OPERABILITY-Refueling LCO 3.9.5 Each withdrawn control rod shall be OPERABLE.APPLICABILITY:

MODE 5.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more withdrawn A.1 Initiate action to fully insert Immediately control rods inoperable, inoperable withdrawn control rods.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 ------------------

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

Not required to be performed until 7 days after the control rod is withdrawn.

Insert each withdrawn control rod at least one In accordance with the notch. Surveillance Frequency Control Proqram7-day-s SR 3.9.5.2 Verify each withdrawn control rod scram In accordance with the accumulator pressure is > 940 psig. Surveillance Frequency Control ProqramT-days I SUSQUEHANNA

-UNIT 2 TS / 3.9-8 Am e n d m e nt J-9-4,-

I PPL Rev. 0 RPV Water Level 3.9.6 3.9 REFUELING OPERATIONS 3.9.6 Reactor Pressure Vessel (RPV) Water Level LCO 3.9.6 RPV water level shall be _> 22 ft above the top of the RPV flange.APPLICABILITY:

During movement of irradiated fuel assemblies within the RPV, During movement of new or irradiated fuel assemblies or handling of control rods within the RPV, when irradiated fuel assemblies are seated within the RPV.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RPV water level not within A.1 Suspend movement of fuel Immediately limit. assemblies and handling of control rods within the RPV.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify RPV water level is >_ 22 ft above the top of In accordance with the the RPV flange. Surveillance Frequency Control Program24 heu~s SUSQUEHANNA

-UNIT 2 TS / 3.9-9 Amendment

ý&f PPL Rev. 0 RHR-High Water Level 3.9.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify one RHR shutdown cooling subsystem is In accordance with the operating.

Surveillance Frequency Control Proqram!2-heurs I SUSQUEHANNA

-UNIT 2 TS /13.9-12 Amendment 1!.5*

PPL Rev. 0 RHR-Low Water Level 3.9.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.8.1 Verify one RHR shutdown cooling subsystem is In accordance with the operating.

Surveillance Frequency Control Proqram!2 -heu I SUSQUEHANNA

-UNIT 2 TS / 3.9-15 Amendment 1,5+

PPL Rev. 0 Reactor Mode Switch Interlock Testing 3.10.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)

A.3.1 Place the reactor mode 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> switch in the shutdown position.OR A.3.2 -------NOTE ------Only applicable in MODE 5 Place the reactor mode 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> switch in the refuel position.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.2.1 Verify all control rods are fully inserted in core cells containing one or more fuel assemblies.

In accordance with the Surveillance Frequency I SUSQUEHANNA

-UNIT 2 TS__/ 3.10-5 Amendment 1W PPL Rev. 0 Single Control Rod Withdrawal

-Hot Shutdown 3.10.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.3.1 Perform the applicable SRs for the required LCOs. According to the applicable SRs SR 3.10.3.2 ----------------

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

Not required to be met if SR 3.10.3.1 is satisfied for LCO 3.10.3.d.1 requirements.

Verify all control rods, other than the control rod In accordance with the being withdrawn, in a five by five array centered Surveillance Frequency on the control rod being withdrawn, are disarmed.

Control Proqram24 heurf SR 3.10.3.3 Verify all control rods other than the control rod In accordance with the being withdrawn, are fully inserted.

Surveillance Frequency Control Program2.4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> I SUSQUEHANNA

-UNIT 2 TS / 3.10-8 Amendment.W PPL Rev. 0 Single Control Rod Withdrawal

-Cold Shutdown 3.10.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more of the above B.1 Suspend withdrawal of Immediately requirements not met with the control rod and the affected control rod not removal of associated insertable.

CRD.AND B.2.1 Initiate action to fully Immediately insert all control rods.OR B.2.2 Initiate action to satisfy Immediately the requirements of this LCO.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.4.1 Perform the applicable SRs for the required LCOs. According to the applicable SRs SR 3.10.4.2 ----------------

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

Not required to be met if SR 3.10.4.1 is satisfied for LCO 3.10.4.c.

1 requirements.

Verify all control rods, other than the control rod In accordance with the being withdrawn, in a five by five array centered Surveillance Frequency on the control rod being withdrawn, are Control Proqram24-heu-s disarmed.(continued)

I SUSQUEHANNA

-UNIT 2 TS__/ 3.10-11 Amendment 1&f PPL Rev. 0 Single Control Rod Withdrawal

-Cold Shutdown 3.10.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.10.4.3 Verify all control rods, other than the control rod In accordance with the being withdrawn, are fully inserted.

Surveillance Frequency Control Program24-heGuF SR 3.10.4.4 -----------------

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

Not required to be met if SR 3.10.4.1 is satisfied for LCO 3.10.4.b.1 requirements.

Verify a control rod withdrawal block is inserted.

In accordance with the Surveillance Frequency Control Proqram24-heur-I SUSQUEHANNA

-UNIT 2 TS / 3.10-12 Amendment 154-PPL Rev. 0 Single CRD Removal -Refueling 3.10.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)

A.2.1 Initiate action to fully Immediately insert all control rods.OR A.2.2 Initiate action to satisfy Immediately the requirements of this LCO.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.5.1 Verify all control rods, other than the control rod In accordance with the withdrawn for the removal of the associated CRD, Surveillance Frequency are fully inserted.

Control Proqram24-ho'Jr SR 3.10.5.2 Verify all control rods, other than the control rod In accordance with the withdrawn for the removal of the associated CRD, Surveillance Frequency in a five by five array centered on the control rod Control Proqram24 hours withdrawn for the removal of the associated CRD, are disarmed.SR 3.10.5.3 Verify a control rod withdrawal block is inserted.

In accordance with the Surveillance Frequency Control Procqram24 heurs SR 3.10.5.4 Perform SR 3.1.1.1. According to SR 3.1.1.1 (continued)

I SUSQUEHANNA

-UNIT 2 TS / 3.10-14 Amendment JZ PPL Rev. 0 Single CRD Removal -Refueling 3.10.5 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.10.5.5 Verify no CORE ALTERATIONS are in progress.

In accordance with the Surveillance Frequency Control Proq ram24-heuws I SUSQUEHANNA

-UNIT 2 TS / 3.10-15 Amendment I-M' PPL Rev. 0 Multiple Control Rod Withdrawal

-Refueling 3.10.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)

A.3.1 Initiate action to fully Immediately insert all control rods in core cells containing one or more fuel assemblies.

OR A.3.2 Initiate action to satisfy Immediately the requirements of this LCO.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.6.1 Verify the four fuel assemblies are removed from In accordance with the core cells associated with each control rod or Surveillance Frequency CRD removed. Control Proqram24-heurs SR 3.10.6.2 Verify all other control rods in core cells containing In accordance with the one or more fuel assemblies are fully inserted.

Surveillance Frequency Control Procqram24 heum SR 3.10.6.3 -----------------

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

Only required to be met during fuel loading.Verify fuel assemblies being loaded are in In accordance with the compliance with an approved reload sequence.

Surveillance Frequency Control Procqram24-heu-s I SUSQUEHANNA

-UNIT 2 TS / 3.10-17 Amendment 1-51 PPL Rev. 2 SDM Test -Refueling 3.10.8 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.10.8.2 ----------------

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

Not required to be met if SR 3.10.8.3 satisfied.

Perform the MODE 2 applicable SRs for LCO According to the applicable 3.3.2.1, Function 2 of Table 3.3.2.1-1.

SRs SR 3.10.8.3 ----------------

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

Not required to be met if SR 3.10.8.2 satisfied.

Verify movement of control rods is in compliance During control rod movement with the approved control rod sequence for the SDM test by a second licensed operator or other qualified member of the technical staff.SR 3.10.8.4 Verify no other CORE ALTERATIONS are in In accordance with the progress.

Surveillance Frequency Control Program42 haurs (continued)

I SUSQUEHANNA

-UNIT 2 TS / 3.10-22 Amendment 154' PPL Rev. 2-SDM Test -Refueling 3.10.8 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.10.8.5 Verify each withdrawn control rod does not go to the withdrawn overtravel position.Each time the control rod is withdrawn to "full out" position AND Prior to satisfying LCO 3.10.8.c requirement after work on control rod or CRD System that could affect coupling SR 3.10.8.6 Verify CRD charging water header pressure940 psig.In accordance with the Surveillance Frequency Control Proqram7 days I SUSQUEHANNA

-UNIT 2 TS / 3.10-23 Amendment 11W PPL Rev. 6 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.14 Control Room Envelope Habitability Program (continued)

e. The quantitative limits on unfiltered air inleakage into the CRE. These limits shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph

c. The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of DBA consequences.

Unfiltered air inleakage limits for hazardous chemicals must ensure that exposure of CRE occupants to these hazards will be within the assumptions in the licensing basis.f. The provisions of SR 3.0.2 are applicable to the Frequencies for assessing CRE habitability, determining CRE unfiltered inleakage, and measuring CRE pressure and assessing the CRE boundary as required by paragraphs c and d, respectively.

K.5.15 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 Limitinq 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.SUSQUEHANNA-UNIT2 TS / 5.0-1 8C Amendment 2W Attachment 4 to PLA-7119 Markups of Existing Technical Specifications Bases PPL Rev. 2 Control Rod OPERABILITY B 3.1.3 BASES SURVEILLANCE REQUIREMENTS SR 3.1.3.1 (continued) determined by the use of OPERABLE position indicators, by moving control rods to a position with an OPERABLE indicator, or by the use of other appropriate methods. The 24 heou Fr.equencay of this SR i6 basod on operating cxperience related to changes in rod positioe and the availability of contFel rod pesition indications in tho contrOl room.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.SR 3.1.3.2 NOT USED SR 3.1.3.3 Control rod insertion capability is demonstrated by inserting each partially or fully withdrawn control rod at least one notch and observing that the control rod moves. The control rod may then be returned to its original position.This ensures the control rod is not stuck and is free to insert on a scram signal. These Surveillances are not required when THERMAL POWER is less than or equal to the actual LPSP of the RWM, since the notch insertions may not be compatible with the requirements of the Banked Position Withdrawal Sequence (BPWS) (LCO 3.1.6) and the RWM (LCO 3.3.2.1).The Surveillance Frequency is controlled under the Surveillance Frequency Control Pro-gram.The 7 day Frequency of SR 3.1.3.2 is based on ep,,atig expeniencn relatcd to the changes in GRP perfoFrance and the ease of performning notch testing for fully withdrawn conrol rods. Partially withdran reductio required to allow the con~trol rod moevement and considering the large testing sample of SR 3.1.3.2. Furthermore~

tThe 31 day FrFequency takes into accoun~t operating experience related to changes, in; CRD pe&Fomance.

At any time, if a control rod is immovable, a determnination o7!f that conrol1 rod's ability to trip (OPERA.BILITY) must be made and aooroori;tP

action ta;kn.SR 3.1.3.4 Verifying that the scram time for each control rod to notch position 05 is_< 7 seconds provides reasonable assurance that the control rod will insert when required during a DBA or transient, thereby completing its shutdown function.

This SR is performed in conjunction with the control rod scram time testing of SR 3.1.4.1, SR 3.1.4.2, SR 3.1.4.3, and SR 3.1.4.4. The LOGIC SYSTEM FUNCTIONAL TEST in (continued)

SUSQUEHANNA

-UNIT 1 TS / B 3.1-20 Revision I$

PPL Rev. 4 Control Rod Scram Times B 3.1.4 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.1.4.2 Additional testing of a sample of control rods is required to verify the continued performance of the scram function during the cycle. A representative sample contains at least 10% of the control rods. The sample remains representative if no more than 7.5% of the control rods in the sample tested are determined to be "slow." With more than 7.5% of the sample declared to be "slow" per the criteria in Table 3.1.4-1, additional control rods are tested until this 7.5% criterion (e.g., 7.5% of the entire sample size) is satisfied, or until the total number of "slow" control rods (throughout the core, from all surveillances) exceeds the LCO limit. For planned testing, the control rods selected for the sample should be different for each test. Data from inadvertent scrams should be used whenever possible to avoid unnecessary testing at power, even if the control rods with data may have been previously tested in a sample. The 200 day Frequeney is based en operating experience that has shOWn control rod scr.Am timee Wdo roasonable based on th-e -add-itionpa!

2Surveillanc~es done on the CRIDS at moree frequent interjals in accordance wioth L CO 313 2nd LCO 3.1.5, "Control Red Scram Accumulatore.'The Surveillance Frequency is controlled under the Surveillance Frequency Control Proqram.SR 3.1.4.3 When work that could affect the scram insertion time is performed on a control rod or the CRD System, testing must be done to demonstrate that each affected control rod retains adequate scram performance over the range of applicable reactor pressures from zero to the maximum permissible pressure.

The scram testing must be performed once before declaring the control rod OPERABLE.

The required scram time testing must demonstrate the affected control rod is still within acceptable limits.The limits for reactor pressures

< 800 psig are established based on a high probability of meeting the acceptance criteria at reactor pressures

_> 800 psig. Limits for > 800 psig are found in Table 3.1.4-1. If testing demonstrates the affected control rod does not meet these limits, but is within the 7-second limit of Table 3.1.4-1, Note 2, the control rod can be declared OPERABLE and "slow." (continued)

I SUSQUEHANNA

-UNIT I TS / B 3.1-26 Revision 4-PPL Rev. 4-Control Rod Scram Accumulators B 3.1.5 BASES ACTIONS D..1 (continued) the inoperable scram accumulators are fully inserted, since the function of the control rods has been performed.

SURVEILLANCE SR 3.1.5.1 REQUIREMENTS SR 3.1.5.1 requires that the accumulator nitrogen pressure be checkeddaysperiodically to ensure adequate accumulator pressure exists to provide sufficient scram force. The primary indicator of accumulator OPERABILITY is the accumulator nitrogen pressure.

A minimum accumulator nitrogen pressure is specified, below which the capability of the accumulator to perform its intended function becomes degraded and the accumulator is considered inoperable.

The minimum accumulator nitrogen pressure of 940 psig is well below the expected pressure of approximately 1100 psig (Ref. 1). Declaring the accumulator inoperable when the minimum pressure is not maintained ensures that significant degradation in scram times does not occur. The Surveillance Frequency is controlled under the Surveillance Frequency Control Proqram.The 7 day Fr4equeRcy has been shown to be acceptable through operating opincand takernt accoun;t indmcationsr available in the conithro!rom REFERENCES

1. FSAR, Section 4.3.2.2. FSAR, Section 4.6.3. FSAR, Section 15.4. Final Policy Statement on Technical Specifications Improvements.

July 22, 1993 (58 FR 39132).I SUSQUEHANNA

-UNIT 1 TS / B 3.1-33 Revision 0 PPL Rev. 2 Rod Pattern Control B 3.1.6 BASES ACTIONS B.1 and B.2 (continued) of a CRDA occurring with the control rods out of sequence.SURVEILLANCE SR 3.1.6.1 REQUIREMENTS The control rod pattern is periodically verified to be in compliance with the BPWS at a 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Frequency to ensure the assumptions of the CRDA analyses are met. The Surveillance Frequency is controlled under the Surveillance Frequency Control Pro-qram.Thhe 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> F=roquency Wa.developed coesiderinq that the primary chock On complianco with the BPIAS5 s p,.0,r..d by the RWM (LCO 3.3.2-1), The RWM Whieprovides control rod blocks to enforce the required sequence and is required to be OPERABLE when operating at _ 10% RTP.REFERENCES

1. XN-NF-80-19(P)(A)

Volume 1 and Supplements I and 2, "Exxon Nuclear Methodology for Boiling Water Reactors," Exxon Nuclear Company, March 1983.2. "Modifications to the Requirements for Control Rod Drop Accident Mitigating System," BWR Owners Group, July 1986.3. NUREG-0979, Section 4.2.1.3.2, April 1983.4. NUREG-0800, Section 15.4.9, Revision 2, July 1981.5. 10 CFR 100.11.6. NEDO-21778-A, "Transient Pressure Rises Affected Fracture Toughness Requirements for Boiling Water Reactors," December 1978.7. ASME, Boiler and Pressure Vessel Code.8. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).9. NEDO 33091-A, Revision 2, "Improved BPWS Control Rod Insertion Process," April 2003.I SUSQUEHANNA-UNIT 1 TS / B 3.1-38 Revision 2 PPL Rev. 3 SLC System B 3.1.7 BASES ACTIONS D._1 (continued)

If any Required Action and associated Completion Time is not met, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to MODE 3 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and MODE 4 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE SR 3.1.7.1, SR 3.1.7.2, and SR 3.1.7.3 REQUIREMENTS SR 3.1.7.1 through SR 3.1.7.3 are 24 hou-r S'ueillances verifyieq certain characteristics of the SLC System (e.g., the volume and temperature of the borated solution in the storage tank), thereby ensuring SLC System OPERABILITY without disturbing normal plant operation.

These Surveillances ensure that the proper borated solution volume and temperature, including the temperature of the pump suction piping, are maintained.

Maintaining a minimum specified borated solution temperature is important in ensuring that the sodium pentaborate remains in solution and does not precipitate out in the storage tank or in the pump suction piping.The temperature versus concentration curve of Figure 3.1.7-2 ensures that a 10°F margin will be maintained above the saturation temperature.

An alternate method of performing SR 3.1.7.3 is to verify the OPERABILITY of the SLC heat trace system. This verifies the continuity of the heat trace lines and ensures proper heat trace operation, which ensure that the SLC suction piping temperature is maintained.

The Surveillance Frequency is controlled under the Surveillance Frequency Control Proqram.The 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Frequen. Y iS based on operating experienne and ha ho-..n therc are relatively

' l'variations in the m~easured par-ameter-s of vollume and tcmfpcrature.

SR 3.1.7.4 and SR 3.1.7.6 SR 3.1.7.4 verifies the continuity of the explosivecharges in the injection valves to ensure that proper operation will occur if required.

Other administrative controls, such as those that limit the shelf life of the explosive charges, must be followed.

The Surveillance Frequency is controlled under the Surveillance Frequency Control Proqram.The 31 day Fr.equency is based o, (continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.1-43 Revision 4-PPL Rev. 3 SLC System B 3.1.7 BASES SURVEILLANCE SURVEQIR NENS SR 3.1.7.4 and SR 3.1.7.6 (continued)

REQUIREMENTS operating exprec nd has demonstrated the reliability of the explosive SR 3.1.7.6 verifies that each valve in the system is in its correct position, but does not apply to the squib (i.e., explosive) valves. Verifying the correct alignment for manual and power operated valves in the SLC System flow path provides assurance that the proper flow paths will exist for system operation.

A valve is also allowed to be in the nonaccident position provided it can be aligned to the accident position from the control room, or locally by a dedicated operator at the valve control. This is acceptable since the SLC System is a manually initiated system. This Surveillance also does not apply to valves that are locked, sealed, or otherwise secured in position since they are verified to be in the correct position prior to locking, sealing, or securing.This verification of valve alignment does not require any testing or valve manipulation; rather, it involves verification that those valves capable of being mispositioned are in the correct position.

This SR does not apply to valves that cannot be inadvertently misaligned, such as check valves. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.The 31 day Froquency is ba.sed on engineerig

udgment and is con~sistent with the procedural controls governing valve operation that oncuroc correct valve positions.

SR 3.1.7.5 This Surveillance requires an examination of the sodium pentaborate solution by using chemical analysis to ensure that the proper concentration of sodium pentaborate exists in the storage tank. SR 3.1.7.5 must be performed anytime sodium pentaborate or water is added to the storage tank solution to determine that the sodium pentaborate solution concentration is within the specified limits. SR 3.1.7.5 must also be performed anytime the temperature is restored to within the limits of Figure 3.1.7-2, to ensure that no significant sodium pentaborate precipitation occurred.

The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.The 31 day Of this Surveillance is appropriate because of the relatively sloW variation of sodium pentaborate cOnccntratien be~een sunveilla(ced.(continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.1-44 Revision 0 PPL Rev. 3 SLC System B 3.1.7 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.1.7.7 Demonstrating that each SLC System pump develops a flow rate _ 40.0 gpm at a discharge pressure >_ 1250 psig without actuating the pump's relief valve ensures that pump performance has not degraded during the fuel cycle. Testing at 1250 psig assures that the functional capability of the SLC system meets the ATWS Rule (10 CFR 50.62) (Ref. 1) requirements.

This minimum pump flow rate requirement ensures that, when combined with the sodium pentaborate solution concentration requirements, the rate of negative reactivity insertion from the SLC System will adequately compensate for the positive reactivity effects encountered during power reduction, cooldown of the moderator, and xenon decay. Additionally, the minimum pump flow rate requirement ensures that adequate buffering agent will reach the suppression pool to maintain pH above 7.0. This test confirms one point on the pump design curve and is indicative of overall performance.

Such inservice inspections confirm component OPERABILITY, trend performance, and detect incipient failures by indicating abnormal performance.

The Frequency of this Surveillance is in accordance with the Inservice Testing Program.SR 3.1.7.8 and SR 3.1.7.9 These Surveillances ensure that there is a functioning flow path from the boron solution storage tank to the RPV, including the firing of an explosive valve. The replacement charge for the explosive valve shall be from the same manufactured batch as the one fired or from another batch that has been certified by having one of that batch successfully fired. The pump and ,xplsive valv.e tested should be alternated such that both complete flow paths arc testd eve.. 48 meonths at altema-.ng 24 month intervals.

The Surveillance may be performed in separate steps to prevent injecting solution into the RPV. An acceptable method for verifying flow from the pump to the RPV is to pump demineralized water from a test tank through one SLC subsystem and into the RPV. The Surveillance Frequency is controlled under the Surveillance Frequency Control Proqram.Thc 24 month FrequenGy is based on the need to perform this Sutvhitllanc under the renditions that apply during a plant outage and the potential for an unplanned transient if the iurjeitlanne were performed Pihrerao t oe.Oean exprince has shown these components usually pass the Sum~illancc v~en pecfeffed at the 24 month Frequency; therefore, the Fmrequency was cone! luded to be acceptable from a reliabilip.y standpoint Demonstrating that all heat traced piping between the boron solution storage tank and the suction inlet to the injection (continued)

I SUSQUEHANNA-UNIT 1 TS / B 3.1-45 Revision 3 PPL Rev. 3 SLC System B 3.1.7 BASES SURVEILLANCE SR 3.1.7.8 and SR 3.1.7.9 (continued)

REQUIREMENTS pumps is unblocked ensures that there is a functioning flow path for injecting the sodium pentaborate solution.

An acceptable method for verifying that the suction piping is unblocked is to pump from the storage tank to the test tank. This test can be performed by any series of overlapping or total flow path test so that the entire flow path is included.The Surveillance Frequency is controlled under the Surveillance Frequency Control Proqram.Th' 21 month Frequency is ac-eptable , ince there i. ac a low probabili ty that the subject piping w.~.ill bep bokdwde to precipitation-.

o-f thie boron fro.. olution in the heat trced piping. This is especially true in light of the temperature verification of this piping required by SR 3.1.7.3.However, if, in performing SR 3.1.7.3, it is determined that the temperature of this piping has fallen below the specified minimum or the heat trace was not properly energized and building temperature was below the temperature at which the SLC solution would precipitate out, SR 3.1.7.9 must be performed once within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after the piping temperature is restored to within the limits of Figure 3.1.7-2.SR 3.1.7.10 Enriched sodium pentaborate solution is made by mixing granular, enriched sodium pentaborate with water. Verification of the actual B-1 0 enrichment must be performed prior to addition to the SLC tank in order to ensure that the proper B-10 atom percentage is being used. This verification may be based on independent isotopic analysis or a manufacturer certificate of compliance.

REFERENCES

1. 10 CFR 50.62.2. FSAR, Section 9.3.5.3. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).SUSQUEHANNA

-UNIT 1 TS / B 3.1-46 Revision 4-1 PPL Rev. 3 SDV Vent and Drain Valves B 3.1.8 BASES ACTIONS C.1 (continued) does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. The allowed Completion Time of 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> is reasonable, based on operating experience, to reach MODE 3 from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS SR 3.1.8.1 During normal operation, the SDV vent and drain valves should be in the open position (except when performing SR 3.1.8.2) to allow for drainage of the SDV piping. Verifying that each valve is in the open position ensures that the SDV vent and drain valves will perform their intended functions during normal operation.

This SR does not require any testing or valve manipulation; rather, it involves verification that the valves are in the correct position.The Surveillance Frequency is controlled under the Surveillance Frequency Control Proqram.The 31 day is based on engineering judgment and is consictont with the proced-ural coentreel-goonn alve operation, which ens-ure correct valvo positions.

SR 3.1.8.2 During a scram, the SDV vent and drain valves should close to contain the reactor water discharged to the SDV piping. Cycling each valve through its complete range of motion (closed and open) ensures that the valve will function properly during a scram. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.The 92 day Fr=equenc.y is based on eperating oxperience and takes into account the level Of redundancy in the ssen; design-.SR 3.1.8.3 SR 3.1.8.3 is an integrated test of the SDV vent and drain valves to verify total system performance.

After receipt of a simulated or actual scram signal, the closure of the SDV vent and drain valves is verified.The closure time of (continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.1-50 Revision 0 PPL Rev. 3 SDV Vent and Drain Valves B 3.1.8 BASES SURVEILLANCE REQUIREMENTS SR 3.1.8.3 (continued) 30 seconds after receipt of a scram signal is based on the bounding leakage case evaluated in the accident analysis based on the requirements of Reference

2. Similarly, after receipt of a simulated or actual scram reset signal, the opening of the SDV vent and drain valves is verified.

The LOGIC SYSTEM FUNCTIONAL TEST in LCO 3.3.1.1 and the scram time testing of control rods in LCO 3.1.3 overlap this Surveillance to provide complete testing of the assumed safety function.

The Surveillance Frequency is controlled under the Surveillance Frequency Control Proqram.The 21 month Frequenc.

is based on the need to perform portion1 of this Sureillanee under the conitinsthat apply during a plant outage and the potential for an unp!anned transie.t if the Su..eillance were pe.formed with the at power Opeating experience hae, shown these components usually pace the Sur'oillanco when peformed at the 21 month F=requency; therefore, the Frequency was conc.mluded to be acceptable from a reliability standpoint.

REFERENCES

1. FSAR, Section 4.6.2. 10 CFR 50.67 3. NUREG-0803, "Generic Safety Evaluation Report Regarding Integrity of BWR Scram System Piping," August 1981.4. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).5. TSTF-404-A, Rev. 0.I SUSQUEHANNA-UNIT 1 TS / B 3.1-51 Revision 3, PPL Rev. 2 APLHGR B 3.2.1 BASES I ACTIONS B.1 (continued)

If the APLHGR cannot be restored to within its required limits within the associated Completion Time, the plant must be brought to a MODE or other specified condition in which the LCO does not apply. To achieve this status, THERMAL POWER must be reduced to < 23% RTP within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />. The allowed Completion Time is reasonable, based on operating experience, to reduce THERMAL POWER to < 23% RTP in an orderly manner and without challenging plant systems.SURVEILLANCE SR 3.2.1.1 REQUIREMENTS APLHGRs are required to be initially calculated within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after THERMAL POWER is _ 23% RTP and then eve. ; 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />speriodicallv thereafter.

Additionally, APLHGRs must be calculated prior to exceeding 44% RTP unless performed in the previous 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. APLHGRs are compared to the specified limits in the COLR to ensure that the reactor is operating within the assumptions of the safety analysis.

The-24-heou Frequency

'r based on both engineering judgment and recognitien of tho cGhangos in di.tFibution during nor.al The 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> allowance after THERMAL POWER > 23% RTP is achieved is acceptable given the large inherent margin to operating limits at low power levels and because the APLHGRs must be calculated prior to exceeding 44% RTP. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.REFERENCES

1. Not used.2. Not used.3. EMF-2361(P)(A), "EXEM BWR-2000 ECCS Evaluation Model," Framatome ANP.4. ANF-CC-33(P)(A)

Supplement 2, "HUXY: A Generalized Multirod Heatup Code with 1OCFR50 Appendix K Heatup Option," January 1991.5. XN-CC-33(P)(A)

Revision 1, "HUXY: A Generalized Multirod Heatup Code with 1OCFR50 Appendix K Heatup Option Users Manual," November 1975.(continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.2-3 Revision ,3 PPL Rev. 3 MCPR B 3.2.2 BASES APPLICABILITY (continued) continue to the 5% to 15% power range when entry into MODE 2 occurs.When in MODE 2, the intermediate range monitor provides rapid scram initiation for any significant power increase transient, which effectively eliminates any MCPR compliance concern. Therefore, at THERMAL POWER levels < 23% RTP, the reactor is operating with substantial margin to the MCPR limits and this LCO is not required.ACTIONS A.1 If any MCPR is outside the required limits, an assumption regarding an initial condition of the design basis transient analyses may not be met.Therefore, prompt action should be taken to restore the MCPR(s) to within the required limits such that the plant remains operating within analyzed conditions.

The 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> Completion Time is normally sufficient to restore the MCPR(s) to within its limits and is acceptable based on the low probability of a transient or DBA occurring simultaneously with the MCPR out of specification.

B. 1 If the MCPR cannot be restored to within its required limits within the associated Completion Time, the plant must be brought to a MODE or other specified condition in which the LCO does not apply. To achieve this status, THERMAL POWER must be reduced to < 23% RTP within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.The allowed Completion Time is reasonable, based on operating experience, to reduce THERMAL POWER to < 23% RTP in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS SR 3.2.2.1 The MCPR is required to be initially calculated within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after THERMAL POWER is > 23% RTP and then eve y heperiodicaluy thereafter.

Additionally, MCPR must be calculated prior to exceeding 44% RTP unless performed in the previous 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. MCPR is compared to the specified limits in the (continued)

I SUSQUEHANNA -UNIT 1 TS / IB 3.2-7 Revision 4-PPL Rev. 3 MCPR B 3.2.2 BASES SURVEILLANCE SR 3.2.2.1 (continued)

REQUIREMENTS COLR to ensure that the reactor is operating within the assumptions of the safety analysis.

The 214 hour0.00248 days <br />0.0594 hours <br />3.53836e-4 weeks <br />8.1427e-5 months <br /> Fequency is based on both g judgment and recognitfien of the slowness of chane in powar distribution during normal operati. The 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> allowance after THERMAL POWER_> 23% RTP is achieved is acceptable given the large inherent margin to operating limits at low power levels and because the MCPR must be calculated prior to exceeding 44% RTP. The Surveillance Frequency is controlled under the Surveillance Frequency Control Proqram.SR 3.2.2.2 Because the transient analysis takes credit for conservatism in the scram time performance, it must be demonstrated that the specific scram time is consistent with those used in the transient analysis.

SR 3.2.2.2 compares the average measured scram times to the assumed scram times documented in the COLR. The COLR contains a table of scram times based on the LCO 3.1.4 "Control Rod Scram Times" and the realistic scram times, both of which are used in the transient analysis.

If the average measured scram times are greater than the realistic scram times then the MCPR operating limits corresponding to the Maximum Allowable Average Scram Insertion Time must be implemented.

Determining MCPR operating limits based on interpolation between scram insertion times is not permitted.

The average measured scram times and corresponding MCPR operating limit must be determined once within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after each set of scram time tests required by SR 3.1.4.1, SR 3.1.4.2, SR 3.1.4.3 and SR 3.1.4.4 because the effective scram times may change during the cycle.The 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Completion Time is acceptable due to the relatively minor changes in average measured scram times expected during the fuel cycle.REFERENCES

1. NUREG-0562, June 1979.2. XN-NF-80-19(P)(A)

Volume 1 and Supplements 1 and 2, "Exxon Nuclear Methodology for Boiling Water Reactors," Exxon Nuclear Company, March 1983.(continued)

I SUSQUEHANNA-UNIT 1 TS / B 3.2-8 Revision 3 PPL Rev. .2 LHGR B 3.2.3 BASES ACTIONS A..1 (continued) restore the LHGR(s) to within its required limits such that the plant is operating within analyzed conditions.

The 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> Completion Time is normally sufficient to restore the LHGR(s) to within its limits and is acceptable based on the low probability of a transient or Design Basis Accident occurring simultaneously with the LHGR out of specification.

B.1 If the LHGR cannot be restored to within its required limits within the associated Completion Time, the plant must be brought to a MODE or other specified condition in which the LCO does not apply. To achieve this status, THERMAL POWER is reduced to < 23% RTP within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />. The allowed Completion Time is reasonable, based on operating experience, to reduce THERMAL POWER to < 23% RTP in an orderly manner and without challenging plant systems.SURVEILLANCE SR 3.2.3.1 REQUIREMENTS The LHGR is required to be initially calculated within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after THERMAL POWER is _> 23% RTP and then overy 24 hourFperiodically thereafter.

Additionally, LHGRs must be calculated prior to exceeding 44%RTP unless performed in the previous 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. The LHGR is compared to the specified limits in the COLR to ensure that the reactor is operating within the assumptions of the safety analysis.

The 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> F.oquoncY is baced on both engineering judgment and recognition of the- cla'W changeG in power diStribution n,, malo .peairattio.n..

The 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> allowance after THERMAL POWER 23% RTP is achieved is acceptable given the large inherent margin to operating limits at lower power levels and because the LHGRs must be calculated prior to exceeding 44% RTP. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.REFERENCES

1. FSAR, Section 4.2. FSAR, Section 5.3. NUREG-0800,Section II.A.2(g), Revision 2, July 1981.(continued)

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-UNIT 1 TS / B 3.2-12 Revision 4--

PPL Rev. 6 RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE SR 3.3.1.1.1 and SR 3.3.1.1.2 REQUIREMENTS Performance of the CHANNEL CHECK ncre eveoy 12 heurs ensures that a gross failure of instrumentation has not occurred.

A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.

It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between 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)

I SUSQUEHANNA

-UNIT I TS / B 3.3-24b Revision 0-" .. ..-'.-. -" -... .. -.Z r t- -.. .... ..' .. .. -....., -.

PPL Rev. 5 RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE SR 3.3.1.1.1 and SR 3.3.1.1.2 (continued)

REQUIREMENTS Agreement criteria which are determined by the plant staff based on an investigation of a combination of the channel instrument uncertainties, may be used to support this parameter comparison and include indication and readability.

If a channel is outside the criteria, it may be an indication that the instrument has drifted outside its limit, and does not necessarily indicate the channel is Inoperable.

The Surveillance Frequency is controlled under the Surveillance Frequency Control Procram.The Frequency o.c ever;y 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for SR 3.3.1.1.1 i based upon eperating experience that dr..nst.ates that channel failr. I -i...46 4r.ae. The Fr.equency of on.e eve; 214 hour0.00248 days <br />0.0594 hours <br />3.53836e-4 weeks <br />8.1427e-5 months <br />. for SR 3.3.1.1.2 is based upon operating experieance that demonstrates that hannAel failure is -rae and the evalu-ation

n RefeFrences 15 and 16. The CHANNEL CHECK supplements less formal checks of channels during normal operational use of the displays associated with the channels required by the LCO.SR 3.3.1.1.3 To ensure that the APRMs are accurately indicating the true core average power, the APRMs are calibrated to the reactor power calculated from a heat balance. The Surveillance Frequency is controlled under the Surveillance Frequency Control Proqram.The FrequeRcy Of ncR-e pe 7 days ic bared .,.mine.'r changes in LPRM sensitivity, which could affGet the APRM reading beteenperormances of SR 33118 A restriction to satisfying this SR when < 23% RTP is provided that requires the SR to be met only at >_ 23% RTP because it is difficult to accurately maintain APRM indication of core THERMAL POWER consistent with a heat balance when < 23% RTP. At low power levels, a high degree of accuracy is unnecessary because of the large, inherent margin to thermal limits (MCPR, LHGR and APLHGR). At _> 23% RTP, the Surveillance is required to have been satisfactorily performed within the last 7 days, in accordance with SR 3.0.2. A Note is provided which allows an increase in THERMAL POWER above 23% if the 7-d7a-Frequency is not met per SR 3.0.2. In this event, the SR must be performed within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reaching or exceeding 23% RTP. Twelve hours is based on operating experience and in (continued)

I SUSQUEHANNA-UNIT 1 TS / B 3.3-25 Revision 3 PPL Rev. 5 RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE REQUIREMENTS SR 3.3.1.1.3 (continued) consideration of providing a reasonable time in which to complete the SR.The Surveillance Frequency is controlled under the Surveillance Frequency Control Proqram.S R 3.3.1.1.4 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function.As noted, SR 3.3.1.1.4 is not required to be performed when entering MODE 2 from MODE 1, since testing of the MODE 2 required IRM Functions cannot be performed in MODE 1 without utilizing jumpers, lifted leads, or movable links. This allows entry into MODE 2 if the 7-day-Frequency is not met per SR 3.0.2. In this event, the SR must be (continued)

I SUSQUEHANNA-UNIT 1 TS / B 3.3-26 Revision PPL Rev. 6 RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE SR 3.3.1.1.4 (continued)

REQUIREMENTS performed within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after entering MODE 2 from MODE 1. Twelve hours is based on operating experience and in consideration of providing a reasonable time in which to complete the SR.The Surveillance Frequency is controlled under the Surveillance Frequency Control Proqram.A rFequency of 7 dayc prvido an acceptable leyeo system average unavailability over the Frequency interval and is based on rliability analysis (Ref. 9)-.SR 3.3.1.1.5 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function.

A Frequencay of :7 days providoc an; acceptable level of system average availability over the rFrequency and is bared On; the rcliability analysis of RefeFenee-&--(The Manual Scram Function's CHANNEL FUNCTIONAL TEST Frequency was credited in the analysis to extend many automatic scram Functions' Frequencies.)

The Surveillance Frequency is controlled under the Surveillance Frequency Control Proqram.SR 3.3.1.1.6 and SR 3.3.1.1.7 These Surveillances are established to ensure that no gaps in neutron flux indication exist from subcritical to power operation for monitoring core reactivity status.The overlap between SRMs and IRMs is required to be demonstrated to ensure that reactor power will not be increased into a neutron flux region without adequate indication.

The overlap is demonstrated prior to fully withdrawing the SRMs from the core. Demonstrating the overlap prior to fully withdrawing the SRMs from the core is required to ensure the SRMs are on-scale for the overlap demonstration.

The overlap between IRMs and APRMs is of concern when reducing power into the IRM range. On power increases, the system design will prevent further increases (by initiating a rod block) if adequate overlap is not maintained.

Overlap between IRMs and APRMs exists when sufficient IRMs and APRMs concurrently have onscale readings such that the transition between MODE 1 and MODE 2 can be made without either APRM downscale rod block, or IRM upscale rod block. Overlap (continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.3-27 Revision -1 PPL Rev. &RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE SR 3.3.1.1.6 and SR 3.3.1.1.7 (continued)

REQUIREMENTS between SRMs and IRMs similarly exists when, prior to fully withdrawing the SRMs from the core, IRMs are above mid-scale on range 1 before SRMs have reached the upscale rod block.As noted, SR 3.3.1.1.7 is only required to be met during entry into MODE 2 from MODE 1. That is, after the overlap requirement has been met and indication has transitioned to the IRMs, maintaining overlap is not required (APRMs may be reading downscale once in MODE 2).If overlap for a group of channels is not demonstrated (e.g., IRM/APRM overlap), the reason for the failure of the Surveillance should be determined and the appropriate channel(s) declared inoperable.

Only those appropriate channels that are required in the current MODE or condition should be declared inoperable.

The Surveillance Frequency is controlled under the Surveillance Frequency Control Proqram.4 Frequency of 7 days is reaconable baced n engi r judgment and the reliabilfity of the !RMs and APRMG SR 3.3.1.1.8 LPRM gain settings are determined from the local flux profiles that are either measured by the Traversing Incore Probe (TIP) System at all functional locations or calculated for TIP locations that are not functional.

The methodology used to develop the power distribution limits considers the uncertainty for both measured and calculated local flux profiles.

This methodology assumes that all the TIP locations are functional for the first LPRM calibration following a refueling outage, and a minimum of 25 functional TIP locations for subsequent LPRM calibrations.

The calibrated LPRMs establish the relative local flux profile for appropriate representative input to the APRM System. The Surveillance Frequency is controlled under the Surveillance Frequency Control Progqram.The 1000 Fr.equency

• s ba,,ed on operating experience with LPRM ,ittiVity change,..SR 3.3.1.1.9 and SR 3.3.1.1.14 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the (continued)

SUSQUEHANNA

-UNIT 1 TS / B 3.3-28 Revision 3 ,, _....L.

PPL Rev. 6 RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE SR 3.3.1.1.9 and SR 3.3.1.1.14 (continued)

REQUIREMENTS intended function.

The Surveillance Frequency is controlled under the Surveillance Frequency Control ProgramThe 92 day Frequenc, y 9f SR 3.3.1.1.9 i6 based on th" roliabi,;t .nalysis of ReferenGe 9.SR 3.3.1.1.9 is modified by a Note that provides a general exception to the definition of CHANNEL FUNCTIONAL TEST. This exception is necessary because the design of instrumentation does not facilitate functional testing of all required contacts of the relay which input into the combinational logic.(Reference

10) Performance of such a test could result in a plant transient or place the plant in an undo risk situation.

Therefore, for this SR, the CHANNEL FUNCTIONAL TEST verifies acceptable response by verifying the change of state of the relay which inputs into the combinational logic.The required contacts not tested during the CHANNEL FUNCTIONAL TEST are tested under the LOGIC SYSTEM FUNCTIONAL TEST, SR 3.3.1.1.15.

This is acceptable because operating experience shows that the contacts not tested during the CHANNEL FUNCTIONAL TEST normally pass the LOGIC SYSTEM FUNCTIONAL TEST, and the testing methodology minimizes the risk of unplanned transients.

The Surveillance Frequency is controlled under the Surveillance Frequency Control ProqramThe 24 month Fr..quc...y of SR 3.3.1.1.14 is ba6sed on the need to perform1 thiS SurveillancGe under the conditions that apply dIuring a plant outage and the poten~tial for an unplanned transient if the Surveillance.Io1e perforAed with the reactoF at power. Operating has shown that there componenits usually pass the Surveillance when performed at the 21 month Frequency.

SR 3.3.1.1.10, SR3.3.1.1.11, SR 3.3.1.1.13, andSR 3.3.1.1.18 A CHANNEL CALIBRATION verifies that 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.

Note 1 for SR 3.3.1.1.18 states that neutron detectors are excluded from CHANNEL CALIBRATION because they are passive devices, with minimal drift, and because of the difficulty of simulating a meaningful signal.Changes in neutron detector sensitivity are compensated for by performing the 7-day-calorimetric calibration (SR 3.3.1.1.3) and the 2000 MWAD/MT LPRM (continued)

I SUSQUEHANNA-UNIT 1 TS / B 3.3-29 Revision ,3 PPL Rev. &RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE SR 3.3.1.1.10, SR 3.3.1.1.11, SR 3.3.1.1.13 and SR 3.3.1.1.18 REQUIREMENTS (continued) calibration against the TIPs (SR 3.3.1.1.8).

A Note is provided for SR 3.3.1.1.11 that requires the IRM SRs to be performed within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> of entering MODE 2 from MODE 1. Testing of the MODE 2 APRM and IRM Functions cannot be performed in MODE 1 without utilizing jumpers, lifted leads, or movable links. This Note allows entry into MODE 2 from MODE 1 if the associated Frequency is not met per SR 3.0.2.Twelve hours is based on operating experience and in consideration of providing a reasonable time in which to complete the SR.A second note is provided for SR 3.3.1.1.18 that requires that the recirculation flow (drive flow) transmitters, which supply the flow signal to the APRMs, be included in the SR for Functions 2.b and 2.f. The APRM Simulated Thermal Power-High Function (Function 2.b) and the OPRM Trip Function (Function 2.f) both require a valid drive flow signal. The APRM Simulated Thermal Power-High Function uses drive flow to vary the trip setpoint.

The OPRM Trip Function uses drive flow to automatically enable or bypass the OPRM Trip output to the RPS. A CHANNEL CALIBRATION of the APRM drive flow signal requires both calibrating the drive flow transmitters and the processing hardware in the APRM equipment.

SR 3.3.1.1.20 establishes a valid drive flow / core flow relationship.

Changes throughout the cycle in the drive flow / core flow relationship due to the changing thermal hydraulic operating conditions of the core are accounted for in the margins included in the bases or analyses used to establish the setpoints for the APRM Simulated Thermal Power-High Function and the OPRM Trip Function.The Surveillance Frequency is controlled under the Surveillance Frequency Control Proqram he Frequency of ,84 .... ,, dy ,, SR 3.3.1.1.12 aind 21 months for SR 3.3.1.1.13 and SR 33118 i, based upon the zacumptions in the determination of the magnitude of equipment drift in the cetpefint analysis.-(continued)

I SUSQUEHANNA-UNIT 1 TS / B 3.3-30 Revision PPL Rev. 6 RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE SR 3.3.1.1.12 REQUIREMENTS A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function.

For the APRM Functions, this test supplements the automatic self-test functions that operate continuously in the APRM and voter channels.

The scope of the APRM CHANNEL FUNCTIONAL TEST is that which is necessary to test the hardware.

Software controlled functions are tested as part of the initial verification and validation and are only incidentally tested as part of the surveillance testing. Automatic self-test functions check the EPROMs in which the software-controlled logic is defined. Changes in the EPROMs will be detected by the self-test function and alarmed via the APRM trouble alarm. SR 3.3.1.1.1 for the APRM functions includes a step to confirm that the automatic self-test function is still operating.

The APRM CHANNEL FUNCTIONAL TEST covers the APRM channels (including recirculation flow processing

-- applicable to Function 2.b and the auto-enable portion of Function 2.f only), the 2-out-of-4 Voter channels, and the interface connections into the RPS trip systems from the voter channels.Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology.

The Surveillance Frequency is controlled under the Surveillance Frequency Control Pro-qramThe-!-84-day FrequeRGY SR is3.1.11 ic based on tho reliability References 15 and 16. (NOTE: The actual voting logic of the 2-out-of-4 Voter Function is tested as part of SR 3.3.1.1.15.

The auto-enable setpoints for the OPRM Trip are confirmed by SR 3.3.1.1.19.)

A Note is provided for Function 2.a that requires this SR to be performed within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> of entering MODE 2 from MODE 1. Testing of the MODE 2 APRM Function cannot be performed in MODE 1 without utilizing jumpers or lifted leads. This Note allows entry into MODE 2 from MODE 1 if the associated Frequency is not met per SR 3.0.2.A second Note is provided for Functions 2.b and 2.f that clarifies that the CHANNEL FUNCTIONAL TEST for Functions 2.b and 2.f includes testing of the recirculation flow processing electronics, excluding the flow transmitters.

SR 3.3.1.1.15 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required trip logic for a specific channel. The functional testing of control rods (LCO 3.1.3), and SDV vent (continued)

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-UNIT 1 TS / B 3.3-30a Revision 0 PPL Rev. 5 RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE SR 3.3.1.1.15 (continued)

REQUIREMENTS and drain valves (LCO 3.1.8), overlaps this Surveillance to provide complete testing of the assumed safety function.The LOGIC SYSTEM FUNCTIONAL TEST for APRM Function 2.e simulates APRM and OPRM trip conditions at the 2-out-of-4 Voter channel inputs to check all combinations of two tripped inputs to the 2-out-of-4 logic in the voter channels and APRM-related redundant RPS relays.The Surveillance Frequency is controlled under the Surveillance Frequency Control ProciramThe

,4 2mnth i; ba"ed on the need to portions of this Surestillance urder titihe omthens that apply durang a plant outage and tho potential foFan unplanned transient if thes sureLowFuncioe peTFmod with theo eadtor at power. peat expurience has shewn that these cempenents usually pass the Smaneitlarne whon peaflormed at the 24 month Frequency.

SR 3.3.1.1.16 This SR ensures that scrams initiated from the Turbine Stop Valve-Closure and Turbine Control Valve Fast Closure, Trip Oil Pressure-Low Functions will not be inadvertently bypassed when THERMAL POWER is > 26% RTP.This is performed by a Functional check that ensures the scram feature is not bypassed at _> 26% RTP. Because main turbine bypass flow can affect this function nonconservatively (THERMAL POWER is derived from turbine first stage pressure), the opening of the main turbine bypass valves must not cause the trip Function to be bypassed when Thermal Power is 26% RTP.If any bypass channel's trip function is nonconservative (i.e., the Functions are bypassed at 2! 26% RTP, either due to open main turbine bypass valve(s)or other reasons), then the affected Turbine Stop Valve-Closure and Turbine Control Valve Fast Closure, Trip Oil Pressure-Low Functions are considered inoperable.

Alternatively, the bypass channel can be placed in the conservative condition (nonbypass).

If placed in the nonbypass condition, this SR is met and the channel is considered OPERABLE.The Surveillance Frequency is controlled under the Surveillance Frequency Control ProqramThe Frequency of 21 months, is based en engineerin judgment and reliability of the com.ponent.

SR 3.3.1.1.17 This SR ensures that the individual channel response times are less than or equal to the maximum values assumed in the accident analysis.

This test may be performed in one (continued)

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-UNIT 1 TS / B 3.3-31 Revision 4 PPL Rev. 6 RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE SR 3.3.1.1.17 (continued)

REQUIREMENTS measurement or in overlapping segments, with verification that all components are tested. The RPS RESPONSE TIME acceptance criteria are included in Reference 11.RPS RESPONSE TIME for the APRM 2-out-of-4 Voter Function (2.e)includes the APRM Flux Trip output relays and the OPRM Trip output relays of the voter and the associated RPS relays and contactors.(Note: The digital portion of the APRM, OPRM and 2-out-of-4 Voter channels are excluded from RPS RESPONSE TIME testing because self-testing and calibration checks the time base of the digital electronics.

Confirmation of the time base is adequate to assure required response times are met. Neutron detectors are excluded from RPS RESPONSE TIME testing because the principles of detector operation virtually ensure an instantaneous response time. See References 12 and 13).The Surveillance Frequency is controlled under the Surveillance Frequency Control Pro-qramRPS RESPONSE TIMIE tests are conducted on aR 214 mnth STAGGEREID TEST BASIS. Note 3 requires STAGGERED TEST BASIS Frequenc~y to be determined based on 4 channels per- trip systemA, in lieu of the 8 channels spccified in Table 3.3. 1.1 1 for the MSIV Closure Function because channels are arranged in pairs.This Frequency is based on the logir ntheresponsetip of theariun channels requircd to producse an RPS Scramn Signal. The 21 month Frequency is consistent with the typical industrY refueling c.Ycle and is base upon plant operating cxperiencc, Wh ich Gh O S tha~t randoAm falilures et ainstwmentatincmonnscasn erious respnse time degradation, but not channel failure, are infrequent occrreces SR 3.3.1.1.17 for Function 2.e confirms the response time of that function, and also confirms the response time of components to Function 2.e and other RPS functions. (Reference 14)Note 3 allows the STAGGERED TEST BASIS Frequency for Function .to be determined based on 8 channels rather than the 4 actual 2 out of , Voter channels.

The redundant outputs from the 2-out-of-4 Voter channel (2 for APRM trips and 2 for OPRM trips) are considered part of the same channel, but the OPRM and APRM outputs are considered to be separate channels for application of SR 3.3.1.1.17, se N -8. The note further requires that testing of OPRM and APRM outputs from a 2-out-of-4 Voter be alternated.

In addition to these commitments, References 15 and 16 require that the testing of inputs to each RPS Trip System alternate.(continued)

I SUSQUEHANNA-UNIT 1 TS / B 3.3-32 Revision PPL Rev. 6 RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE SR 3.3.1.1.19 REQUIREMENTS This surveillance involves confirming the OPRM Trip auto-enable setpoints.

The auto-enable setpoint values are considered to be nominal values as discussed in Reference

21. This surveillance ensures that the OPRM Trip is enabled (not bypassed) for the correct values of APRM Simulated Thermal Power and recirculation drive flow. Other surveillances ensure that the APRM Simulated Thermal Power and recirculation drive flow properly correlate with THERMAL POWER (SR 3.3.1.1.2) and core flow (SR 3.3.1.1.20), respectively.

If any auto-enable setpoint is nonconservative (i.e., the OPRM Trip is bypassed when APRM Simulated Thermal Power _> 25% and recirculation drive flow < value equivalent to the core flow value defined in the COLR, then the affected channel is considered inoperable for the OPRM Trip Function.

Alternatively, the OPRM Trip auto-enable setpoint(s) may be adjusted to place the channel in a conservative condition (not bypassed).

If the OPRM Trip is placed in the not-bypassed condition, this SR is met, and the channel is considered OPERABLE.For purposes of this surveillance, consistent with Reference 21, the conversion from core flow values defined in the COLR to drive flow values used for this SR can be conservatively determined by a linear scaling assuming that 100% drive flow corresponds to 100 Mlb/hr core flow, with no adjustment made for expected deviations between core flow and drive flow below 100%.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program The F.equoncy of 24 is basod on engine.ring judgment considoring the reliability of the components.

SR 3.3.1.1.20 The APRM Simulated Thermal Power-High Function (Function 2.b) uses drive flow to vary the trip setpoint.

The OPRM Trip Function (Function 2.f)uses drive flow to automatically enable or bypass the OPRM Trip output to RPS. Both of these Functions use drive flow as a representation of reactor core flow. SR 3.3.1.1.18 ensures that the drive flow transmitters and processing electronics are calibrated.

This SR adjusts the recirculation drive flow scaling factors in each APRM channel to provide the appropriate drive flow/core flow alignment.(continued)

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-UNIT 1 TS / B, 3.3-32b Revision 4--

I PPL Rev. 6 RPS Instrumentation B 3.3.1.1 SURVEILLANCE REQUIREMENTS SR 3.3.1.1.20 The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The FrFequency of 21 mon~ths, considers that any change.An the copre flow to driY'3 floW funcGtional relationship during poWer operation would bo gradual and the mnaintenance of the RccIrculation System and core components that may impact the relationship is expected to be performned during refueling outages. Thus frequency also considers the period after reachIn plant eqUilibriUM conditions necessary to perform the test, engineering judgment of the time required to collect and analyze the necessar; flow data, and engineering judgment of the time required to enter and cheek the applicable scaling factor-s in each of the APRM channels.

This timoframe is acceptable based on the relatively small alignment errors expected, and the margins already included in; the APRM Simulated Thermal PoWer High and OPRM TrFip F=unction trip enable setpeirts REFERENCES

1. FSAR, Figure 7.2-1.2. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).3. NEDO-23842, "Continuous Control Rod Withdrawal in the Startup Range," April 18, 1978.4. FSAR, Section 5.2.2.5. FSAR, Chapter 15.6. FSAR, Section 6.3.3.(continued)

I SUSQUEHANNA-UNIT 1 TS / B 3.3-32c Revision 0 PPL Rev. 2 SRM Instrumentation B 3.3.1.2 BASES SURVEILLANCE SR 3.3.1.2.1 and SR 3.3.1.2.3 (continued)

REQUIREMENTS is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.

Agreement criteria which are determined by the plant staff based on an investigation of a combination of the channel instrument uncertainties, may be used to support this parameter comparison and include indication and readability.

If a channel is outside the criteria, it may be an indication that the instrument has drifted outside its limit, and does not necessarily indicate the channel is Inoperable.

The Surveillance Frequency is controlled under the Surveillance Frequency Control ProgramTh Froquon. y of nco. every 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. for SIR 3.3.1.2.1 is based on operating eXperiencoe that demonstratee channe! failure ic rare. While i MOD)ES 3- and 4, reactivitY changec are not experted; thcroforo, the 12 ho-ur Frequenc..

m y laxed to 24 hou, for SIR 3.3.1.2.3. -The CHANNEL CHECK supplements less formal checks of channels during normal operational use of the displays associated with the channels required by the LCO.SR 3.3.1.2.2 To provide adequate coverage of potential reactivity changes in the core, a maximum of two SRMs are required to be OPERABLE.

One SRM is required to be OPERABLE in the quadrant where CORE ALTERATIONS are being performed, and the other OPERABLE SRM must be in an adjacent quadrant containing fuel. However, in accordance with Table.3.3.1.2-1, only one SRM is required during a spiral reload until the fueled region is large enough to encompass a second installed SRM. Note 1 states that the SR is required to be met only during CORE ALTERATIONS.

It is not required to be met at other times in MODE 5 since core reactivity changes are not occurring.

This Surveillance consists of a review of plant logs to ensure that SRMs required to be OPERABLE for given CORE ALTERATIONS are, in fact, OPERABLE.

In the event that only one SRM is required to be OPERABLE, per Table 3.3.1.2-1, footnote (b), only the a. portion of this SR is required.Note 2 clarifies that more than one of the three requirements can be met by the same OPERABLE SRM. The Surveillance Frequency is controlled under the Surveillance Frequency Control ProqramThe 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Frequency is based upon operating cxperience and supplements operational controld over refueling activities (continued)

I SUSQUEHANNA-UNIT 1 TS / B 3.3-40 Revision 4-1 PPL Rev. 2 SRM Instrumentation B 3.3.1.2 BASES SURVEILLANCE SR 3.3.1.2.2 (continued)

REQUIREMENTS that include steps to ensureF that the SRMs required by the LCO are in the pr~epeF quad~a~t.SR 3.3.1.2.4 This Surveillance consists of a verification of the SRM instrument readout to ensure that the SRM reading is greater than a specified minimum count rate,-whic-h-ensures-th-at the-detectors-are indicating -count-rates indieative of neutron flux levels within the core. The signal-to-noise ratio shown in Figure 3.3.1.2-1 is the SRM count rate at which there is a 95% probability that the SRM signal indicates the presence of neutrons and only a 5% probability that the SRM signal is a result of noise (Ref. 1). With few fuel assemblies loaded, the SRMs will not have a high enough count rate to satisfy the SR.Therefore, allowances are made for loading sufficient "source" material, in the form of irradiated fuel assemblies, to establish the minimum count rate.To accomplish this, the SR is modified by a Note that states that the count rate is not required to be met on an SRM that has less than or equal to four fuel assemblies adjacent to the SRM and no other fuel assemblies are in the associated core quadrant.

With four or less fuel assemblies loaded around each SRM and no other fuel assemblies in the associated core quadrant, even with a control rod withdrawn, the configuration will not be critical.

The signal to noise ratio is only required to be deteR.,ined ever; 7ýor 31 days the requirements of SR 3,341.2.5 or 3.3.1.2.6.

The Surveillance Frequency is controlled under the Surveillance Frequency Control ProqramThe Frequency

.. based upon channel redundancy and other i"nfation available in the control room, and ensur.es that the required channels are frequently mon~itored while core reactiVity changes are occurring.

When no reartivity change ar nrgress, the FrFequency is relaxed fromR 12 hourS to 2 Chus.SR 3.3.1.2.5 and SR 3.3.1.2.6 Performance of a CHANNEL FUNCTIONAL TEST demonstrates the associated channel will function properly.

SR 3.3.1.2.5 is (continued)

I SUSQUEHANNA-UNIT 1 TS / B 3.3-41 Revision .-1 PPL Rev. 2 SRM Instrumentation B 3.3.1.2 BASES SURVEILLANCE SR 3.3.1.2.5 and SR 3.3.1.2.6 (continued)

REQUIREMENTS required in MODE 5, and the 7- day FrequenGy ensures that the channels are OPERABLE while core reactivity changes could be in progress.

The Surveillance Frequency is controlled under the Surveillance Frequency Control ProcramThis Fr.eqenc.

i r..o nable, baed on .perating experience

.nd on o ther SuwrFoil lanczc (suc-h -as an C-H.AbI NN ELI CHECGK), th at ensr6 e proeper between CHANNEL FUNCTIONAL TESTS.SR 3.3.1.2.6 is required in MODE 2 with IRMs on Range 2 or below, and in MODES 3 and 4The Surveillance Frequency is controlled under the Surveillance Frequency Control Program,.

Sinc cor .e reactiVity change. do not norm.ally take place, the F=requency has been ex4ended from :7 days to 31 days. The 31 day ,F.eq.ccYis baFsed o operating e.pe e and on ot Surve:ilanceS (SUch as CHANNEL CHECGK) that enSUre proere functionig between CHANNLh-1 FUINCTIONAL.

TESTS.Verification of the signal to noise ratio also ensures that the detectors are inserted to an acceptable operating level. In a fully withdrawn condition, the detectors are sufficiently removed from the fueled region of the core to essentially eliminate neutrons from reaching the detector.

Any count rate obtained while the detectors are fully withdrawn is assumed to be "noise" only.The Note to the Surveillance allows the Surveillance to be delayed until entry into the specified condition of the Applicability (THERMAL POWER decreased to IRM Range 2 or below). The SR must be performed within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after IRMs are on Range 2 or below. The allowance to enter the Applicability with the ,?1-day-Frequency not met is reasonable, based on the limited time of 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> allowed after entering the Applicability and the inability to perform the Surveillance while at higher power levels. Although the Surveillance could be performed while on IRM Range 3, the plant would not be expected to maintain steady state operation at this power level. In this event, the 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Frequency is reasonable, based on the SRMs being otherwise verified to be OPERABLE (i.e., satisfactorily performing the CHANNEL CHECK) and the time required to perform the Surveillances.(continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.3-42 Revision 4--

PPL Rev. 2 SRM Instrumentation B 3.3.1.2 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.1.2.7 Performance of a CHANNEL CALIBRATION at a Fr.qu.ncy of 24 .onthe verifies the performance of the SRM detectors and associated circuitry.

The Frequency considers the plant conditions required to perform the test, the ease of performing the test, and the likelihood of a change in the system or component status. The Surveillance Frequency is controlled under the Surveillance Frequency Control Proqram.-The neutron detectors are excluded from the CHANNEL CALIBRATION because they cannot readily be adjusted.

The detectors are fission chambers that are designed to have a relatively constant sensitivity over the range and with an accuracy specified for a fixed useful life.Note 2 to the Surveillance allows the Surveillance to be delayed until entry into the specified condition of the Applicability.

The SR must be performed in MODE 2 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> of entering MODE 2 with IRMs on Range 2 or below. The allowance to enter the Applicability with the 24 month Frequency not met is reasonable, based on the limited time of 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> allowed after entering the Applicability and the inability to perform the Surveillance while at higher power levels. Although the Surveillance could be performed while on IRM Range 3, the plant would not be expected to maintain steady state operation at this power level. In this event, the 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Frequency is reasonable, based on the SRMs being otherwise verified to be OPERABLE (i.e., satisfactorily performing the CHANNEL CHECK)and the time required to perform the Surveillances.

REFERENCES

1. General Electric Service Information Letter (SIL) 478 "SRM Minimum Count Rate" dated December 16, 1988.(continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.3-43 Revision 4-PPL Rev. 3 Control Rod Block Instrumentation 3.3.2.1 BASES SURVEILLANCE assumption of the average time required to perform channel Surveillance.

REQUIREMENTS That analysis demonstrated that the 6 hour6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> testing allowance does not (continued) significantly reduce the probability that a control rod block will be initiated when necessary.

SR 3.3.2.1.1 A CHANNEL FUNCTIONAL TEST is performed for each RBM channel to ensure that the entire channel will perform the intended function.

It includes the Reactor Manual Control Multiplexing System input. The Surveillance Frequency is controlled under the Surveillance Frequency Control ProgramThe FreqUencY Of 184 days is based on reliability analyses (Refc. 8, 12 and 13).SR 3.3.2.1.2 and SR 3.3.2.1.3 A CHANNEL FUNCTIONAL TEST is performed for the RWM to ensure that the entire system will perform the intended function.

The CHANNEL FUNCTIONAL TEST for the RWM is performed by attempting to withdraw a control rod not in compliance with the prescribed sequence and verifying a control rod block occurs and by verifying proper indication of the selection error of at least one out-of-sequence control rod. As noted in the SRs, SR 3.3.2.1.2 is not required to be performed until 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after any control rod is withdrawn in MODE 2. As noted, SR 3.3.2.1.3 is not required to be performed until 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after THERMAL POWER is < 10% RTP in MODE 1.This allows entry into MODE 2 for SR 3.3.2.1.2, and entry into MODE 1 when THERMAL POWER is _ 10% RTP for SR 3.3.2.1.3, to perform the required Surveillance if the 2- day-Frequency is not met per SR 3.0.2. The 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> allowance is based on operating experience and in consideration of providing a reasonable time in which to complete the SRs. The Surveillance Frequency is controlled under the Surveillance Frequency Control ProqramThe Frequenciec arc based on reliability analysis (Ref-. 8.SR 3.3.2.1.4 The RBM setpoints are automatically varied as a function of Simulated Thermal Power. Three control rod block Allowable Values are specified in Table 3.3.2.1-1, each within a specific power range. The power at which the control rod block Allowable Values automatically change are based on the APRM signal's input to each RBM channel. Below the minimum power setpoint, the RBM is automatically bypassed.

These control rod block NTSPs must be verified periodically to be less than or equal to the specified Allowable Values. If any power range setpoint is non-conservative, then the affected RBM channel is considered inoperable.

As noted, neutron detectors are excluded from the Surveillance because they are passive devices, with minimal drift, and because of the difficulty of simulating a meaningful signal. Neutron detectors are adequately tested in SR 3.3.1.1.3 and SR 3.3.1.1.8.

The Surveillance Frequency is controlled under the Surveillance Frequency Control ProqramThe 24 ,n,,t- ..e..Ue... is based en the actual tFW. sentpent metkpedenew udaid frr theseGa (noniud (continued)

I SUSQUEHANNA-UNIT 1 TS / B 3.3-51 Revision3 PPL Rev. 3 Control Rod Block Instrumentation 3.3.2.1 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.2.1.5 The RWM is automatically bypassed when power is above a specified value. The power level is determined from steam flow signals. The automatic bypass setpoint must be verified periodically to be not bypassed_< 10% RTP. This is performed by a Functional check. If the RWM low power setpoint is nonconservative, then the RWM is considered inoperable.

Alternately, the low power setpoint channel can be placed in the conservative condition (nonbypass).

If placed in the nonbypassed condition, the SR is met and the RWM is not considered inoperable.

The Surveillance Frequency is controlled under the Surveillance Frequency Control ProqramT-he FFreguon';

06 based en the need to perform the Surveillance during a plant SR 3.3.2.1.6 A CHANNEL FUNCTIONAL TEST is performed for the Reactor Mode Switch-Shutdown Position Function to ensure that the entire channel will perform the intended function.

The CHANNEL FUNCTIONAL TEST for the Reactor Mode Switch-Shutdown Position Function is performed by attempting to withdraw any control rod with the reactor mode switch in the shutdown position and verifying a control rod block occurs.As noted in the SR, the Surveillance is not required to be performed until 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after the reactor mode switch is in the shutdown position, since testing of this interlock with the reactor mode switch in any other position cannot be performed without using jumpers, lifted leads, or movable (continued)

I SUSQUEHANNA-UNIT 1 TS / B 3.3-52 Revision -2 PPL Rev. 3 Control Rod Block Instrumentation B 3.3.2.1 BASES (continued)

SURVEILLANCE SR 3.3.2.1.6 (continued)

REQUIREMENTS links. This allows entry into MODES 3 and 4 if the 24-month-Frequency is not met per SR 3.0.2. The 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> allowance is based on operating experience and in consideration of providing a reasonable time in which to complete the SRs.The Surveillance Freauencv is controlled under the Surveillance Freguency Control ProciraIiT-ho 24 month FrFequency is bascd on the need to performn po~tieAs Of this Suryeillance undor the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillancc were performoed with thc reactor at power. Operating experience has shown these components usually pass the Su~veillanco when performned at the 24 Fmonth SR 3.3.2.1.7 CHANNEL CALIBRATION is a test that verifies the channel responds to the measured parameter with the necessary range and accuracy.

CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive calibration consistent with the plant specific setpoint methodology.

As noted, neutron detectors are excluded from the CHANNEL CALIBRATION because they are passive devices, with minimal drift, and because of the difficulty of simulating a meaningful signal. Neutron detectors are adequately tested in SR 3.3.1.1.2 and SR 3.3.1.1.8.

The Surveillance Frequency is controlled under the Surveillance Frequency Control ProgramThe Frequency is based upon the asSUm.ption of a 24 month calibration intcrwal in the determ~ination of the magnitude of equipmfent drift i the 6etpoint analysis.SR 3.3.2.1.7 for the RBM Functions is modified by two Notes as identified in Table 3.3.2.1-1.

The RBM Functions are Functions that are LSSSs for reactor core Safety Limits. The first Note requires evaluation of channel performance for the condition where the as-found setting for the channel setpoint is not the NTSP but is conservative with respect to the Allowable Value. For digital channel components, no as-found tolerance or as-left tolerance can be specified.

Evaluation of instrument performance will verify that the instrument will continue to behave in accordance with design-basis assumptions.

The purpose of the assessment is to ensure confidence in the instrument performance prior to returning the instrument to service. These channels will also be identified in the Corrective Action Program.(continued)

SUSQUEHANNA -UNIT 1 TS / B 3.3-53 Revision 2 PPL Rev. 2 Feedwater

-Main Turbine High Water Level Trip Instrumentation B 3.3.2.2 BASES SURVEILLANCE or the applicable Condition entered and Required Actions taken. This REQUIREMENTS Note is based on the reliability analysis (Ref. 2) assumption that 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> (continued) is the average time required to perform channel Surveillance.

That analysis demonstrated that the 6 hour6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> testing allowance does not significantly reduce the probability that the feedwater pump turbines and main turbine will trip when necessary.

SR 3.3.2.2.1 Performance of the CHANNEL CHECK once every 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ensures that a gross failure of instrumentation has not occurred.

A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.

It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between 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.

Agreement criteria, which are determined by the plant staff based on an investigation of a combination of the channel instrument uncertainties, may be used to support this parameter comparison and include indication and readability.

If a channel is outside the criteria, it may be an indication that the instrument has drifted outside its limit, and does not necessarily indicate the channel is Inoperable.

The Surveillance Frequency is controlled under the Surveillance Frequency Control ProqramThe FrequencY is based on operating exp,.ien.

.th demon..trate channel failue .;s rare. The CHANNEL CHECK supplements less formal checks of channel status dudrin normal operational use of the displays associated with the channels Fcquircd by t-he- -GG.SPR 3.3.2.2.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function.(continued)

SUSQUEHANNA

-UNIT 1 TS / B 3.3-60 Revisionig PPL Rev. 2 Feedwater

-Main Turbine High Water Level Trip Instrumentation B 3.3.2.2 BASES SURVEILLANCE SR 3.3.2.2.2 (continued)

REQUIREMENTS The Surveillance Frequency is controlled under the Surveillance Frequency Control Proqra -Th Frequenc of 2 days Or baed o eliability (Ref. 2).This SR is modified by two Notes. Note 1 provides a general exception to the definition of CHANNEL FUNCTIONAL TEST. This exception is necessary because the design architecture of the ICS (e.g. digital control blocks and logic) does not facilitate complete functional testing of all required logic blocks, which input into the combinational logic. (Reference

4) Performance of such a test could result in a plant transient or place the plant in an undo risk situation.

Therefore, for this SR, the CHANNEL FUNCTIONAL TEST verifies acceptable response by verifying the change of state of the "logical blocks" which input into the combinational logic. The required "logical blocks" not tested during the CHANNEL FUNCTIONAL TEST are tested under the LOGIC SYSTEM FUNCTIONAL TEST, SR 3.3.2.2.4.

This is acceptable because operating experience shows that the "logical blocks" not tested during the CHANNEL FUNCTIONAL TEST normally pass the LOGIC SYSTEM FUNCTIONAL TEST, and the testing methodology minimizes the risk of unplanned transients.

Note 2 provides a second specific exception to the definition of CHANNEL FUNCTIONAL TEST. For the Feedwater

-Main Turbine High Water Level Trip Function, certain required channel "logical blocks" are not included in the performance of the CHANNEL FUNCTIONAL TEST.These exceptions are necessary because the circuit design does not facilitate functional testing of the entire channel through to the combinational logic. (Reference

4) Specifically, testing of all required"logical blocks" could lead to unplanned transients.

Therefore, for this circuit, the CHANNEL FUNCTIONAL TEST verifies acceptable response by verifying the actuation of circuit devices up to the point where further testing could result in an unplanned transient. (References 5 and 6) The required "logical blocks" not tested during the CHANNEL FUNCTIONAL TEST are tested under the LOGIC SYSTEM FUNCTIONAL TEST, SR 3.3.2.2.4.

This exception is acceptable because operating experience shows that the devices not tested during the CHANNEL FUNCTIONAL TEST normally pass the LOGIC SYSTEM FUNCTIONAL TEST, and the testing methodology minimizes the risk of unplanned transients.(continued)

I SUSQUEHANNA-UNIT 1 TS / B 3.3-61 Revision -1 PPL Rev. 2 Feedwater

-Main Turbine High Water Level Trip Instrumentation B 3.3.2.2 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.2.2.3 CHANNEL CALIBRATION verifies that 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 Frequency Control ProqramThe Frequency is based upon the assumption of an 24 mon~th calibration interval in the determination of the m~agnitude of equiement d-rift in the- qset-noint analysis.SR 3.3.2.2.4 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required trip logic for a specific channel. The system functional test of the feedwater

-main turbine valves is included as part of this Surveillance and overlaps the LOGIC SYSTEM FUNCTIONAL TEST to provide complete testing of the assumed safety function.

Therefore, if a valve is incapable of operating, the associated instrumentation would also be inoperable.

The Surveillance Frequency is controlled under the Surveillance Frequency Control Proqram-T*-244Tegth Frequency i..s based en the need to pe.4 FR, thi- Su..eillance under the conditiens that apply dWuing a plant outage and the potential for an unplanncd transient if the Surve'.'ilaRce were pe~formed with the reactor at power. Operating experience has shoWn that there components, u~pass the Surve-illance when pe~feFmed at the 24 month FrFequency.

wally REFERENCES

1. FSAR, Section 15.1.2.2. GENE-770-06-1, "Bases for Changes to Surveillance Test Intervals and Allowed Out-of-Service Times for Selected Instrumentation Technical Specifications," February 1991.3. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).(continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.3-62 Revision 0 PPL Rev. Q PAM Instrumentation B 3.3.3.1 BASES ACTIONS E.1 (continued) from full power conditions in an orderly manner and without challenging plant systems.F. 1 Since alternate means of monitoring primary containment area radiation have been developed and tested, the Required Action is not to shut down the plant, but rather to follow the directions of Specification 5.6.7. These alternate means will be temporarily installed if the normal PAM channel cannot be restored to OPERABLE status within the allotted time. The report provided to the NRC should discuss the alternate means used, describe the degree to which the alternate means are equivalent to the installed PAM channels, justify the areas in which they are not equivalent, and provide a schedule for restoring the normal PAM channels.SURVEILLANCE The following SRs apply to each PAM instrumentation Function in REQUIREMENTS Table 3.3.3.1-1.

SR 3.3.3.1.1 Performance of the CHANNEL CHECK occe .very 31 days nsures that a gross failure of instrumentation has not occurred.

A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel against 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 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.

Agreement criteria which are determined by the plant staff based on an investigation of a combination of the channel instrument uncertainties, may be used to support this (continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.3-73 Revision 2 PPL Rev. 9 PAM Instrumentation B 3.3.3.1 BASES SURVEILLANCE REQUIREMENTS SR 3.3.3.1.1 (continued) parameter comparison and include indication and readability.

If a channel is outside the criteria, it may be an indication that the instrument has drifted outside its limit and does necessarily indicate the channel is Inoperable.

The Surveillance Frequency is controlled under the Surveillance Frequency Control ProaqramThe of 31 days is based upon plant operating expriecewith regard to channel OPERABILITY and drift, which demostrtesthat failure of moere than one chann;el of a given FuncGtion i an~y 31 day intcr.al i6 rare. The CHANNEL CHEC:K supplements less formal checks, of channols during normnal operational ure of those displays aprsociated wiith the roquircd channels of this LCOG.SR 3.3.3.1.2 and SR 3.3.3.1.3 A tAI

o 3 o r the,-+,., CHANNE GALIBRTIONI is pefre ever' 02 days G h containment Hydrogen and Oxygen Analyzers Or 24 month1s fGr the othei Functions except for the PCIV! Position Function.

The PCIV Position Function is adequately demonstrated by the Remote Position Indication performed in accordance with 5.5.6, "Inservice Testing Program".CHANNEL CALIBRATION verifies that the channel responds to measured parameter with the necessary range and accuracy, and does not include alarms.The CHANNEL CALIBRATION for the Containment High Radiation instruments shall consist of an electronic calibration of the channel, not including the detector, for range decades above 10 R/hr and a one point calibration check of the detector below 10 R/hr with an installed or portable gamma source.Tho- CHWA NNEL CALIBRATION for the hydrogen analyzersi, use a sample gaS containing:

a) Nominal zero volume percen~t hydrogen, balance nfitrogen and b) Nominal thirty volume percent hydrogen, balance nitoGqený.

The Surveillance Frequency is controlled under the Surveillance Frequency Control ProqramThe Frequency.is based on .p..ating e;peri.nc.

and fWr the 21 month Frequency

on ..... cYith ith ;hc .. uty refeling The FrFequency is based 9n operating exeiec nd for the 21 month FrequencY consistency With the idtrreulncycles.(continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.3-74 Revision 3, PPL Rev. 1-Remote Shutdown System B 3.3.3.2 BASES ACTIONS B.1 (continued)

If the Required Action and associated Completion Time of Condition A are not met, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. The allowed Completion Time is reasonable, based on operating experience, to reach the required MODE from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE As noted at the beginning of the SRs, the SRs for each Remote Shutdown REQUIREMENTS System Instrument Function are located in the SRs column of Table 3.3.3.2-1.

SR 3.3.3.2.1 Performance of the CHANNEL CHECK once .ver; 31 days nsures that a gross failure of instrumentation has not occurred.

A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other 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.

Agreement criteria which are determined by the plant staff based on an investigation of a combination of the channel instrument uncertainties, may be used to support this parameter comparison and include indication and readability.

If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit, and does not necessary indicate the channel is Inoperable.

As specified in the Surveillance, a CHANNEL CHECK is only required for those channels that are normally energized.

The Surveillance Frequency is controlled under the Surveillance Frequency Control ProoqramThe F=.oquoncY is based upon plant operating eXpeienc that dementr~atoc channel failure is rare.(continued)

I SUSQUEHANNA

-UNIT I TS / B 3.3-79 Revision 0 PPL Rev. 4-Remote Shutdown System B 3.3.3.2 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.3.2.2 SR 3.3.3.2.2 verifies each required Remote Shutdown System transfer switch and control circuit performs the intended function.

This verification is performed from the remote shutdown panel. Operation of the equipment from the remote shutdown panel is not necessary.

The Surveillance can be satisfied by performance of a continuity check. This will ensure that if the control room becomes inaccessible, the plant can be placed and maintained in MODE 3 from the remote shutdown panel and the local control stations.The Surveillance Frequency is controlled under the Surveillance Frequency Control ProgramOpeat.ig experienc.e demonstrates that Remote Shutdown System contro' chan;nol usually pacs the Sur-eillance when performed at the I 24 month Frequency.

SR 3.3.3.2.3 CHANNEL CALIBRATION verifies that the channel responds to measured parameter values with the necessary range and accuracy.The Surveillance Frequency is controlled under the Surveillance Frecquency Control ProcqramThe 21, month FrequencY or, ba"ed upon g eer- c oncitency with the typical indut1. ,efuelinFgy cle.REFERENCES

1. 10 CFR 50, Appendix A, GDC 19.2. FSAR 7.4.1.4.3. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 32193)I SUSQUEHANNA

-UNIT 1 TS / B, 3.3-80 Revision 0 PPL Rev. 4-EOC-RPT Instrumentation B 3.3.4.1 BASES SURVEILLANCE time required to perform channel Surveillance.

That analysis demonstrated REQUIREMENTS that the 6 hour6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> testing allowance does not significantly reduce the probability (continued) that the recirculation pumps will trip when necessary.

SR 3.3.4.1.1 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function.This SR is modified by a Note that provides a general exception to the definition of CHANNEL FUNCTIONAL TEST. This exception is necessary because the design of instrumentation does not facilitate functional testing of all required contacts of the relay which input into the combinational logic.(Reference

7) Performance of such a test could result in a plant transient or place the plant in an undo risk situation.

Therefore, for this SR, the CHANNEL FUNCTIONAL TEST verifies acceptable response by verifying the change of state of the relay which inputs into the combinational logic.The required contacts not tested during the CHANNEL FUNCTIONAL TEST are tested under the LOGIC SYSTEM FUNCTIONAL TEST, SR 3.3.4.1.3.

This is acceptable because operating experience shows that the contacts not tested during the CHANNEL FUNCTIONAL TEST normally pass the LOGIC SYSTEM FUNCTIONAL TEST, and the testing methodology minimizes the risk of unplanned transients.

The Surveillance Frequency is controlled under the Surveillance Frequency Control ProcqramTh Frequency of 92 dYc i. based on reliability analysis o, Ref e~eR~e 5 SR 3.3.4.1.2 CHANNEL CALIBRATION verifies that 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.(continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.3-88 Revision 0 PPL Rev. 4-EOC-RPT Instrumentation B 3.3.4.1 BASES SURVEILLANCE SURVEQIR NENS SR 3.3.4.1.2 (continued)

REQUIREMENTS The Surveillance Frequency is controlled under the Surveillance Frequency Control ProqramThe

.i based upon the a.. umption of an 24 month calfibrateon.

iintervwal in the determ~ination of the magnitude of equipment drift i the sotpoint analysis.SR 3.3.4.1.3 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required trip logic for a specific channel. The system functional test of the pump breakers is included as a part of this test, overlapping the LOGIC SYSTEM FUNCTIONAL TEST, to provide complete testing of the associated safety function.

Therefore, if a breaker is incapable of operating, the associated instrument channel(s) would also be inoperable.

The Surveillance Frequency is controlled under the Surveillance Freguency Control ProTSrvaThe 214m Frequency is bacr ed on the need toe peqfourm pontiro of thug uý eill. ance unde .rA the conditions that apply during a plant outage and the petentia!

for an unplanned trancient if the Surveillance

%ve-re perform~ed with the reactor at power.Op~erating experience has shown these cornponents usually pass tho SUrVeil'anee When performed at the 21 month Frcquency.

SR 3.3.4.1.4 This SR ensures that an EOC-RPT initiated from the TSV-Closure and TCV Fast Closure, Trip Oil Pressure-Low Functions will not be inadvertently bypassed when THERMAL POWER is _> 26% RTP. This is performed by a Functional check that ensures the EOC-RPT Function is not bypassed.

Because increasing the main turbine bypass flow can affect this function nonconservatively (THERMAL POWER is derived from first stage pressure) the main turbine bypass valves must not cause the trip Functions to be bypassed when thermal power is _> 26% RTP. If any functions are bypassed at > 26% RTP, either due to open main turbine bypass valves or other reasons, the affected TSV-Closure and TCV Fast Closure, Trip Oil Pressure-Low Functions are considered inoperable.

Alternatively, the bypass channel can be placed in the conservative condition (nonbypass).

If placed in the nonbypass condition, this SR is met with the channel considered OPERABLE.(continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.3-89 Revision 4-PPL Rev. 4 EOC-RPT Instrumentation B 3.3.4.1 BASES SURVEILLANCE SR 3.3.4.1.4 (continued)

REQUIREMENTS The Surveillance Frequency is controlled under the Surveillance Frequency Control Prog ramThe Frequency of 24 months has shown that channel bypa.. failures betheen ...uccessive tests are trae.SR 3.3.4.1.5 This SR ensures that the individual channel response times are less than or equal to the maximum values assumed in the accident analysis.

The EOC-RPT SYSTEM RESPONSE TIME acceptance criteria are included in Reference 5.A Note to the Surveillance states that breaker interruption time may be assumed from the most recent performance of SR 3.3.4.1.6.

This is allowed since the time to open the contacts after energization of the trip coil and the arc suppression time are short and do not appreciably change, due to the design of the breaker opening device and the fact that the breaker is not routinely cycled.EOC RPT SYSTEM RESPONSE TIME tests aFeG Gcdwuted on an 21 month STAGGERED TEST BASIS. For this SR, STAGGERED TEST BASIS m~eans that eac-h 214 month test shall include at least the logic of one type of channel input, turbine control valve fact closure or turbine stop valVe closure such that both types of channel inputs are tosted at least one pe 418 months Response times cannot be determined at power because operation of final actuated devices is required.

The Surveillance Frequency is controlled under the Surveillance Frequency Control ProqramTherefore, the.24.month Frequency i, c .nsictent with the typical industry refueling and i.. based upon plant operating experience, which shows that random fanilures Ofintueaio compRoents that cause eri r ..e time degradation, but nt channel Ta,,s4. Weiitq J IL gUggJ J vJ SR 3.3.4.1.6 This SR ensures that the RPT breaker interruption time (arc suppression time plus time to open the contacts) is provided to the EOC-RPT SYSTEM RESPONSE TIME test. The Surveillance Frequency is controlled under the Surveillance Frequency Control ProqramThe 60 month Fr.equency of the testing is based on the difficulty of performing the test and the iab(lity of the circui bfeakeF&(continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.3-90 Revision 4-PPL Rev. 0 ATWS-RPT Instrumentation B 3.3.4.2 BASES SURVEILLANCE REQUIREMENTS 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 the associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the associated Function maintains ATWS-RPT trip capability.

Upon completion of the Surveillance, or expiration of the 6 hour6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 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 (Ref. 2) assumption of the average time required to perform channel Surveillance.

That analysis demonstrated that the 6 hour6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> testing allowance does not significantly reduce the probability that the recirculation pumps will trip when necessary.

I SR 3.3.4.2.1 Performance of the CHANNEL CHECK once ever; 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. ensures that a gross failure of instrumentation has not occurred.

A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other 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.

Agreement criteria which are determined by the plant staff based on an investigation of a combination of the channel instrument uncertainties, may be used to support this parameter comparison and include indication and readability.

If a channel is outside the criteria, it may be an indication that the instrument has drifted outside its limit, and does not necessarily indicate the channel is inoperable.

The Surveillance Frequency is controlled under the Surveillance Frequency Control ProgramTh:

requency is based upon operating experience that demons., atoc channel failure is rar .The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with the required channels of this LCO.(continued)

I SUSQUEHANNA

-UNIT 1 TS / R 3.3-98 Revision 4-I PPL Rev. 0 ATWS-RPT Instrumentation B 3.3.4.2 BASES SURVEILLANCE SR 3.3.422 REQUIREMENTS (continued)

A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function.This SR is modified by a Note that provides a general exception to the definition of CHANNEL FUNCTIONAL TEST. This exception is necessary because the design of instrumentation does not facilitate functional testing of all required contacts of the relay which input into the combinational logic.(Reference

4) Performance of such a test could result in a plant transient or place the plant in an undo risk situation.

Therefore, for this SR, the CHANNEL FUNCTIONAL TEST verifies acceptable response by verifying the change of state of the relay which inputs into the combinational logic.The required contacts not tested during the CHANNEL FUNCTIONAL TEST are tested under the LOGIC SYSTEM FUNCTIONAL TEST, SR 3.3.4.2.5.

This is acceptable because operating experience shows that the contacts not tested during the CHANNEL FUNCTIONAL TEST normally pass the LOGIC SYSTEM FUNCTIONAL TEST, and the testing methodology minimizes the risk of unplanned transients.

The Surveillance Frequency is controlled under the Surveillance Frequency Control ProqramThe Fr.equency of 92 days i6 based on th

,,,,.YS..

o.ReeFen~e 2.SR 3.3.4.2.3 and SR 3.3.4.2.4 A CHANNEL CALIBRATION verifies that 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 Frequency Control ProqramTh

,-lihbated Frequency is baed upon the a......ption used for the calibrntion intorwal in the deteFmination of the magnitude of equipment dri the 6etpeint analycis.(continued)

I SUSQUEHANNA

-UNIT 1 TS I B 3.3-99 Revision 41 PPL Rev. 0 ATWS-RPT Instrumentation B 3.3.4.2 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.4.2.5 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required trip logic for a specific channel. The system functional test of the pump RPT breakers is included as part of this Surveillance and overlaps the LOGIC SYSTEM FUNCTIONAL TEST to provide complete testing of the assumed safety function.

Therefore, if a breaker is incapable of operating, the associated instrument channel(s) (two channels of Reactor Vessel Water Level--Low Low, Level 2 and two channels of Reactor Steam Dome Pressure--High) would be inoperable.

The Surveillance Frequency is controlled under the Surveillance Frequency Control ProaraThe 24 month Frequency is based on the need to perform this SuProeia.ne unde the condition.

that apply d..ing a plant outage and the potential for an unplanned transient

• if the Surveillance wore perform~ed with the reac-tor at power. Operating experience has shown these components usually pass the Surveillance when perform~ed at thoe 21 month FrFequency.

REFERENCES

1. GENE-637, 024, -0893, Evaluation of SSES ATWS Performance for Power Uprate Conditions, Sept 1993.2. NEDE-770-06-1, "Bases for Changes To Surveillance Test Intervals and Allowed Out-of-Service Times For Selected Instrumentation Technical Specifications," February 1991.3. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 32193).4. NRC Inspection and Enforcement Manual, Part 9900: Technical Guidance, Standard Technical Specification Section 1.0 Definitions, Issue date 12/08/86.I SUSQUEHANNA

-UNIT 1 TS / B 3.3-100 Revision 4-PPL Rev. 3 ECCS Instrumentation B 3.3.5.1 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.5.1.1 Performance of the CHANNEL CHECK once ovr; 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> ensures that a gross failure of instrumentation has not occurred.

A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other 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 guarantees that undetected channel failure is limited te 12 hGWrs; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.

Agreement criteria which are determined by the plant staff based on an investigation of a combination of the channel instrument uncertainties, may be used to support this parameter comparison and include indication and readability.

If a channel is outside the criteria, it may be an indication that the instrument has drifted outside its limit, and does not necessarily indicate the channel is Inoperable.

The Surveillance Frequency is controlled under the Surveillance Frequency Control ProqramThe Frequency

..upon operating experience that d emon.tratec-;

c'h-annel .failue ic Frae. The CHANNEL CHECK supplements less formal checks of channels during normal operational use of the displays associated with the channels required by the LCO.SR 3.3.5.1.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function.

The Surveillance Frequency is controlled under the Surveillance Frequency Control ProaramThe FrequencY of " 2 days is baced on tho reliability analyses oT.RefeFeRnee-&

This SR is modified by a Note that provides a general exception to the definition of CHANNEL FUNCTIONAL TEST. This exception is necessary because the design of instrumentation does not facilitate functional testing of all required contacts of the relay which input into the combinational logic.(Reference

5) Performance of such a test could result in a plant transient or place the plant in an undo risk situation.

Therefore, for this SR, the CHANNEL FUNCTIONAL TEST verifies acceptable response by verifying the (continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.3-132 Revision 0 PPL Rev. 3 ECCS Instrumentation B 3.3.5.1 BASES SURVEILLANCE SR 3.3.5.1.2 (continued)

REQUIREMENTS change of state of the relay which inputs into the combinational logic. The required contacts not tested during the CHANNEL FUNCTIONAL TEST are tested under the LOGIC SYSTEM FUNCTIONAL TEST, SR 3.3.5.1.5.

This is acceptable because operating experience shows that the contacts not tested during the CHANNEL FUNCTIONAL TEST normally pass the LOGIC SYSTEM FUNCTIONAL TEST, and the testing methodology minimizes the risk of unplanned transients.

SR 3.3.5.1.3 and SR 3.3.5.1.4 A CHANNEL CALIBRATION is a complete check that 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 Frequency Control Proqram Te rFrequencGy of SR 3.3.5.1.3 as based upon the accumption of a 92 day calibration interwzl in the determfination of tho magnitude of equipmenpt drif in the cctpeint analysis.The F=requency of SR 3.3.5.1.4 is based upon the assumption of a 214 Mont alibration intIIIal in the determination of the magnitude of equipment drift4in the setpoint anialysis.

SR 3.3.5.1.5 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required initiation logic for a specific channel. The system functional testing performed in LCO 3.5.1, LCO 3.5.2, LCO 3.8.1, and LCO 3.8.2 overlaps this Surveillance to complete testing of the assumed safety function.

The LOGIC SYSTEM FUNCTIONAL TEST tests the operation of the initiation logic up to but not including the first contact which is unique to an individually supported feature such as the starting of a DG.(continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.3-133 Revision 0 PPL Rev. 3 ECCS Instrumentation B 3.3.5.1 BASES SURVEILLANCE SR 3.3.5.1.5 (continued)

REQUIREMENTS The Surveillance Frequency is controlled under the Surveillance Frequency Control ProciramThe 24 -FreuoncY

i. hased on tho need to peForm, , portion Of thi Suilne une tho; Rconditi1; oner that apply during a plant outage and the potential fo an unplanned transient if the Sunxcillancoe were-pwerfored with the reactor at poer9. petigoPerieF;Ge har, shown that there esompont uuly pass the Surveillan-e iwhen; pwerom~ed at the 21 month Frequency.

REFERENCES

1. FSAR, Section 6.3.2. FSAR, Chapter 15.3. NEDC-30936-P-A, "BWR Owners' Group Technical Specification Improvement Analyses for ECCS Actuation Instrumentation, Part 2," December 1988.4. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 32193).5. NRC Inspection and Enforcement Manual, Part 9900: Technical Guidance, Standard Technical Specification Section 1.0 Definitions, Issue date 12/08/86.I SUSQUEHANNA-UNIT 1 TS / B 3.3-134 Revision 0 PPL Rev. 0 RCIC System Instrumentation B 3.3.5.2 BASES ACTIONS D.1, D.2.1, and D.2.2 (continued) to the suppression pool, which also performs the intended function.

If it is not desired to perform Required Actions D.2.1 and D.2.2, Condition E must be entered and its Required Action taken.E. 1 With any Required Action and associated Completion Time not met, the RCIC System may be incapable of performing the intended function, and the RCIC System must be declared inoperable immediately SURVEILLANCE As noted in the beginning of the SRs, the SRs for each RCIC System REQUIREMENTS instrumentation Function are found in the SRs column of Table 3.3.5.2-1.

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 as follows: (a) for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for Function 2 and 4; and (b) for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for Functions other than Function 2 and 4, provided the associated Function maintains trip capability.

Upon completion of the Surveillance, or expiration of the 6 hour6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 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 (Ref. 1) assumption of the average time required to perform channel surveillance.

That analysis demonstrated that the 6 hour6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> testing allowance does not significantly reduce the probability that the RCIC will initiate when necessary.

SR 3.3.5.2.1 Performance of the CHANNEL CHECK once evory 12 heu'- ensures that a gross failure of instrumentation has not occurred.

A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a parameter on other similar (continued)

I SUSQUEHANNA-UNIT T TS / B 3.3-143 Revision 0 PPL Rev. 0 RCIC System Instrumentation B 3.3.5.2 BASES SURVEILLANCE SR 3.3.5.2.1 (continued)

REQUIREMENTS 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.

Agreement criteria which are determined by the plant staff based on an investigation of a combination of the channel instrument uncertainties, may be used to support this parameter comparison and include indication and readability.

If a channel is outside the criteria, it may be an indication that the instrument has drifted outside its limit, and does not necessarily indicate the channel is Inoperable.

The Surveillance Frequency is controlled under the Surveillance Frequency Control Pro iramThe Frequency is based upon operating experience that demonstrates channel failure is rare. The CHANNEL CHECK supplements less formal checks of channels during normal operational use of the displays associated with the channels required by the LCO.SR 3.3.5.2.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function.The Surveillance Frequency is controlled under the Surveillance Frequency Control ProgqramThe F=requency of 92 days is based on the + ,liabi.ity analysis ef

,.This SR is modified by a Note that provides a general exception to the definition of CHANNEL FUNCTIONAL TEST. This exception is necessary because the design of instrumentation does not facilitate functional testing of all required contacts of the relay which input into the combinational logic.(Reference

3) Performance of such a test could result in a plant transient or place the plant in an undo risk situation.

Therefore, for this SR, the CHANNEL FUNCTIONAL TEST verifies acceptable response by verifying (continued)

I SUSQUEHANNA-UNIT 1 TS / B 3.3-144 Revision 0 PPL Rev. 0 RCIC System Instrumentation B 3.3.5.2 BASES SURVEILLANCE REQUIREMENTS SR 3.3.5.2.2 (continued) the change of state of the relay which inputs into the combinational logic. The required contacts not tested during the CHANNEL FUNCTIONAL TEST are tested under the LOGIC SYSTEM FUNCTIONAL TEST, SR 3.3.5.2.5.

This is acceptable because operating experience shows that the contacts not tested during the CHANNEL FUNCTIONAL TEST normally pass the LOGIC SYSTEM FUNCTIONAL TEST, and the testing methodology minimizes the risk of unplanned transients.

SR 3.3.5.2.3 and SR 3.3.5.2.4 A CHANNEL CALIBRATION verifies that 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 Frequency Control ProaqramThe Frequency of SR 3.3.5.2.3 is based upon the assumption of a 92 day calibratio intewal in the determination of the magnitudo of equipment drift in thAre stpeint analvsis-.

The Frequenc.y of SR 3.3.5.2.drift of the equipmnnt and the 4 ef 24 Fn onI'the s based upon the histWorial C300ur"Pt~

~ ~~~. *i i qzr r 1J7 p SR 3.3.5.2.5 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required initiation logic for a specific channel. The system functional testing performed in LCO 3.5.3 overlaps this Surveillance to provide complete testing of the safety function.(continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.3-145 Revision 0 PPL Rev. Q RCIC System Instrumentation B 3.3.5.2 BASES SURVEILLANCE SR 3.3.5.2.5 (continued)

REQUIREMENTS The Surveillance Frequency is controlled under the Surveillance Frequency Control ProqramThe 24 month Frequency is basod on the neoed to perForm portion. of thiGe uriln undor the conditions that apply during a plant ua I nd _ ...th the reactor at power. Operating experience hae, she.own that thes components usually pacs the Survoill-an whn erFomed at the 21 month REFERENCES

1. NEDE-770-06-2, "Addendum to Bases for Changes to Surveillance Test Intervals and Allowed Out-of-Service Times for Selected Instrumentation Technical Specifications," February 1991.2. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 32193).3. NRC Inspection and Enforcement Manual, Part 9900: Technical Guidance, Standard Technical Specification Section 1.0 Definitions, Issue date 12/08/86.I SUSQUEHANNA

-UNIT 1 TS / B 3.3-146 Revision 0 PPL Rev. &Primary Containment Isolation Instrumentation B 3.3.6.1 BASES SURVEILLANCE As noted at the beginning of the SRs, the SRs for each Primary REQUIREMENTS Containment Isolation instrumentation Function are found in the SRs column of Table 3.3.6.1-1.

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 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the associated Function maintains trip capability.

Upon completion of the Surveillance, or expiration of the 6 hour6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 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. 5 and 6) assumption of the average time required to perform channel surveillance.

That analysis demonstrated that the 6 hour6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> testing allowance does not significantly reduce the probability that the PCIVs will isolate the penetration flow path(s) when necessary.

SR 3.3.6.1.1 Performance of the CHANNEL CHECK once ever; 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> ensures that a gross failure of instrumentation has not occurred.

A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other 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 of 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.

Agreement criteria which are determined by the plant staff based on an investigation of a combination of the channel instrument uncertainties, may be used to support this parameter comparison and include indication and readability.

If a channel is outside the criteria, it may be an indication that the instrument has drifted outside its limit, and does not necessarily indicate the channel is Inoperable.

The Surveillance Frequency is controlled under the Surveillance Frequency Control ProaramThe Frequency is ba"ed on .p..ating oxp.. ien. e th. t demonstrates channel fal'urc is rare. The CHANNEL CHECK supplements less formal checks of channels during normal operational use of the displays associated with the channels required by the LCO.(continued)

I SUSQUEHANNA-UNIT 1 TS / B 3.3-177 Revision 4-PPL Rev. &Primary Containment Isolation Instrumentation B 3.3.6.1 BASES SURVEILLANCE SR 3.3.6.1.2 REQUIREMENTS (continued)

A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function.The Surveillance Frequency is controlled under the Surveillance Frequency Control ProuramThe 92 day Fr-equency of SR 3.3.6.1.2 is based en the reliability analysis described in Referencesr 5 and 6.This SR is modified by two Notes. Note 1 provides a general exception to the definition of CHANNEL FUNCTIONAL TEST. This exception is necessary because the design of instrumentation does not facilitate functional testing of all required contacts of the relays which input into the combinational logic. (Reference

11) Performance of such a test could result in a plant transient or place the plant in an undo risk situation.

Therefore, for this SR, the CHANNEL FUNCTIONAL TEST verifies acceptable response by verifying the change of state of the relay which inputs into the combinational logic. The required contacts not tested during the CHANNEL FUNCTIONAL TEST are tested under the LOGIC SYSTEM FUNCTIONAL TEST, SR 3.3.6.1.5.

This is acceptable because operating experience shows that the contacts not tested during the CHANNEL FUNCTIONAL TEST normally pass the LOGIC SYSTEM FUNCTIONAL TEST, and the testing methodology minimizes the risk of unplanned transients.

Note 2 provides a second specific exception to the definition of CHANNEL FUNCTIONAL TEST. For Functions 2.e, 3.a, and 4.a, certain channel relays are not included in the performance of the CHANNEL FUNCTIONAL TEST. These exceptions are necessary because the circuit design does not facilitate functional testing of the entire channel through to the coil of the relay which enters the combinational logic. (Reference 11)Specifically, testing of all required relays would require rendering the affected system (i.e., HPCI or RCIC) inoperable, or require lifting of leads and inserting test equipment which could lead to unplanned transients.

Therefore, for these circuits, the CHANNEL FUNCTIONAL TEST verifies acceptable response by verifying the actuation of circuit devices up to the point where further testing could result in an unplanned transient.(References 10 and 12) The required relays not tested during the CHANNEL FUNCTIONAL TEST are tested under the LOGIC SYSTEM FUNCTIONAL TEST, SR 3.3.6.1.5.

This exception (continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.3-178 Revision -2 PPL Rev. 6 Primary Containment Isolation Instrumentation B 3.3.6.1 BASES SURVEILLANCE REQUIREMENTS SR 3.3.6.1.2 (continued) is acceptable because operating experience shows that the devices not tested during the CHANNEL FUNCTIONAL TEST normally pass the LOGIC SYSTEM FUNCTIONAL TEST, and the testing methodology minimizes the risk of unplanned transients.

SR 3.3.6.1.3 and SR 3.3.6.1.4 A CHANNEL CALIBRATION verifies that 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 FrequencV is controlled under the Surveillance Frequency Control Prog raiTh FrequencY of SR;3.3.6.1.3 is based- on the arumption

f. a 92 day csalibration intcrval in the determination of the magnitudea based en the assu1mption of an 24 month calibration interval inth detPrmination of the magnitude of equipment drift in the cetpeit analysis.It should be noted that ,ome of thoe pimay containment High D;,,, welo pressre istruents, although only required te be calibrated on a 21 monthFrequeny, arc calibrated quarterly based 9n other T-S Fequi~eRentrsr-SR 3.3.6.1.5 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required isolation logic for a specific channel. The system functional testing performed on PCIVs in LCO 3.6.1.3 overlaps this Surveillance to provide complete testing of the assumed safety function.The Surveillance Frequency is controlled under the Surveillance Frequency Control ProgqramThe 24 month Frequen;cy is based on the, need- to pe.form poetions of this Sur'.,eillancc under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were pe"Formed with the reactor at power. Operating experiene has shown these components usually pass the SuIveillance when performed at the 21 month FrFequency.(continued)

I SUSQUEHANNA -UNIT 1 TS / B 3.3-179 Revision -2 PPL Rev. 6 Primary Containment Isolation Instrumentation B 3.3.6.1 BASES SURVEILLANCE SR 3.3.6.1.6 REQUIREMENTS (continued)

This SR ensures that the individual channel response times are less than or equal to the maximum values assumed in the accident analysis.Testing is performed only on channels where the guidance given in Reference 9 could not be met, which identified that degradation of response time can usually be detected by other surveillance tests.As stated in Note 1, the response time of the sensors for Functions l.b, is excluded from ISOLATION SYSTEM RESPONSE TIME testing. Because the vendor does not provide a design instrument response time, a penalty value to account for the sensor response time is included in determining total channel response time. The penalty value is based on the historical performance of the sensor. (Reference

13) This allowance is supported by Reference 9 which determined that significant degradation of the sensor channel response time can be detected during performance of other Technical Specification SRs and that the sensor response time is a small part of the overall ISOLATION RESPONSE TIME testing.Function 1.a and 1 .c channel sensors and logic components are excluded from response time testing in accordance with the provisions of References 14 and 15.As stated in Note 2, response time testing of isolating relays is not required for Function 5.a. This allowance is supported by Reference

9. These relays isolate their respective isolation valve after a nominal 45 second time delay in the circuitry.

No penalty value is included in the response time calculation of this function.

This is due to the historical response time testing results of relays of the same manufacturer and model number being less than 100 milliseconds, which is well within the expected accuracy of the 45 second time delay relay.ISOLATION SYSTEM RESPONSE TIME acceptance criteria are included in Reference

7. This test may be performed in one measurement, or in overlapping segments, with verification that all components are tested.The Surveillance Frequency is controlled under the Surveillance Frequency Control ProqramlSOLA~TlON SYSTEM RESPONSEi TIME tests are cn-educ-tedo an 24 STAGGERED TEST BASIS. The 21 month Fren i, cnietent with the typical industry refueling cye anRd is- ba plant prating experience that shews that random failur~es of instrumentation (continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.3-179a Revision -2 PPL Rev. 6 Primary Containment Isolation Instrumentation B 3.3.6.1 BASES SURVEILLANCE SR 3.3.6.1.6 (continued)

REQUIREMENTS comfpeonontecucn riu roeponc time degradation, bu not channel fail"re, re infrequent occurronc e.REFERENCES

1. FSAR, Section 6.3.2. FSAR, Chapter 15.3. NEDO-31466, "Technical Specification Screening Criteria Application and Risk Assessment," November 1987.4. FSAR, Section 4.2.3.4.3.

5. NEDC-31677P-A, "Technical Specification Improvement Analysis for BWR Isolation Actuation Instrumentation," July 1990.6. NEDC-30851 P-A Supplement 2, "Technical Specifications Improvement Analysis for BWR Isolation Instrumentation Common to RPS and ECCS Instrumentation," March 1989.7. FSAR, Table 7.3-29.8. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).9. NEDO-32291-A "System Analyses for Elimination of Selected Response Time Testing Requirements," October 1995.10. PPL Letter to NRC, PLA-2618, Response to NRC INSPECTION REPORTS 50-387/85-28 AND 50-388/85-23, dated April 22,1986.11. NRC Inspection and Enforcement Manual, Part 9900: Technical Guidance, Standard Technical Specification Section 1.0 Definitions, Issue date 12/08/86.12. Susquehanna Steam Electric Station NRC REGION I COMBINED INSPECTION 50-387/90-20; 50-388/90-20, File R41-2, dated March 5, 1986.13. NRC Safety Evaluation Report related to Amendment No. 171 for License No. NPF-14 and Amendment No. 144 for License No. NPF-22.14. NEDO 32291-A, Supplement 1, "System Analyses for the Elimination of Selected Response Time Testing Requirements," October 1999.(continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.3-179b Revision 0 PPL Rev. 4 Secondary Containment Isolation Instrumentation B 3.3.6.2 BASES SURVEILLANCE REQUIREMENTS (continued) 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. 5 and 6) assumption of the average time required to perform channel surveillance.

That analysis demonstrated the 6 hour6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> testing allowance does not significantly reduce the probability that the SCIVs will isolate the associated penetration flow paths and that the SGT System will initiate when necessary.

SR 3.3.6.2.1 Performance of the CHANNEL CHECK once ever'y 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> ensures that a gross failure of instrumentation has not occurred.

A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other 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.

Agreement criteria which are determined by the plant staff based on an investigation of a combination of the channel instrument uncertainties, may be used to support this parameter comparison and include indication and readability.

If a channel is outside the criteria, it may be an indication that the instrument has drifted outside its limit, and does not necessarily indicate the channel is Inoperable.

The Surveillance Frequency is controlled under the Surveillance Frequency Control ProgramThe Fr.equen.y is baced on operating experience that demonst L. ,* I ;- "f'L t~L A It" I I ,I Ii I Ghauririu ifiiuru is; rFir. The k219N;rIML Unizi..,rx 1 chocks of channel status during normnal eperati associated With channels Fcquirzed by the LCO.I uso of the displays RrI (continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.3-189 Revision -1 PPL Rev. 4 Secondary Containment Isolation Instrumentation B 3.3.6.2 BASES SURVEILLANCE SR 3.3.6.2.2 REQUIREMENTS (continued)

A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function.This SR is modified by a Note that provides a general exception to the definition of CHANNEL FUNCTIONAL TEST. This exception is necessary because the design of instrumentation does not facilitate functional testing of all required contacts of the relay which input into the combinational logic.(Reference

8) Performance of such a test could result in a plant transient or place the plant in an undo risk situation.

Therefore, for this SR, the CHANNEL FUNCTIONAL TEST verifies acceptable response by verifying the change of state of the relay which inputs into the combinational logic.The required contacts not tested during the CHANNEL FUNCTIONAL TEST are tested under the LOGIC SYSTEM FUNCTIONAL TEST, SR 3.3.6.2.5.

This is acceptable because operating experience shows that the contacts not tested during the CHANNEL FUNCTIONAL TEST normally pass the LOGIC SYSTEM FUNCTIONAL TEST, and the testing methodology minimizes the risk of unplanned transients.

The Surveillance Frequency is controlled under the Surveillance Frequency Control Pro qramTho Frequency of 02 days is based on the reliability Refrencos 5 and 6.SR 3.3.6.2.3 and SR 3.3.6.2.4 A CHANNEL CALIBRATION verifies that 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 Frequency Control Proc qraThe Frequencices of SR 3.3.6.2.3 and S-R 3-236-2.4 ar, baed on the asrcumptien of a 92 day and an 21 month calibration intcrwal, Frepectivoly, in the detefrmination of the magnitude of equipment drift in the sotpoint analyir, (continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.3-190 Revision 4-PPL Rev. 4 Secondary Containment Isolation Instrumentation B 3.3.6.2 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.6.2.5 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required isolation logic for a specific channel. The system functional testing performed on SCIVs and the SGT System in LCO 3.6.4.2 and LCO 3.6.4.3, respectively, overlaps this Surveillance to provide complete testing of the assumed safety function.The Surveillance Frequency is controlled under the Surveillance Frequency Control Progra mThe Frequency is based on the Reed t p,.,Fom po.tiOn, of thic Survoillanco undor the conditions that apply a plant outage and the potential for an unplanned tranciont if the Survoillance wore pe&rfored with the reactor at power-.Operating eXperience has shown that there components usually pass the Surweillanco when performned at the 21 mon~th FrequencY.

REFERENCES

1. FSAR, Section 6.3.2. FSAR, Chapter 15 3. FSAR, Section 15.2.4. FSAR, Sections 15.7.5. NEDC-31677P-A, "Technical Specification Improvement Analysis for BWR Isolation Actuation Instrumentation," July 1990.6. NEDC-30851P-A Supplement 2, "Technical Specifications Improvement Analysis for BWR Isolation Instrumentation Common to RPS and ECCS Instrumentation," March 1989.7. Final Policy Statement on Technical Specifications Improvements, July 22, 1993. (58 FR 32193)8. NRC Inspection and Enforcement Manual, Part 9900: Technical Guidance, Standard Technical Specification Section 1.0 Definitions, Issue date 12/08/86.I SUSQUEHANNA -LUNIT 1 TS / B 3.3-191 Revision 4-1 PPL Rev. 2 CREOAS System Instrumentation B83.3.7.1 BASES ACTIONS D.1 (continued)

With any Required Action and associated Completion Time not met, the associated CREOAS subsystem must be declared inoperable immediately per Required Action D.1 to ensure that control room personnel will be protected in the event of a Design Basis Accident.SURVEILLANCE As noted at the beginning of the SRs, the SRs for each CREOAS System REQUIREMENTS instrumentation Function are located in the SRs column of Table 3.3.7.1-1.

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 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, provided the associated Function maintains CREOAS System initiation capability.

Upon completion of the Surveillance, or expiration of the 6 hour6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 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. 3 and 4) assumption of the average time required to perform channel surveillance.

That analysis demonstrated that the 6 hour6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> testing allowance does not significantly reduce the probability that the CREOAS System will initiate when necessary.

SR 3.3.7.1.1 Performance of the CHANNEL CHECK once eve,'y 12 houres cnsures that a gross failure of instrumentation has not occurred.

A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other 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)

I SUSQUEHANNA

-UNIT 1 TS / B 3.3-201 Revision 0 PPL Rev. 2 CREOAS System Instrumentation B 3.3.7.1 BASES SURVEILLANCE SR 3.3.7.1.1 (continued)

REQUIREMENTS Agreement criteria, which are determined by the plant staff based on an investigation of a combination of the channel instrument uncertainties, may be used to support this parameter comparison and include indication and readability.

If a channel is outside the criteria, it may be an indication that the instrument has drifted outside its limit, and does not necessarily indicate the channel is Inoperable.

The Surveillance Frequency is controlled under the Surveillance Frequency Control Pro ramThe FrequencY

i. based upon ope.ating 9;....onc.

that deFmnStratec chaRnel failure is rare. The CHANNEL CHECK supplements less formal checks of channel status during normal operational 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.The Surveillance Frequency is controlled under the Surveillance Frequency Control ProaqramTho Frequency of .2 days is based on the ro..ability analysec o Reforncccs 3 and 4.This SR is modified by two Notes. Note 1 provides a general exception to the definition of CHANNEL FUNCTIONAL TEST. This exception is necessary because the design of instrumentation does not facilitate functional testing of all required contacts of the relays which input into the combinational logic. (Reference

6) Performance of such a test could result in a plant transient or place the plant in an undo risk situation.

Therefore, for this SR, the CHANNEL FUNCTIONAL TEST verifies acceptable response by verifying the change of state of the relay which inputs into the combinational logic. The required.

contacts not tested during the CHANNEL FUNCTIONAL TEST are tested under the LOGIC SYSTEM FUNCTIONAL TEST, SR 3.3.7.1.5.

This is acceptable because operating experience shows that the contacts not tested during the CHANNEL FUNCTIONAL TEST normally pass the LOGIC SYSTEM FUNCTIONAL TEST, and the testing methodology minimizes the risk of unplanned transients.(continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.3-202 Revision 0 PPL Rev. 2 CREOAS System Instrumentation B 3.3.7.1 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.7.1.2 Note 2 provides a second specific exception to the definition of CHANNEL FUNCTIONAL TEST. For Function 8, certain channel relays are not included in the performance of the CHANNEL FUNCTIONAL TEST. These exceptions are necessary because the circuit design does not facilitate functional testing of the entire channel through to the coil of the relay, which enters the combinational logic. (Reference 6)Specifically, testing of all required relays would require lifting of leads and inserting test equipment, which could lead to unplanned transients.

Therefore, for these circuits, the CHANNEL FUNCTIONAL TEST verifies acceptable response by verifying the actuation of circuit devices up to the point where further testing would result in an unplanned transient.(References 7 and 8) The required relays not tested during the CHANNEL FUNCTIONAL TEST are tested under the LOGIC SYSTEM FUNCTIONAL TEST, SR 3.3.7.1.5.

This is acceptable because operating experience shows that the devices not tested during the CHANNEL FUNCTIONAL TEST normally pass the LOGIC SYSTEM FUNCTIONAL TEST, and the testing methodology minimizes the risk of unplanned transients.

SR 3.3.7.1.3 and SR 3.3.7.1.4 A CHANNEL CALIBRATION verifies that 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 Frequency Control ProgramThe r.equenci..

of SIR 3.3.7.1.3 and SIR 3.3.7.1.4 arc based upon the assumption of a 92 day and a 21 mon.th calibration anteria respectivelly, in the detorMination of the magnitude of equipment drift i h (continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.3-203 Revision 0 PPL Rev. 2 CREOAS System Instrumentation B 3.3.7.1 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.7.1.5 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required initiation logic for a specific channel. The system functional testing performed in LCO 3.7.3, "Control Room Emergency Outside Air Supply (CREOAS) System," overlaps this Surveillance to provide complete testing of the assumed safety function.The Surveillance Frequency is controlled under the Surveillance Frequency Control ProgramThe 214 mnth Frequency i,. based on the need to perForm portion" o9f this Survepillance under the conditions that apply during a plant outage and tho ptential f or an unplanned transient if the u.... ,eilan...

wo.performed with the reactor at power. Operating experience has shown there components usually paSs the Su.veillance when peformed at the 21 month FrFequency.

REFERENCES

1. FSAR, Section 6.4.1.2. FSAR, Table 15.2.3. GENE-770-06-1, "Bases for Changes to Surveillance Test Intervals and Allowed Out-of-Service Times for Selected Instrumentation Technical Specifications," February 1991.4. NEDC-31677P-A, "Technical Specification Improvement Analysis for BWR Isolation Actuation Instrumentation," July 1990.5. Final Policy Statement on Technical Specification Improvements, July 22, 1993 (58 FR 32193).6. NRC Inspection and Enforcement Manual, Part 9900: Technical Guidance, Standard Technical Specification Section 1.0 Definitions, Issue date 12/08/86.7. PPL Letter to NRC, PLA-2618, Response to NRC INSPECTION REPORTS 50-387/85-28 and 50-388/85-23, dated April 22, 1986.8. Susquehanna Steam Electric Station NRC REGION I COMBINED INSPECTION 50-387/90-20; 50-388/90-20, File R41-2, dated March 5, 1986.I SUSQUEHANNA

-UNIT 1 TS / B 3.3-204 Revision 0 PPL Rev. 2 LOP Instrumentation B 3.3.8.1 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.8.1.1 Performance of the CHANNEL CHECK once eve;y 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> ensures that a gross failure of instrumentation has not occurred.

A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other 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.

Agreement criteria which are determined by the plant staff based on an investigation of a combination of the channel instrument uncertainties, may be used to support this parameter comparison and include indication and 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 Frequency Control Prog amThe F=requency is b ,ased upo. operating c ..... e that demonstrates channel failurFe is rare. The CHANNEL CHECK supplements less formal checks of channels during normal operational use of the displays associated with channels required by the LCO.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.The Surveillance Frequency is controlled under the Surveillance Frequency Control ProgramThe Frequenc.y of 31 days is based on operating experience..th regard to channel OPERABILITY and drift, which deMOnStrates that failure of more than one channel of a given Function in anY 31 day inteval is a rare event SR 3.3.8.1.3 A CHANNEL CALIBRATION verifies that the channel responds to the measured parameter within the necessary range and (continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.3-211 Revision 0 PPL Rev. 2 LOP Instrumentation B 3.3.8.1 BASES SURVEILLANCE REQUIREMENTS SR 3.3.8.1.3 (continued) 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.

The Surveillance Frequency is controlled under the Surveillance Frecquency Control ProcqramThe Frequoncy.

i based upon the assumption of an 24 month the setpeint analysie.9t tH0 E19RIWER" et equip eHt thl SR 3.3.8.1.4 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required actuation logic for a specific channel. The system functional testing performed in LCO 3.8.1 and LCO 3.8.2 overlaps this Surveillance to provide complete testing of the assumed safety functions.

The Surveillance Frequency is controlled under the Surveillance Frequency Control ProgramThe 214 month Frequency is bared on the need to perform p...ins" of this Survgeillance under the conditions that apply during a plant outage and the p ;tential for an unplanned transient if the Surve.llance were pe-form.ed with the reactor at power. Operating cxper.ien"ce has ,hown thee F~eqUeRGY.

REFERENCES

1. FSAR, Section 6.3.2. FSAR, Chapter 15.3. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 32193)I SUSQUEHANNA

-UNIT 1 TS / B 3.3-212 Revision 0 PPL Rev. G RPS Electric Power Monitoring B 3.3.8.2 BASES ACTIONS D.1, D.2.1, and D.2.2 (continued)

In addition, action must be immediately initiated to either restore one electric power monitoring assembly to OPERABLE status for the inservice power source supplying the required instrumentation powered from the RPS bus (Required Action D.2.1) or to isolate the RHR Shutdown Cooling System (Required Action D.2.2). Required Action D.2.1 is provided because the RHR Shutdown Cooling System may be needed to provide core cooling. All actions must continue until the applicable Required Actions are completed.

SURVEILLANCE REQUIREMENTS SR 3.3.8.2.1 A CHANNEL FUNCTIONAL TEST is performed on each overvoltage, undervoltage, and underfrequency system to ensure that the entire channel will perform the intended function.

Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology.

As noted in the Surveillance, the CHANNEL FUNCTIONAL TEST is only required to be performed while the plant is in a condition in which the loss of the RPS bus will not jeopardize steady state power operation (the design of the system is such that the power source must be removed from service to conduct the Surveillance).

The 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> is intended to indicate an outage of sufficient duration to allow for scheduling and proper performance of the Surveillance.

The 184 day Frequency and th, Note in the Surveillance is aFe-based on guidance provided in Generic Letter 91-09 (Ref. 2).The 184 day Frequency is based on Reference

2. The Surveillance Frequency is controlled under the Surveillance Frequency Control Procqram SR 3.3.8.2.2 CHANNEL CALIBRATION verifies that 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.(continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.3-218 Revision 0 PPL Rev. 0 RPS Electric Power Monitoring B 3.3.8.2 BASES SURVEILLANCE REQUIREMENTS SR 3.3.8.2.2 (continued)

The Surveillance Frequency is controlled under the Surveillance Frequency Control Pro'rarThe Frequency is ba.ed on the a,-umpti;n of an 24 month calibration inter.val in the determination of the magnitude of equpment drift in the setpeint analysis.SR 3.3.8.2.3 Performance of a system functional test demonstrates that, with a required system actuation (simulated or actual) signal, the logic of the system will automatically trip open the associated power monitoring assembly.

Only one signal per power monitoring assembly is required to be tested. This Surveillance overlaps with the CHANNEL CALIBRATION to provide complete testing of the safety function.

The system functional test of the Class 1 E circuit breakers is included as part of this test to provide complete testing of the safety function.

If the breakers are incapable of operating, the associated electric power monitoring assembly would be inoperable.

The Surveillance Frequency is controlled under the Surveillance Frequency Control ProgramThe 21 month Frequency is bared on the need te this Survellane under the conditioes that apply during a plant outage and the potential for an unplanned transiont if the SurVeillance were perfo~rmed with the reactor at power. Operating experience has shown that tho components usually pace the Surveillance when performned at the 21 month REFERENCES

1. FSAR, Section 8.3.1.6.2. NRC Generic Letter 91-09, "Modification of Surveillance Interval for the Electrical Protective Assemblies in Power Supplies for the Reactor Protection System 3. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 32193)I SUSQUEHANNA

-UNIT 1 TS / B 3.3-219 Revision 0 PPL Rev. 4 Recirculation Loops Operating B 3.4.1 BASES SURVEILLANCE SR 3.4.1.1 (continued)

REQUIREMENTS The mismatch is measured in terms of core flow. If the flow mismatch exceeds the specified limits, the loop with the lower flow is considered inoperable.

The SR is not required when both loops are not in operation since the mismatch limits are meaningless during single loop or natural circulation operation.

The Surveillance must be performed within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after both loops are in operation.

The Surveillance Frequency is controlled under the Surveillance Frequency Control ProqramThe 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Froquency is , cnsistent with the Su,'oillance FrequncY for' jo- p EWR..ILITY and has bcen shown by operating eXperionce to be adequate to detect Off norma jet pump loop flows in a timely m.anner.SR 3.4.1.2 As noted, this SR is only applicable when in single loop operation.

This SR ensures the recirculation pump limit is maintained.

The Surveillance Frequency is controlled under the Surveillance Frequency Control ProqramThe 24 heuw Frequency is, based on operating exporience and the operatorineren knowledge of the current reactor statue.REFERENCES

1. FSAR, Section 6.3.3.7.2. FSAR, Section 5.4.1.4.3. GE NEDO-31960-A "BWROG Long Term Stability Solutions Licensing Methodology," November 1995.4. GE NEDO-31960-A "BWROG Long Term Stability Solutions Licensing Methodology, Supplement 1," November 1995.5. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).I SUSQUEHANNA-UNIT 1 TS / B 3.4-6 Revision 2 PPL Rev. 3 Jet Pumps B 3.4.2 BASES SURVEILLANCE SR 3.4.2.1 (continued)

REQUIREMENTS drive flow versus pump speed) are determined by the flow resistance from the loop suction through the jet pump nozzles. A change in the relationship indicates a plug, flow restriction, loss in pump hydraulic performance, leakage, or new flow path between the recirculation pump discharge and jet pump nozzle. For this criterion, loop drive flow versus pump speed relationship must be verified.

Note that recirculation pump speed is directly proportional to recirculation motor generator speed (Reference 5).Therefore, recirculation motor generator speed can be used for the purposes of this surveillance.

Individual jet pumps in a recirculation loop normally do not have the same flow. The unequal flow is due to the drive flow manifold, which does not distribute flow equally to all risers. The flow (or jet pump diffuser to lower plenum differential pressure) pattern or relationship of one jet pump to the loop average is repeatable.

An appreciable change in this relationship is an indication that increased (or reduced) resistance has occurred in one of the jet pumps. This may be indicated by an increase in the relative flow for a jet pump that has experienced beam cracks.The deviations from normal are considered indicative of a potential problem in the recirculation drive flow or jet pump system (Ref. 2). Normal flow ranges and established jet pump flow and differential pressure patterns are established by plotting historical data as discussed in Reference 2.The Surveillance Frequency is controlled under the Surveillance Frequency Control ProgqramThe 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Frequency has been shown by .pe.ating experience to be timely for detecting jet pump degrndatien and is concistent with tho Sur.eillance rFrequency for WeiFG.Ulation loop QPE-R-A.B-I1ITY verifirsatiGR.

This SR is modified by two Notes. If this SR has not been performed in the previous 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> at the time an idle recirculation loop is restored to service, Note 1 allows 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> after the idle recirculation loop is in operation before the SR must be completed because these checks can only be performed during jet pump operation.

The 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> is an acceptable time to establish conditions and complete data collection and evaluation.

Note 2 allows deferring completion of this SR until 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after THERMAL POWER is greater than 23% of RTP. During low flow conditions, jet pump noise approaches the threshold (continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.4-13 Revision 2-PPL Rev. 0 RCS Operational LEAKAGE B 3.4.4 BASES ACTIONS C.1 and C.2 (continued) based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant safety systems.SURVEILLANCE REQUIREMENTS The RCS LEAKAGE is monitored by a variety of instruments designed to provide alarms when LEAKAGE is indicated and to quantify the various types of LEAKAGE. Leakage detection instrumentation is discussed in more detail in the Bases for LCO 3.4.6, "RCS Leakage Detection Instrumentation." Sump level and flow rate are typically monitored to determine actual LEAKAGE rates; however, any method may be used to quantify LEAKAGE within the guidelines of Reference

5. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.in conjunction with alarmes and other adMinistratiVo contFGrol, a 12 heuF FrFquencY for this Sur'eillance is appropriate for identifying LEAKAGE and for Frocking required trendr (Ref. 6). The leakage limit of 2 gpmice in LEAKAGE within the pra.ious 4 hoer .erified by firet determ~ining leakage does not icroaee by more than 2 gpm in the preyiouc 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> period and if leakage is found to have inrGeasod by >2 qpm, if a -2 gpm incrsFae occ.urred ovo any 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> REFERENCES

1. 10 CFR 50, Appendix A, GDC 30.2. GEAP-5620, April 1968.3. NUREG-76/067, October 1975.4. FSAR, Section 5.2.5.4.5. Regulatory Guide 1.45.6. Generic Letter 88-01, Supplement 1.7. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).I SUSQUEHANNA

-UNIT 1 TS / B 3.4-23 Revision 0 PPL Rev. 3 RCS Leakage Detection Instrumentation B 3.4.6 BASES ACTIONS B.1 and B.2 (continued) restoration recognizes that at least one other form of leakage detection is available.

C.1 and C.2 If any Required Action of Condition A or B cannot be met within the associated Completion Time, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and MODE 4 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. The allowed Completion Times are reasonable, based on operating experience, to perform the actions in an orderly manner and without challenging plant systems.D. 1 With all required monitors inoperable, no required automatic means of monitoring LEAKAGE are available, and immediate plant shutdown in accordance with LCO 3.0.3 is required.SURVEILLANCE REQUIREMENTS SR 3.4.6.1 This SR is for the performance of a CHANNEL CHECK of the required primary containment atmospheric monitoring system. The check gives reasonable confidence that the channel is operating properly.

The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.The Fr.equenc.y of 12 hur-s r,, based on inc.rume.t Feiability and is Foasonable for detecting Off noFrmal renditions.(continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.4-33 Revision 4-1 PPL Rev. 3 RCS Leakage Detection Instrumentation B 3.4.6 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.4.6.2 This SR is for the performance of a CHANNEL FUNCTIONAL TEST of the required RCS leakage detection instrumentation.

The test ensures that the monitors can perform their function in the desired manner. The Surveillance Frequency is controlled under the Surveillance Frequency Control Procqram.The Fr.quenc.y of 31 days cnider, intrum6ent reliability, and operating eXPerience hac6 chown it proper for detecting dogradation.

SR 3.4.6.3 This SR is for the performance of a CHANNEL CALIBRATION of required leakage detection instrumentation channels.

The calibration verifies the accuracy of the instrument string, including the instruments located inside containment.

The Surveillance Frequency is controlled under the Surveillance Frequency Control Proqram.The of 24 months ir a typical refueling c.ycle and consider%GllIelilI liab4*.REFERENCES

1. 10 CFR 50, Appendix A, GDC 30.2. Regulatory Guide 1.45, May 1973.3. FSAR, Section 5.2.5.1.2.

4. GEAP-5620, April 1968.5. NUREG-75/067, October 1975.6. FSAR, Section 5.2.5.4.7. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).I SUSQUEHANNA-UNIT 1 TS / B 3.4-34 Revision 0 PPL Rev. 2 RCS Specific Activity B 3.4.7 BASES (continued)

SURVEILLANCE REQUIREMENTS SR 3.4.7.1 This Surveillance is performed to ensure iodine remains within limit during normal operation.

The Surveillance Frequency is controlled under the Surveillance Frequency Control Progiram.The 7 Fr ieuat-the idin.e level.This SR is modified by a Note that requires this Surveillance to be performed only in MODE 1 because the level of fission products generated in other MODES is much less.REFERENCES

1. Deleted.2. FSAR, Section 15.6.4.3. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).I SUSQUEHANNA

-UNIT 1 TS / B 3.4-38 Revision 41 PPL Rev. 2 RHR Shutdown Cooling System-Hot Shutdown B 3.4.8 BASES ACTIONS B.1, B.2, and B.3 (continued) and is modified such that the 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> is applicable separately for each occurrence involving a loss of coolant circulation.

Furthermore, verification of the functioning of the alternate method must be reconfirmed every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter.

This will provide assurance of continued temperature monitoring capability.

During the period when the reactor coolant is being circulated by an alternate method (other than by the required RHR shutdown cooling subsystem or recirculation pump), the reactor coolant temperature and pressure must be periodically monitored to ensure proper function of the alternate method.The once per hour Completion Time is deemed appropriate.

SURVEILLANCE SR 3.4.8.1 REQUIREMENTS This Surveillance verifies that one RHR shutdown cooling subsystem or recirculation pump is in operation and circulating reactor coolant. The required flow rate is determined by the flow rate necessary to provide sufficient decay heat removal capability.

The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.The Frequency of 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> is sufficient in viow of other visual and audible indiations afamilablee to the operator for monitoring the RHR subsystem i h This Surveillance is modified by a Note allowing sufficient time to align the RHR System for shutdown cooling operation after the pressure interlock that isolates the system resets, or for placing a recirculation pump in operation.

The Note takes exception to the requirements of the Surveillance being met (i.e., forced coolant circulation is not required for this initial 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> period), which also allows entry into the Applicability of this Specification in accordance with SR 3.0.4 since the Surveillance will not be "not met" at the time of entry into the Applicability.

REFERENCES

1. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).I SUSQUEHANNA

-UNIT 1 TS / B 3.4-43 Revision 0 PPL Rev. 4 RHR Shutdown Cooling System-Cold Shutdown B 3.4.9 BASES ACTIONS B.1 and B.2 (continued)

During the period when the reactor coolant is being circulated by an alternate method (other than by the required RHR Shutdown Cooling System or recirculation pump), the reactor coolant temperature and pressure must be periodically monitored to ensure proper function of the alternate method.The once per hour Completion Time is deemed appropriate.

SURVEILLANCE SR 3.4.9.1 REQUIREMENTS This Surveillance verifies that one RHR shutdown cooling subsystem or recirculation pump is in operation and circulating reactor coolant. The required flow rate is determined by the flow rate necessary to provide sufficient decay heat removal capability.

The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.The Fr4eguoncy of 12 houre is suff irient in view of other visu-ial and audible indications available to the operator for mo~nitoring the RHR cUbGYctom in tho REFERENCES

1. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).I SUSQUEHANNA

-UNIT 1 TS / B 3.4-48 Revision 0 PPL Rev. 3 RCS P/T Limits B 3.4.10 BASES ACTIONS B.1 and B.2 (continued)

Pressure and temperature are reduced by placing the plant in at least MODE 3 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in MODE 4 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.C.1 and C.2 Operation outside the P/T limits in other than MODES 1, 2, and 3 (including defueled conditions) must be corrected so that the RCPB is returned to a condition that has been verified by stress analyses.

The Required Action must be initiated without delay and continued until the limits are restored.Besides restoring the P/T limit parameters to within limits, an evaluation is required to determine if RCS operation is allowed. This evaluation must verify that the RCPB integrity is acceptable and must be completed before approaching criticality or heating up to > 200 0 F. Several methods may be used, including comparison with pre-analyzed transients, new analyses, or inspection of the components.

ASME Code,Section XI, Appendix E (Ref. 6), may be used to support the evaluation; however, its use is restricted to evaluation of the beltline.SURVEILLANCE SR 3.4.10.1 REQUIREMENTS Verification that operation is within limits (i.e., to the right of the applicable curves in Figures 3.4.10-1 through 3.4.10-3) is required eve.y 30 Minu.tes when RCS pressure and temperature conditions are undergoing planned changes. The Surveillance Frequency is controlled under the Surveillance Frequency Control ProgramThis FrequencY is ,ensidered reasonable in view o.the control roomA indication available to MOR4oF RCS8 status11-.

Also, 6ince temnperature rate Of change limits arc specified in hoUrlY inrGemnents, 30 mninutes prm~its a reasonable time for assessmnent and coFrrec~tion nof mi deviateeR&

Surveillance for heatup, cooldown, or inservice leakage and hydrostatic testing may be discontinued when the criteria given in the relevant plant procedure for ending the activity are satisfied.

This SR has been modified with a Note that requires this Surveillance to be performed only during system heatup and cooldown operations and inservice leakage and hydrostatic testing.(continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.4-54 Revision -2 PPL Rev. 3 RCS P/T Limits B 3.4.10 BASES SURVEILLANCE REQUIREMENTS SR 3.4.10.7, SR 3.4.10.8, and SR 3.4.10.9 (continued)

The Surveillance Frequency is controlled under the Surveillance Frequency Control Pro~qram 1 The fan.g. tempe.atures must be v..ifiod to be above the limFit 30 m~inutee, before and while tensioning the vessel head bolti9ng studs, to ens6ure that onco the head is tensioned the lim~its are satisfied.*

When in MODE 4 with RCS temporatura

!i 802F, 30 minute checks of the flange temperatre ar reurd because of the reduced margin to the imite.WheR E 4I ,with RCS temperature

<. 1 00 0 F, monitorin-g f the flange temprature is required ers to ensure the temperature is within the specified limits.The 30 m~inute FrequencGy reflects the urgency of maintainingth temperatures within limits, and also limite; the ti~me that the temperature limfitso could be eXceeded.

The- 12 ho-ur FrequencY is reasonable based on the rate of temperature change possible at these temperatueres REFERENCES

1. 10 CFR 50, Appendix G.2. ASME, Boiler and Pressure Vessel Code,Section XI, Appendix G.3. ASTM E 185-73.4. 10 CFR 50, Appendix H.5. Regulatory Guide 1.99, Revision 2, May 1988.6. ASME, Boiler and Pressure Vessel Code, Section Xl, Appendix E.7. NEDO-21778-A, December 1978.8. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).9. PPL Calculation EC-062-0573, "Study to Support the Bases Section of Technical Specification 3.4.10." 10. FSAR, Section 15.4.4.11. Regulatory Guide 1.190, March 2001.12. FSAR, Section 4.1.4.5.I SUSQUEHANNA

-UNIT 1 TS / B 3.4-57 Revision 3 PPL Rev. G Reactor Steam Dome Pressure B 3.4.11 BASES APPLICABILITY (continued) pressure is well below the required limit, and no anticipated events will challenge the overpressure limits.ACTIONS A.. 1 With the reactor steam dome pressure greater than the limit, prompt action should be taken to reduce pressure to below the limit and return the reactor to operation within the bounds of the analyses.

The 15 minute Completion Time is reasonable considering the importance of maintaining the pressure within limits. This Completion Time also ensures that the probability of an accident occurring while pressure is greater than the limit is minimized.

If the operator is unable to restore the reactor steam dome pressure to below the limit, then the reactor should be placed in MODE 3 to be operating within the assumptions of the transient analyses.B. 1 If the reactor steam dome pressure cannot be restored to within the limit within the associated Completion Time, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. The allowed Completion Time of 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> is reasonable, based on operating experience, to reach MODE 3 from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS SR 3.4.11.1 Verification that reactor steam dome pressure is < 1050 psig ensures that the initial conditions of the over-pressurization analysis are met. The Surveillance Frequency is controlled under the Surveillance Frequency Control Proqramvperting e .peri.n..

has shown the 112 hour0.0013 days <br />0.0311 hours <br />1.851852e-4 weeks <br />4.2616e-5 months <br /> Froequ.Y to be rufcon~-t for identifying trende and Yerifying oporti.n within safety anlalyco, assumptien&-(continued)

Revision 4 I SUSQUEHANNA

-UNIT 1 TS / B 3.4-59 PPL Rev. 2 ECCS-Operating B 3.5.1 BASES SURVEILLANCE SR 3.5.1.1 (continued)

REQUIREMENTS full of water ensures that the ECCS will perform properly, injecting its full capacity into the RCS upon demand. This will also prevent a water hammer following an ECCS initiation signal. One acceptable method of ensuring that the lines are full is to vent at the high points. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.Tho 31 day Frequency is based on the gradual nature of void buildup in the EGGS piping, the c"ntrol go..rnin .ystem; operation, and operating experiene SR 3.5.1.2 Verifying the correct alignment for manual, power operated, and automatic valves in the ECCS flow paths provides assurance that the proper flow paths will exist for ECCS operation.

This SR does not apply to valves that are locked, sealed, or otherwise secured in position since these were verified to be in the correct position prior to locking, sealing, or securing.

A valve that receives an initiation signal is allowed to be in a nonaccident position provided the valve will automatically reposition in the proper stroke time.This SR does not require any testing or valve manipulation; rather, it involves verification that those valves capable of potentially being mispositioned are in the correct position.

This SR does not apply to valves that cannot be inadvertently misaligned, such as check valves. For the HPCI System, this SR also includes the steam flow path for the turbine and the flow controller position.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.The 31 day Fr.equency of this SR war, derived fromA the inser:.cc TestiRg Program requirementS for pcrF-ming valve testing at least once eve'y 02 days. The Frcgquency of 31 days is further justified because the valve6 are operated under procedural control and becaus imrprvalve posfitio would only affect a single subsystem.

This Frequenc asbe shown to be acceptable through operating experience.

This SR is modified by a Note that allows LPCI subsystems to be considered OPERABLE during alignment and operation for decay heat removal with reactor steam dome pressure less than the RHR cut in permissive pressure in MODE 3, if capable of being manually realigned (remote or local) to the (continued)

I SUSQUEHANNA-UNIT 1 TS / B 3.5-10 Revision 0 PPL Rev. 2 ECCS-Operating B 3.5.1 BASES SURVEILLANCE SR 3.5.1.2 (continued)

REQUIREMENTS LPCI mode and not otherwise inoperable.

This allows operation in the RHR shutdown cooling mode during MODE 3, if necessary.

SR 3.5.1.3 Verification

every3, day-that ADS gas supply header pressure is>_ 135 psig ensures adequate gas pressure for reliable ADS operation.

The accumulator on each ADS valve provides pneumatic pressure for valve actuation.

The design pneumatic supply pressure requirements for the accumulator are such that, following a failure of the pneumatic supply to the accumulator, at least one valve actuations can occur with the drywell at 70%of design pressure.The ECCS safety analysis assumes only one actuation to achieve the depressurization required for operation of the low pressure ECCS. This minimum required pressure of _> 135 psig is provided by the containment instrument gas system. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.The 31 day Fr=equencY takes into consfideration admi~nistratie conPetrols over operation; of the gas System and alarms as.ociated with the containment instrument gas system.SR 3.5.1.4 Verification every 31 day&-that at least one RHR System cross tie valve is closed and power to its operator is disconnected ensures that each LPCI subsystem remains independent and a failure of the flow path in one subsystem will not affect the flow path of the other LPCI subsystem.

Acceptable methods of removing power to the operator include opening the breaker, or racking out the breaker, or removing the breaker. If both RHR System cross tie valves are open or power has not been removed from at least one closed valve operator, both LPCI subsystems must be considered inoperable.

The Surveillance Frequency is controlled under the Surveillance Frequency Control Proqram.The 31 day Frequencay has been found acceptable, considering that these valves are under strict administratiVe cOntrols that will ensure the valves continue to remain with motive power removed.(continued)

I SUSQUEHANNA-UNIT 1 TS / B 3.5-11 Revision 4-PPL Rev. 2 ECCS-Operating B 3.5.1 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.5.1.5 Verification eeiy-3---dayer-that each 480 volt AC swing bus transfers automatically from the normal source to the alternate source on loss of power while supplying its respective bus demonstrates that electrical power is available to ensure proper operation of the associated LPCI inboard injection and minimum flow valves and the recirculation pump discharge and bypass valves. Therefore, each 480 volt AC swing bus must be OPERABLE for the associated LPCI subsystem to be OPERABLE.

The test is performed by actuating the load test switch or by disconnecting the preferred power source to the transfer switch and verifying that swing bus automatic transfer is accomplished.

The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.The 31 day FrFequencY hac been found to be acceptable through operating9 SR 3.5.1.6 Cycling the recirculation pump discharge and bypass valves through one complete cycle of full travel demonstrates that the valves are mechanically OPERABLE and provides assurance that the valves will close when required to ensure the proper LPCI flow path is established.

Upon initiation of an automatic LPCI subsystem injection signal, these valves are required to be closed to ensure full LPCI subsystem flow injection in the reactor via the recirculation jet pumps. De-energizing the valve in the closed position will also ensure the proper flow path for the LPCI subsystem.

Acceptable methods of de-energizing the valve include opening the breaker, or racking out the breaker, or removing the breaker.The specified Frequency is once during reactor startup before THERMAL POWER is > 25% RTP. However, this SR is modified by a Note that states the Surveillance is only required to be performed if the last performance was more than 31 days ago. Therefore, implementation of this Note requires this test to be performed during reactor startup before exceeding 25% RTP.Verification during reactor startup prior to reaching > 25% RTP is an exception to the normal Inservice Testing Program generic valve cycling Frequency-of-Q2--dys, but is considered acceptable due to (continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.5-12 Revision 0 PPL Rev. 2 ECCS-Operating B 3.5.1 BASES SURVEILLANCE SR 3.5.1.7, SR 3.5.1.8, and SR 3.5.1.9 (continued)

REQUIREMENTS completed and there is no indication or reason to believe that HPCI is inoperable.

Therefore, SR 3.5.1.8 and SR 3.5.1.9 are modified by Notes that state the Surveillances are not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after the reactor steam pressure and flow are adequate to perform the test.The Frequency for SR 3.5.1.7 and SR 3.5.1.8 is in accordance with the Inservice Testing Program requirements.

The Surveillance Frequency for SR 3.5.1.9 is controlled under the Surveillance Frequency Control Program.RThe 21 month Frequency fo SR 3.6.1.9 is based on the need to perform the Susueillanye under the cqnditiens that apply just prora to OrF dring a staitup ftom a plant outage. Operating perifien e has shewr that these intiptoncts usually pass the SR When performed at the 21 month Frequency, LPhIch is bcased on the refueling cycle. Therefore, the Frequengy as; cncl luded t bc aceptablo s em froa reliability gtandpeintg SR 3.5.1.10 The ECCS subsystems are required to actuate automatically to perform their design functions.

This Surveillance verifies that, with a required system initiation signal (actual or simulated), the automatic initiation logic of HPCI, CS, and LPCI will cause the systems or subsystems to operate as designed, including actuation of the system throughout its emergency operating sequence, automatic pump startup and actuation of all automatic valves to their required positions.

This functional test includes the LPCI and CS interlocks between Unit 1 and Unit 2 and specifically requires the following:

A functional test of the interlocks associated with the LPCI and CS pump starts in response to an automatic initiation signal in Unit 1 followed by a false automatic initiation signal in Unit 2;A functional test of the interlocks associated with the LPCI and CS pump starts in response to an automatic initiation signal in Unit 2 followed by a false automatic initiation signal in Unit 1; and (continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.5-14 Revision G PPL Rev. 2-ECCS-Operating B 3.5.1 BASES SURVEILLANCE SR 3.5.1.10 (continued)

REQUIREMENTS A functional test of the interlocks associated with the LPCI and CS pump starts in response to simultaneous occurrences of an automatic initiation signal in both Unit 1 and Unit 2 and a loss of Offsite power condition affecting both Unit 1 and Unit 2.The purpose of this functional test (preferred pump logic) is to assure that if a false LOCA signal were to be received on one Unit simultaneously with an actual LOCA signal on the second Unit, the preferred LPCI and CS pumps are started and the non-preferred LPCI and CS pumps are tripped for each Unit. This functional test is performed by verifying that the non-preferred LPCI and CS pumps are tripped. The verification that preferred LPCI and CS pumps start is performed under a separate surveillance test. Only one division of LPCI preferred pump logic is required to be OPERABLE for each Unit, because no additional failures needs to be postulated with a false LOCA signal. If the preferred or non-preferred pump logic for CS is inoperable, the associated CS pumps shall be declared inoperable and the pumps should not be operated to ensure that the opposite Unit's CS pumps or 4.16 kV ESS Buses are protected.

This SR also ensures that the HPCI System will automatically restart on an RPV low water level (Level 2) signal received subsequent to an RPV high water level (Level 8) trip and that the suction is automatically transferred from the CST to the suppression pool. The LOGIC SYSTEM FUNCTIONAL TEST performed in LCO 3.3.5.1 overlaps this Surveillance.

This SR can be accomplished by any series of sequential overlapping or total steps such that the entire channel is tested.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.The 24 month Frequency is acceptable bec~ause-operating experience has shown that these componcnts usually pass the SR when performed at the 21 month Frequency, Which is barsed on the refueling cycle. Therefore, the Frequencsy Was concluded to be acceptable from; a Feliability standpoint.

This SR is modified by a Note that excludes vessel injection/spray during the Surveillance.

Since all active components are testable and full flow can be demonstrated by recirculation through the test line, coolant injection into the RPV is not required during the Surveillance.(continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.5-15 Revision 0 PPL Rev. 2 ECCS-Operating B 3.5.1 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.5.1.11 The ADS designated S/RVs are required to actuate automatically upon receipt of specific initiation signals. A system functional test is performed to demonstrate that the mechanical portions of the ADS function (i.e., solenoids) operate as designed when initiated either by an actual or simulated initiation signal, causing proper actuation of all the required components.

SR 3.5.1.12 and the LOGIC SYSTEM FUNCTIONAL TEST performed in LCO 3.3.5.1 overlap this Surveillance to provide complete testing of the assumed safety function.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.The 24 month Frcquency ir, based on the need to perform portions of the Survcillance under tho conditions that apply during a plant outage and the poten~tai Tor an unpiannca ra-ns-ie-nt iT me buriiianco Wore poFFomee Rht the reactor at power. Operating experience has shown that the components usually pass the SR When performed at the 21 month FrFequency, which is based en the refueling cycle. T-herefore, the Frequency WVn dtV.ItUD**%DDWD,.DDI.W*D*t, e "C1DD t W U t This SR is modified by a Note that excludes valve actuation.

This prevents an RPV pressure blowdown.SR 3.5.1.12 A manual actuation of each ADS valve is performed to verify that the valve and solenoid are functioning properly.

This is demonstrated by one of the two methods described below. Proper operation of the valve tailpipes is ensured through the use of foreign material exclusion during maintenance.

One method is by manual actuation of the ADS valve under hot conditions.

Proper functioning of the valve and solenoid is demonstrated by the response of the turbine control or bypass valve or by a change in the measured flow or by any other method suitable to verify steam flow.Adequate reactor steam dome pressure must be available to perform this test to avoid damaging the valve due to seat impact during closure. Also, adequate steam flow must be passing through the main turbine or turbine bypass valves to continue to control reactor pressure when the ADS valves divert steam flow upon opening. Sufficient time is therefore allowed after the required pressure and flow are achieved to perform this SR. Adequate pressure at which this SR is to be performed is 150 psig. However, the requirements of SR 3.5.1.12 are met by a successful performance at any pressure.

Adequate steam flow is represented by at least 1.25 turbine bypass valves open. Reactor startup is allowed prior to performing this SR by this method because valve OPERABILITY and the setpoints for (continued)

I SUSQUEHANNA

-UNIT I TS / B 3.5-16 Revision 4-PPL Rev. 2 ECCS-Operating B 3.5.1 BASES SURVEILLANCE SR 3.5.1.12 (continued)

REQUIREMENTS overpressure protection are verified, per ASME requirements, prior to valve installation.

Therefore, this SR is modified by a Note that states the Surveillance is not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam pressure and flow are adequate to perform the test. The 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> allowed for manual actuation after the required pressure is reached is sufficient to achieve stable conditions and provides adequate time to complete the Surveillance.

Another method is by manual actuation of the ADS valve at atmospheric temperature and pressure during cold shutdown.

When using this method, proper functioning of the valve and solenoid is demonstrated by visual observation of actuator movement.

Actual disc travel is measured during valve refurbishment and testing per ASME requirements.

Lifting the valve at atmospheric pressure is the preferred method because lifting the valves with steam flow increases the likelihood that the valve will leak. The Note that modifies this SR is not needed when this method is used because the SR is performed during cold shutdown.SR 3.5.1.11 and the LOGIC SYSTEM FUNCTIONAL TEST performed in LCO 3.3.5.1 overlap this Surveillance to provide complete testing of the assumed safety function.

The Surveillance Frequency is controlled under the Surveillance Frequency Control Proqram.The Fr-equcnc';

of 24 months on a STAGGERED TEST [BASIS cncsures th~1-4,4 -; ~-,F A1 fl~c 1+ r + 1 aý -------------

p E.. ...* lt* 1^ ^i~I , At based on the need to perfoRm; the SurveiIlanroI under the coditinOWR that apply just prior to OF during a starFup from a plant outage. Operating experience has shown that these comnpnenets usually pass the SIR whesn performed at the 21 month IFrequency, Which is based on the r-efuoling cycle-.Therefore, the FrFequencay was concluded to be acceptable from a reliability SR 3.5.1.13 This SR ensures that the ECCS RESPONSE TIME for each ECCS injection/spray subsystem is less than or equal to the maximum value assumed in the accident analysis.

Response Time testing acceptance criteria are included in Reference 13.This SR is modified by a Note that allows the instrumentation portion of the response time to be assumed to be based on historical response time data and therefore, is excluded from the ECCS RESPONSE TIME testing. This is allowed since the instrumentation response time is a small part of the ECCS RESPONSE TIME (e.g., sufficient margin exists in the diesel generator start time when compared to the instrumentation response time) (Ref. 14).(continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.5-17 Revision -1 PPL Rev. 2 ECCS-Operating B 3.5.1 BASES SURVEILLANCE SR 3.5.1.13 (continued)

REQUIREMENTS The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.The 24 mnth is consi.tent with the typical indurtr; refueling cycle and is acceptable based upon plant operating REFERENCES

1. FSAR, Section 6.3.2.2.3.

2. FSAR, Section 6.3.2.2.4.

3. FSAR, Section 6.3.2.2.1.

4. FSAR, Section 6.3.2.2.2.

5. FSAR, Section 15.2.4.6. FSAR, Section 15.2.5.7. FSAR, Section 15.2.6.8. 10 CFR 50, Appendix K.9. FSAR, Section 6.3.3.10. 10 CFR 50.46.11. FSAR, Section 6.3.3.12. Memorandum from R.L. Baer (NRC) to V. Stello, Jr. (NRC),"Recommended Interim Revisions to LCOs for ECCS Components," December 1, 1975.13. FSAR, Section 6.3.3.3.14. NEDO 32291-A, "System Analysis for the Elimination of Selected Response Time Testing Requirements, October 1995.15. Final Policy Statement on Technical Specifications Improvements, July 22, 1993 (58 FR 39132).I SUSQUEHANNA

-UNIT I TS / B 3.5-18 Revision 4-1 PPL Rev. 0 ECCS Shutdown B 3.5.2 BASES SURVEILLANCE SR 3.5.2.1 and SR 3.5.2.2 (continued)

REQUIREMENTS the other required ECCS subsystem has adequate makeup volume.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.Thoe 12 hourF FrequneRY of thero SRs was developod considering operating expriece elated to suppression pool water level and CST watcr level vaiatio and ind the appliGable MODES. FrPthermore, the 12 hur as considered adequate iview of other indications; available in the control room, inldn lamt lort the operator to an abnormnal suppression pool or O.ST water level condition.

SR 3.5.2.3, SR 3.5.2.5, SR 3.5.2.6, and SR 3.5.2.7 The Bases provided for SR 3.5.1.1, SR 3.5.1.7, SR 3.5.1.10, and SR 3.5.1.13 are applicable to SR 3.5.2.3, SR 3.5.2.5, SR 3.5.2.6 and SR 3.5.2.7, respectively.

SR 3.5.2.4 Verifying the correct alignment for manual, power operated, and automatic valves in the ECCS flow paths provides assurance that the proper flow paths will exist for ECCS operation.

This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since these valves were verified to be in the correct position prior to locking, sealing, or securing.

A valve that receives an initiation signal is allowed to be in a nonaccident position provided the valve will automatically reposition in the proper stroke time. This SR does not require any testing or valve manipulation; rather, it involves verification that those valves capable of potentially being mispositioned are in the correct position.

This SR does not apply to valves that cannot be inadvertently misaligned, such as check valves. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.The 31 day FrFequency is approepriate because the valves are operated under procedural control ad the probability of their being mispositionedthis time peFred is low.In MODES 4 and 5, the RHR System may operate in the shutdown cooling mode to remove decay heat and sensible heat from the reactor. There-fore, RHR valves that are required for LPCI (continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.5-23 Revision 0 PPL Rev. 2 RCIC System B 3.5.3 BASES ACTIONS B.1 and B.2 (continued) are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in a orderly manner and without challenging plant systems.SURVEILLANCE SR 3.5.3.1 REQUIREMENTS The flow path piping has the potential to develop voids and pockets of entrained air. Maintaining the pump discharge line of the RCIC System full of water ensures that the system will perform properly, injecting its full capacity into the Reactor Coolant System upon demand. This will also prevent a water hammer following an initiation signal. One acceptable method of ensuring the line is full is to vent at the high points. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.The 31 day Frequency is based on the gr-adual nature of void buildup in the RCIC piping, the procedural controls goenigstem operation, and epeFatWng xperience.

SR 3.5.3.2 Verifying the correct alignment for manual, power operated, and automatic valves in the RCIC flow path provides assurance that the proper flow path will exist for RCIC operation.

The SR does not apply to valves that are locked, sealed, or otherwise secured in position since these valves were verified to be in the correct position prior to locking, sealing, or securing.

A valve that receives an initiation signal is allowed to be in a nonaccident position provided the valve will automatically reposition in the proper stroke time. This SR does not require any testing or valve manipulation; rather, it involves verification that those valves capable of potentially being mispositioned are in the correct position.

This SR does not apply to valves that cannot be inadvertently misaligned, such as check valves. For the RCIC System, this SR also includes the steam flow path for the turbine and the flow controller position.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.The 31 day Frequency of this SIR was derived from the lse (oe Testing Program requiements fo performing valve testing at least once every 92 days. The FrFequencay of (continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.5-28 Revision 0 PPL Rev. 2 RCIC System B 3.5.3 BASES SURVEILLANCE SR 3.5.3.2 (continued)

REQUIREMENTS 31 days is fu'ther juMtified beause the valve, are operated under procedura4 Gontrol and impror ,,'ho position would affect only the System. This Frequency-hans boen. sshown to be acceptable threoug operating ep.e ec.SR 3.5.3.3 and SR 3.5.3.4 The RCIC pump flow rates ensure that the system can maintain reactor coolant inventory during pressurized conditions with the RPV isolated.

The flow tests for the RCIC System are performed at two different pressure ranges such that system capability to provide rated flow is tested both at the higher and lower operating ranges of the system. Additionally, adequate steam flow must be passing through the main turbine or turbine bypass valves to continue to control reactor pressure when the RCIC System diverts steam flow. Reactor steam pressure is considered adequate when >_ 920 psig to perform SR 3.5.3.3 and >_ 150 psig to perform SR 3.5.3.4. However, the requirements of SR 3.5.3.4 are met by a successful performance at any pressure _< 165 psig. Adequate steam flow is represented by at least 1.25 turbine bypass valves open.Therefore, sufficient time is allowed after adequate pressure and flow are achieved to perform these SRs. Reactor startup is allowed prior to performing the low pressure Surveillance because the reactor pressure is low and the time allowed to satisfactorily perform the Surveillance is short.The reactor pressure is allowed to be increased to normal operating pressure since it is assumed that the low pressure Surveillance has been satisfactorily completed and there is no indication or reason to believe that RCIC is inoperable.

Therefore, these SRs are modified by Notes that state the Surveillances are not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after the reactor steam pressure and flow are adequate to perform the test.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.The rFrequency for SR 3.5.3.3 is determ~ined by the lnser-vice Testing Pogr-am requirements.

The 24 month Frequency for SR 3.5.3.4 is based on the need to perfo~rm the Surveillance under conditions that apply just prior to or during a startup fromn a plant outage. Operating expeiridnce hags shown that these components u.ually pas.. the SR when pe ..r.ed at th 21 month Frequenc.y, which is based on the (continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.5-29 Revision 4-1 PPL Rev. 2 RCIC System B 3.5.3 BASES SURVEILLANCE REQUIREMENTS SR 3.5.3.3 and SR 3.5.3.4 (continued) cycle. Therefor, the rFreqi reliability standpoint.

ueR, y waS concluded to beeptable ftem a SR 3.5.3.5 The RCIC System is required to actuate automatically in order to verify its design function satisfactorily.

This Surveillance verifies that, with a required system initiation signal (actual or simulated), the automatic initiation logic of the RCIC System will cause the system to operate as designed, including actuation of the system throughout its emergency operating sequence; that is, automatic pump startup and actuation of all automatic valves to their required positions.

This test also ensures the RCIC System will automatically restart on an RPV low water level (Level 2)signal received subsequent to an RPV high water level (Level 8) trip and that the suction is automatically transferred from the CST to the suppression pool. The LOGIC SYSTEM FUNCTIONAL TEST performed in LCO 3.3.5.2 overlaps this Surveillance to provide complete testing of the assumed safety function.The Surveillance Frequency is controlled under the Surveillance Frequency Control Progqram.The 21 month Frequency is based on the need to pe-form portions of the Sur-veillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the- RSun'exPilanco wcre performed with the reactor at power. Ope ra t .rience has shown that these components usually pass the SR when performed at the 21 month Froequency, which is based on the refueling cycle. TherefFre, the Frequency was concluded to be acceptable from a Feliability standpoGit.

This SR is modified by a Note that excludes vessel injection during the Surveillance.

Since all active components are testable and full flow can be demonstrated by recirculation through the test line, coolant injection into the RPV is not required during the Surveillance.

REFERENCES

1. 10 CFR 50, Appendix A, GDC 33.2. FSAR, Section 5.4.6.(continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.5-30 Revision 0 PPL Rev. 4 Primary Containment B 3.6.1.1 BASES SURVEILLANCE SR 3.6.1.1.2 (continued)

REQUIREMENTS and also in view of the fact that component failures that might have affected this test are identified by other primary containment SRs. Two consecutive test failures, however, would indicate unexpected primary containment degradation; in this event, as the Note indicates, increasing the Frequency t ..... ...o .24 ,-months is required until the situation is remedied as evidenced by passing two consecutive tests.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.SR 3.6.1.1.3 Maintaining the pressure suppression function of primary containment requires limiting the leakage from the drywell to the suppression chamber. Thus, if an event were to occur that pressurized the drywell, the steam would be directed through downcomers into the suppression pool. This SR measures suppression chamber-to-drywell vacuum breaker leakage to ensure the leakage paths that would bypass the suppression pool are within allowable limits. The total allowable leakage limit is 30% of the SR 3.6.1.1.2 limit. The allowable leakage per set is 12% of the SR 3.6.1.1.2 limit.The leakage is determined by establishing a 4.3 psi differential pressure across the drywell-to-suppression chamber vacuum breakers and verifying the leakage. Thc leakage test is p;f. -rmed over; 24 months. Tho 24 month Frequency was dovclopod conSido~Rng the surveillance must be performed durinig a unit eutage. A Note is provided which allows this Surveillance not to be performed when SR 3.6.1.1.2 is performed.

This is acceptable because SR 3.6.1.1.2 ensures the OPERABILITY of the pressure suppression function including the suppression chamber-to-drywell vacuum breakers.

The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.REFERENCES

1. FSAR, Section 6.2.2. FSAR, Section 15.3. 10 CFR 50, Appendix J, Option B.4. Nuclear Energy Institute, 94-01 (continued)

I SUSQUEHANNA

-UNIT 1 TS / B 3.6-5 Revision 3 PPL Rev. 4 Primary Containment Air Lock B 3.6.1.2 BASES SURVEILLANCE SR 3.6.1.2.1 (continued)

REQUIREMENTS criteria were established based on engineering judgement and industry operating experience.

The periodic testing requirements verify that the air lock leakage does not exceed the allowed fraction of the overall primary containment leakage rate. The Frequency is required by the Primary Containment Leakage Rate Testing Program.The SR has been modified by two Notes, Note 1 states that an inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test. This is considered reasonable since either air lock door is capable of providing a fission product barrier in the event of a DBA. Note 2 requires the results of airlock leakage tests be evaluated against the acceptance criteria of the Primary Containment Leakage Testing Program, 5.5.12. This ensures that the airlock leakage is properly accounted for in determining the combined Type B and C primary containment leakage.SR 3.6.1.2.2 The air lock interlock mechanism is designed to prevent simultaneous opening of both doors in the air lock. Since both the inner and outer doors of an air lock are designed to withstand the maximum expected post accident primary containment pressure, closure of either door will support primary containment OPERABILITY.

Thus, the interlock feature supports primary containment OPERABILITY while the air lock is being used for personnel transit in and out of the containment.

Periodic testing of this interlock demonstrates that the interlock will function as designed and that simultaneous inner and outer door opening will not inadvertently occur. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.(Due to the puroly mechanical nature of this interlock, and given tht the interlock mechanism is not normally challenged when primary containment is used for entry and exit (procedures ;trct adherence to single door openings), this test is onlY required to be performed every 21 moenths. The 21 month frequency is based on the need to porform; this surveillance undePr codtosthat apply during a plant outage, and the potential for loss Of Primar; cotinent OPERABILITY, if the su.veillanc were .p.ford W.ih reactGF at power. The 21 month frequency for the interlock is justified based on§e)peFatin (continued)

I SUSQUEHANNA

-UNIT 1 TS / B T-11,16-13 Revision 0 PPL Rev. 4 Primary Containment Air Lock B 3.6.1.2 BASES SURVEILLANCE SR 3.6.1.2.2 (continued)

REQUIREMENTS exporience.

The 24 month Frequency ic based o n juget and is conridered adequate given tho neloki not chl-ned during the use of the air lock.REFERENCES

1. FSAR, Section 3.8.2.1.2.(continued)

2. 10 CFR 50, Appendix J, Option B.3. FSAR, Section 6.2.4. Final Policy Statement on Technical Specifications Improvements July 22, 1993 (58 FR 39132).I SUSQUEHANNA-UNIT 1 TS / B, 3.6-14 Revision 0 PPL Rev. 4-0 PCIVs B 3.6.1.3 BASES SURVEILLANCE SR 3.6.1.3.1 (continued)

REQUIREMENTS limited periods of time. The Surveillance Frequency is controlled under the Surveillance Frequency Control Proqram.The 31 day Fr-equencsy is consistent with othor PCIV requirements discGussed in SR 3.6.1.3.-2L.

SR 3.6.1.3.2 This SR verifies that each primary containment isolation manual valve and blind flange that is located outside primary containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. The SR helps to ensure that post accident leakage of radioactive fluids or gases outside the primary containment boundary is within design limits.This SR does not require any testing or valve manipulation.

Rather, it involves verification that those PCIVs outside primary containment, and capable of being mispositioned, are in the correct position.

The Surveillance Frequency is controlled under the Surveillance Frequency Control Proqram.Since ,erification of valve position for PCIV. out.ido primary containment us relatively easy, the 31 day Fr.equencY waS cho to provide added aseuranco that the PCIVc are in the correct Two Notes have been added to this SR. The first Note allows valves and blind flanges located in high radiation areas to be verified by use of administrative controls.

Allowing verification by administrative controls is considered acceptable since access to these areas is typically restricted during MODES 1, 2, and 3 for ALARA reasons. Therefore, the probability of misalignment of these PCIVs, once they have been verified to be in the proper position, is low. A second Note has been included to clarify that PCIVs that are open under administrative controls are not required to meet the SR during the time that the PCIVs are open. This SR does not apply to valves that are locked, sealed, or otherwise secured in the closed position, since these were verified to be in the correct position upon locking, sealing, or securing.SR 3.6.1.3.3 This SR verifies that each primary containment manual isolation valve and blind flange that is located inside primary containment and not locked, sealed, or otherwise (continued)

I SUSQUEHANNA

-UNIT I TS / B 3.6-24 Revision 0 PPL Rev. 40 PCIVs B 3.6.1.3 BASES SURVEILLANCE SR 3.6.1.3.3 (continued)

REQUIREMENTS secured and is required to be closed during accident conditions is closed. The SR helps to ensure that post accident leakage of radioactive fluids or gases outside the primary containment boundary is within design limits. For PCIVs inside primary containment, the Frequency defined as "prior to entering MODE 2 or 3 from MODE 4 if primary containment was de-inerted while in MODE 4, if not performed within the previous 92 days" is appropriate since these PCIVs are operated under administrative controls and the probability of their misalignment is low. This SR does not apply to valves that are locked, sealed, or otherwise secured in the closed position, since these were verified to be in the correct position upon locking, sealing, or securing.

Two Notes have been added to this SR. The first Note allows valves and blind flanges located in high radiation areas to be verified by use of administrative controls.

Allowing verification by administrative controls is considered acceptable since the primary containment is inerted and access to these areas is typically restricted during MODES 1, 2, and 3 for ALARA reasons. Therefore, the probability of misalignment of these PCIVs, once they have been verified to be in their proper position, is low. A second Note has been included to clarify that PCIVs that are open under administrative controls are not required to meet the SR during the time that the PCIVs are open.SR 3.6.1.3.4 The traversing incore probe (TIP) shear isolation valves are actuated by explosive charges. Surveillance of explosive charge continuity provides assurance that TIP valves will actuate when required.

Other administrative controls, such as those that limit the shelf life of the explosive charges, must be followed.

The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.The 31 day Frequency ic based on operating experience that a demonstr-ated the rcliability of the explosive charge continuityý.

SR 3.6.1.3.5 Verifying the isolation time of each power operated and each automatic PCIV is within limits is required to demonstrate OPERABILITY.

MSIVs may be excluded from this SR since MSIV (continued)

I SUSQUEHANNA-UNIT 1 TS / B 3.6-25 Revision 0 PPL Rev. 1-0 PCIVs B 3.6.1.3 BASES SURVEILLANCE SR 3.6.1.3.5 (continued)

REQUIREMENTS full closure isolation time is demonstrated by SR 3.6.1.3.7.

The isolation time test ensures that the valve will isolate in a time period less than or equal to that assumed in the Final Safety Analyses Report. The isolation time and Frequency of this SR are in accordance with the requirements of the Inservice Testing Program.SR 3.6.1.3.6 For primary containment purge valves with resilient seals, the Appendix J Leakage Rate Test Interval of 24 menths is sufficient.

The acceptance criteria for these valves is defined in the Primary Containment Leakage Rate Testing Program, 5.5.12.The Surveillance Frequency is controlled under the Surveillance Frequency Control Pro-gram.The SR is modified by a Note stating that the primary containment purge valves are only required to meet leakage rate testing requirements in MODES 1, 2, and 3. If a LOCA inside primary containment occurs in these MODES, purge valve leakage must be minimized to ensure offsite radiological release is within limits.At other times when the purge valves are required to be capable of closing (e.g., during handling of irradiated fuel), pressurization concerns are not present and the purge valves are not required to meet any specific leakage criteria.SR 3.6.1.3.7 Verifying that the isolation time of each MSIV is within the specified limits is required to demonstrate OPERABILITY.

The isolation time test ensures that the MSIV will isolate in a time period that does not exceed the times assumed in the DBA analyses.

This ensures that the calculated radiological consequences of these events remain within regulatory limits. The Frequency of this SR is in accordance with the requirements of the Inservice Testing Program.(continued)

I SUSQUEHANNA-UNIT 1 TS / B 3.6-26 Revision 2