CP-201900368, Revision to Technical Specifications 3.8.1, AC Sources - Operating

Revision to Technical Specifications 3.8.1, AC Sources - Operating

ML20091H586
Person / Time
Site:	Comanche Peak
Issue date:	03/31/2020
From:	Thomas McCool Luminant, TXU Energy, Vistra Energy
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
CP-201900368, TXX-19064
Download: ML20091H586 (178)

Text

6555 SIERRA DRIVE IRVING, TEXAS 75039 o214-812-4600 VISTRAENERGY.COM Thomas P. McCool Site Vice President Luminant P.O. Box 1002 6322 North FM 56 Glen Rose, TX 76043 o 254.897.6042 CP-201900368 TXX-19064 U. S. Nuclear Regulatory Commission Ref 10 CFR 50.90 ATTN: Document Control Desk 10 CFR 50.91(b)(1)

Washington, DC 20555-0001 03/31/2020

SUBJECT:

COMANCHE PEAK NUCLEAR POWER PLANT DOCKET NOS. 50-445 AND 50-446 LICENSE AMENDMENT REQUEST (LAR)15-001 REVISION TO TECHNICAL SPECIFICATIONS (TS) 3.8.1, AC SOURCES -- OPERATING

Dear Sir or Madam:

Pursuant to 10CFR50.90, Vistra Operations Company LLC (Vistra OpCo) hereby requests an amendment to the Comanche Peak Nuclear Power Plant (CPNPP) Unit 1 Operating License (NPF-87) and CPNPP Unit 2 Operating License (NPF-89) by incorporating the attached change into the CPNPP Units 1 and 2 Technical Specifications.

This change request applies to both units.

The proposed change will revise Technical Specification 3.8.1 entitled AC SOURCES -- OPERATING. The proposed change will revise the Emergency Diesel Generator surveillance requirement steady state frequency band. The current steady state frequency band of 58.8 Hz to 61.2 Hz will be changed to 59.9 Hz to 60.1 Hz in multiple Surveillance Requirements. This amendment request also removes historical information from TS 3.8.1, Required Action A.3 Completion Time and a Note from SR 3.8.1.13.

The enclosure provides a description and assessment of the proposed changes. Attachment 1 provides the existing TS pages, marked TS pages to show the proposed changes, and the retyped TS pages. TS Bases current, marked, and retype pages are included for information only. Attachments 2, 3, 4, and 5 are provided for information only are not intended to become part of the CPNPP licensing basis. Attachment 2 provides CPNPP figures for 6900VAC and 480VAC and Electrical Grid Connection. Attachment 3 provides requested TS 3.8.1 surveillance requirement information. Attachment 4 provides safety related pump and motor operated valve (MOV) response to voltage and frequency changes. Attachment 5 provides safety related MOV minimum required starting voltage.

Approval of the proposed amendment is requested within one year of the NRC acceptance date. Once approved, the amendment shall be implemented within 90 days.

TXX-19064 Page 2 of 2 In accordance with 10CFR50.91(b)(1}, Vistra OpCo is providing the State ofTexas with a copy of this proposed amendment.

This letter contains no new regulatory commitments.

If you have any questions regarding this submittal, please contact Garry W Struble at (254) 897-6628 or garry.struble@luminant.com.

I state under penalty of perjury that the foregoing is true and correct.

Executed on 03/31/2020.

Enclosure:

Attachments:

c-Sincerely, Thomas P. McCool LICENSE AMENDMENT REQUEST (LAR)15-001, REVISION TO TECHNICAL SPECIFICATIONS (TS) 3.8.1, AC SOURCES -- OPERATING

1.

CPNPP TECHNICAL SPECIFICATION 3.8.1, AC SOURCES -- OPERATING TECHNICAL SPECIFICATION AND BASES PAGES

2.

CPNPP FIGURES

3.

CPNPP TECHNICAL SPECIFICATION 3.8.1, AC SOURCES -- OPERATING, SURVEILLANCE REQUIREMENT INFORMATION IN ACCORDANCE WITH THE SURVEILLANCE FREQUENCY CONTROL PROGRAM

4.

CPNPP SAFETY RELATED PUMP AND MOTOR OPERATED VALVE RESPONSE

5.

CPNPP DBD-EE-041, 480V AND 120V AC ELECTRICAL POWER SYSTEM, TABLE 5.3, MOV MINIMUM STARTING VOLTAGE REQUIRED Scott Morris, Region IV Dennis Galvin, NRR Resident Inspectors, Comanche Peak Mr. Robert Free Environmental Monitoring & Emergency Response Manager Texas Department of State Health Services Mail Code 1986 P. 0. Box 149347 Austin TX, 78714-9347

1.0

SUMMARY

DESCRIPTION 2.0 DETAILED DESCRIPTION 2.1 System Design and Operation 2.2 Current Technical Specification Requirements 2.3 Reason for Proposed Change 2.4 Description of Proposed Change

4.0 REGULATORY EVALUATION

4.1 Applicable Regulatory Requirements 4.2 Precedent 4.3 No Significant Hazards Consideration Determination 4.4 Conclusions

5.0 ENVIRONMENTAL CONSIDERATION

S

6.0 REFERENCES

ATTACHMENTS Comanche Peak Nuclear Power Plant (CPNPP) Technical Specifications. Technical Specification Bases (For Information Only)

CPNPP Figures (For Information Only)

CPNPP Technical Specification 3.8.1, AC Sources -

Operating, Surveillance Requirement Information (For Information Only)

Safety Related Pump and Motor Operated Valve Response (For Information Only)

DBD-EE-041, 480V & 120V Electrical Power System, Table 5.3, MOV Minimum Starting Voltage (For Information Only)

Enclosure to TXX-19064 Page 1 of 18

1.0

SUMMARY

DESCRIPTION Proposed License Amendment Request (LAR)15-001 revises Technical Specifications (TS) 3.8.1, AC Sources -- Operating for Comanche Peak Nuclear Power Plant (CPNPP) Units 1 and 2.

Vistra Operation Company LLC (Vistra OpCo) is requesting this change to the Emergency Diesel Generator (EDG), Surveillance Requirement(s) (SR) descriptions (acceptance criteria). Revising these acceptance criteria is necessary for validation of steady state voltage and frequency requirements.

These steady state requirements are necessary when the EDG is the sole power source for safety related loads. LAR 15-001 also includes two editorial changes to delete historical information.

There are no changes to the CPNPP Final Safety Analysis Report (FSAR) as a result of LAR 15-001 (References 6.1 and 6.2).

2.0 DETAILED DESCRIPTION The design function of the EDGs is to provide power for safe shutdown of the plant when offsite power is not available. EDGs operate in the isochronous mode to perform their design function. Following restoration of offsite power, the EDGs are required to synchronize with the grid to restore offsite power to safety buses without interruption of power. EDG capability to provide adequate voltage and frequency for performance of safety related functions during isochronous mode is required to be validated by the surveillance testing program. As noted in section 2.3, the NRC has questioned the adequacy of EDG surveillance testing frequency tolerance of (60 + 1.2) Hz for steady state operation, to adequately ensure power for performance of safety related Structures, Systems, and Components (SSC).

The preferred source of power for safe shutdown of the plant is offsite power.

CPNPP has established voltage and frequency requirements for offsite sources to ensure adequate voltage and frequency for performance of SSCs.

Switchyard steady state voltage is maintained, between 135 and 144 kV, for the 138 kV switchyard and between 340 and 361 kV, for the 345 kV switchyard.

Switchyard voltage requirements are documented in agreements with Electric Reliability Council of Texas (ERCOT) (grid operator) and Oncor (transmission and distribution provider). These requirements ensure a voltage of + 10% of rated voltage at motor terminals for adequate performance of SSCs. To meet the requirement of + 10% of rated voltage at motor terminals, EDG steady state voltage is defined as > 6480 V and < 7150 V. These voltage requirements are used to validate EDG capability to provide adequate voltage for performance of SSCs.

Enclosure to TXX-19064 Page 2 of 18

CPNPP Engineering Report ER-ME-109 (Reference 6.10) evaluates safety related pump degradation issues and concludes that a + 0.1 Hz frequency variation has insignificant impact on 60 Hz motor and pump performance.

Therefore, to ensure adequate performance of SSCs, offsite power steady state frequency limits were defined as > 59.9 Hz and < 60.1 Hz, and documented in an agreement with ERCOT. However, these frequency acceptance criteria were not incorporated into Technical Specification (TS) 3.8.1 surveillance testing because the testing acceptance criteria of 60 + 1.2 Hz were based on Regulatory Guide (RG) 1.9 frequency limits and were considered adequate for steady state operation.

6900 V bus voltage and frequency, when tied to the grid, is controlled by the grid.

Therefore, an EDG operating in parallel with the grid provides adequate voltage and frequency for performance of SSCs. The design function of an EDG, operating in isochronous mode, is to provide adequate voltage and frequency for performance of SSCs when offsite power is not available. Therefore, the TS 3.8.1 surveillance program is being revised to incorporate steady state frequency limits, > 59.9 Hz and < 60.1 Hz, in the SRs. This will align the surveillance acceptance criteria for DG frequency with the Offsite Power System steady state frequency and will ensure insignificant impact on 60 Hz motor and pump performance.

Current SR descriptions (acceptance criteria) do not align with EDG steady state frequency limits with desired EDG control system performance. CPNPP is administratively trending the steady state frequency in the surveillance testing program. If steady state frequency is outside the 60 + 0.1 Hz band engineering is contacted for assistance. LAR 15-001 will make this administrative trending acceptance criterion.

Refer to Attachment 1 to TXX-19064 for the CPNPP Current, Markup, and Retyped Technical Specification, 3.8.1 AC Sources - Operating. Included as For Information Only are the CPNPP Current, Markup, and Retyped Technical Specification Bases, B 3.8.1 AC Sources - Operating.

2.1 System Design and Operation The Emergency Diesel Generators provide emergency onsite power for safety-related equipment. There are two EDGs for each unit and they are train-related.

Unit 1 EDG 1-01 Train A 1EA1 EDG 1-02 Train B 1EA2 Unit 2 EDG 2-01 Train A 2EA1 EDG 2-02 Train B 2EA2 Enclosure to TXX-19064 Page 3 of 18

During normal power operation the 6900 V safeguards buses 1EA1, 1EA2, 2EA1, and 2EA2 are power from their preferred offsite power source.

The preferred offsite power source for Unit 1 is from the 345 KV switchyard through transformer XST2 or XST2A. The alternate offsite power source for Unit 1 is from the 138 KV switchyard through transformer XST1 or XST1A.

The preferred offsite power source for Unit 2 is from the 138 KV switchyard through transformer XST1 or XST1A. The alternate offsite power source for Unit 2 is from the 345 KV switchyard through transformer XST2 or XST2A.

For the CPNPP 6900 V safeguards buses the transfer from the preferred offsite source to the alternate offsite source is a Slow Transfer only. If the Slow Transfer fails, the associated EDG will start and provide power to the bus. In either case the loads will be sequenced onto the bus by the Blackout Sequencer. If the preferred offsite source is lost coincident with a Safety Injection, the Safety Injection Sequencer will load the bus.

Conditions required for a Slow Transfer include the following:

Transfer switch for the alternate power supply breaker selected to the Control Room Alternate power supply breaker handswitch on the main control board in AUTO Preferred power supply breaker in connect and open Voltage available from the alternate source Undervoltage condition on the bus for at least 0.5 seconds 1.9 seconds have NOT elapsed EDG output breaker open No 86 lockouts on the bus If the preferred and alternate offsite power sources are unavailable, then a dedicated EDG may be aligned to each safeguards 6900 V bus. The EDGs receive an automatic emergency start due to bus undervoltage (Blackout) and buses are loaded by a Blackout Sequencer. The EDGs also receive an automatic emergency start due to Safety Injection and buses are loaded by a Safety Injection Sequencer. A Safety Injection may be initiated manually, by low pressurizer pressure, low main steam line pressure, or containment building high pressure. The sequencers are designed to load the EDGs in a controlled manner to ensure that loading does not cause the EDG to trip.

EDG ratings are 7000 kW at 0.8 PF (Power Factor) and 60 Hz. EDGs maintain their voltage within + 0.5% of 6900 V. EDGs are required to maintain their frequency within + 0.6 Hz; however, test experience shows Enclosure to TXX-19064 Page 4 of 18

that the EDGs will maintain frequency at + 0.1 Hz. The EDGs are capable of operating in parallel with 6900 V buses, fed from the offsite power grid. 6900 V bus and electrical distribution system frequency, when tied to the grid, is same as grid frequency. 6900 V bus voltage when tied to the grid, is controlled by grid voltage and voltage drop across the Startup Transformers (SUT). The grid normally maintains its frequency at 60 + 0.03 Hz and switchyards normally maintain their voltages > 138 kV for 138 kV switchyard and > 342 kV for 345 kV switchyard. These voltages correspond to 6900 V bus voltages of 6900/6840 V at no load.

Surveillance testing performed during plant operation may require EDG parallel operation with the grid. Station procedures provide administrative controls for EDG parallel operation with the grid without declaring the paralleled EDG inoperable. During such testing, only one of the redundant DGs shall be paralleled at any one time, leaving the other EDG available in standby. To synchronize with the grid, EDG frequency and voltage controls are used to bring EDG voltage and frequency to values necessary for synchronization. After synchronization the EDG voltage and frequency will be controlled by the grid during EDG parallel operation.

Refer to Attachment 2 to TXX-19064 for CPNPP simplified plant diagrams; Figure 1 - 6900VAC and 480VAC and Figure 2 - CPNPP Electrical Grid Connection Diagram.

2.2 Current Technical Specification 3.8.1 Requirements 2.2.1 TS 3.8.1 Surveillance Requirements with a specified Diesel Generator frequency band The current acceptance criteria for the following SRs includes a diesel generator frequency band of > 58.8 Hz and < 61.2 Hz:

3.8.1.2 (DG Monthly Slow Start) 3.8.1.7 (DG Semi-annual Fast Start) 3.8.1.11 (Emergency Bus Load Shed, DG Start, Sequence and Run on Loss of Offsite Power) 3.8.1.15 (DG Hot Restart) 3.8.1.19 (Emergency Bus Load Shed, DG Start, Sequence and Run on Safety Injection in Conjunction with Loss of Offsite Power) 3.8.1.20 (Simultaneous Start of Both DGs) 2.2.2 TS 3.8.1, CONDITION A, REQUIRED ACTION A.3, COMPLETION TIME This REQUIRED ACTION A.3 incudes a current COMPLETION TIME of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OR 14 days for a one time outage on XST1 to complete a plant modification to be completed by March 31, 2017.

Enclosure to TXX-19064 Page 5 of 18

The proposed editorial change deletes OR 14 days for a one time outage on XST1 to complete a plant modification to be completed by March 31, 2017. from the COMPLETION TIME as it is historical and no longer needed.

2.2.3 TS Surveillance Requirement 3.8.1.13 The current NOTE in SR 3.8.1.13 is For Unit 2, testing need only be performed for LOOP concurrent with SI until startup following 2RF05. The proposed editorial change deletes the NOTE in SR 3.8.1.13 as it is historical and no longer needed.

Refer to Attachment 1 to TXX-19064 for the CPNPP Current, 3.8.1 AC Sources - Operating. Included as For Information Only are the CPNPP Current Technical Specification Bases, B 3.8.1 AC Sources - Operating.

2.3 Reason for Proposed Change During a Component Design Bases Inspection performed in 2013, the inspectors identified a Green, non-cited violation of 10 CFR Part 50, Appendix B, Criterion XVI, Corrective Action, states, in part, measures shall be established to assure that conditions adverse to quality are promptly identified and corrected. Specifically, since May 2010, the licensee failed to correct a condition adverse to quality in a timely manner that involved updating design basis calculations for safety-related equipment to include the allowed technical specification frequency range of +/- 2 percent for the emergency diesel generators.

The issue led to an industry sponsored evaluation that yielded no concrete actions to address the issue. CPNPP is submitting this LAR 15-001 to close this issue.

CPNPP is proposing a technical specification change to address EDG frequency acceptance criteria. CPNPP proposed acceptance criteria provides a better basis for determining if diesel generator controls are performing as designed.

A frequency of 60 + 0.1 Hz has no significant impact on 60 Hz motor or pump performance, per ER-ME-109 Rev 1 (Ref. 16). EDG steady state frequency of > 59.9 Hz and < 60.1 Hz ensures adequate frequency at safety related loads for performance of their safety related function. The EDG control system maintains steady state frequency within 60 + 0.1 Hz.

In accordance with North American Electric Reliability Corporation (NERC)

Mandatory Reliability Standard NUC-001, Nuclear Plant Interface Requirement-1 (NPIR-1) the offsite power system is maintained at 60 +

0.1 Hz and switchyard voltages are maintained 340 kV to 361 kV for the 345 kV switchyard and 135 kV to 144 kV for the 138 kV switchyard. After synchronizing with the grid the CPNPP electrical system frequency will be the same as grid frequency and safety bus voltage will remain between the required voltage limits of 6480 V and 7150 V. Switchyard controls in conjunction with plant administrative controls for EDG parallel operation Enclosure to TXX-19064 Page 6 of 18

with the grid, ensure the EDG capability limits, to maintain voltage of >

6480 V and frequency of > 59.9 Hz can be verified for synchronizing to the offsite circuit, and the grid will maintain EDG frequency at 60 + 0.1 Hz and voltage between 6480 V and 7150 V after synchronization.

These SURVEILLANCE REQUIREMENT changes will adequately address the original issue from 2010 and allow closure of all actions regarding the finding from 2013. The editorial changes will remove historical information no longer required from TS 3.8.1, AC -- Operating, CONDITION A, REQUIRED ACTION A.3 COMPLETION TIME and the NOTE from SR 3.8.1.13.

2.4 Description of Proposed Change 2.4.1 TS 3.8.1 Surveillance Requirements with a specified Diesel Generator frequency band The current acceptance criteria for the following SRs includes a diesel generator frequency band of > 58.8 Hz and < 61.2 Hz:

3.8.1.2 (DG Monthly Slow Start) 3.8.1.7 (DG Semi-annual Fast Start) 3.8.1.11 (Emergency Bus Load Shed, DG Start, Sequence and Run on Loss of Offsite Power) 3.8.1.15 (DG Hot Restart) 3.8.1.19 (Emergency Bus Load Shed, DG Start, Sequence and Run on Safety Injection in Conjunction with Loss of Offsite Power) 3.8.1.20 (Simultaneous Start of Both DGs)

LAR 15-001 proposes to change the diesel generator frequency band from > 58.8 Hz and < 61.2 Hz to > 59.9 Hz and < 60.1 Hz for the SRs listed above.

2.4.2 TS 3.8.1, CONDITION A, REQUIRED ACTION A.3, COMPLETION TIME This REQUIRED ACTION A.3 incudes a current COMPLETION TIME of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OR 14 days for a one time outage on XST1 to complete a plant modification to be completed by March 31, 2017.

The proposed editorial change deletes OR 14 days for a one time outage on XST1 to complete a plant modification to be completed by March 31, 2017. from the COMPLETION TIME as it is historical and no longer needed.

2.4.3 TS Surveillance Requirement 3.8.1.13 The current NOTE in SR 3.8.1.13 is For Unit 2, testing need only be performed for LOOP concurrent with SI until startup following 2RF05. The proposed editorial change deletes the NOTE in SR Enclosure to TXX-19064 Page 7 of 18

3.8.1.13 as it is historical and no longer needed.

Refer to Attachment 1 to TXX-19064 for the CPNPP Markup, 3.8.1 AC Sources - Operating.

2.4.4 Changes to TS 3.8.1 Bases provided For Information Only The change to the TS Bases includes several editorial changes that will assist the operators while in TS 3.8.1, AC Sources -- Operating.

The background adds that an associated bus undervoltage will automatically start the associated EDG as well as a Safety Injection (SI) signal.

The change updates current administrative controls to implement when performing surveillance testing the EDG paralleled to the grid.

The surveillance requirement section updates the steady state frequency bands proposed for TS 3.8.1.

Refer to Attachment 1 to TXX-19064 which includes For Information Only are the CPNPP Markup Technical Specification Bases, B 3.8.1 AC Sources - Operating.

The retyped pages for the proposed change to Technical Specification, TS 3.8.1 are provided for review.

Refer to Attachment 1 to TXX-19064 for the CPNPP Retyped, 3.8.1 AC Sources - Operating. Included as For Information Only are the CPNPP Retyped Technical Specification Bases, B 3.8.1 AC Sources - Operating.

3.0 TECHNICAL EVALUATION

The proposed change provides surveillance requirements that are aligned with diesel generator voltage and frequency required to supply power to safety related SSCs. The EDG SRs test the time required to have the diesel generators ready-to-load to ensure compliance with the maximum time to load under accident conditions. The band for frequency of 60 Hz + 0.1 Hz tests the ability of the DG controls to maintain steady state frequency when required. Years of empirical data show that the sole time when DG controls could not control frequency at 60 Hz + 0.1 Hz the DG controls were inoperable and thus the DG was inoperable. The voltage band of > 6480 volts and < 7150 volts fulfills two requirements; first the band ensures components down to the 120-volt level provide adequate voltage for safety related SSCs and second the band ensures compliance with TS 3.8.9, Distribution Systems - Operating and TS 3.8.10, Distribution Systems - Shutdown.

The design basis event, Loss of Coolant Accident (LOCA) with a Loss of Offsite Power (LOOP) is the primary event where the diesel generators must perform in order to cool the core and provide for long term cooling. This design basis event assumes that at least one train of onsite emergency power (DG) and one train of Emergency Core Cooling System (ECCS) are available. The proposed Enclosure to TXX-19064 Page 8 of 18

Technical Specification change does not adversely impact the ability to meet those two objectives. The proposed changes enhance the ability of CPNPP to discover, during diesel generator surveillance testing, possible degraded conditions.

CPNPP has included Attachment 4, Safety Related Pump and Motor Operated Valve (MOV) Response and Attachment 5, DBD-EE-041, 480V and 120V AC Electrical Power System, Table 5.3, MOV Minimum Starting Voltage Required. uses simple mathematical principles to show the effect of a change in frequency on pump volumetric flowrate. It illustrates that the current frequency band of 2% and the proposed frequency band of 0.2% have minor effect on actual pump volumetric flowrates. Attachment 4 also illustrates the impact of varying voltage and frequency on motor operated valves. Again simple mathematical principles are used to show the effect on MOV motor torque. It illustrates that the current frequency band of 2% and the proposed frequency band of 0.2% have minor effect on actual MOV motor torque. These attachments are provided for illustration only they are not intended to become part of the CPNPP licensing basis.

See Attachment 4 to TXX-19064, for Safety Related Pump and Motor Operated Valve Response. See Attachment 5 to TXX-19064, for DBD-EE-041, 480V and 120V AC Electrical Power System, Table 5.3, MOV Minimum Starting Voltage Required. Attachments 4 and 5 are provided For Information Only.

For these reasons, Vistra OpCo concludes that the Surveillance Requirement changes proposed by this amendment do not alter any existing analysis. The proposed change does not adversely affect diesel generator; design function, evaluation methodology (surveillance testing), operation or testing procedures, design bases or safety analysis, and does not create a new test or experiment.

In summary, the proposed technical specification changes align acceptance criteria for TS 3.8.1 surveillance requirements with the steady state voltage and frequency required to support performance of safety related SSCs and provide a better indicator of EDG control system performance. The overall scope of the diesel generator surveillance requirements includes a series of sequential, overlapping, and total examination of the entire operation of the diesel generators. The frequencies at which each surveillance requirement is performed, is controlled within the Surveillance Frequency Control Program (SFCP).

The CPNPP EDG surveillance requirements are made up of 22 separate tests that are either performed alone or in a specific sequence.

Refer to Attachment 3 to TXX-19064, for Technical Specification 3.8.1, AC Sources - Operating Surveillance Requirement Information. The surveillance requirement intervals provided are taken from the CPNPP SFCP.

The two editorial changes remove historical information that no longer applies to Enclosure to TXX-19064 Page 9 of 18

the CPNPP Technical Specifications. Their removal has no impact on the Technical Evaluation.

4.0 REGULATORY EVALUATION

4.1 Applicable Regulatory Requirements The regulatory basis for Technical Specifications 3.8.1, AAC Sources --

Operating@ is to ensure that a Loss of Offsite Power or a Loss of Coolant Accident with a Loss of Offsite Power are sensed and operation of systems and components important to safety are initiated in order to protect against violating core design limits, challenging the reactor coolant system pressure boundary, and to mitigate the consequences of accidents.

Section 182a of the Atomic Energy Act requires applicants for nuclear power plant operating licenses to include technical specifications as part of the license. The Commission's regulatory requirements related to the content of the technical specifications are contained in Title 10, Code of Federal Regulations (10 CFR), Section 50.36, "Technical Specifications,"

of 10 CFR Part 50 "Domestic Licensing of Production and Utilization Facilities." The technical specification requirements in 10 CFR 50.36 include the following categories: (1) safety limits, limiting safety systems settings and control settings, (2) limiting conditions for operation, (3) surveillance requirements, (4) design features, and (5) administrative controls. The requirements for AC Sources -- Operating are included in the technical specifications in accordance with 10 CFR 50.36(c)(2),

"Limiting Conditions for Operation."

This license amendment request is submitted pursuant to 10 CFR 50.90 as a change to the technical specifications is required. Vistra OpCos submittal meets the requirements of 10 CFR 50.90.

General Design Criterion (GDC) 17 "Electric power Systems," of Appendix A "General Design Criteria for Nuclear Power Plants," to 10 CFR Part 50 requires, among other things, an onsite electric power system and an offsite electric power system shall be provided to permit functioning of structures, systems, and components important to safety. The safety function for each system (assuming the other system is not functioning) shall be to provide sufficient capacity and capability to assure that (1) specified acceptable fuel design limits and design conditions of the reactor coolant pressure boundary are not exceeded as a result of anticipated operational occurrences and (2) the core is cooled and containment integrity and other vital functions are maintained in the event of postulated accidents. The proposed operational change continues to provide onsite electric power supplies, including the batteries, and the onsite electric Enclosure to TXX-19064 Page 10 of 18

distribution system, shall have sufficient independence, redundancy, and testability to perform their safety functions assuming a single failure.

(Reference 6.3)

General Design Criterion (GDC) 18 "Inspection and Testing of Electric Power Systems," of Appendix A "General Design Criteria for Nuclear Power Plants," to 10 CFR Part 50 requires, among other things, Electric power systems important to safety shall be designed to permit appropriate periodic inspection and testing of important areas and features, such as wiring, insulation, connections, and switchboards, to assess the continuity of the systems and the condition of their components. The systems shall be designed with a capability to test periodically (1) the operability and functional performance of the components of the systems, such as onsite power sources, relays, switches, and buses, and (2) the operability of the systems as a whole and, under conditions as close to design as practical, the full operation sequence that brings the systems into operation, including operation of applicable portions of the protection system, and the transfer of power among the nuclear power unit, the offsite power system, and the onsite power system. The proposed operational change continues to periodically test the specific operability and functionality of the Emergency Diesel Generators and loading sequencers. (Reference 6.4)

Regulatory Guide 1.9 [1971], Selection of Diesel Generator Set Capacity for Standby Power Supplies.

The rating of the diesel generators is based on the maximum continuous load demand. This rating exceeds the sum of the conservatively rated loads. Motor loads are based on nameplate rating, pump runout conditions, or flow pressure conditions. 6600-V motor efficiency is based on design data.

During preoperational testing, the maximum continuous load demand is verified by tests. Each diesel generator set is capable of starting and accelerating to rated speed and loading all Class 1E loads in the required sequence.

Sequencing of large loads at 5-sec intervals ensures that large motors have reached rated speed and that voltage and frequency have stabilized before the succeeding loads are applied. The voltage may dip below 75 percent of nominal voltage when the diesel generator breaker closes and energizes the two 2000/2666 KVA, 6.9 KV/480-V unit substation transformers supplied from each diesel generator. This dip is due to magnetizing inrush current which exists for two to three cycles. The diesel generators are designed to recover to 80 percent of nominal voltage within 10 cycles for this transient. The effect on the first load group would, therefore, be a maximum possible delay of 12 to 13 cycle after closure of the diesel generator breaker. However, the objective of first load group and subsequent load groups is not affected. During recovery Enclosure to TXX-19064 Page 11 of 18

from transients caused by step load increases or resulting from the disconnection of the largest single load, the speed of the diesel generator set should not exceed the nominal speed plus 75 percent of the difference between nominal speed and the overspeed trip setpoint or 115 percent of nominal, whichever is lower. The voltage is restored to within 10 percent of nominal; and the frequency is restored to within two percent of nominal in less than 40 percent of each load sequence time interval. The diesel generator supplier has successfully performed these tests in their facility on one CPNPP diesel generator set.

The prototype qualification test program of

a.

Start and load capability at full load, and

b.

300 valid start and load tests on the diesel generator (Reference 6.5)

Regulatory Guide 1.32 [1977], Criteria for Safety-Related Electric Power Systems for Nuclear Power Plants.

The offsite power system includes the preferred design stated in NRC Regulatory Guide 1.32: namely, two immediate access circuits from the transmission network are available to the emergency (Class 1E) bus systems. (Reference 6.6)

Regulatory Guide 1.93 [1974], Availability of Electric Power Sources.

CPNPP power operation procedure is in compliance with NRC Regulatory Guide 1.93 as described in technical specifications. The power operation procedure is initiated and continued without restriction only when the limiting conditions for operation (TS) are met. If the TSs are not met, the power operation will be restricted in accordance with the technical specification. (Reference 6.7)

Regulatory Guide 1.108 [1977], Periodic Testing of Diesel Generator Units used as Onsite Electric Power Systems at Nuclear Power Plants.

The CPNPP design complies with the intent of Revision 1 (8/77) of this regulatory guide.

1.

The requirements of position C. 1b.4 are satisfied as described below:

a.

Diesel generator (D-G) "Ready Stand by" status indication in the Control Room can be acknowledged by the combination of a green light for output breaker and the absence of a "D-G disable" and a "D-G trouble" annunciator indication.

b.

"D-G Lockout" status is indicated by means of a "D-G disable" annunciation in the Control Room. This status is also indicated by "DG PWR" indication on the safety system bypass and inoperable status indicating light box in the Enclosure to TXX-19064 Page 12 of 18

Control Room due to any of the following:

1.

DC power unavailable

2.

Remote-Local-Maintenance switch not in remote on the generator control panel.

c.

"D-G undertest" status light is not provided in the CPNPP design.

d.

A means of communication is provided between the diesel generator room and the Control Room.

2.

The requirements of Regulatory Positions are clarified as described below:

Regulatory Position C.2.a.(4)

The largest single load is taken to be the largest single end load and not combined distribution system loads (e.g., distribution system transformers or load centers). This load is 783 kW equal to the nameplate rating of the Component Cooling Water pump.

Regulatory Position C.2.d If the number of failures in the last 100 valid tests is seven or more for an individual diesel generator unit, the reliability of that diesel generator requires special evaluation (i.e., the reliability of both diesel generators is not impacted).

3.

The CPNPP periodic testing program meets the intent of the regulatory guide with the following exceptions:

a. Regulatory Position C.2.a.3 During preoperational testing, testing will be conducted at the full-load-carrying capability for an interval of not less than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, of which 22 hours2.546296e-4 days <br />0.00611 hours <br />3.637566e-5 weeks <br />8.371e-6 months <br /> will be at the continuous rating capability of the diesel generator and 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> at a load equivalent to the two hour rating of the diesel generator. At a frequency specified in accordance with Technical Specification 5.5.21, "Surveillance Frequency Control Program", testing will be conducted to demonstrate full-load-carrying capability for an interval of not less than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, of which 22 hours2.546296e-4 days <br />0.00611 hours <br />3.637566e-5 weeks <br />8.371e-6 months <br /> will be at a load which exceeds the maximum expected diesel generator load requirements and 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> at a load which is approximately 110% of this maximum expected load.

b. Regulatory Position C.2.a.5 Demonstrate functional capability at full load temperature conditions by rerunning the test phase outlined in Regulatory Position C.2.a.1 and by demonstrating proper operation for shutdown-loading-sequence to shutdown-load requirements Enclosure to TXX-19064 Page 13 of 18

immediately following the performance of C.2.a.3, except during preoperational testing when the proper operation for the design-accident-loading-sequence to design-load requirements will be demonstrated.

c. Regulatory Position C.2.a.9 Demonstrate the reliability of the Emergency Diesel Generator by performing at least a total of 69 (but no less than 35 per Emergency Diesel Generator) consecutive valid start and load tests on the Emergency Diesel Generators from cold ambient conditions to at least 50 percent continuous rating for at least 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> with no failures. These tests need not be performed as part of the pre-operational test program, but may be performed at any time prior to the required operability of the Emergency Diesel Generator.

d. Regulatory Position C.2.c.2 Periodic testing of the diesel generator units during normal plant operation to demonstrate full-load-carrying capability will be conducted at a load which exceeds the maximum expected diesel generator load requirements. During this test, loading to the diesel generator is accomplished in accordance with vendor recommendations.

e. Regulatory Position C.2.d Diesel generators testing frequency is in accordance with the requirements of the technical specifications.

4.

The requirements of Regulatory Position c.3.b is satisfied as described below:

Other existing reporting requirements adequately ensure that the NRC learns of significant problems with diesel generator performance. Reporting requirements for EDG failures provided in this section will not be submitted.

(Reference 6.8)

IEEE 387-1977, Criteria for Diesel Generator Units Applied as Standby Power Supplies for Nuclear Power Generating Stations.

Testability and Maintenance Circuit design provisions incorporate test capability to periodically monitor the operational capability of the safety-related Class 1E systems during power operation. Initially, all safety-related equipment is tested during the startup testing phase.

Diesel generator sets are tested after final assembly and preliminary startup. Site acceptance tests are given to each diesel generator set to demonstrate its required capabilities.

Enclosure to TXX-19064 Page 14 of 18

The following tests are administered to certify the adequacy of the units for the intended service:

a.

Starting tests

b.

Load acceptance tests

c.

Rated load tests

d.

Design load tests

e.

Load rejection tests

f.

Electrical tests

g.

Subsystem tests The objectives and requirements of the preceding tests are established in IEEE 387-1977 [32].

Periodic testing of the diesel generators will be performed as specified in the Technical Specifications to verify their continued capability and availability to perform their design function after commercial operation of the plant. Typical tests consist of availability and operational tests as outlined in IEEE 387-1977.

The CPNPP preventive maintenance program is established to prevent failures. Should failures occur, however, the program will function to identify root cause of any malfunctions and to perform the required repairs or component replacement. On completion of the repairs/maintenance, final equipment check is performed prior to starting of any tests to assure a good start. On satisfactory completion of the post-maintenance testing, control of equipment is transferred to the control room operator. These are accomplished by maintenance department procedure. (Reference 6.9) 4.2 Precedent None cited.

4.3 No Significant Hazards Consideration Determination Vistra OpCo has evaluated whether or not a significant hazards consideration is involved with the proposed amendment by focusing on the three standards set forth in 10 CFR 50.92, AIssuance of amendment,@

as discussed below:

1.

Do the proposed changes involve a significant increase in the probability or consequences of an accident previously evaluated?

Response: No The design basis event of a LOCA with a LOOP bounds all other Enclosure to TXX-19064 Page 15 of 18

loss of offsite power events. This design basis event evaluation assumes at least one train of emergency onsite power (DG) and one train of ECCS equipment will be available. The single train of emergency on site power and single train of ECCS equipment are credited in design basis accidents and are, therefore, part of the primary success path for postulated accident mitigation as defined by 10 CFR 50.36(c)(2)(ii), Criterion 3. The proposed change in EDG frequency bands is bounded by the current frequency bands and therefore does affect any safety analysis. The proposed change to TS 3.8.1 surveillance requirements will not impact any previously evaluated design basis accidents. The two editorial changes remove historical information that is no longer required.

Their removal will not impact any previously evaluated design basis accidents.

Therefore, the proposed change does not involve a significant increase in the probability or consequences of an accident previously evaluated.

2.

Do the proposed changes create the possibility of a new or different kind of accident from any accident previously evaluated?

Response: No This technical specification change provides surveillance requirement acceptance criteria that aligns diesel generator steady state voltage and frequency required to support performance of safety related SSCs. These changes do not impact accident analysis. Since these changes only affect surveillance requirement acceptance criteria and do not affect the function of the emergency diesel generators, it will not be an initiator to a new or different kind of accident from any accident previously evaluated.

And as previously stated, the proposed change in EDG frequency bands is bounded by the current frequency bands. The two editorial changes remove historical information that is no longer required. Their removal will not be an initiator to a new or different kind of accident from any accident previously evaluated.

Therefore, the proposed change does not create the possibility of a new or different kind of accident from any previously evaluated.

3.

Do the proposed changes involve a significant reduction in a margin of safety?

Response: No This Technical Specification change involves surveillance Enclosure to TXX-19064 Page 16 of 18

requirement acceptance criteria, which does not affect an assumed start signal for design basis events. The two editorial changes remove historical information that is no longer required. Their removal deletes a one time Completion Time that has expired and deletes a surveillance requirement Note that has not been used since CPNPP Unit 2, fifth refueling outage. These changes do not modify any values or limits involved in a safety related function or accident analysis.

Therefore, the proposed change does not involve a significant reduction in a margin of safety.

Based on the above evaluations, Vistra OpCo concludes that the proposed amendment presents no significant hazards consideration under the standards set forth in 10 CFR 50.92(c) and, accordingly, a finding of Ano significant hazards consideration@ is justified.

4.4 Conclusions The requirements of GDC 17 (Reference 6.3) and 18 (Reference 6.4) continue to be met since no changes are being proposed which would affect the design capability, function, operation, or method of testing the Emergency Diesel Generators. The changes are to some surveillance requirement acceptance criteria and the editorial removal of historical information that is no longer required for Technical Specification 3.8.1, AC Sources - Operating. Therefore, the applicable guidance of Regulatory Guides 1.9, 1.32, 1.93, and 1.108 continue to be met. AC Sources -

Operating will continue to meet the requirements of IEEE 327-1977.

In conclusion, based on the considerations discussed above, (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner, (2) such activities will be conducted in compliance with the Commission=s regulations, and (3) the issuance of the amendment will not be adverse to the common defense and security or to the health and safety of the public.

5.0 ENVIRONMENTAL CONSIDERATION

S Vistra OpCo has determined that the proposed amendment would change requirements with respect to the installation or use of a facility component located within the restricted area, as defined in 10 CFR 20, or would change an inspection or surveillance requirement. However, the proposed amendment does not involve (i) a significant hazards consideration, (ii) a significant change in the types or significant increase in the amount of effluent that may be released offsite, or (iii) a significant increase in the individual or cumulative occupational radiation exposure. Accordingly, the proposed change meets the eligibility Enclosure to TXX-19064 Page 17 of 18

criterion for categorical exclusion set forth in 10 CFR 51.22(c)(9). Therefore, pursuant to 10 CFR 51.22(b), an environmental assessment of the proposed change is not required.

6.0 REFERENCES

6.1 CPNPP FSAR Section 8.3.1, "AC Power Systems" 6.2 CPNPP FSAR Section 15.6.5, "Loss of Coolant Accident Resulting from a Spectrum of Postulated Piping Breaks within the Reactor Coolant Pressure Boundary" 6.3 General Design Criteria (GDC) of 10 CFR 50 Appendix A, GDC 17 "Electric Power Systems 6.4 General Design Criteria (GDC) of 10 CFR 50 Appendix A, GDC 18 Inspection and Testing of Electric Power Systems 6.5 Regulatory Guide 1.9, Selection of Diesel Generator Set Capacity for Standby Power Supplies (3/10/71) 6.6 Regulatory Guide 1.32, Criteria for Safety-Related Electric Power Systems for Nuclear Power Plants (Revision 2, 2/77) 6.7 Regulatory Guide 1.93, Availability of Electric Power Sources (12/74) 6.8 Regulatory Guide 1.108, Periodic Testing of Diesel Generator Units used as Onsite Electric Power Systems at Nuclear Power Plants (Revision 1, August 1977) 6.9 IEEE 387-1977, Criteria for Diesel Generator Units Applied as Standby Power Supplies for Nuclear Power Generating Stations.

6.10 ER-ME-109 Rev 1, Evaluation of Safety-Related Pump Degradation Issues Enclosure to TXX-19064 Page 18 of 18

to TXX-19064 CPNPP Technical Specification 3.8.1, AC Sources -- Operating Technical Specification and Bases Pages

1.

Current Technical Specification Page 3.8-1 through 3.8-16

2.

Markup of Technical Specification Page 3.8-1 through 3.8-16

3.

Retype of Technical Specification Page 3.8-1 through 3.8-16

4.

Current Technical Specification Bases Pages B 3.8-1 through B 3.8-29 (For Information Only)

5.

Markup of Technical Specification Bases Pages B 3.8-1 through B 3.8-29 (For Information Only)

6.

Retype of Technical Specification Bases Pages B 3.8-1 through B 3.8-30 (For Information Only) to TXX-19064 Page 1 of 137

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INSERT A Prior to EDG start:

1. Ensure no Severe Thunderstorm or Tornado Warning is in effect.

2. Verify local grid stability by contacting the Grid Controller.

3. Ensure no switchyard activities will be performed that could impact the test.

4. Verify all required systems, subsystems, trains, components and devices that depend on the opposite train EDG are OPERABLE.

5. Verify the affected Unit Turbine Driven AFW pump is OPERABLE.

6. Verify offsite power sources are OPERABLE and SRs for opposite train EDG are current.

7. Ensure all safeguards 6900 V buses (both Units) are powered from their preferred offsite source.

8. Ensure affected Unit safeguards 6900 V bus voltages are > 6750 volts.

Once the EDG is paralleled with an offsite power source, TERMINATE the test if any of the following occur:

1. Affected Unit Reactor trips.

2. The EDG being tested exceeds the limit established for the test. Momentary transients do not invalidate the test.

3. The EDG being tested requires frequent or continuous adjustment to maintain load below that specified for the test.

4. The EDG being tested exceeds 5000 KVAR.

5. Associated bus steady state voltage lowers > 200 V.

6. Associated bus steady state frequency is < 59 Hz.

If test termination is required;

1. Open the EDG output breaker.

2. Slowly adjust EDG voltage to 6900 V.

3. Slowly adjust EDG frequency to 60.0 Hz. to TXX-19064 Page 108 of 137

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to TXX-19064 CPNPP FIGURES For Information Only Figure

1. 6900 VAC & 480 VAC (Unit 1 Only - Both units are similar)

Figure

2. CPNPP Electric Grid Connection Diagram to TXX-19064 Page 1 of 3

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6900VAC and 480VAC FOR INFORATION ONLY Figure 1

8080 8030 8020 W11 W10 E10 8645 W9 8079 8081 8029 8031 8021 8019 8644 8646 8090 W7 8089 8091 7980 7970 W6 E6 7979 7981 7971 7969 8050 W5 8049 8051 8010 8000 W3 8009 8011 8001 7999 E3 These breakers controlled by CPNPP 8070 W2 8069 8071 WEST BUS EAST BUS 345 KV Switchyard 8075 8076 8074 Iso Phase Bus Duct Cooling PT Flex Link Rigid Link Bus Conn Gen Flex Link Flex Conn Aux Bus Lower Link Aux Bus Upper Link Aux Bus Link Flex Conn Flex Conn Generator Line Bushing Box Neutral Bushing Neutral Bushing Box Neutral Grounding Transformer Y

X 2ST 2A2-2, 2A4-2, XA1-2 2MT1 2MT2 2UT Y

X 2A1-2, 2A3-2 2A2-1, 2A4-1 2A1-1, 2A3-1 Potential Transformers Y

X 1ST 1A2-2, 1A4-2, XA1-1 1A1-2, 1A3-2 Y

X Y

X M

M M

XST2A XST2 MOAS 8032 MOAS 8052 MOAS 8012 1MT1 1MT2 Iso Phase Bus Duct Cooling PT Flex Link Rigid Link Bus Conn Gen Flex Link Aux Bus Lower Link Aux Bus Upper Link Aux Bus Link Flex Conn Flex Conn Generator Line Bushing Box Neutral Bushing Neutral Bushing Box Neutral Grounding Transformer 1UT Y

X 1A2-1, 1A4-1 1A1-1, 1A3-1 Unit 2 Main Generator Unit 1 Main Generator Transformer

1. 1 25 kV Loop 7050 7030 7040 7029 7031 7041 7039 7022 7020 7019 7021 7052 Transformer

1. 2 25 kV Loop Capacitor Banks 8035 WEST BUS EAST BUS 138 KV Switchyard PT Fuses Flex Conn Potential Transformers PT Fuses Aux TRFMR Link CPNPP Electrical Grid Connection Diagram FOR INFORMATION ONLY Meter and Relay Meter and Relay Upper Lower Upper Lower Stephenville Parker #2 Switchyard Parker #1 Switchyard Comanche Switchyard Venus Switchyard Everman Switchyard Wolf Hollow Switchyard Mitchell Bend 345 kV Switchyard 9860 9855 9854 9856 9859 9861 9865 6800 6799 6801 9864 9866 7515 7510 7509 7511 7514 7516 9770 9775 9774 9776 9769 9771 10040 10045 10044 10046 10039 10041 7150 7155 7154 7156 7149 7151 9864 9866 Decordova 138 kV Switchyard 4460 Y

X M

XST1 MOAS 8085 Ground Switch 1EA1-2, 1EA2-2 2EA1-1, 2EA2-1 Y

X M

XST1A MOAS 8095 Removable Link 8060 E1 8061 8059 8650 E4 8651 8649 8040 E8 8041 8039 1EA1-1, 1EA2-1 2EA1-2, 2EA2-2 Removable Link 7051 7049 8002 8022 9766 9765 9764 4500 Venus E11 13485 13490 Control Room performs Grid Controller duties for these Air Switches Figure 2 to TXX-19064 Page 3 of 3

to TXX-19064 CPNPP Technical Specification 3.8.1, AC Sources - Operating, Surveillance Requirement Information in accordance with the Surveillance Frequency Control Program For Information Only to TXX-19064 Page 1 of 4

Comanche Peak Nuclear Power Plant Technical Specification 3.8.1, AC Sources -- Operating Surveillance Requirement Information in accordance with the SFCP and Site Procedures SR SR Frequency SR Title Procedure Procedure Title 3.8.1.1 7 days Offsite & Onsite Circuit Continuity OPT-215 Class 1E Electrical Systems Operability 3.8.1.2 31 Days DG Monthly Slow Start OPT-214A/B Diesel Generator Operability Test 3.8.1.3 31 Days DG Monthly 60 Minute Load Test OPT-214A/B Diesel Generator Operability Test 3.8.1.4 31 Days DG Fuel Oil Day Tank Level OPT-214A/B Diesel Generator Operability Test 3.8.1.5 31 Days DG Fuel Oil Day Tank Water Removal OPT-214A/B Diesel Generator Operability Test 3.8.1.6 92 Days DG Fuel Oil Transfer Test OPT-515A/B Diesel Generator Fuel Oil Transfer System 3.8.1.7 184 Days DG Semi-annual Fast Start OPT-214A/B Diesel Generator Operability Test 3.8.1.8 18 Months Offsite Power Source Transfer MSE-S1-0602A/B MSE-S2-0602A/B Train A/B UV Relay/RTT &

Bus Transfer Tests 3.8.1.9 18 Months (STB)

Single Largest Load Rejection OPT-430A/B OPT-435A/B Train A/B Integrated Test Sequence 3.8.1.10 18 Months (STB)

Full Load Rejection OPT-430A/B OPT-435A/B Train A/B Integrated Test Sequence to TXX-19064 Page 2 of 4

Comanche Peak Nuclear Power Plant Technical Specification 3.8.1, AC Sources -- Operating Surveillance Requirement Information in accordance with the SFCP and Site Procedures SR SR Frequency SR Title Procedure Procedure Title 3.8.1.11 18 Months (STB)

Emergency Bus Load Shed, DG Start, Sequence and Run on Loss of Offsite Power OPT-430A/B OPT-435A/B Train A/B Integrated Test Sequence 3.8.1.12 18 Months DG Safety Injection Auto Start OPT-465A/B OPT-467A/B OPT-489A/B OPT-491A/B Train A/B Safeguards Slave Relay K603, K609 Actuation Test 3.8.1.13 18 Months (STB)

DG Non-Emergency Trip Signals Bypassed on Safety Injection OPT-430A/B OPT-435A/B Train A/B Integrated Test Sequence 3.8.1.14 18 Months (STB)

DG 24/2 Hour Run OPT-214A/B Diesel Generator Operability Test 3.8.15 18 Months (STB)

DG Hot Restart OPT-430A/B OPT-435A/B Train A/B Integrated Test Sequence 3.8.1.16 18 Months (STB)

DG Synchronization and Load Transfer OPT-430A/B OPT-435A/B Train A/B Integrated Test Sequence 3.8.1.17 18 Months (STB)

DG Safety Injection Override Test OPT-430A/B OPT-435A/B MSE-S1-0602A/B MSE-S2-0602A/B Train A/B Integrated Test Sequence Train A/B UV Relay/RTT &

Bus Transfer Tests 3.8.1.18 18 Months Automatic Load Sequencing INC-7917A/B INC-7918A/B Channel Calibration Solid State Sequencer Train A/B to TXX-19064 Page 3 of 4

Comanche Peak Nuclear Power Plant Technical Specification 3.8.1, AC Sources -- Operating Surveillance Requirement Information in accordance with the SFCP and Site Procedures SR SR Frequency SR Title Procedure Procedure Title 3.8.1.19 18 Months (STB)

Emergency Bus Load Shed, DG Start, Sequence and Run on Safety Injection in Conjunction with Loss of Offsite Power OPT-430A/B OPT-435A/B Train A/B Integrated Test Sequence 3.8.1.19b 18 Months (STB)

Load Shedding on SI with Loss of Offsite Power OPT-430A/B OPT-435A/B Train A/B Integrated Test Sequence 3.8.1.20 10 Years Simultaneous Start of Both DGs OPT-236A OPT-236B Simultaneous Start of Unit 1(2) Train A and B Diesel Generators 3.8.1.21 18 Months Blackout Sequencer Under Voltage Relay Test INC-7917A/B INC-7918A/B MSE-S1-0673A/B MSE-S2-0673A/B Channel Calibration Solid State Sequencer Train A/B Train A/B Sequencer Under Voltage Relay Surveillance 3.8.1.22 31 Days (STB)

Safety Injection and Blackout Sequencer Trip Actuating Device Operational Test OPT-414A/B SI/Blackout Sequencers STB - Staggered Test Basis to TXX-19064 Page 4 of 4

to TXX-19064 CPNPP Safety Related Pump and Motor Operated Valve Response For Information Only to TXX-19064 Page 1 of 4

For Information Only This Data is for Illustration Only CPNPP Safety Related Pump and Motor Operated Valve Response Safety Related Pumps The following relationship has been used to populate the above Table; V = volumetric flowrate in gpm n = pump speed in rpm f = frequency in hertz V2 = V1 (n2 / n1), with frequency directly proportional to speed this relationship is used V2 = V1 (f2 / f1)

The above numbers are for illustration only. In actual plant operation with power sources operating as designed the frequency of the off-site power source is 60 Hz + 0.03 Hz and the frequency of the Emergency Diesel Generators (EDG) is 60 Hz + 0.1 Hz. To have frequency affect flow as illustrated in the table above there would have to be a malfunction of the off-site or EDG control system.

The table shows that flows at the frequencies given, provide adequate flow for Loss of Coolant Accident (LOCA) mitigation.

All nominal flows (@ 60 Hz) are selected within the acceptance criteria band used during surveillance testing for the listed pumps. The current Technical Specification minimum and maximum values for frequency would result in a 2% change in flow from each pumps nominal flow. The proposed Technical Specification minimum and maximum frequency values Safety Related Pump Flows as a Function of Frequency Pump Flow @ 58.8 Hz Flow @ 59.9 Hz Flow @ 60 Hz Flow @ 60.1 Hz Flow @ 61.2 Hz Auxiliary Feedwater 426 gpm 434 gpm 435 gpm 436 gpm 444 gpm Containment Spray 3259 gpm 3320 gpm 3325 gpm 3331 gpm 3392 gpm Residual Heat Removal 3864 gpm 3936 gpm 3943 gpm 3950 gpm 4022 gpm Safety Injection 593 gpm 604 gpm 605 gpm 606 gpm 617 gpm Centrifugal Charging 421 gpm 429 gpm 430 gpm 431 gpm 439 gpm Station Service Water 15532 gpm 15823 gpm 15849 gpm 15875 gpm 16166 gpm Component Cooling Water 16293 gpm 16597 gpm 16625 gpm 16653 gpm 16958 gpm Safety Chilled Water Recirc 279 gpm 285 gpm 285 gpm 286 gpm 291 gpm to TXX-19064 Page 2 of 4

For Information Only This Data is for Illustration Only would result in a 0.2% change in flow from each pumps nominal flow. A 0.2% change in pump flow is indistinguishable from nominal pump flow.

The current Technical Specification 6900-volt acceptance criteria minimum of 6480 volts and maximum of 7150 volts do not adversely impact pump performance.

Safety Related Motor Operated Valves (MOV)

Motor Operated Valve (MOV) Motor V/Hz as a Function of Voltage and Frequency Voltage V/Hz @ 58.8 Hz V/Hz @ 59.9 Hz V/Hz @ 60.0 Hz V/Hz @ 60.1 Hz V/Hz @ 61.2 Hz 368 (1) 6.26 6.14 6.13 6.12 6.01 410 (2) 6.97 6.84 6.83 6.82 6.70 455 (3) 7.74 7.60 7.58 7.57 7.43 460 (4) 7.82 7.68 7.67 7.65 7.52 480 (5) 8.16 8.01 8.00 7.99 7.84 508 (6) 8.64 8.48 8.47 8.45 8.30 The current Technical Specification 480-volt acceptance criteria minimum of 455 volts and maximum of 508 volts do not adversely impact MOV performance. Attachment 5 lists the minimum required starting voltage for Class 1E MOVs. As shown in Attachment 5 the highest minimum voltage required is 410 volts which is well below the Technical Specification minimum of 455 volts.

(1) Lowest Minimum Starting Voltage Safety-Related MOVs (4) Motor Operated Valve Nameplate Voltage (2) Highest Minimum Starting Voltage Safety-Related MOVs (5) Nominal 480V Bus Voltage (3) Minimum Technical Specification Voltage (6) Maximum Technical Specification Voltage to TXX-19064 Page 3 of 4

For Information Only This Data is for Illustration Only Motor Operated Valve (MOV) Motor Torque as a Function of Volts per Hertz (V/Hz)

Voltage V/Hz@ 58.8 Hz V/Hz@ 59.9 Hz V/Hz@ 60.0 Hz V/Hz@ 60.1 Hz V/Hz@ 61.2 Hz 368 (1) 15.78 FT-LB 15.47 FT-LB 15.45 FT-LB 15.42 FT-LB 15.14 FT-LB 410 (2) 15.77 FT-LB 15.47 FT-LB 15.45 FT-LB 15.42 FT-LB 15.15 FT-LB 455 (3) 15.80 FT-LB 15.49 FT-LB 15.45 FT-LB 15.43 FT-LB 15.14 FT-LB 460 (4) 15.75 FT-LB 15.47 FT-LB 15.45 FT-LB 15.41 FT-LB 15.14 FT-LB 480 (5) 15.76 FT-LB 15.47 FT-LB 15.45 FT-LB 15.42 FT-LB 15.14 FT-LB 508 (6) 15.76 FT-LB 15.47 FT-LB 15.45 FT-LB 15.41 FT-LB 15.14 FT-LB (1) Lowest Minimum Starting Voltage Safety-Related MOVs (4) Motor Operated Valve Nameplate Voltage (2) Highest Minimum Starting Voltage Safety-Related MOVs (5) Nominal 480V Bus Voltage (3) Minimum Technical Specification Voltage (6) Maximum Technical Specification Voltage Since; M = Magnetic Flux is proportional to Volts/Hertz

= Torque is proportional to M The following example illustrates that as long as Technical Specification Maximum and Minimum voltages and frequencies are maintained there is little change to motor torque; Torque = 10 HP x 5252 / 3400 rpm (V/Hz1/V/Hz2)

V/Hz1 = Volts per Hertz at 60.0 Hz V/Hz2 = Volts per Hertz at current or proposed Technical Specification values to TXX-19064 Page 4 of 4

to TXX-19064 CPNPP DBD-EE-041, 480V and 120V AC Electrical Power System, Table 5.3, MOV Minimum Starting Voltage Required For Information Only to TXX-19064 Page 1 of 10

CPNPP UNITS 1 AND 2 DBD-EE-041 480V AND 120V AC ELECTRICAL POWER SYSTEM REVISION 32 PAGE 42 OF 168 5.3.2 Safeguard 480V and 120V AC System A.

The maximum available short circuit currents at the 480V AC unit substations, at the MCC buses, and at the 120V AC and 208/120V AC panelboards are addressed in calculations # EE-SC-U1-1E & 16345-EE(B)-019 for unit 1 and EE-SC-U2-1E & 2-EE-013 for Unit 2.

B.

The 480V AC Safeguard System is designed to furnish a nominal voltage of 480V at its unit substation buses. The 6.9 kV / 480 V voltage spread and the variation of bus voltages is addressed in calculation # EE-VP-U1-1E for Unit 1 and calculation

1. EE-VP-U2-1E for Unit 2.

C.

Class 1E MOV voltage requirement is given in Table - 5.3 below based on the requirement as analyzed in Calc. # ME-CA-0000-1093.

TABLE - 5.3 MOV TAG #

MOV Minimum Starting Voltage Required Valve Actuation Signal REF. DWG ICD #

1-8000A 410 MANUAL M1-2251-07 1-8000B 410 MANUAL M1-2251-07 to TXX-19064 Page 2 of 10

CPNPP UNITS 1 AND 2 DBD-EE-041 480V AND 120V AC ELECTRICAL POWER SYSTEM REVISION 32 PAGE 43 OF 168 MOV TAG #

MOV Minimum Starting Voltage Required Valve Actuation Signal REF. DWG ICD #

1-8100 388 PH. A ISOL M1-2253-09 1-8104 390 MANUAL M1-2255-18A 1-8105 389 "S" SIGNAL M1-2255-18 1-8106 390 "S" SIGNAL M1-2255-18 1-8110 390 "S" SIGNAL M1-2255-19 1-8111 391 "S" SIGNAL M1-2255-19 1-8112 389 PH. A ISOL M1-2253-09 1-8351A 410 MANUAL M1-2253-16 1-8351B 410 MANUAL M1-2253-16 1-8351C 410 MANUAL M1-2253-16 1-8351D 410 MANUAL M1-2253-16 1-8511A 386 "S" SIGNAL M1-2255-21 1-8511B 390 "S" SIGNAL M1-2255-21 1-8512A 410 MANUAL w/VLV INTRLK M1-2255-22 1-8512B 410 MANUAL w/VLV INTRLK M1-2255-22 1-8701A 410 MANUAL M1-2260-05 1-8701B 399 MANUAL M1-2260-05 1-8702A 390 MANUAL M1-2260-05 1-8702B 383 MANUAL M1-2260-05 1-8716A 410 MANUAL M1-2260-05A 1-8716B 410 MANUAL M1-2260-05A 1-8801A 385 "S" SIGNAL M1-2261-05 1-8801B 385 "S" SIGNAL M1-2261-05 1-8802A 410 MANUAL M1-2263-05 1-8802B 410 MANUAL M1-2263-05 1-8804A 410 MANUAL w/VLV INTRLK M1-2261-06 1-8804B 410 MANUAL w/VLV INTRLK M1-2261-06 1-8806 410 MANUAL M1-2263-05 1-8807A 410 MANUAL M1-2261-07 1-8807B 410 MANUAL M1-2261-07 1-8809A 410 MANUAL M1-2263-06 1-8809B 410 MANUAL M1-2263-06 1-8811A 410 "S" SIGNAL w/RWST INTRLK M1-2263-06 1-8811B 410 "S" SIGNAL w/RWST INTRLK M1-2263-06 1-8812A 410 MANUAL M1-2263-06 1-8812B 410 MANUAL M1-2263-06 1-8813 410 MANUAL M1-2263-07 to TXX-19064 Page 3 of 10

CPNPP UNITS 1 AND 2 DBD-EE-041 480V AND 120V AC ELECTRICAL POWER SYSTEM REVISION 32 PAGE 44 OF 168 MOV TAG #

MOV Minimum Starting Voltage Required Valve Actuation Signal REF. DWG ICD #

1-8814A 410 MANUAL M1-2263-07 1-8814B 410 MANUAL M1-2263-07 1-8821A 410 MANUAL M1-2263-08 1-8821B 410 MANUAL M1-2263-08 1-8835 410 MANUAL M1-2263-09 1-8840 410 MANUAL M1-2263-09 1-8923A 410 MANUAL M1-2263-12 1-8923B 410 MANUAL M1-2263-12 1-8924 410 MANUAL M1-2261-11 1-FCV-0610 395 "S" SIGNAL M1-2260-03 1-FCV-0611 397 "S" SIGNAL M1-2260-03 1-FV-4772-1 391 "P" SIGNAL M1-2232-03 1-FV-4772-2 391 "P" SIGNAL M1-2232-03 1-FV-4773-1 391 "P" SIGNAL M1-2232-03 1-FV-4773-2 391 "P" SIGNAL M1-2232-03 1-HV-2480 410 MANUAL M1-2206-08 1-HV-2481 410 MANUAL M1-2206-08 1-HV-2482 410 MANUAL M1-2206-08 1-HV-2484 390 "S" SIGNAL (AFW PUMP START)

M1-2206-09 1-HV-2485 389 "S" SIGNAL (AFW PUMP START)

M1-2206-09 1-HV-2491A 410 MANUAL M1-2206-10 1-HV-2491B 410 MANUAL M1-2206-10 1-HV-2492A 410 MANUAL M1-2206-10 1-HV-2492B 410 MANUAL M1-2206-10 1-HV-2493A 410 MANUAL M1-2206-10 1-HV-2493B 410 MANUAL M1-2206-10 1-HV-2494A 410 MANUAL M1-2206-10 1-HV-2494B 410 MANUAL M1-2206-10 1-HV-4075B 387 PH. A ISOL M1-2225-01B 1-HV-4075C 389 PH. A ISOL M1-2225-01B 1-HV-4286 391 "S" SIGNAL @ T= 25 M1-2233-05 1-HV-4287 392 "S" SIGNAL @ T= 25 M1-2233-05 1-HV-4393 392 EDG START M1-2234-02A 1-HV-4394 410 EDG START M1-2234-02A 1-HV-4395 410 MANUAL M1-2234-02 1-HV-4396 410 MANUAL M1-2234-02 1-HV-4512 385 PH. B ISOL M1-2229-02 to TXX-19064 Page 4 of 10

CPNPP UNITS 1 AND 2 DBD-EE-041 480V AND 120V AC ELECTRICAL POWER SYSTEM REVISION 32 PAGE 45 OF 168 MOV TAG #

MOV Minimum Starting Voltage Required Valve Actuation Signal REF. DWG ICD #

1-HV-4513 387 PH. B ISOL M1-2229-02 1-HV-4514 385 PH. B ISOL M1-2229-04B 1-HV-4515 388 PH. B ISOL M1-2229-02 1-HV-4524 385 PH. B ISOL M1-2229-04B 1-HV-4525 387 PH. B ISOL M1-2229-02 1-HV-4526 384 PH. B ISOL M1-2229-04B 1-HV-4527 387 PH. B ISOL M1-2229-02 1-HV-4572 390 "S" SIGNAL M1-2229-06 1-HV-4573 391 "S" SIGNAL M1-2229-06A 1-HV-4574 390 "P" SIGNAL M1-2229-06 1-HV-4575 391 "P" SIGNAL M1-2229-06A 1-HV-4696 388 "P" SIGNAL M1-2231-02A 1-HV-4699 389 "P" SIGNAL M1-2231-03 1-HV-4700 392 "P" SIGNAL M1-2231-03 1-HV-4701 392 "P" SIGNAL M1-2231-03 1-HV-4708 386 "P" SIGNAL M1-2231-05 1-HV-4709 375 "P" SIGNAL M1-2231-05A 1-HV-4758 410 MANUAL M1-2232-02 1-HV-4759 410 MANUAL M1-2232-02 1-HV-4776 386 "P" SIGNAL M1-2232-04 1-HV-4777 386 "P" SIGNAL M1-2232-04 1-HV-4782 410 MANUAL M1-2232-05 1-HV-4783 398 MANUAL M1-2232-05 1-HV-5540 395 "S" SIGNAL (CVI)

M1-2301-05 1-HV-5541 394 "S" SIGNAL (CVI)

M1-2301-05 1-HV-5542 390 "S" SIGNAL (CVI)

M1-2301-05 1-HV-5543 393 "S" SIGNAL (CVI)

M1-2301-05 1-HV-5562 393 "S" SIGNAL (CVI)

M1-2301-09 1-HV-5563 393 "S" SIGNAL (CVI)

M1-2301-09 1-HV-6082 392 PH. A ISOL M1-2307-05 1-HV-6083 393 PH. A ISOL M1-2307-05 1-HV-6084 385 PH. A ISOL M1-2307-06 1-HV-8402A 368 NA M1-2255-18 1-LCV-0112B 383 "S" SIGNAL M1-2255-07 1-LCV-0112C 388 "S" SIGNAL M1-2255-07 1-LCV-0112D 384 "S" SIGNAL M1-2255-08 1-LCV-0112E 387 "S" SIGNAL M1-2255-08 to TXX-19064 Page 5 of 10

CPNPP UNITS 1 AND 2 DBD-EE-041 480V AND 120V AC ELECTRICAL POWER SYSTEM REVISION 32 PAGE 46 OF 168 MOV TAG #

MOV Minimum Starting Voltage Required Valve Actuation Signal REF. DWG ICD #

1-LV-4754 390 "P" SIGNAL M1-2232-01 1-LV-4755 389 "P" SIGNAL M1-2232-01 2-8000A 410 MANUAL M2-2251-07 2-8000B 410 MANUAL M2-2251-07 2-8100 375 PH. A ISOL M1-2253-09 2-8104 379 MANUAL M1-2255-18A 2-8105 376 "S" SIGNAL M1-2255-18 2-8106 382 "S" SIGNAL M1-2255-18 2-8110 369 "S" SIGNAL M1-2255-19 2-8111 372 "S" SIGNAL M1-2255-19 2-8112 377 PH. A ISOL M1-2253-09 2-8351A 410 MANUAL M1-2253-16 2-8351B 410 MANUAL M1-2253-16 2-8351C 410 MANUAL M1-2253-16 2-8351D 410 MANUAL M1-2253-16 2-8511A 368 "S" SIGNAL M1-2255-21 2-8511B 379 "S" SIGNAL M1-2255-21 2-8512A 410 MANUAL w/VLV INTRLK M1-2255-22 2-8512B 410 MANUAL w/VLV INTRLK M1-2255-22 2-8701A 410 MANUAL M1-2260-05 2-8701B 399 MANUAL M1-2260-05 2-8702A 393 MANUAL M1-2260-05 2-8702B 373 MANUAL M1-2260-05 2-8716A 410 MANUAL M1-2260-05A 2-8716B 410 MANUAL M1-2260-05A 2-8801A 381 "S" SIGNAL M1-2261-05 2-8801B 378 "S" SIGNAL M1-2261-05 2-8802A 410 MANUAL M1-2263-05 2-8802B 410 MANUAL M1-2263-05 2-8804A 410 MANUAL w/VLV INTRLK M1-2261-06 2-8804B 410 MANUAL w/VLV INTRLK M1-2261-06 2-8806 410 MANUAL M1-2263-05 2-8807A 410 MANUAL M1-2261-07 2-8807B 410 MANUAL M1-2261-07 2-8809A 410 MANUAL M1-2263-06 2-8809B 410 MANUAL M1-2263-06 2-8811A 410 "S" SIGNAL w/RWST INTRLK M1-2263-06 to TXX-19064 Page 6 of 10

CPNPP UNITS 1 AND 2 DBD-EE-041 480V AND 120V AC ELECTRICAL POWER SYSTEM REVISION 32 PAGE 47 OF 168 MOV TAG #

MOV Minimum Starting Voltage Required Valve Actuation Signal REF. DWG ICD #

2-8811B 393 "S" SIGNAL w/RWST INTRLK M1-2263-06 2-8812A 408 MANUAL M1-2263-06 2-8812B 409 MANUAL M1-2263-06 2-8813 410 MANUAL M1-2263-07 2-8814A 410 MANUAL M1-2263-07 2-8814B 410 MANUAL M1-2263-07 2-8821A 410 MANUAL M1-2263-08 2-8821B 408 MANUAL M1-2263-08 2-8835 410 MANUAL M1-2263-09 2-8840 410 MANUAL M1-2263-09 2-8923A 410 MANUAL M1-2263-12 2-8923B 410 MANUAL M1-2263-12 2-8924 410 MANUAL M1-2261-11 2-FCV-0610 386 "S" SIGNAL M1-2260-03 2-FCV-0611 385 "S" SIGNAL M1-2260-03 2-FV-4772-1 378 "P" SIGNAL M2-2232-03 2-FV-4772-2 378 "P" SIGNAL M2-2232-03 2-FV-4773-1 378 "P" SIGNAL M2-2232-03 2-FV-4773-2 378 "P" SIGNAL M2-2232-03 2-HV-2480 410 MANUAL M2-2206-08 2-HV-2481 410 MANUAL M2-2206-08 2-HV-2482 410 MANUAL M2-2206-08 2-HV-2484 383 "S" SIGNAL (AFW PUMP START)

M2-2206-09 2-HV-2485 385 "S" SIGNAL (AFW PUMP START)

M2-2206-09 2-HV-2491A 410 MANUAL M2-2206-10 2-HV-2491B 410 MANUAL M2-2206-10 2-HV-2492A 410 MANUAL M2-2206-10 2-HV-2492B 410 MANUAL M2-2206-10 2-HV-2493A 410 MANUAL M2-2206-10 2-HV-2493B 410 MANUAL M2-2206-10 2-HV-2494A 410 MANUAL M2-2206-10 2-HV-2494B 410 MANUAL M2-2206-10 2-HV-4075B 373 PH. A ISOL M2-2225-01B 2-HV-4075C 376 PH. A ISOL M2-2225-01B 2-HV-4286 380 "S" SIGNAL @ T= 25 M2-2233-05 2-HV-4287 383 "S" SIGNAL @ T= 25 M2-2233-05 2-HV-4393 385 EDG START M2-2234-02A to TXX-19064 Page 7 of 10

CPNPP UNITS 1 AND 2 DBD-EE-041 480V AND 120V AC ELECTRICAL POWER SYSTEM REVISION 32 PAGE 48 OF 168 MOV TAG #

MOV Minimum Starting Voltage Required Valve Actuation Signal REF. DWG ICD #

2-HV-4394 387 EDG START M2-2234-02A 2-HV-4395 410 MANUAL M2-2234-02 2-HV-4396 410 MANUAL M2-2234-02 2-HV-4512 378 PH. B ISOL M2-2229-02 2-HV-4513 382 PH. B ISOL M2-2229-02 2-HV-4514 377 PH. B ISOL M2-2229-04B 2-HV-4515 383 PH. B ISOL M2-2229-02 2-HV-4524 378 PH. B ISOL M2-2229-04B 2-HV-4525 383 PH. B ISOL M2-2229-02 2-HV-4526 377 PH. B ISOL M2-2229-04B 2-HV-4527 383 PH. B ISOL M2-2229-02 2-HV-4572 383 "S" SIGNAL M2-2229-06 2-HV-4573 386 "S" SIGNAL M2-2229-06 2-HV-4574 383 "P" SIGNAL M2-2229-06 2-HV-4575 387 "P" SIGNAL M2-2229-06 2-HV-4696 379 "P" SIGNAL M2-2231-02A 2-HV-4699 380 "P" SIGNAL M2-2231-03 2-HV-4700 381 "P" SIGNAL M2-2231-03 2-HV-4701 383 "P" SIGNAL M2-2231-03 2-HV-4708 380 "P" SIGNAL M2-2231-05 2-HV-4709 373 "P" SIGNAL M2-2231-05A 2-HV-4758 410 MANUAL M2-2232-02 2-HV-4759 410 MANUAL M2-2232-02 2-HV-4776 383 "P" SIGNAL M2-2232-04 2-HV-4777 381 "P" SIGNAL M2-2232-04 2-HV-4782 410 MANUAL M2-2232-05 2-HV-4783 393 MANUAL M2-2232-05 2-HV-5540 384 "S" SIGNAL (CVI)

M2-3201-03 2-HV-5541 386 "S" SIGNAL (CVI)

M2-2301-03 2-HV-5542 384 "S" SIGNAL (CVI)

M2-2301-03 2-HV-5543 386 "S" SIGNAL (CVI)

M2-2301-03 2-HV-5562 383 "S" SIGNAL (CVI)

M2-2301-07 2-HV-5563 383 "S" SIGNAL (CVI)

M2-2301-07 2-HV-6082 380 PH. A ISOL M2-2307-05 2-HV-6083 385 PH. A ISOL M2-2307-05 2-HV-6084 378 PH. A ISOL M2-2307-06 2-HV-8402A 368 NA M2-2255-18 to TXX-19064 Page 8 of 10

CPNPP UNITS 1 AND 2 DBD-EE-041 480V AND 120V AC ELECTRICAL POWER SYSTEM REVISION 32 PAGE 49 OF 168 MOV TAG #

MOV Minimum Starting Voltage Required Valve Actuation Signal REF. DWG ICD #

2-LCV-0112B 368 "S" SIGNAL M2-2255-07 2-LCV-0112C 373 "S" SIGNAL M2-2255-07 2-LCV-0112D 379 "S" SIGNAL M2-2255-08 2-LCV-0112E 384 "S" SIGNAL M2-2255-08 2-LV-4754 381 "P" SIGNAL M2-2232-01 2-LV-4755 377 "P" SIGNAL M2-2232-01 X-PV-3583 90 "S" SIGNAL M1-2229-07 X-PV-3584 90 "S" SIGNAL M1-2229-07 X-PV-3585 90 "S" SIGNAL M1-2229-07 X-PV-3586 90 "S" SIGNAL M1-2229-07 NOTES:

1-Minimum required voltages are from Calculation ME-CA-0000-1093 2-The table lists voltage and actuation requirements for active MOVs. The minimum opening or closing voltage for all non -

active MOVs is 368V except for MOVs # 2-8808A/B &C which requires 395V, 395V & 385V respectively ( Ref.

Calculation ME-CA-0000-1093 )

3-All automatically actuated active MOVs, except 1 / 2-8811A/B, and manually actuated active MOVs 1-8104 and 2-8104 shall be evaluated for acceptability of required voltage concurrent with the start of four (4) CT Pump motors 4-All non - active valves, all manually actuated active valves, except for 1/2-8104, and automatically actuated active MOVs

1. 1 / 2-8811A/B shall be evaluated for acceptability of required voltage when the MCC bus is at steady state condition. to TXX-19064 Page 9 of 10

CPNPP UNITS 1 AND 2 DBD-EE-041 480V AND 120V AC ELECTRICAL POWER SYSTEM REVISION 32 PAGE 50 OF 168 5-All MOVs listed in the table actuate automatically upon receipt of actuation signal except for MOVs identified withManualaction. to TXX-19064 Page 10 of 10