Text

Technical Specification
	ML080300472
Person / Time
Site:	Susquehanna
Issue date:	01/30/2008
From:	; NRC/NRR/ADRO/DORL/LPLI-1
To:	;
	Guzman R
References
	TAC MD3309, TAC MD3310
	Download: ML080300472 (94)
	v • d • e

.(4)

PPL Susquehanna, LLC, pursuant to the Act and 10 CFR Parts 30, 40, and 70, to receive, possess, and use in amounts as required any byproduct, source or.

special nuclear material without restriction to chemical or physical form, for sample analysis or instrument.calibration or associated with radioactive apparatus or components; and (5)

PPL Susquehanna, LLC, pursuant to the Act and.10 CFR.Parts 30, 40, and 70, to possess, but not separate, such byproduct and special nuclear materials as may be produced by the operation of the facility.

C.

This license shall be deemed to contain and' is subject to the conditions specified in the Commission's regulations set forth in 10 CFR Chapter I and is subject to all applicable provisions of the Act and to the rules, regulations and orders of the Commission now or hereafter.in effect; and is subject to the additional. conditions specified or incorporated below:

(1)

Maximum Power Level PPL Susquehanna, LLC is authorized to operate the facility at reactor core power levels not in excess of 3952 megawatts thermal in accordance with the conditions specified herein. The preoperational tests, startup tests, and other items identified in License Conditions 2.C.(36), 2.C.(37), 2.C.(38), and 2.C.(39) to this license shall be completed as specified..

(2)

Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No. 246 and.the Environmental Protection Plan contained in Appendix B, are hereby incorporated in'the license. PPL Susquehanna, LLC shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

For Surveillance Requirements (SRs) that are new in Amendment 178 to Facility Operating License No. NPF-1 4, the first performance is due at the end of the first surveillance interval that begins at implementation of Amendment 178. For SRs that existed prior to Amendment 178, including SRs with modified acceptance criteria and SRs whose frequency of performance is being extended, the first performance is due at the end of the first surveillance interval that begins on the date the Surveillance was last performed prior to implementation of Amendment 178.

(3)

Conduct of Work Activities During Fuel Load and Initial Startup The operating licensee shall review by committee all facility construction, Preoperational Testing, and System Demonstration activities performed concurrently with facility initial fuel loading or with the facility Startup Test Amendment No. 5, +43, 1-78,-1, 1-88, 4+94, 2-35, 2W, 237, 238, 2-39, 24e, 244, 242, 243, 244, 245, 246

-113-(32) Emergency Service Water System (Section 6.3.4, SSER #4)

Prior to startup following the first refueling outage, the operating licensee shall complete design modifications to the emergency service water (ESW) system, approved by the staff, to eliminate single failure in the ESW system which leads to the need for an uncooled residual heat removal (RHR) pump.

(33) The Additional Conditions contained in Appendix C, as revised through Amendment No. 188, are hereby incorporated into this license. PPL Susquehanna, LLC shall operate the facility in accordance with the Additional Conditions.

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

(a)

Fire fighting response strategy with the following elements:

1. Pre-defined coordinated fire response strategy and guidance

2. Assessment of mutual aid fire fighting assets

3. Designated staging areas for equipment and materials

4. Command and control

5. Training of response personnel (b)

Operations to mitigate fuel damage considering the following:

1. Protection and use of personnel assets

2. Communications

3. Minimizing fire spread

4. Procedures for implementing integrated fire response strategy

5. Identification of readily-available pre-staged equipment

6. Training on integrated fire response strategy

7. Spent fuel pool mitigation measures (c)

Actions to minimize release to include consideration of:

1. Water spray scrubbing

2. Dose to onsite responders (35) The licensee shall implement and maintain all Actions required by Attachment 2 to NRC Order EA-06-137, issued June 20, 2006, except the last action that requires incorporation of the strategies into the site security plan, contingency plan, emergency plan and/or guard training and qualification plan, as appropriate.

(36) Potential Adverse Flow Effects These license conditions provide for monitoring, evaluating, and taking prompt action in response to potential adverse flow effects as a result of power uprate operation on plant structures, systems, and components (including verifying the continued structural integrity of the steam dryer).

Amendment No. 5, +-5, +7-8, 1-88, 246

- 14:-

(a)

The following requirements are placed on operation of the PPL Susquehanna, LLC (PPL) facility above the licensed thermal power (CLTP) level* of 3489 megawatts thermal (MWt):

1:

PPL shall obtain at each 3.5% power ascension step up to 107% of 3489 MWt, dryer strain gauge data and compare it to the acceptance criteria during power ascension above 3489 MWt. PPL shall obtain at each 3.5% power ascension step above 107% of 3489 MWt, main steam line strain gauge data and compare it to the limit curve for the dryer strains during power ascension.

2.

PPL shall monitor the main steam line (MSL) strain gauges during power ascension testing above 3489 MWt for increasing pressure fluctuations in the steam lines.

3.

PPL shall hold the facility at each 3.5% ascension step to collect data from License Condition 2.C.(36)(a) and conduct plant inspections and walk-downs, and evaluate steam dryer performance based on the data; shall provide the evaluation to the NRC staff by facsimile or electronic transmission to the NRC project manager upon completion of the evaluation; and shall not increase power above each hold point until 96

/ hours after the NRC project manager confirms receipt of the transmission.

4.

If any acceptance criteria for steam dryer strains at each 3.5% power ascension step up to 107% of 3489 MWt or frequency peak from the MSL strain gauge data exceeds the limit curve for the MSL strains above 107% of 3489 MWt, PPL shall return the facility to a power level at which the acceptance criteria is not exceeded. PPL shall resolve the discrepancy, document the continued structural integrity of the steam dryer, and provide that documentation to the NRC staff by facsimile or electronic transmission to the NRC project manager prior to further increases in reactor power.

5.

In addition to evaluating the dryer instrumentation data and MSL strain gauge data, PPL shall monitor reactor pressure vessel water level instrumentation and MSL piping accelerometers during power ascension above 3489 MWt.. If resonance frequencies are identified as increasing above nominal levels in proportion to instrumentation data, PPL shall stop power ascension, document the continued structural integrity of the steam dryer, and provide that documentation to the NRC staff by facsmilie or electronic transmission to the NRC project manager prior to further increases in reactor power.

6.

Following CPPU start-up testing, PPL shall resolve any discrepancies in the steam dryer analysis and provide that resolution to the NRC staff by facsimile or electronic transmission to the NRC project manager. If the discrepancies are not resolved within 90 days of identification, PPL shall return the facility to a power level at which the discrepancy does not exist.

Amendment No. 65, +5, +7-8, +88, 246 (b)

PPL shall implement the following actions:

1.

PPL shall. provide to NRC the as-built dryer stress reconciliation and load limit.curves 45 days prior to operation. above 3489 MWt.

2.

After the dryer stress analysis is benchmarked to the Unit 1 startup test data (Unit. 1 data taken up to 107 % of 3489 MWt), the benchmark results and updated MSL limit curves shall be provided to the NRC 90 days prior to operation above 107% of 3489 MWt.

3.

In the event that acoustic signals are identified that challenge the limit curve during power ascension above 107%, PPL shall evaluate dryer

..loads and re-establish the acceptance criteria based on the new data, and shall perform an assessment of ACM uncertainty at the acoustic signal frequency.

4.

After reaching 107% of CLTP, PPL shall obtain measurements from the steam dryer instrumentation and establish the steam dryer flow-induced vibration load fatigue margin for the facility, update the dryer stress report, and re-establish the limit curve with the updated ACM load definition and revised instrument uncertainty, which will be provided to the NRC staff.

5.

During power ascension above 107 % CLTP, if an engineering evaluation for the steam dryer is required because a Level 1 acceptance criteria is exceeded, PPL shall perform the structural analysis to address frequency uncertainties up to +/-10 % and assure that peak responses that fall within this uncertainty band are addressed.

6.

PPL shall revise the Post Constant Pressure Power Uprate (CPPU)

Monitoring & Inspection Program to reflect long-term monitoring of plant parameters potentially indicative of steam dryer failure; to reflect consistency of the facility's steam dryer inspection program with General Electric Service Information Letter (SIL) 644, "BWR/3 Steam Dryer Failure," Revision 2; and to identify the NRC Project Manager for the facility as the point of contact for providing Power Ascension Test Plan (PATP) information during power ascension.

7.

PPL shall submit CPPU steam dryer reports to the NRC. Two written reports will be provided to the NRC. These reports will be issued following completion of testing of Unit 1 power ascension to 107% CLTP and 114% CLTP. Each report will include evaluations or corrective actions that were required to assure steam dryer structural integrity. Additionally, they will include relevant data collected at each power step, comparisons to performance criteria (design predictions), and evaluations performed in conjunction with steam dryer structural integrity monitoring.

Amendment No. 5, +5, 17-8, +88, 246

-16.-

8.

PPL shall submit the flow-induced vibration related portions of the CPPU startup test procedure to the NRC,: including methodology for updating-the limit curve, prior to initial power ascension above 3489 MWt.

(c)

PPL shall prepare the CPPU startup test procedureito include the:

.1.

steam dryer strain gauge acceptance criteria to be used up to 107% of CLTP and.the main steam line strain gauge limit curves to be applied for evaluating steam dryer performance above 107% CLTP;

2.

specific hold points and their duration during CPPU power ascension;

3.

activities to be accomplished during hold points;

4.

plant parameters to be monitored;

5.

inspections and walk-downs to be conducted for steam, feedwater, and condensate systems and components during the hold points;

6.

methods to be used to trend plant parameters;

7.

acceptance criteria for monitoring and trending plant parameters, and conducting the walk-downs and inspections;

8.

actions to be taken if acceptance criteria are.not satisfied; and

9.

verification of the completion of commitments and planned actions specified in its application and all supplements to the application in support of the CPPU license amendment request pertaining to the steam dryer prior to power increase above 3489 MWt. PPL shall provide the related CPPU startup test procedure sections to the NRC by facsimile or electronic transmission to the NRC project manager prior to increasing power above 3489 MWt.

(d)

The following key attributes of the PATP shall not be made less restrictive without prior NRC approval:

1.

During initial power ascension testing above 3489.MWt, each test plateau increment shall be approximately 3.5% of 3489 MWt;

2.

Level 1 performance criteria; and

3.

The methodology for establishing the stress criteria used for the Level 1 and Level 2 performance criteria.

Changes to other aspects of the PATP may be made in accordance with the guidance of Nuclear Energy Institute (NEI) 99-04, "Guidelines for Managing NRC Commitments," issued July 1999.

Amendment No. 5, 1-5, +-7-8, +88, 246 (e)

During each scheduled refueling outage until at least two full operating I

cycles at full CPPU conditions have been achieved, a visual inspection I

shall be conducted of all accessible, susceptible locations of the steam I

dryer in accordance with BWRVIP-139 and General*Electric inspection I

guidelines.

(f)

The results of the visual inspections of the steam dryer shall be reported to the NRC staff within 60. days following startup.. The results of the PATP shall be submitted to the NRC staff in a report within 60 days following the completion of all CPPU power ascension testing.

f (g)

This license condition shall expire upon satisfaction of the requirements in License Conditions 2.C.(36)(e) and 2.C.(36)(f) provided that a visual inspection of the steam dryer does not reveal any new unacceptable flaw or unacceptable flaw growth that'is due to fatigue.

(37) Transient Testing (a)

PPL will demonstrate through performance of transient testing on each

SSES unit that the loss of one condensate pump will not.result in a complete loss of reactor feedwater. The test shall be performed on each unit during the unit's CPPU power ascension test program within 336 hours0.00389 days 0.0933 hours 5.555556e-4 weeks 1.27848e-4 months of achieving and prior to exceeding a nominal power level of 3733 MWt with feedwater and condensate flow rates stabilized. PPL shall confirm that the plant response to the transient is as expected in accordance with the acceptance criteria that are established. If a loss of all reactor feedwater occurs as a result of the test, the test failure shall be addressed in accordance with corrective action program requirements I

and the provisions of the power ascension test program prior to continued operation of the SSES Unit above 3489 MWt..

(b)

Unless the NRC issues a letter notifying the licensee that the tests specified by License Condition 2.C.(37)(a) adequately demonstrate that a single condensate pump trip will not result in a loss of all feedwater while operating at the. full CPPU power level of 3952 MWt, PPL shall perform the transient test on either SSES unit (whichever unit is first to achieve the following specified operating conditions) specified by License Condition 2.C.(37)(a) during the power ascension test program while operating at 3872 MWt to 3952 (98% to 100% of the full CPPU power level) with feedwater.and condensate flow rates stabilized. Thetest shall be performed within 90 days of operating at greater than 3733 MWt and within 336 hours0.00389 days 0.0933 hours 5.555556e-4 weeks 1.27848e-4 months of achieving a nominal power level of 3872 MWt with feedwater and condensate flow rates stabilized. PPL will demonstrate through performance of transient testing on either Susquehanna Unit 1 or Unit 2 (whichever unit is first to achieve the specified conditions) that the loss of one condensate pump will not result in a complete loss of reactor feedwater. PPL shall confirm that the plant response to the transient is.

as expected in accordance with the acceptance criteria that are established. If a loss of all feedwater occurs as a result of the test, the test failure shall be addressed in accordance with corrective action Amendment No. 5, +5, 8, +8-8, 246 program requirements and the provisions of the power ascension-test program prior to continued operation of either SSES Unit above 3733 MWt.

(38) Neutronic Methods (a)

An OPRM amplitude setpoint penalty will be applied to account for a reduction in thermal neutrons around the LPRM detectors caused by transients that increase voiding. This penalty will reduce the OPRM scram setpoint according to the methodology described in Response No.

3 of PPL letter, PLA-6306, dated November 30, 2007. This penalty will be applied until NRC evaluation determines that a penalty to account for this phenomenon is not warranted.

(b)

For SSES SLMCPR, a conservatively adjusted pin power distribution uncertainty and bundle power correlation coefficient will be applied as stated in Response No. 4 of PPL letter, PLA-6306, dated November 30, 2007, when performing the analyses in accordance with ANF-524(P)(A),

"Critical Power Methodology for Boiling Water Reactors," using the uncertainty parameters associated with EMF-2158(P)(A) "Siemens Power Corporations Methodology for Boiling Water Reactors:

Evaluation and Validation of CASMO-4/MICROBURN-B2."

(39) Containment Operability for EPU PPL shall ensure that the CPPU containment analysis is consistent with the SSES 1 and 2 operating and emergency procedures. Prior to operation above CLTP, PPL shall notify the NRC project manager that all appropriate actions have been completed.

D.

The operating licensee shall fully implement and maintain in effect all provisions of the Commission-approved physical security, guard training and qualification, and safeguards contingency plans including amendments made pursuant to provisions of the Miscellaneous Amendments and Search Requirements revisions to 10 CFR 73.55 (51 FR 27817 and 27822) and to the authority of 10 CFR 50.90 and 10 CFR 50.54(p). The plans, which contain Safeguards Information protected under 10 CFR 73.21, are entitled: "Susquehanna Steam Electric Station Physical Security Plan," with revisions submitted through September 24, 1987; "Susquehanna Steam Electric Station Guard Training and Qualification Plan," with revisions submitted through May 28, 1985; and "Susquehanna Steam Electric Station Safeguards Contingency Plan," with revisions submitted through September 24, 1987. Changes made in accordance with 10 CFR 73.55 shall be implemented in accordance with the schedules set forth therein.

E.

Exemptions from certain requirements of Appendices G and H to 10 CFR Part 50 are described in the Safety Evaluation Report and Supplements 1 and 2 to the Safety Evaluation Report. In addition, an exemption was requested until receipt of new fuel for first refueling from the requirements for criticality monitors in the spent fuel pool area, 10 CFR Part 70.24. Also, an exemption was Amendment No. 1-3, 8-1-, +7-8, -188, 246 requested from the requirements of Appendix J of 10 CFR Part 50 for the first fuel cycle when performing local leak rate testing of Residual Heat Removal (RHR) relief valves in accordance with Technical Specification 4.6.1.2. This latter exemption is describedin the safety evaluation of.License Amendment No.

13. These exemptions are authorized by law and will not endanger life or property or the common defense and security and are otherwise in the public interest and have been granted pursuant to 10 CFR 50-. 12. Except as here exempted, the facility will operate, to the extent authorized herein, in conformity with the application, as amended, and the rules and regulations of the Commission and the provisions of the Act.

F.

This license is subject to the following additional condition for the protection of the environment:

Before engaging in additional construction or operational activities which may result in a significant adverse environmental impact that was not evaluated or that is significantly greater than that evaluated in the Final Environmental Statement and its Addendum, PPL Susquehanna, LLC shall provide a written notification to the Director of the Office of Nuclear Reactor Regulation and receive written approval from that office before proceeding with such activities.

G.

Deleted.

H.

PPL Susquehanna, LLC shall have and maintain financial protection of such type and in such amounts as the Commission shall require in accordance with Section 170 of the Atomic Energy Act of 1954, as amended, to cover public liability claims.

Amendment No. -27, 488, 2447 246

1.

.In accordance with the Commission's direction in its Statement of Policy, Licensing and Regulatory Policy and Procedures for Environmental Protection;

'Uranium Fuel Cycle Impacts, October 29, 1982, this license is subject to the final resolution of the pending litigation involving Table S-3. See, Natural Resources Defense Council v. NRC, No. 74-1586 (April 27, 1982).

J.

This license is effective as of the date of issuance and shall expire at midnight on July 17, 2022.

FOR.THE NUCLEAR REGULATORY COMMISSION Original signed by Harold R. Denton Harold R. Denton, Director Office of Nuclear Reactor Regulation Attachments:

1..

2.

Appendix A - Technical Specifications (NUREG-0931)

3.

Appendix B - Environmental Protection Plan Date of Issuance: July 17, 1982 (5% Power Issuance)

FOR THE NUCLEAR REGULATORY COMMISSION Original signed by Darrell G. Eisenhut Darrell G. Eisenhut, Director Division of Licensing Office of Nuclear Reactor Regulation Date of Issuance: November 12, 1982 (100% Full Power Issuance)

Amendment No. 5, -88, 246

PPL Rev.

Definitions 1

D1.1 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 consist of the testing of one of the systems, subsystems, channels, or other designated components during the interval specified by the Surveillance Frequency, so that all.

systems, subsystems, channels, or other designated components are tested during rn Surveillance Frequency intervals, where rl is the total number of systems, subsystems, channels, or other designated components 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)

I STAGGERED TEST BASIS THERMAL POWER TURBINE BYPASS SYSTEM RESPONSE TIME SUSQUEHANNA - UNIT 1 1.1-6 Amendment 164, 246

PPL Rev.

Safety Limits (SLs) 2.0 2.0 SAFETY LIMITS (SLs) 2.1 SLs 2.1.1 Reactor Core SLs 2.1.1.1 With the reactor steam dome pressure < 785 psig or core flow

< 10 million lbm/hr:

THERMAL POWER shall be 23% RTP.

2.1.1.2 With the reactor steam dome pressure > 785 psig and core flow

> 10 million Ibm/hr:

MCPR shall be>Ž 1.09 for two recirculation loop operation or> 1.12 for single recirculation loop operation.

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

2.1.2 Reactor Coolant System Pressure SL Reactor steam dome pressure shall be < 1325 psig.

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

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

SUSQUEHANNA -UNIT 1 TS 2.0-1 Amendment 19, 2X, 2,X, X1, 246

PPL Rev.

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

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

APPLICABILITY:

THERMAL POWER Ž23% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

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

B.

Required Action and B.1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion to < 23% RTP.

Time not met.

SUSQUEHANNA - UNIT 1 3.2-1 Amendment 1/8, 246

PPL Rev.

APLHGR 3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE

-FREQUENCY SR 312.1.1 Verify all APLHGRs are less than or equal Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after to the limits specified in the COLR.

in23%

RTP AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter AND Prior to exceeding 44% RTP SUSQUEHANNA - UNIT 1 3.2-2 Amendment 178,246

PPL Rev.

MCPR

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

LCO 3.2.2.

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

APPLICABILITY:

THERMAL POWER Ž 23% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

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

within limits.

B.

Required Action and B.1 Reduce THERMAL 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion POWER to <.23% RTP.

Time not met.

SUSQUEHANNA - UNIT 1 3.2-3 Amendment 1,79, 246

PPL Rev.

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

Ž23% RTP 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after I.

AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , thereafter AND Prior to exceeding 44% RTP SR 3.2.2.2 Determine the MCPR limits.

Once within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after each completion of SRs in 3.1.4 SUSQUEHANNA - UNIT 1 3.2-4 Amendment jX, 246

PPL Rev.

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

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

APPLICABILITY:

THERMAL POWER Ž 23% RTP.

I1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Any LHGR not A.1 Restore LHGR(s) to within limits.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months within limits.

B.

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

< 23% RTP.

Completion Time not met.

SUSQUEHANNA - UNIT 1 3.2-5*

Amendment /8, 246

PPL Rev.

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 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after

>23% RTP AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter AND Prior to exceeding 44% RTP SUSQUEHANNA - UNIT 1 3.2-6 Amendment 1,--8,246

PPL Rev.

RPS Instrumentation 3.3.1.1 ACTIONS (continued)..

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Enter the Condition.referenced in Immediately associated Completion Table 3.3.1.1-1 for the channels.

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

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

<26% RTP.

referenced in Table 3.3.1.1-1.

F. As required by Required F.1 Be in MODE 2.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action D.1 and referenced in Table 3.3.1.1-1.

G. As required by Required G.1 Be in MODE 3.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Action D.1 and referenced in Table 3.3.1.1-1.

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

Table 3.3.1.1-1.

assemblies.

I. As required by Required 1.1 Initiate alternate method to detect 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Action D.1 and and suppress thermal hydraulic referenced in instability oscillations, Table 3.3.1.1-1.

AND

.. 1.2 Restore required channels to 120 days OPERABLE.

J.

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

<23% RTP.

Time of Condition I not met.

SUSQUEHANNA - UNIT 1 TS / 3.3-2 Amendment,?8, 2.ao, 246

PPL Rev.

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS NOTES --

'----I- - -

1.

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

2.

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

SURVEILLANCE FREQUENCY SR 3.3.1.1.1 Perform CHANNEL CHECK.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.1.1.2 Perform CHANNEL CHECK.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SR 3.3.1.1.3 Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER Ž23% RTP.

Verify the absolute difference between the average 7 days power range monitor (APRM) channels and the calculated power is < 2% RTP while operating at

Ž23% RTP.

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 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2.

Perform CHANNEL FUNCTIONAL TEST.

7 days (continued)

SUSQUEHANNA - UNIT 1 TS / 3.3-3 Amendment 1,76, 2T 2,41, 246

PPL Rev.

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.5 Perform CHANNEL FUNCTIONAL TEST.

7 days 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.

7 days SR 3.3.1.1.8 Calibrate the local power range monitors.

2000 MWD/MT average core exposure SR 3.3.1.1.9 NOTE A test of all required contacts does not have to be performed.

Perform CHANNEL FUNCTIONAL TEST.

92 days SR 3.3.1.1.10 Perform CHANNEL CALIBRATION.

92 days (continued)

SUSQUEHANNA - UNIT 1 3.3-4 Amendment 1/8,246

PPL Rev.

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY 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 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2.

Perform CHANNEL CALIBRATION.

184 days 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 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2.

2.

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

Perform CHANNEL FUNCTIONAL TEST 184 days SR 3.3.1.1.13 Perform CHANNEL CALIBRATION.

24 months SR 3.3.1.1.14 Perform CHANNEL FUNCTIONAL TEST.

24 months SR 3.3.1.1.15 Perform LOGIC SYSTEM FUNCTIONAL TEST.

24 months SR 3.3.1.1.16 Verify Turbine Stop Valve-Closure and Turbine 24 months Control Valve Fast Closure, Trip Oil Pressure-Low Functions are not bypassed when THERMAL POWER is Ž 26% RTP.

(continued)

SUSQUEHANNA - UNIT 1 TS / 3.3-5 Amendment 1.78,.2, 246

PPL Rev.

RPS Instrumentation

.3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.17

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

1.

Neutron detectors are excluded.

2.

For Function 5 "n" equals 4 channels for the purpose of determining the STAGGERED TEST BASIS Frequency

3.

For Function 2.e, "n" equals 8 channels for the purpose of determining the STAGGERED TEST BASIS Frequency. Testing of APRM and OPRM outputs shall alternate.

Verify the RPS RESPONSE TIME is within limits.

24 months on a STAGGERED TEST BASIS 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 24 months SR 3.3.1.1.19 Verify OPRM is not bypassed when APRM Simulated 24 months Thermal Power is _> 25% and recirculation drive flow is : value equivalent to the core flow value defined in the COLR.

SR 3.3.1.1.20 Adjust recirculation drive flow to conform to reactor 24 months core flow.

SUSQUEHANNA - UNIT 1 TS / 3.3-6 Amendment I.R1, 2-30,246

PPL Rev.

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

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS:

FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

1. Intermediate Range Monitors

a.

Neutron Flux-High 2

5 (a)

b.

Inop 2

3 3

3(c) 3(c) 5 (a)

G SR 3.3.1.1.1 SR 3.3.1.1.4 SR 3.3.1.1.6 SR 3.3.1.1.7 SR 3.3.1.1.11 SR 3.3.1.1.15 H

SR 3.3.1.1.1 SR 3.3.1.1.5 SR 3.3.1.1.11 SR 3.3.1.1.15 G

SR 3.3.1.1.4 SR 3.3.1.1.15 H

SR 3.3.1.1.5 SR 3.3.1.1.15 G

SR 3.3.1.1.2 SR 3.3.1.1.7 SR 3.3.1.1.8 SR 3.3.1.1.12 SR 3.3.1.1.18 F

SR 3.3.1.1.2 SR 3.3.1.1.3 SR 3.3.1.1.8 SR 3.3.1.1.12 SR 3.3.1.1.18 SR 3.3.1.1.20

< 122/125 divisions of full scale

!5 122/125*divisions of full scale NA NA

_20% RTP

!5 0.55 W

+ 60.7% RTP(b) and

_115.5% RTP (continued)

2. Average Power Range Monitors

a.

Neutron Flux-High (Setdown)

b.

Simulated Thermal Power-High 2

1 (a)

(b)

(c)

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

0.55 (W-AW) + 60.7% RTP when reset for single loop operation per LCO 3.4.1, "Recirculation Loops Operating."

Each APRM channel provides inputs to both trip systems.

I SUSQUEHANNA - UNIT 1 TS 3.3-7 Amendment 1-4 225, 2.W, 24, 246

PPL Rev.

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

Reactor Protection System Instrumentation APPLICABLE 2 CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

2. Average Power Range Monitors (continued)

c.

Neutron Flux-High

d.

Inop

e.

2-Out-Of-4

Voter

f.

OPRM Trip

3. Reactor Vessel Steam Dome Pressure-High

4. Reactor Vessel Water Level-Low, Level 3

5. Main Steam Isolation Valve-Closure

6. Drywell Pressure-High 1,2 1,2 3(c) 3(c) 2

_23% RTP 1,2 1,2

.1,2 3(c) 2 2

8 2

F SR 3.3.1.1.2 SR 3.3.1.1.3 SR.3.3.1.1.8 SR 3.3.1.1.12 SR 3.3.1.1.18 G

SR 3.3.1.1.12 G

SR 3.3.1.1.2 SR 3.3.1.1.12 SR 3.3.1.1.15 SR 3.3.1.1.17 SR 3.3.1.1.2

'SR 3.3.1.1.8

'SR 3.3.1.1.12 SR 3.3.1.1.18 SR 3.3.1.1.19 SR 3.3.1.1.20 G

SR 3.3.1.1.9 GSR 3.3.1.1.10 SR 3.3.1.1.15 GSR 3.3.1.1.1 SR 3.3.1.1.9 SR 3.3.1.1.10 SR 3.3.1.1.15 F

SR 3.3.1.1.9 SR 3.3.1.1.13 SR 3.3.1.1.15 SR 3.3.1.1.17 G

SR 3.3.1.1.9 SR 3.3.1.1.10 SR 3.3.1.1.15 (d)

' 1093 psig

_ 11.5 inches

< 11% closed

< 1.88 psig

_ 120% RTP NA NA (continued)

(C)

(d)

Each APRM channel provides inputs to both trip systems.

See COLR for OPRM period based detection algorithm (PBDA) setpoint limits.

SUSQUEHANNA -UNIT 1 TS / 3.3-8 Amendment 1WIM, 2-30, 246

PPL Rev.

RPS Instrumentation 3.3.1.1 Table 3.3.1.1-1 (page3 of 3)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED.

REFERENCED OTHER:_

CHANNELS, FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE.

ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE*

7. Scram Discharge Volume Water Level-High

a.

Level Transmitter

(.

1,2 5(a) 1,2 5(a) 2

b.

Float Switch

8. Turbine Stop Valve-Closure

9. Turbine Control Valve Fast Closure, Trip Oil Pressure-Low

10. Reactor Mode Switch-Shutdown Position

-26% RTP

>26% RTP 1,2 2

2 2

2 G

SR '3.3.1.1.9 SR 3.3.1.1.13 SR 3.3.1.1.15 H

SR 3.3.1.1.9

SR.3.3.1.1.13 SR 3.3.1.1.15 G.

SR 3.3.1.1.9 SR 3.3.1.1:13 SR 3.3.1.1.15 H

SR 3.3.1.1.9 SR 3.3.1.1.13 SR 3.3.1.1.15 E

SR 3.3.1.1.9 SR 3.3.1.1.13 SR 3.3.1.1.15 SR 3.3.1.1.16 SR '3.3.1.1.17 E

SR 3.3.1.1.9 SR 3.3.1.1.13 SR 3.3.1.1.15 SR 3.3.1.1.16 SR 3.3.1.1.17 G

SR :3.3.1.1.14

" SR 3.3.1.1.15 H

SR.3.3.1.1.14 SR 3.3.1.1.15 G

SR 3.3.1.1.5 SR 3.3.1.1.15 H

SR 3.3.1.1.5 SR 3.3.1.1.15

_66 gallons

< 66 gallons

62 gallons

< 62 gallons

< 7% dosed

Ž_ 460 psig NA

11.

Manual Scram 5(a) 1,2 51a1 NA NA' NA (a)

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

SUSQUEHANNA-UNIT 1 TS / 3.3-9 Amendment 1.76, 2-3, 246

PPL Rev.

Feedwater - Main Turbine High Water Level Trip Instrumentation 3.3.2.2 3.3 INSTRUMENTATION 3.3.2.2 Feedwater - Main Turbine High Water Level Trip Instrumentation LCO 3.3.2.2 Three channels of feedwater main turbine high water level trip instrumentation shall be OPERABLE.

APPLICABILITY:

THERMAL POWER>_ 23% RTP.

.ACTIONS

-S--

..ar - Conit

-o entry....

i--

is l for eah cnNOE Separate Condition entry is allowed for each channel.,

CONDITION REQUIRED ACTION COMPLETION TIME A.

One feedwater - main A.1 Place channel in trip.

7 days turbine high water level trip channel inoperable.

B.

Two or more B.1 Restore feedwater - main 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months feedwater - main turbine highwater level trip turbine high water capability.

level trip channels inoperable.

C.

Required Action and C.1 Reduce THERMAL POWER to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated

<ý23% RTP.

Completion*Time of Conditions A or B not met.

SUSQUEHANNA - UNIT 1 3.3-21 Amendment 1A, 246

PPL Rev.

EOC-RPT Instrumentation 3.3.4.1 3.3 INSTRUMENTATION 3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT) Instrumentation LCO 3.3.4.1

a.

Two channels per trip system for each EOC-RPT instrumentation Function listed below shall be OPERABLE:

1 Turbine Stop Valve (TSV)-Closure; and

2.

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

OR

b.

LCO 3.2.2,."MINIMUM CRITICAL POWER RATIO (MCPR)," limits for inoperable EOC-RPT as specified in the COLR are made applicable.

APPLICABILITY:

THERMAL POWER > 26% RTP.

ACTIONS N O T E,

Separate Condition entry is allowed for each chann CONDITION REQUIRED ACTION COMPLETION TIME A.

One or more channels A.1 Restore channel to OPERABLE 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable, status.

AND OR MCPR limit for A.2 inoperable EOC-RPT Not applicable if inoperable not made applicable, channel is the result of an inoperable breaker.

Place channel in trip.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR (continued)

SUSQUEHANNA - UNIT 1 3.3-29 Amendment/8, 246

PPL Rev.

EOC-RPT Instrumentation 3.3.4.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

(continued)

A.3 Apply the MCPR limit for 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable EOC-RPT as specified in the COLR.

B.

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

RPT trip capability not, maintained.

OR AND MCPR limit for B.2 Apply the MCPR limit for 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months inoperable EOC-RPT inoperable EOC-RPT as not made applicable, specified in the COLR.

C.

Required Action and C.1 Remove the associated 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated recirculation pump from service.

Completion Time not met.

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

< 26% RTP.

SUSQUEHANNA - UNIT 1 3.3-30 Amendment 1,76 246

PPL Rev.

EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS NOTE----

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

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

Perform CHANNEL FUNCTIONAL TEST.

92 days SR 3.3.4.1.2 Perform CHANNEL CALIBRATION. The Allowable Values 24 months shall be:

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 24 months breaker actuation.

SR 3.3.4.1.4 Verify TSV-Closure and TCV Fast Closure, Trip Oil 24 months Pressure-Low Functions are not bypassed when THERMAL POWER is Ž_ 26% RTP.

(continued)

SUSQUEHANNA - UNIT 1 3.3-31 Amendment JA, 246

PPL Rev.

Primary Containment Isolation. Instrumentation 3.3.6.1 Table 13..6.1-1 (page 1 of 6)

Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED FUNCTION OTHER CHANNELS FROM SPECIFIED.

PER TRIP REQUIRED SURVEILLANCE ALLOWABLE CONDITIONS SYSTEM ACTION CA REQUIREMENTS VALUE 1

Main Steam Line Isolation

a.

Reactor Vessel 1,2,3 2

D SR 3.3.6.1.1

_>-136inches Water Level - Low SR 3.3.6.1.2 Low Low, Level 1 SR 3.3.6.1.4 SR 3.3.6.1.5

b.

Main Steam Line 1

2 E

SR 3.3.6.1.2

>841 psig Pressure - Low SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6

c.

Main Steam Line 1,2,3 2 per MSL D

SR 3.3.6.1.1

<- 179 psid Flow-High SR 3.3.6.1.2 SR 3.3.6.1.4 SR 3.3.6.1.5

d.

Condenser Vacuum 1

2 D

SR 3.3.6.1.2

_8.8 inches (a)

(a)

SR 3.3.6.1.3 Hg vacuum SLow 2

3 SR 3.3.6.1.5

e.

Reactor Building 1,2,3 2

D SR 3.3.6.1.2

< 184°F Main Steam Tunnel SR 3.3.6.1.3 Temperature - High SR 3.3.6.1.5

f.

Manual Initiation 1,2,3 G

SR 3.3.6.1.5 NA (continued)

(a)

With any main turbine stop valve not-closed.

SUSQUEHANNA - UNIT 1 TS / 3.3-57 Amendment X1, 246

PPL Rev.

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 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after associated recirculation loop is in operation.

2. Not required to be completed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after > 23% RTP.

Verify at least two of the following criteria (a, 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months b, or c) are satisfied for each operating recirculation loop:

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.

SUSQUEHANNA - UNIT 1 3.4-7 Amendment 1/8,246

PPL Rev.

S/RVs 3.4.3 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.3 Safety/Relief Valves (S/RVs)

LCO 3.4.3 APPLICABILITY:

The safety function of 14 S/RVs shall be OPERABLE.

MODES 1, 2, and 3.

I ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.1 One or more required A.1 Be in MODE 3.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months S/RVs inoperable.

AND A.2 Be in MODE 4.

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SUSQUEHANNA - UNIT 1 3.4-8 Amendment j/8 246

PPL Rev.

RCS P/T Limits 3.4.10 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE

.. :FREQUENCY SR 3.4.10.3 NOTE-------

Only required to be met in MODES 1, 2, 3, and 4 during recirculation pump start.

Verify the difference between the bottom head Once within 15 minutes coolant temperature and the reactor pressure vessel prior to each startup of a (RPV) coolant temperature is < 1450F.

recirculation pump SR 3.4.10.4 NOTE----

Only required to be met in MODES 1, 2, 3, and 4 during recirculation pump start.

Verify the difference between the reactor coolant Once within 15 minutes temperature in the recirculation loop to be started prior to each startup of a and the RPV coolant temperature is _ 500F.

recirculation pump SR 3.4.10.5 Only required to be met in single loop operation when:

a.

THERMAL POWER *27% RTP; or

b.

The operating recirculation loop flow

< 21,320 gpm.

Verify the difference between the bottom head Once within 15 minutes coolant temperature and the RPV coolant prior to an increase in temperature is < 1450F.

THERMAL POWER or

__an increase in loop flow (continued)

SUSQUEHANNA - UNIT 1 3.4-27 Amendment 416 246

PPL Rev.

RCS P/T Limits 3.4.10 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.10.6

NOTE'-------,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

<500F.

an increase in loop flow.

SR 3.4.10.7 NOT-.

Only required to be performed when tensioning the reactor vessel head bolting studs.

Verify reactor vessel flange and head flange 30 minutes temperatures are > 700F.

SR 3.4.10.8 NT----------------

Not required to be performed until 30 minutes after RCS temperature < 800F in MODE 4.

Verfy reactor vessel flange and head flange 30 minutes temperatures are _. 70°F.

.(continued)

SUSQUEHANNA - UNIT 1 3.4-28 Amendment 1A 246

PPL Rev.

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE

.FREQUENCY SR 3.6.1.3.10 Remove and test the explosive squib from each 24 months on a shear isolation valve of the TIP System.

STAGGERED TEST BASIS 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 In accordance secondary containment bypass leakage with the Primary paths is < 9 scfh when pressurized to Containment

> Pa.

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 !5300 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 1T TS / 3.6-15 AmendmentX4246

PPL Rev..

RHRSW.System and UHS 3.7.1 3.7 PLANT SYSTEMS 3.7.1 Residual Heat Removal Service Water (RHRSW) System and the Ultimate Heat Sink (UHS)

LCO 3.7.1 Two.RHRSW subsystems and the UHS shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3.

ACTIONS

-- ---- NOTE-*_

Enter applicable Conditions and Required Actions of LCO 3.4.8, "Residual Heat Removal (RHR)

Shutdown Cooling System-Hot Shutdown,' for RHR shutdown cooling made inoperable by RHRSW System.

CONDITION REQUIRED ACTION COMPLETION TIME A.

NOTE-A.1 Declare the associated Immediately Separate Condition entry is RHRSW subsystems allowed for each valve, inoperable AND One valve in Table 3.7.1-1 inoperable.

A.2 Establish an open flow path to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months the UHS.

OR AND

.One valve in Table 3.7.1-2 inoperable.

A.3 Restore the inoperable valve(s) 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months from the to OPERABLE status.

discovery of an OR inoperable RHRSW subsystem in the One valve in Table 3.7.1-3 opposite loop from the inoperable.

inoperable valve(s)

OR AND Any combination of valves in 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Table 3.7.1-1, Table 3.7.1-2, or Table 3.7.1-3 in the same return loop inoperable:

(continued)

SUSQUEHANNA - UNIT 1 TS / 3.7-1 Amendmentr--7-8, 266..,246

PPL Rev.

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 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 1 inch above Mean Sea Level.

SR 3.7.1.2 Verify the average water temperature of the UHS is:

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

a. ------- -

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

! 850F; or b..N T..

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 0F; or

c.

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

<880 F SR 3.7.1.3 Verify each RHRSW manual, power operated, and 31 days automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position or can be aligned to the correct position.

SR 3.7.1.4 Verify that valves HV-01 222A and B (the spray array 92 days bypass valves) close upon receipt of a closing signal and open upon receipt of an opening signal.

SR 3.7.1.5 Verify that valves HV-01224A1 and B1 (the large spray 92 days array valves) close upon receipt of a closing signal and open upon receipt of an opening signal.

(continued)

SUSQUEHANNA - UNIT 1 TS / 3.7-3 Amendment'"7-8, T82,246 296.

PPL Rev.

RHRSW System and UHS 3[7.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1.6 Verify that valves HV-01224A2 and B2 (the small spray 92 days array valves) close upon receipt of a closing signal and open upon receipt of an opening signal.

SR 3.7.1.7 Verify that valves 012287A and 012287B (the spray array 92 days bypass manual valves) are capable-of being opened and closed.

SUSQUEHANNA-UNIT 1 TS / 3.7-3a Amend ment'206,, 246

PPL Rev.

RHRSW System and UHS 3.7.1 TABLE 3.7.1-1 Ultimate Heat Sink Spray Array Valves VALVE NUMBER VALVE DESCRIPTION HV-01224A1 Loop A large spray array valve HV-01224B1 Loop. B large spray array valve HV-01224A2 Loop A small spray array valve HV-01224B2 Loop B small spray array valve SUSQUEHANNA - UNIT 1 TS / 3.7-3b Amendment 28fi,, 246

PPL Rev.

RHRSW System and UHS 3.7.1 TABLE 3.7.1-2 Ultimate Heat Sink Spray Array Bypass Valves VALVE NUMBER VALVE DESCRIPTION HV-01222A Loop A spray array bypass valve HV-01222B Loop B spray array bypass valve SUSQUEHANNA - UNIT 1 TS / 3.7-3c Amendment 246

PPL Rev.

RHRSW System and UHS 3.7.1 TABLE 3.7.1-3 Ultimate Heat Sink Spray Array Bypass Manual Valves VALVE NUMBER VALVE DESCRIPTION 012287A Loop A spray array bypass manual valve 012287B Loop B spray array bypass manual valve SUSQUEHANNA - UNIT 1 TS / 3-7-3d Amendment 246

PPL Rev.

Main Turbine Bypass System 3.7.6 3.7 PLANT SYSTEMS 3.7.6 Main Turbine Bypass System LCO 3.7.6 The Main Turbine Bypass System shall be OPERABLE.

OR Apply the following limits for an inoperable Main Turbine Bypass System as specified in the COLR:

a.

LCO 3.2.2, "MINIMUM CRITICAL POWER RATIO (MCPR),-" and

b.

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

APPLICABILITY:

THERMAL POWER > 23% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Main Turbine Bypass System A.1 Satisfy the requirements of the 2.hours inoperable.

LCO or restore Main Turbine Bypass System to OPERABLE status.

AND Requirements of LCO 3.2.2 not met.

OR Requirements of LCO 3.2.3 not met.

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

< 23% RTP.

not met.

SUSQUEHANNA - UNIT 1 TS /3.7-15 TS /37-15Amendment 17X, 21$, 2A 246

PPL Rev.

Main Turbine Pressure Regulation System 3.7.8 3.7 PLANT SYSTEMS

3.7.8 Main Turbine Pressure Regulation System LCO 3.7.8 Both Main Turbine Pressure Regulators shall be OPERABLE.

OR Apply the following limits for an inoperable Main Turbine Pressure Regulator as specified in the COLR:

a.

LCO 3.2.2, "MINIMUM CRITICAL POWER RATIO (MCPR)", and

b.

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

APPLICABILITY:

THERMAL POWER _Ž 23% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One Main Turbine Pressure A.1 Satisfy the requirements of the 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months Regulator inoperable.

LCO or restore Main Turbine Pressure Regulator to AND OPERABLE status.

Requirements of LCO 3.2.2 not met.

OR Requirements of LCO 3.2.3 not met.

B. Required Action and B.1 Reduce THERMAL POWER to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Associated Completion Time

< 23% RTP.

not met.

SUSQUEHANNA - UNIT 1 TS / 3.7-18 Amendment 246

PPL Rev.

Main Turbine Pressure Regulation System 3.7.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.8.1 Verify that both Main Turbine Pressure.Regulators 92 days are each capable of controlling main steam pressure.

SR 3.7.8.2 Perform a system functional test.

24 months SUSQUEHANNA - UNIT 1 TS /3.7-19 Amendment 246

PPL Rev.

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.11 Safety Function Determination Program (SFDP). (continued):

The SFDP identifies where a loss of safety function exists. If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered. When a loss of safety function is caused by the inoperability of a single Technical Specification support system, the appropriate Conditions and Required Actions to enter are those of the support system.

5.5.12 Primary Containment Leakaqe Rate Testing Program A program shall be established, implemented, and maintained to comply with the leakage rate testing of the containment as required by 10 CFR 50.54(o) and 10 CFR 50, Appendix J, Option B, as modified. by approved exemptions. This program shall be in accordance with the guidelines contained in Regulatory Guide 1.163, "Performance-Based Containment Leak-Test Program," dated September 1995, as modified by the following exceptions:

a. The visual examination of containment concrete surfaces intended to fulfill the requirements of 10 CFR 50, Appendix J, Option B testing, will be performed in accordance with the requirements of and frequency specified by the ASME Section X1 Code, Subsection IWL, except where relief has been authorized by the NRC.

b. The visual examination of the steel liner plate inside containment intended to fulfill the requirements of 10 CFR 50, Appendix J, Option B, will be performed in accordance with the requirements of and frequency specified by the ASME Section Xl Code, Subsection IWE, except where relief has been authorized by the NRC.

c.

NEI 94-01-1995, Section 9.2.3: The first Type A test performed after the May 4, 1992 Type A test shall be performed no later than May 3, 2007.

The peak calculated containment internal pressure for the design basis loss of coolant accident, Pa, is 48.6 psig.

The maximum allowable primary containment leakage rate, La, at Pa, shall be 1 % of the primary containment air weight per day.

(continued)

SUSQUEHANNA-UNIT 1 TS /5.0-18 Amendment 1/8, 20, 20(9. 24F1.2/, -(

PPL Rev.

Reporting Requirements 5.6 5.6 Reporting Requirements (continued)

5.6.4 Not Used 5.6.5 CORE OPERATING LIMITS REPORT (COLR)

a.

Core operating limits shall be established prior to each reload cycle, or prior to any remaining portion of a reload cycle, and shall be documented in the COLR for the following:

1.

The Average Planar Linear Heat Generation Rate for Specification. 3.2.1;

2. The Minimum Critical Power Ratio for Specification 3.2.2;

3. The Linear Heat Generation Rate for Specification 3.2.3;

4. The Shutdown Margin for Specification 3.1.1;

5. Oscillation Power Range Monitor (OPRM) Trip Setpoints, for Specification 3.3.1.1; and

6. The Allowable Values and power range setpoints for Rod Block Monitor Upscale-Functions for Specification 3.3.2.-1, Table 3.3.2.1-1.

b.

The analytical.methods used to determine the core operating limits shall be those previously reviewed and approved by the NRC.

(continued)

SUSQUEHANNA - UNIT 1 TS / 5.0-21 Amendment 1,&6, 194, 2>45, 241, 2-3, 23M, 24*,

246

PPL Rev.

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.5 COLR (continued)

The approved analytical methods are described in The following documents, the approved version(s) of which are specified in the COLR.

1. XN-NF-81-58(P)(A), "RODEX2 Fuel Rod Thermal-Mechanical Response Evaluation Model," Exxon Nuclear Company.

2. XN-NF-85-67(P)(A), "Generic Mechanical Design for Exxon Nuclear Jet pump BWR ReloadFuel," Exxon Nuclear Company.

3. EMF-85-74(P)(A), "RODEX2A (BWR) Fuel Rod Thermal-Mechanical Evaluation Model," Siemens Power Corporation.

4. ANF-89-98(P)(A), "Generic Mechanical Design Criteria for BWR Fuel Designs," Advanced. Nuclear Fuels Corporation.

5. XN-NF-80-19(P)(A), "Exxon Nuclear Methodology for Boiling Water Reactors," Exxon Nuclear Company.

6. EMF-2158(P)(A), "Siemens Power Corporation Methodology for Boiling Water Reactors: Evaluation and Validation of CASMO-4/MICROBURN-B2," Siemens Power. Corporation.

7. EMF-2361(P)(A), "EXEM BWR-2000 ECCS Evaluation Model,"

Framatome ANP.

8. EMF-2292(P)(A), "ATRIUMm-10: Appendix K Spray Heat Transfer Coefficients," Siemens Power Corporation (continued).

SUSQUEHANNA - UNIT 1 TS / 5.0-22 Amendment 17-6, 1W, 1,94, ZOR 24-6ý 1-31, 2 4 6

PPL Rev.

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.5 COLR (continued)

9. XN-NF-84-105(P)(A), "XCOBRA-T: A Computer Code for BWR.

Transient:ThermaI-Hydraulic Core Analysis," Exxon Nuclear Company.

10. ANF-524(P)(A), "ANF Critical Power Methodology for Boiling Water Reactors," Advanced Nuclear Fuels Corporation.

11., ANF-913(P)(A),."COTRANSA2: A Computer Program for Boiling Water Reactor Transient Analyses," Advanced Nuclear Fuels Corporation.

12. ANF-1358(P)(A), "The Loss of Feedwater Heating Transient in Boiling Water Reactors," Advanced Nuclear Fuels Corporation.

13. EMF-2209(P)(A), "SPCB Critical Power Correlation," Siemens Power Corporation.

14. EMF-CC-074(P)(A), "BWR Stability Analysis - Assessment of STAIF with Input from MICROBURN-B2," Siemens Power Corporation.

15. NE-092-001A, "Licensing Topical Report for Power Uprate With Increased Core Flow," Pennsylvania Power & Light Company.

16. NEDO-32465-A, "BWROG Reactor Core Stability Detect and Suppress Solutions Licensing Basis Methodology for Reload Applications.

c. The core operating limits shall be determined such that all applicable limits (e.g., fuel thermal mechanical limits, core thermal hydraulic limits, Emergency Core Cooling Systems (ECCS) limits, nuclear limits such as SDM, transient analysis limits, and accident analysis limits) of the safety analysis are met.

d. The COLR, including any midcycle revisions or supplements, shall be provided upon issuance for each reload cycle to the NRC.

(continued)

SUSQUEHANNA - UNIT 1 TS / 5.0-23 Amendment 1,78, 1,86, I1K8, P4, 0j,

ýt PS*,

2,ý-7, 2-e*, 246 (4)

PPL Susquehanna, LLC, pursuant to the Act and 10 CFR Parts 30, 40, and 70,.

to. receive, possess, and use in amountsas required any byproduct, source or special nuclear material without restriction to chemical or physical form, for sample analysis or instrument calibration. or associated with radioactive apparatus orcomponents; and (5)

PPL Susquehanna, LLC, pursuant to the Act and 10 CFR Parts 30, 40, and 70, to possess,. but not separate, such byproduct and special nuclear materials as may be produced by the operation of the facility.

C.

This license shall be deemed to contain and is subject to the conditions specified in the Commission's regulations set forth in 10 CFR Chapter I and is subject to all applicable provisions of the Act and to the rules, regulations and orders of the Commission now or hereafter in effect; and is subject to the additional conditions specified or incorporated below:

(1)

Maximum Power Level PPL Susquehanna, LLC is. authorized to operate the facility at reactor core power levels not in excess of 3952 megawatts thermal in accordance with the conditions specified herein. The preoperational tests, startup tests, and other items identified in License Conditions. 2.C.(20), 2.C.(21), 2.C.(22), and 2.C.(22) to this license shall be completed as specified.

(2)

Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No. 224, and the Environmental Protection Plan contained in Appendix B, are hereby incorporated in.the license. PPL Susquehanna, LLC shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

For Surveillance Requirements (SRs) that are new in Amendment 151 to Facility Operating License No. NPF-22, the first performance is due at the end of the first surveillance interval that begins at implementation of Amendment 151. For SRs that existed prior to Amendment 151, including SRs with modified acceptance criteria and SRs whose frequency of performance is being extended, the first performance is due at the end of the first surveillance interval that begins on.the date the Surveillance was last performed prior to implementation of Amendment 151.

2.C.(3) PPL Susquehanna, LLC shall implement and maintain in effect all provisions of the approved fire protection program as described in the Fire Protection Review Report for the facility and as approved in Fire Protection Program, Section 9.5, SER, SSER#1, SSER#2, SSER#3, SSER#4, SSER#6, Safety Evaluation of Fire Protection Report dated August 9, 1989, Safety Evaluation Amendment No. 4, 2, +03, 1-56, +5+, -53, +62, 469, 2-+2, 2+3, 2+4, 2+5, 2-6, 2+7-, 2+-8, 2+9, 226, 22+, 2-2-2, 223, 224 (a)

Fire fighting response strategy with the following elements:

1. Pre-defined coordinated fire response strategy and guidance

2. Assessment of mutual aid fire fighting assets 3.:Designated staging areas for equipment and materials

4. Command and control

5. Training.of response personnel (b)

Operations to mitigate fuel damage considering the following:

1. Protection and use of personnel assets

2. Communications

3. Minimizing fire spread

4. Procedures for implementing integrated fire response strategy

5. Identification of readily-available pre-staged equipment

.6. Training on integrated fire response strategy

7. Spent fuel pool mitigation measures (c)

Actions to minimize release to include consideration of:

1. Water spray scrubbing

2. Dose to onsite responders (19) The licensee shall implement and maintain all Actions required by Attachment 2 to NRC Order EA-06-137, issued June 20, 2006, except the. last action that requires incorporation of the strategies into the site security plan, contingency plan, emergency plan and/or guard training and qualification plan, as appropriate.

(20) Potential Adverse Flow Effects These license conditions provide for monitoring, evaluating, and taking prompt action in response to potential adverse flow effects as a result of power uprate operation on plant structures, systems, and components (including verifying the continued structural integrity of the steam dryer).

(a)

The following requirements are placed on operation of the PPL Susquehanna, LLC (PPL) facility above the licensed thermal power (CLTP) level of 3489 megawatts thermal (MWt):

1.

PPL shall obtain at each 3.5 % power ascension step, main steam line strain gauge data and compare it to the limit curve for the dryer strains during power ascension.

2.

PPL shall monitor the main steam line (MSL) strain gauges during power ascension above 3489 MWt for increasing pressure fluctuations in the steam lines.

3.

PPL shall hold the facility at each 3.5% ascension step to collect data from License Condition 2.C.(20)(a) and conduct plant inspections and walk-downs, and evaluate steam dryer performance based. on the data; shall provide the evaluation to the NRC staff by facsimile or electronic Amendment No. 46-2, 224 transmission to the NRC project manager upon completion of the I

evaluation; and shall not increase. power above each hold point until 96 I

hours after the NRC projectý manager. confirms receipt of transmission.

I

4.

If any frequency peak from the MSL strain gauge data exceeds the limit i

curve for dryer strains above 3489 MWt, PPL shall return the facility to a power level at which the acceptance criteria is not exceeded. PPL shall I

resolve the discrepancy, document the continued structural integrity of I

the steam dryer, and provide that documentation to the NRC staff by I

facsimile or electronic transmission to the NRC project manager prior to I

further increases in reactor power.

5.

In addition to evaluating the dryer strain and MSL strain gauge data, I

' PPL shall monitor reactor pressure vessel water level instrumentation or MSL piping accelerometers during power ascension above 3489 MWt. If resonance frequencies are identified as increasing above nominal levels

.in proportion to instrumentation -data, PPL shall stop power ascension, document the continued structural integrity of the steam dryer, and provide that documentation to the NRC staff by facsimile or electronic transmission to the NRC project manager prior to further increases in reactor power.

6.

Following CPPU start-up testing, PPL shall resolve the discrepancies in the steam dryer analysis and provide that resolution to the NRC staff by facsimile or electronic transmission to the NRC project manager. If the discrepancies are not resolved within 90 days of identification, PPL shall return the facility to a power level at which the discrepancy does not exist.

(b)

PPL shall implement the following actions:

1.

PPL shall provide to NRC the as-built dryer stress analysis and load limit curves 45 days prior to operation. above 3489 MWt.

2.

After the dryer stress analysis is benchmarked to the Unit 1 startup test data. (Unit 1 data taken up to 107 % of 3489 MWt), the benchmarked PATP and MSL limit curves shall be provided to the NRC 90 days prior to operation above 107% of 3489 MWt..

3.

In the event that acoustic signals are identified that challenge the limit curves during power ascension above 3489 MWt, PPL shall evaluate dryer loads and re-establish the acceptance criteria based on the new data, and shall perform an assessment of ACM uncertainty at the acoustic signal frequency.

4.

After reaching full CPPU, PPL shall obtain measurements from the MSL strain gauges and establish the steam dryer flow-induced vibration load fatigue margin for the facility, update the dryer stress report, if required, and re-establish the limit curve with the updated ACM load definition and revised instrument uncertainty, which will be provided to the NRC staff.

Amendment No. 46-2, 224

-. 11 -

5.

During power ascension above 3489 MWt, if an engineering evaluation for the steam dryer is required because a Level 1 acceptance criteria is exceeded, PPL shall perform the structural analysis'to address frequency uncertainties up to +/-10% and assure that peak responses that fall within this uncertainty band are addressed..

6.

PPL shall revise the Post Constant Pressure Power Uprate (CPPU)

Monitoring & Inspection Program to reflect long-term monitoring of plant parameters potentially indicative of steam dryer failure; to reflect consistency of the facility's steam dryer inspection program with General Electric Service Information Letter (SIL) 644, "BWR/3 Steam Dryer Failure," Revision 2; and to identify the NRC Project Manager for the facility as the point of*contact for providing PATP information during power ascension.,

7.

PPL shall submit a CPPU steam.dryer report to the NRC. The report will be issued following completion of Unit 2 ascension to 114 % CLTP. The report shall include evaluations or corrective actions that were required to assure steam dryer structural integrity. Additionally, it shall include relevant data collected at each power step, comparisons to performance criteria (design predictions), and evaluations performed in conjunction with steam dryer structural integrity monitoring.

8.

PPL shall submit the flow-induced vibration related portions of the CPPU startup test procedure to the NRC, including methodology for updating the limit curve; prior to initial power ascension above 3489 MWt.

(c)

PPL shall prepare the CPPU startup test procedure to include the:

1.

main steam line strain gauge limit curves to be used up to 114 % of CLTP;

2.

specific hold points and their duration during CPPU power ascension;

3.

activities to be accomplished during hold points;.

4.

plant parameters to be monitored;

5.

inspections and walk-downs to be conducted for steam, feedwater, and condensate systems and components during the hold points;

6.

methods to be used to trend plant parameters;

7.

acceptance criteria for monitoring and trending plant parameters, and conducting the walk-downs and inspections;

8.

actions to be taken if acceptance criteria are not satisfied; and Amendment No. 462, 224 9.1-verification of the completion of commitments and planned actions specified in its application and.all supplements to the application in support of the CPPU license amendment request pertaining to the steam dryer 1

prior to power increase above 3489 MWt. PPL shall provide the related I

CPPU. startup test procedure sections to the NRC by facsimile or electronic I

transmission to the NRC project manager prior to.increasing power above I

3489 MWt.

(d)

The following key attributes of the PATP shall not be made less restrictive without prior NRC approval:

1.

During initial power ascension testing above 3489 MWt, each test plateau increment shall be approximately 3.5 % of 3489 MWt;

2.

Level 1 performance criteria; and

3.

The methodology for establishing the stress criteria used for the Level 1 and Level 2 performance criteria.

Changes to other aspects of the PATP may be made in accordance with the guidance of Nuclear Energy Institute (NEI) 99-04, "Guidelines for Managing NRC Commitments," issued July 1999.

(e)

During the first two scheduled refueling outages after reaching full CPPU conditions, a visual inspection shall be conducted of all accessible,

.susceptible locations of the steam dryer in accordance with BWRVIP-139 and General Electric inspection guidelines.

(f)

The results of the visual inspections of the steam dryer shall be reported to the NRC staff within 60 days following startup. The results of the PATP shall be submitted to the NRC staff in a report within 60 days following the completion of all CPPU power ascension testing.

(g)

This license condition shall expire upon satisfaction of the requirements in License Conditions 2.C.(20)(e) and 2.C.(20)(f) provided that a visual inspection of the steam dryer does not reveal any new unacceptable flaw or unacceptable flaw growth that is due to fatigue.

(21) Transient Testing (a)

PPL will demonstrate through performance of transient testing on each SSES unit that the loss of one condensate pump will not result in a complete loss of reactor feedwater. The test shall be performed on each unit during the unit's CPPU power ascension test program within 336 hours0.00389 days 0.0933 hours 5.555556e-4 weeks 1.27848e-4 months of achieving and prior to exceeding a nominal power level of 3733 MWt with feedwater and condensate flow rates stabilized. PPL shall confirm that the plant response to the transient is as expected in accordance with the acceptance criteria that are established. If a loss of all reactor feedwater occurs as a result of the test, the test failure shall be Amendment No. 462, 224 addressed in accordance with corrective action program requirements and the provisions of the power ascension test program prior to continued operation of the SSES Unit above 3489 MWt.

(b)

Unless the NRC issues a letter notifying the licensee that the tests specified by License Condition 2.C.(21 )(a) adequately demonstrate that a single condensate pump trip will not result in a loss of all feedwater while operating at the full CPPU power level of 3952 MWt, PPL shall perform the transient test on" either SSES unit (whichever unit is first to achieve the following specified operating conditions) specified by License Condition 2.C.(21 )(a) during the power ascension test program while operating at 3872 MWt to 3952 (98% to 100% of the full CPPU. power level) with feedwater and condensate flow rates stabilized. The test shall be performed within 90 days of operating at greater than 3733 MWt and within 336 hours0.00389 days 0.0933 hours 5.555556e-4 weeks 1.27848e-4 months of achieving a nominal power level of 3872 MWt with feedwater and condensate flow rates stabilized. PPL will demonstrate through performance of transient testing on either Susquehanna Unit 1 or Unit 2 (whichever unit is first to achieve the specified conditions) that the loss. of one condensate pump will not result in a complete loss of reactor feedwater. PPL shall confirm that the plant response to the transient is as expected in accordance with the acceptance criteria that are established. If a loss of all feedwater occurs as a result of the test, -the test failure shall be addressed in accordance with corrective action program requirements and the provisions of the power ascension test program prior to continued operation of either SSES Unit above 3733 MWt.

(22) Neutronic Methods (a)

An OPRM amplitude setpoint penalty will be applied to account for a reduction in thermal neutrons around the LPRM detectors caused by transients that increase voiding. This penalty will reduce the OPRM scram setpoint according to the methodology described in Response No.

3 of PPL letter, PLA-6306, dated November 30, 2007. This penalty will be applied until NRC evaluation determines that a penalty to account for this phenomenon is not warranted.

(b)

For SSES SLMCPR, a conservatively adjusted pin power distribution uncertainty and bundle power correlation coefficient will be applied as stated in Response No. 4 of PPL letter, PLA-6306, dated November 30, 2007, when performing the analyses in accordance with. ANF-524(P)(A),

"Critical Power Methodology for Boiling Water Reactors," using the uncertainty parameters associated with EMF-2158(P)(A) "Siemens Power Corporations Methodology for Boiling Water Reactors: Evaluation and Validation of CASMO-4/MICROBURN-B2."

Amendment No. +6-2, 224 (23) Containment Operability for EPU PPL shall ensure.that the CPPU containment analysis is consistent with the SSES 1 and 2 operating and emergency, procedures. Prior to operation above'CLTP, PPL shall notify the NRC project manager that all appropriate actions have been completed.

2. D. The operating licensee shall fully implement and maintain in effect all provisions of the Commission-approved physical security, guard training and qualification, and safeguards contingency plans including amendments made pursuant to provisions of the Miscellaneous Amendments and Search Requirements revisions to 10 CFR 73.55 (51 FR 27817 and 27822) and to the authority of 10 CFR 50.90 and 10 CFR 50.54(p). The plans, which contain Safeguards Information protected under 10.CFR 73.21, are entitled:, "Susquehanna Steam.

Electric Station Physical Security Plan," with revisions submitted. through September 24, 1987; "Susquehanna Steam Electric Station Guard Training and Qualification Plan," with revisions submitted through May 28, 1985; and "Susquehanna Steam Electric Station Safeguards Contingency Plan," with revisions submitted through September 24, 1987. Changes made in accordance with 10 CFR 73.55 shall be implemented in accordance with the schedules set forth therein.

E.

Deleted.

F.

PPL Susquehanna, LLC shall have and maintain financial protection of such type and in such amounts as the Commission shall require in accordance with Section 170 of the Atomic Energy Act of 1954, as amended', to cover public liability claims.

G.

This license is effective as of the date of issuance and shall expire at midnight on March 23, 2024.

FOR THE NUCLEAR REGULATORY COMMISSION Original signed by Darrell G. Eisenhut for Harold R. Denton Harold R. Denton, Director Office of Nuclear Reactor Regulation Attachments:

1.

2.

3.

Appendix A - Technical Specifications (NUREG-1042)

4.

Appendix B -.Environmental Protection Plan Date of Issuance: March 23, 1984 Amendment No. +-62, 2-22 224

PPL Rev.

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 680F; 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 consist of the testing of one of the systems, subsystems, channels, or other designated components during the interval specified by the Surveillance Frequency, so that all systems, subsystems, channels, or other designated components are tested during n Surveillance Frequency intervals, where n is the total number of systems, subsystems, channels, or other designated components in the associated function.

THERMAL POWER 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 BASIS THERMAL POWER TURBINE BYPASS SYSTEM RESPONSE TIME SUSQUEHANNA - UNIT 2 1.1-6 Amendment 2,24 224

PPL Rev.

SLs 2.0 2.0 SAFETY LIMITS (SLS) 2.1 SLs 2.1.1 Reactor Core SLs 2.1.1.1 With the reactor steam dome pressure < 785 psig or core flow

< 10 million Ibm/hr:

THERMAL POWER shall be< 23% RTP.

2.1.1.2 With the reactor steam dome pressure Ž785 psig and core flow

> 10 million Ibm/hr:

MCPR shall be > 1.11 for two recirculation loop operation. or 1.14 for single recirculation loop operation.

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

2.1.2 Reactor Coolant System Pressure SL Reactor steam dome pressure shall be < 1325 psig.

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

2.2.1 Restore compliance with all SLs; and.

2.2.2 Insert all insertable control rods.

SUSUQUEHANNA - UNIT 2 TS / 2.0-1 Amendment W 1.64, 184, 1.

.UK4, 24"8,224

PPL Rev.

APLHGR 3.2.1 3.2.

3.2.1 LCO POWER DISTRIBUTION LIMITS AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR) 3.2.1 All APLHGRs shall be less than or equal to the limits specified in the COLR.

ICABILITY:

THERMAL POWER Ž 23% RTP.

APPL ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

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

limits, limits.

B.

Required Action and B.1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion to < 23% RTP.

Time not met.

SUSQUEHANNA - UNIT 2 3.2-1 Amendment I.,it.,224

PPL Rev.

APLHGR

3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after SR 3.2.1.1 Verify all APLHGRs are less than or equal to the limits specified in the COLR.

Once within 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s* after

Ž23% RTP AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter AND Prior to exceeding 44% RTP SUSQUEHANNA - UNIT 2 3.2-2 Amendment 4ý31,224

PPL Rev.

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

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

APPLICABILITY:

THERMAL POWER _Ž23% RTP.

ACTIONS_

CONDITION REQUIRED ACTION COMPLETION TIME A.

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

limits, limits.

B.

Required Action and B.1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion to < 23% RTP.

Time not met.

SUSQUEHANNA - UNIT 2 3.2-3 Amendment W,224

PPL Rev.

MCPR 3.2.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify all MCPRs are greater than or equal to the Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after limits specified in the COLR.

2! 23% RTP AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter AND Prior to exceeding 44% RTP SR 3.2.2.2 Determine the MCPR limits.

Once within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after each completion of SRs in 3.1.4 SUSQUEHANNA - UNIT 2 3.2-4 Amendment IW,224

PPL Rev.

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

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

APPLICABILITY:

THERMAL POWER Ž23% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

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

limits.

B.

Required Action and B.1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion to < 23% RTP.

Time not met.

I SUSQUEHANNA - UNIT 2 3.2-5 Amendment j&%224

PPL Rev.

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 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after

'a 23% RTP AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter AND Prior to exceeding 44% RTP I

SUSQUEHANNA-UNIT2 3.2-6 Amendment 1ý51,224

PPL Rev.

RPS Instrumentation 3.3.1.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME.

D.

Required Actionand D.1 Enter the Condition referenced Immediately associated Completion in Table 3.3.1.1-1 for the Time of Condition A, B, channels.

or C not met.

E.

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

< 26% RTP.

and referenced in Table 3.3.1.1-1.

F.

As required by F.1 Be in MODE 2.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Required Action D.1 and referenced in Table 3.3.1.1-1.

G.

As required by G.1 Be in MODE 3.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Required Action D.1 and referenced in Table 3.3.1.1-1.

H.

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

assemblies.

As required by 1.1 Initiate alternate method to detect 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Required Action D.1 and suppress thermal hydraulic and referenced in instability oscillations.

Table 3.3.1.1-1.

AND 1.2 Restore required channels to 120 days OPERABLE.

J.

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

<23% RTP.

Time of Condition I not met.

SUSQUEHANNA - UNIT 2 3.3-2 Amendment 1.81, 2.97, 224

PPL Rev.

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS

1.

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

2.

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

SURVEILLANCE FREQUENCY SR 3.3.1.1.1 Perform CHANNEL CHECK.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.1.1.2 Perform CHANNEL CHECK.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SR 3.3.1.1.3 NOTE Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER Ž23% RTP.

Verify the absolute difference between the average power 7 days range monitor (APRM) channels and the calculated power is < 2% RTP while operating at_> 23% RTP.

SR 3.3.1.1.4 Not required to be performed whenentering MODE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2.

Perform CHANNEL FUNCTIONAL TEST.

7 days (continued)

SUSQUEHANNA-UNIT2 3.3-3 24edmnt I-1, -77,

220,

PPL Rev.

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY..

SR 3.3.1.1.5 Perform CHANNEL FUNCTIONAL TEST.

7 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.

7 days SR 3.3.1.1.8 Calibrate the local power range monitors.

2000 MWD/MT average core exposure SR 3.3.1.1.9 N-A test of all required contacts does not have to be performed.

Perform CHANNEL FUNCTIONAL TEST.

92 days SR 3.3.1.1.10 Perform CHANNEL CALIBRATION.

92 days (continued)

SUSQUEHANNA -UNIT 2 3.3-4 Amendment V-5'1 224

PPL Rev.

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE

-FREQUENCY 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 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2.

Perform CHANNEL CALIBRATION.

184 days 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 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2.

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

Perform CHANNEL FUNCTIONAL TEST 184 days SR 3.3.1.1.13 Perform CHANNEL CALIBRATION.

24 months SR 3.3.1.1.14 Perform CHANNEL FUNCTIONAL TEST.

24 months SR 3.3.1.1.15 Perform LOGIC SYSTEM FUNCTIONAL TEST.

24 months SR 3.3.1.1.16 Verify Turbine Stop Valve-Closure and Turbine Control 24 months Valve Fast Closure, Trip Oil Pressure-Low Functions are not bypassed when THERMAL POWER is

>26% RTP.

(continued)

SUSQUEHANNA - UNIT 2 3.3-5 Amendment 1-51, 2, 224

PPL Rev.

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.17

-- NOTES--------

1. Neutron detectors are excluded.

2. For Function 5, "n" equals 4 channels for the purpose of determining the STAGGERED TEST BASIS Frequency.

3. For Function 2.e, "n" equals 8 channels for them purpose of determining the STAGGERED TEST BASIS Frequency. Testing of APRM and OPRM outputs shall alternate.

Verify the RPS RESPONSE TIME is within limits.

24 months on a STAGGERED TEST BASIS SR 3.3.1.1.18

-NOTES

1. Neutron detectors are excluded.

2.

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

Perform CHANNEL CALIBRATION 24 months SR 3.3.1.1.19 Verify OPRM is not-bypassed when APRM Simulated 24 months Thermal Power is >_ 25% and recirculation drive flow is

_<value equivalent to the core flow value defined in the COLR.

SR 3.3.1.1.20 Adjust recirculation drive, flow to conform to reactor core 24 months flow.

I SUSQUEHANNA - UNIT 2 3.3-6 Amendment 1,66, 227,224

PPL Rev.

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

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

1. Intermediate Range Monitors

a. Neutron

Flux-High 2

3 G

5(a) 3 H

b; Inop 2

3 3

G H

5(a)

.SR 3.3.1.1.1 SR 3.3.1.1.4 SR 3.3.1.1.6 SR 3.3.1.1.7.

SR 3.3.1.1.11 SR 3.3.1.1.15 SR 3.3.1.1.1 SR 3.311.1.5 SR 3.3.1.1.111 SR 3.3.1.1.15 SR 3.3.1.1.4 SR 3.3.1.1.15 SR 3.3.1.1.5 SR 3.3.1.1.15 SR 3.3.1.1.2 SR 3.3.1.1.7 SR 3.3.1.1.8 SR 3.3.1.1.12 SR 3.3.1.1.18 SR 3.3.1.1.2 SR 3.3.1.1.3 SR 3.3.1.1.8 SR 3.3.1.1.12 SR 3.3.1.1.18 SR 3.3.1.1.20 122/125 divisions of full scale

5 122/125 divisions of full scale NA NA

20% RTP

< 0.55 W

+ 60.7% RTP(b) and s 115.5% RTP (continued)

2. Average Power Range Monitors

a. Neutron Flux-High (Setdown)

b. Simulated Thermal Power-High 2

3 (c)

G 1

3(c)

F (a)

(b)

(c)

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

0.55 (W-AW) + 60.7% RTP when reset for single loop operation per LCO 3.4;1, "Recirculation Loops Operating."

Each APRM channel provides inputs to both trip systems.

I SUSQUEHANNA - UNIT 2 TS / 3.3-7 Amendment 1-51, 202, W7", 22*, 224

PPL Rev.

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

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

2.

Average Power Range Monitors (continued)

c. Neutron Flux-High

d. Inop

e. 2-Out-Of-4 Voter

f. OPRM Trip

3. Reactor Vessel Steam Dome Pressure-High

4. Reactor Vessel Water Level--

Low, Level 3

5. Main Steam Isolation Valve-Closure

6.

Drywell Pressure-High 1,2 3(c)

F 3(c)

G G

1,2

_> 23% RTP 1,2 2

3(c)

SR 3.3.1.1.2 SR 3.3.1.1.3 SR 3.3.1.1.8 SR 3.3.1.1.12 SR 3.3.1.1.18 SR 3.311.1.12 SR 3.3.1.1.2 SR 3.3.1.1.12 SR 3.3.1.1.15 SR 3.3.1.1.17 SR 3.3.1.1.2 SR 3.3.1.1.8 SR 3.3.1.1.12 SR 3.3.1.1.18 SR 3.31.1.19 SR 3.3.1.1.20 SR 3.3.1.1.9 SR 3.3.1.1.10 SR 3.3.1.1.15 SR 3.3.1.1.1 SR 3.3.1.1.9 SR 3.3.1.1.10 SR 3.3.1.1.15 SR 3.3.1.1.9 SR 3.3.1.1.13 SR 3.3.1.1.15 SR 3.3.1.1.17 SR 3.3.1.1.9 SR 3.3.1.1.10 SR 3.3.1.1.15

_120% RTP NA NA (d)

< 1093 psig

>11.5 inches 2

2 G

G 1,2 1*

8 F

_ 11% closed 1,2 2

G

1.88 psig (continued)

(c)

Each APRM channel provides inputs to both trip systems.

(d)

See COLR for OPRM period based detection algorithm (PBDA) setpoint limits.

SUSQUEHANNA - UNIT 2 TS / 3.3-8 Amendment 1'ýg6, 2.o7,224

PPL Rev.

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

Reactor Protection System Instrumentation.

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

7. Scram Discharge Volume Water Level--High

a. Level Transmitter 1,2 5(a) 1,2 5(a) 2 2

2 2

b. Float Switch G

H G

H E

8. Turbine Stop Valves-Closure

9. Turbine Control Valve Fast Closure, Trip Oil Pressure-Low

10. Reactor Mode Switch-Shutdown Position

> 26% RTP

>26% RTP 4

SR 3.3.1.1.9 SR 3.3.1.1.13 SR 3.3.1.1.15 SR 3.3.1.1.9 SR 3.3.1.1.13 SR 3.3.1.1.15 SR 3.3.1.1.9 SR 3.3.1.1.13 SR 3.3.1.1.15 SR 3.3.1.1.9.

SR 3.3.1.1.13 SR 3.3.1.1.15 SR 3.3.1.1.9 SR 3.3.1.1.13 SR 3.3.1.1.15 SR 3.3.1.1.16 SR 3.3.1.1.17 SR 3.3.1.1.9 SR 3.3.1.1.13 SR 3.3.1.1.15 SR 3.3.1.1.16 SR 3.3.1.1.17 SR 3.3.1.1.14 SR 3.3.1.1.15 SR 3.3.1.1.14 SR 3.3.1.1.15 SR 3.3.1.1.5 SR 3.3.1.1.15 SR 3.3.1.1.5 SR 3.3.1.1.15

5 66 gallons

!5 66 gallons

< 62 gallons

< 7% closed Z! 460 psig NA.

2 E

1,2 2

G

11. Manual Scram 5 (a) 1,2 5 (a) 2 2

2 H

G H

NA NA NA (a)

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

SUSQUEHANNA-UNIT2 3.3-9 Amendment e15, 2-?,

224

PPL Rev.

Feedwater - Main Turbine High Water Level Trip Instrumentation 3.3.2.2 3.3 INSTRUMENTATION 3.3.2.2 Feedwater - Main Turbine High Water Level Trip Instrumentation LCO 3.3.2.2 Three channels of feedwater - main turbine high water level trip instrumentation shall be OPERABLE.

APPLICABILITY:

THERMAL POWER > 23% RTP.

ACTIONS Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One feedwater - main A. 1 Place channel in trip.

7 days turbine high water level trip channel inoperable.

B. Two or more feedwater B. 1 Restore feedwater - main turbine 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months

- main turbine high high water level trip capability.

water level trip channels inoperable.

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

< 23% RTP.

Time of Conditions A or B not met.

SUSQUEHANNA - UNIT 2 3.3-21 Amendment IBI 224

PPL Rev.

EOC-RPT Instrumentation 3.3.4.1 3.3 INSTRUMENTATION 3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT) Instrumentation LCO 3.3.4.1

a.

Two channels per trip system for each EOC-RPT instrumentation Function listed below shall be OPERABLE:

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

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

OR

b.

LCO 3.2.2, "MINIMUM CRITICAL POWER RATIO (MCPR)," limits for inoperable EOC-RPT as specified in the COLR are made applicable.

APPLICABILITY:

THERMAL POWER > 26% RTP.

ACTIONS NOTE-Separate Condition entry is allowed for each channel.

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

AND OR MCPR limit for A.2

-NOTE inoperable EOC-RPT Not applicable if inoperable not made applicable, channel is the result of an inoperable breaker.

Place channel in trip.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR (continued)

'SUSQUEHANNA - UNIT 2 3.3-30 Amendment IRf224

PPL Rev.

EOC-RPT Instrumentation 3.3.4.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)

A.3 Apply the MCPR limit for 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable EOC-RPT as specified in the COLR.

B. One or more Functions B.1 Restore EOC-RPT trip capability.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months with EOC-RPT trip capability not maintained.

OR AND MCPR limit for B.2 Apply the MCPR limit for 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months inoperable EOC-RPT inoperable EOC-RPT as specified not made applicable in the COLR.

C. Required Action and C.1 Remove the associated 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion recirculation pump from service.

Time not met.

OR,

'C.2 Reduce THERMAL POWER to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months

< 26% RTP.

SUSQUEHANNA - UNIT 2 3.3-31 Amendment 15ý224

PPL Rev.

EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS, i,.'--NOTE--

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

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

Perform CHANNEL FUNCTIONAL TEST.

92 days SR 3.3.4.1.2 Perform CHANNEL CALIBRATION. The Allowable 24 months Values shall be:

TSV--Closure: < 7% closed; and TCV Fast Closure, Trip Oil Pressure-Low: Ž460 psig.

SR 3.3.4.1.3 Perform LOGIC SYSTEM FUNCTIONAL TEST including 24 months breaker actuation.

SR 3.3.4.1.4 Verify TSV-Closure and TCV Fast Closure, Trip Oil 24 months Pressure-Low Functions are not bypassed when THERMAL POWER is Ž26% RTP.

(continued)

SUSQUEHANNA - UNIT 2 3.3-32 Amendment IF6 224

PPL Rev.

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 1 of.6)

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

1.

Main Steam Line Isolation

a.

Reactor Vessel 1,2,3 2

D SR 3.3.6.1.1

-136 inches Water Level - Low SR 3.3.6.1.2 Low Low, Level 1 SR 3.3.6.1.4 SR 3.3.6.1.5

b.

Main Steam Line 1

2 SR 3.3.6.1.2

>841 psig Pressure - Low SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6

c.

Main Steam Line 1,2,3 2 per MSL D

SR 3.3.6.1.1 5 179 psid Flow-High SR 3.3.6.1.2 SR 3.3.6.1.4 SR 3.3.6.1.5

d.

Condenser Vacuum 1

2 D

SR 3.3.6.1.2

> 8.8 inches (a) (a)

SR 3.3.6.1.3 Hg vacuum

-Low 21 3SR 3.3.6.1.5

e.

Reactor Building 1,2,3 2

D SR 3.3.6.1.2

< 184°F Main Steam Tunnel SR 3.3.6.1.3 Temperature - High.

SR 3.3.6.1.5

f.

Manual Initiation 1,213 1

G SR 3.3.6.1.5 NA (continued)

(a)

With any main turbine stop valve not closed.

SUSQUEHANNA - UNIT 2 TS / 3.3-57 Amendment 1fi6,224

PPL Rev.

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 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after associated recirculation loop is in operation.

2. Not required to -be completed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after > 23% RTP.

Verify at least two of the following criteria (a, 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months b,ý or c) are satisfied for each operating recirculation loop:

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.

SUSQUEHANNA - UNIT 2 3.4-7 Amendment 1,5% 224

PPL Rev.

S/RVs 3.4.3 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.3 Safety/Relief Valves (S/RVs)

LCO 3.4.3 APPLICABILITY:

The safety function of 14 S/RVs shall be OPERABLE.

MODES. 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.1 One or more required A.1 Be in MODE 3.:

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months S/RVs inoperable..

AND A.2 Be in MODE 4.

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SUSQUEHANNA - UNIT 2 3.4-8 Amendment IZI 224

PPL Rev.

RCS PIT Limits 3.4.10 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.10.3

'NOTE-.--------

Only required to be met in MODES 1, 2, 3, and 4 during recirculation pump start.

Once within 15 minutes Verify the difference between the bottom head prior to each startup of a coolant temperature and the reactor pressure vessel recirculation pump (RPV) coolant temperature is < 1450F.

SR 3.4.10.4 NOTE---

Only required to be met in MODES 1, 2, 3, and 4 during recirculation pump start.

Verify the difference between the reactor coolant Once within 15 minutes temperature in the recirculation loop to be started prior to each startup of a and the RPV coolant temperature is < 500F.

recirculation pump SR 3.4.10.5 Only required to be met in single loop operation when:

a.

THERMAL POWER *27% RTP; or

b.

The operating recirculation loop flow

21,320 gpm.

Verify the difference between the bottom head Once within 15 minutes coolant temperature and the RPV coolant prior to an increase in temperature is:* 145,F.

THERMAL POWER or an increase in loop flow (continued)

SUSQUEHANNA - UNIT 2 3.4-27 Amendment 1R1, 224

PPL Rev.

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.

I Once within 15 minutes prior to an increase in THERMAL POWER or an increase in loop flow.

Verify the difference between the reactor coolant temperature in the recirculation loop not in operation and the RPV coolant temperature is

< 500F.

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 30 minutes temperatures are? _700F.

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 30 minutes temperatures are __ 700F.

(continued)

SUSQUEHANNA - UNIT 2 3.4-28 Amendment2121, 224

PPL Rev.

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY 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 In accordance secondary containment bypass leakage with the Primary paths is < 9-scfh when pressurized to Containment

> Pa.

Leakage Rate Testing Program.

SR 3.6.1.3.12 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 Cotaiment leakage including the leakage from the MS Line LeakageRt Drains when the MSIVs are tested at >_ 24.3 psig Leakage Rate or P. and the MS Line Drains are tested at Pa.

Testing Program.

(continued)

SUSQUEHANNA - UNIT 2 TS / 3.6-15 Amendment 1.,

224

PPL Rev.

RHRSW System and UHS 3.7.1 3.7 PLANT SYSTEMS 3.7.1 Residual Heat Removal Service Water (RHRSW).System and the..

Ultimate Heat Sink (UHS)

LCO 3.7.1 Two RHRSW subsystems and the UHS shall be OPERABLE.

APPLICABILITY' MODES 1, 2, and 3.

ACTIONS k I/"*'lt

.l*it

]

Enter applicable Conditions and Required Actions of LCO 3.4.8, "Residual Heat Removal (RHR)

Shutdown Cooling System-Hot Shutdown," for RHR shutdown cooling made inoperable by RHRSW System.

CONDITION REQUIRED ACTION COMPLETION TIME A. --------- NOTE-------

Separate Condition entry is allowed for each valve.

A.1, Declare the associated.

RHRSW subsystems inoperable.

Immediately 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months AND One valve in Table 3.7.1-1 inoperable.

OR One valve in Table 3.7.1-2 inoperable.

OR One valve in Table 3.7.1-3 inoperable.

OR Any combination of valves in Table 3.7.1-1, Table 3.7.1-2, or Table 3.7.1-3 in the same return loop inoperable.

A.2 Establish an open flow path to the UHS.

I AND A.3 Restore the inoperable valve(s) to OPERABLE status.

8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months from the discovery of an inoperable RHRSW subsystem in the opposite loop from the inoperable valve(s)

AND 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months (continued)

SUSQUEHANNA - UNIT 2 TS / 3.7-1 Amendment J-6i, tW, 224

PPL Rev.

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 1 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months inch above Mean Sea Level.

SR 3.7.1.2 Verify the average water temperature of the UHS is:

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

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.

< 850 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 0F; or

c. -------------------

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

5 880F.

SR 3.7.1.3 Verify each RHRSW manual, power operated, and 31 days automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position or can be aligned to the correct position.

SR 3.7.1.4 Verify that valves HV-01222A and B (the spray array bypass 92 days valves) close upon receipt of a closing signal and open upon receipt of an opening signal.

(continued)

I SUSQUEHANNA - UNIT 2 TS / 3.7-3 Amendment W, 1.56 186,224

PPL Rev.

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 92 days array valves) close upon receipt of a closing signal and open upon receipt of an opening signal.

SR. 3.7.1.6 Verify that valves HV-01224A2 and B2 (the small spray 92 days array valves) close upon receipt of a closing signal and open upon receipt of an opening signal.

SR 3.7.1.7 Verify that valves 012287A and 012287B (the spray array 92 days bypass manual valves) are capable of being opened and closed.

SUSQUEHANNA-UNIT2 TS / 3.7-3a Amendment IZO,224

PPL Rev.

RHRSW System and UHS

3.7.1 TABLE 3.7.1-1 Ultimate Heat Sink Spray Array Valves I

VALVE NUMBER, VALVE DESCRIPTION HV-01224A1 Loop A large spray array valve HV-01224811 Loop B large spray array valve HV-01224A2 Loop A small spray array valve HV-01224B2 Loop B small spray array valve SUSQUEHANNA - UNIT 2 TS /3.7-3b Amendment 10,224

PPL Rev.

RHRSW System AND UHS 3.7.1 TABLE 3.7.1-2 Ultimate Heat Sink Spray Array Bypass Valves VALVE NUMBER VALVE DESCRIPTION HV-01222A Loop A spray array bypass valve.

HV-01222B Loop B spray array bypass valve SUSQUEHANNA - UNIT 2 TS / 3.7-3c Amendment 224

PPL Rev.

RHRSW System AND UHS 3.7.1 TABLE 3.7.1-3

.Ultimate Heat Sink Spray Array Bypass Manual Valves.

VALVE NUMBER VALVE DESCRIPTION 012287A Loop A spray array bypass manual valve 012287B Loop B spray array bypass manual valve SUSQUEHANNA - UNIT 2 TS / 3.7-3d Amendment 224

PPL Rev.

Main Turbine Bypass System 3.7.6 3.7 PLANT SYSTEMS Main Turbine Bypass System 3.7.6 LCO 3.7.6 The Main Turbine Bypass System shall be OPERABLE.

OR Apply the following limits for an inoperable Main Turbine Bypass System as specified in the COLR:

a.

LCO 3.2.2, "MINIMUM CRITICAL POWER RATIO (MCPR)," and

b.

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

APPLICABILITY:

THERMAL POWER 23% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Main Turbine Bypass A.1 Satisfy the requirements of the 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months System inoperable.

LCO or restore Main Turbine Bypass System to OPERABLE status.

AND Requirements of LCO 3.2.2 not met.

OR Requirements of LCO 3.2.3 not met.

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

<ý23% RTP.

not met.

SUSQUEHANNA - UNIT 2 TS / 3.7-15 Amendment 1ZI 1.85, 1-83, 224

PPL Rev.

Main Turbine Pressure Regulation System 3.7.8 3.7 PLANT SYSTEMS 3.7.8 Main Turbine Pressure Regulation System LCO 3.7.8 Both Main Turbine Pressure Regulators shall be OPERABLE.

OR Apply the following limits for an inoperable Main Turbine Pressure Regulator as specified in the COLR:

a.

LCO 3.2.2, "MINIMUM CRITICAL POWER RATIO (MCPR)", and

b.

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

APPLICABILITY:

THERMAL POWER >_ 23% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One Main Turbine Pressure A.1 Satisfythe requirements of the 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months Regulator inoperable.

LCO or restore Main Turbine Pressure Regulator to AND OPERABLE status.

Requirements of LCO 3.2.2 not met.

OR Requirements of LCO 3.2.3 not met.

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

< 23% RTP.

not met.

SUSQUEHANNA - UNIT 2 TS / 3.7-18 Amendment 224

PPL Rev.

Main Turbine Pressure Regulation System.

3.7.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.8.1 Verify that both Main Turbine Pressure Regulators 92 days are each capable of controlling main steam pressure.

SR 3.7.8.2 Perform a system functional test.

24 months SUSQUEHANNA - UNIT 2 TS, / 3.7-19 Amendment 224

PPL Rev.

Programs and Manuals

.5.5 5.5 Programs and Manuals 5.5.11 Safety Function Determination Program (SFDP) (continued)

The SFDP identifies where a loss of safety function exists. If a loss of safety function is determined to exist by this program, the appropriate Conditions and

.Required Actions of the LCO in which the loss of safety function exists are required to be entered. When a loss of safety function is caused by the inoperability of a single Technical Specification support system, the appropriate Conditions and Required Actions to enter are those of the support system.

5.5.12 Primary Containment Leakage Rate Testinq Progqram A program shall be established, implemented, and maintained to comply with the leakage rate testing of the containment as required by 10 CFR 50.54(o) and 10 CFR 50, Appendix J, Option B, as modified by approved exemptions. This program shall be in accordance with the guidelines contained in Regulatory Guide 1.163, "Performance-Based Containment Leak-Test Program," dated September 1995, as modified by the following exceptions:

a. The visual examination of containment concrete surfaces intended to fulfill the.

requirements of 10CFR 50, Appendix J, Option B testing, will be performed in accordance with the requirements of and frequency specified.by the ASME Section XI Code, Subsection IWL, except where relief has been authorized by the NRC.

b. The visual examination of the steel liner plate inside containment intended to fulfill the requirements of 10 CFR 50, AppendixJ, Option B,. will be performed in accordance with the requirements of and frequency specified by the ASME Section XI Code, Subsection IWE, except where relief has been authorized by the NRC.

c. NEI 94-01-1995, Section 9.2.3: The first Type A test performed after the October 31, 1992 Type A test shall be performed no later than October 30, 2007..

The peak calculated containment internal pressure.for the design basis loss of coolant accident, Pa, is 48.6 psig.

The maximum allowable primary containment leakage rate, La, at Pa, shall be 1% of the primary containment air weight per day.

(continued)

SUSQUEHANNA - UNIT 2 TS /5.0-18 Amendment 1 76, 1.,

1283, 2,n, 224

PPL Rev.

Reporting Requirements 5.6 5.6 Reporting Requirements (continued) 5.6.4 Not Used 5.6.5 CORE OPERATING LIMITS REPORT (COLR)

a.

Core operating limits shall be established prior to each reload cycle, or prior to any remaining portion of a reload cycle, and shall be documented in the COLR for the following:

1.

The Average Planar Linear Heat Generation Rate for Specification 3.2.1;

2.

The Minimum Critical Power Ratio for Specification 3.2.2;

3.

The Linear Heat Generation Rate for Specification 3.2.3;

4.

The Shutdown Margin for Specification 3.1.1;

5.

Oscillation Power Range Monitor (OPRM) Trip setpoints, for Specification 3.3.1.1; and

6.

The Allowable Values and power range setpoints for Rod Block Monitor Upscale Functions for Specification 3.3.2.1, Table 3.3.2.1-1.

b.

The analytical methods used to determine the core operating limits shall be those previously reviewed and approved by the NRC.

SUSQUEHANNA - UNIT 2 TS / 5.0-21 (continued)

Amendment 1.69, 1W, 1192, 2v7, 224

PPL Rev.

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.5 COLR (continued)

The approved analytical methods are described in the following documents, the approved version(s) of which are specified in the COLR.

1.

XN-NF-81-58(P)(A), "RODEX2 Fuel Rod Thermal-Mechanical Response Evaluation Model," Exxon Nuclear Company.

2.

XN-NF-85-67(P)(A), "Generic Mechanical Design for Exxon Nuclear Jet pump BWR Reload Fuel," Exxon Nuclear Company.

3.

EMF-85-74(P)(A), "RODEX2A (BWR) Fuel Rod Thermal-Mechanical Evaluation Model," Siemens Power Corporation.

4' ANF-89-98(P)(A), "Generic Mechanical Design Criteria for BWR Fuel Designs," Advanced Nuclear Fuels Corporation.

5.

XN-NF-80-19(P)(A), "Exxon Nuclear Methodology for Boiling Water Reactors," Exxon Nuclear Company.

6.

EMF-2158(P)(A), "Siemens Power Corporation Methodology for Boiling Water Reactors: Evaluation and Validation of CASMO-4/MICROBURN-B2," Siemens Power Corporation.

-7.

EMF-2361(P)(A), "EXEM BWR-2000 ECCS Evaluation Model," Framatome ANP.

8.

EMF-2292(P)(A), "ATRIUMTm-10: Appendix K Spray Heat Transfer Coefficients," Siemens Power Corporation.

9.

XN-NF-84-105(P)(A), "XCOBRA-T: A Computer Code for BWR Transient Thermal-Hydraulic Core Analysis," Exxon Nuclear Company.

(continued)

SUSQUEHANNA - UNIT 2 TS / 5.0-22 Amendment 1XI 2249, 6 3, 1,,4, 1V4, 224.

PPL Rev.

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.5 COLR (continued)

10.

ANF-524(P)(A), "ANF Critical Power Methodology for Boiling Water Reactors," Advanced Nuclear Fuels Corporation.

11.

ANF-913(P)(A), "COTRANSA2: A Computer Program for Boiling Water Reactor Transient Analyses," Advanced Nuclear Fuels Corporation.

12.

ANF-1358(P)(A), "The Loss of Feedwater Heating Transient in Boiling Water Reactors," Advanced Nuclear Fuels Corporation.

13.

EMF-2209(P)(A), "SPCB Critical Power Correlation," Siemens Power Corporation.

14.

EMF-CC-074(P)(A), "BWR Stability Analysis - Assessment of STAIF with Input from MICROBURN-B2," Siemens Power Corporation.

15.

NE-092-001A, "Licensing Topical Report for Power Uprate with Increased Core Flow," Pennsylvania Power & Light Company.

16.

NEDO-32465-A, "BWROG Reactor Core Stability Detect and Suppress, Solutions Licensing Basis Methodology for Reload Applications."

c.

The core operating limits shall be determined such that all applicable limits (e.g., fuel thermal mechanical limits, core thermal hydraulic limits, Emergency Core Cooling Systems (ECCS) limits, nuclear limits such as SDM, transient analysis limits, and accident analysis limits) of the safety analysis are met.

d.

The COLR, including any midcycle revisions or supplements, shall be provided upon issuance for each reload cycle to the NRC.

continued SUSQUEHANNA - UNIT 2 TS / 5.0-23 Amendment 1-9 182241.84,29,

v t e Letter Sequence Other
TAC:MD3309, (Approved, Closed) TAC:MD3310, (Approved, Closed)
Initiation Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request Acceptance, Acceptance Supplement, Supplement, Supplement, Supplement, Supplement, Supplement, Supplement, Supplement, Supplement, Supplement Administration Withholding Request Acceptance, Withholding Request Acceptance, Withholding Request Acceptance Questions 19 March 2007 15 March 2007 20 March 2007 29 March 2007 12 April 2007 10 April 2007 12 April 2007 16 April 2007 12 April 2007 12 April 2007 18 April 2007 30 April 2007 27 April 2007 27 April 2007 27 April 2007 30 April 2007 14 May 2007 12 July 2007 1 August 2007 Answers Results Approval Other: ML062900160, ML071620334, ML073320383, ML073390289, ML073390306, ML080300472, ML081000038, ML081000429, PLA-6187, Response for Additional Information Requested in Regard to Proposed License Amendment No. 285, Constant Pressure Power Uprate Environmental, PLA-6255, Proposed License Amendments 285 and 253, Constant Pressure Power Uprate Application Regarding Steam Dryer Flow Effects Verbal and Confirmatory Requests for Additional Information Responses, PLA-6266, Proposed License Amendment No. 285 for Unit 1, License No. NPF-14 & Proposed License Amendment No. 253 for Unit 2, License No. NPF-22, Extended Power Uprate Application Regarding Change to Technical Specification SR 3.7.1 - RHRSW and UHS, PLA-6370, License Renewal Application, Amendment to Section 4.2.2, PLA-6633, Providing Notice That the License Conditions 2.C.(36)(a)3, 2.C.(36(b)7 & 2.C.(36)(f) Have Been Met, PLA-6876, Th Rio Steam Dryer Visual Inspection Report, PLA-7047, Th Rio Steam Dryer Visual Inspection Report
MONTHYEAR2007-04-10 [Table View]

ML080300472

Text

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