Text

License Amendment Request 10-01, Revision to Technical Specification 3.8.1, AC Sources - Operating.
	ML100621315
Person / Time
Site:	Diablo Canyon
Issue date:	02/24/2010
From:	Becker J; Pacific Gas & Electric Co
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	DCL-10-018
	Download: ML100621315 (112)
	v • d • e

W Pacific ElectricGas and Company" James R,Backer Diablo Canyon Power Plant Site VicePresident Mail Code 104/5/601 P O Box 56 Avila Beach, CA 93424 805.545.3462 February 24, 2010 Internal: 691.3462 Fax: 805.545.6445 PG&E Letter DCL-10-018 U.S. Nuclear Regulatory Commission 10 CFR 50.90 ATTN: Document Control Desk Washington, D.C. 20555-0001 Diablo Canyon Units 1 and 2 Docket No. 50-275, OL-DPR-80 Docket No. 50-323, OL-DPR-82 License Amendment Request 10-01 Revision to Technical Specification 3.8.1, "AC Sources - Operating"

Dear Commissioners and Staff:

Pursuant to 10 CFR 50.90, Pacific Gas and Electric Company (PG&E) hereby requests approval of the enclosed proposed amendment to Facility Operating License Nos. DPR-80 and DPR-82 for Units 1 and 2 of the Diablo Canyon Power Plant (DCPP) respectively. The enclosed license amendment request (LAR) proposes to revise the Technical Specification (TS) 3.8.1, "AC Sources - Operating,"

Surveillance Requirement (SR) 3.8.1.3 Diesel Generator (DG) load band, the SR 3.8.1.10 DG power factor and load band, the SR 3.8.1.14 DG power factor and load values, and the SR 3.8.1.15 Note 1 DG load band. In addition, SR 3.8.1.10 and SR 3.8.1.14 are revised to add a new note addressing the power factor limit when testing with the DG synchronized with offsite power.

The changes in this LAR are not required to address an immediate safety concern.

PG&E requests approval of this LAR no later than February 24, 2011. PG&E requests the license amendment(s) be made effective upon NRC issuance, to be implemented within 120 lays from the date of issuance.

This communication contains new commitments to be implemented following NRC approval of the LAR. The commitments are contained in the Attachment 4 of the Enclosure.

Ifyou have any questions or require additional information, please contact Tom Baldwin at 805-545-4720.

A member of the STARS (Strategic Teaming and Resource Sharing) Alliance Callaway . Comanche Peak

Diablo Canyon

Palo Verde. San Onofre

South Texas Project

Wolf Creek

Document Control Desk PG&E Letter DCL-10-018

~F ebruary 24, 2010 a Page 2 I state under penalty of perjury that the foregoing is true and correct.

Executed on February 24, 2010.

Sincerely, James Becker Site Vice President kjse/4328 SAPN 50232181

Enclosure:

Evaluation of the Proposed Change cc: Gary W. Butner, Acting Branch Chief, California Department of Public Health Elmo E. Collins, NRC Region IV Michael S. Peck, NRC, Senior Resident Inspector Diablo Distribution cc/enc: Alan B. Wang, Project Manager, Office of Nuclear Reactor Regulation A member of the STARS (Strategic Teaming and Resource Sharing) Alliance Callaway - Comanche Peak

Diablo Canyon - Palo Verde- San Onofre

South Texas Project

Wolf Creek

Enclosure PG&E Letter DCL-10-018 Evaluation of the Purpose Change License Amendment Request 10-01 Revision to Technical Specification 3.8.1, "AC Sources - Operating"

1.

SUMMARY

DESCRIPTION

2. DETAILED DESCRIPTION

3. TECHNICAL EVALUATION

4. REGULATORY EVALUATION 4.1 Applicable Regulatory Requirements/Criteria 4.2 Precedent 4.3 Significant Hazards Consideration 4.4 Conclusions

5. ENVIRONMENTAL CONSIDERATION

6. REFERENCES ATTACHMENTS:

1. Technical Specification Markups

2. Retyped Technical Specification Pages

3. Technical Specification Bases Page Markups

4. Commitments

5. PG&E Calculation No. 9000037760, Revision 20

6. PG&E Calculation No. 9000040769, Revision 0

Enclosure PG&E Letter DCL-10-018 EVALUATION

1.

SUMMARY

DESCRIPTION This letter is a request to amend Operating Licenses DPR-80 and DPR-82 for Units 1 and 2 of the Diablo Canyon Power Plant (DCPP), respectively.

The proposed changes would revise the Operating Licenses to revise the Technical Specification (TS) 3.8.1, "AC Sources - Operating," Surveillance Requirement (SR) 3.8.1.3 Diesel Generator (DG) load band, the SR 3.8.1.10 DG power factor and load band, the SR 3.8.1.14 DG power factor and load values, and the SR 3.8.1.15 Note 1 DG load band. In addition, SR 3.8.1.10 and SR 3.8.1.14 are revised to add a new note addressing the power factor limit when testing with the DG synchronized with offsite power.

The current TS 3.8.1 SRs contain load and power factor values that are nonconservative compared to the worst case design basis accident loading conditions contained in the existing calculations. The changes proposed in this License Amendment Request (LAR) correct the nonconservative DG load and power factor values contained in the current TS 3.8.1 SRs.

2. DETAILED DESCRIPTION Proposed Amendment The following changes are proposed to the TS 3.8.1 SRs:

SR 3.8.1.3 is revised from:

Verify each DG is synchronized and loaded and operates for _ 60 minutes at a load __2340 kW and < 2600 kW.

to:

Verify each DG is synchronized and loaded and operates for >_60 minutes at a load >_2475 kW and < 2750 kW.

SR 3.8.1.10 is revised from:

Verify each DG operating at a power factor < 0.87 does not trip and voltage is maintained _<5075 V during and following a load rejection of _ 2340 kW and _<

2600 kW.

to:

1

Enclosure PG&E Letter DCL-10-018

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

If performed with DG synchronized with offsite power, it shall be performed at a power factor

< 0.85. However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable.

Verify each DG does not trip and voltage is maintained < 5075 V during and following a load rejection of >_2475 kW and _<2750 kW.

SR 3.8.1.14 is revised from:

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

1. Momentary transients outside the load and power factor ranges do not invalidate this test.

Verify each DG operating at a power factor

__0.87 operates for > 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s:

a. For > 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded _>2600 kW and < 2860 kW; and

-b. For the remaining hours of the test loaded __2340 kW and < 2600 kW.

to:

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

1. Momentary transients outside the load and power factor ranges do not invalidate this test.

2. If performed with DG synchronized with offsite power, it shall be performed at a power factor

< 0.85. However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable.

Verify each DG operates for _ 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s:

a. For __2 hours loaded _ 2750 kW and ___ 2860 kW; and

b. For the remaining hours of the test loaded __2475 kW and < 2750 kW.

2

Enclosure PG&E Letter DCL-10-018 SR 3.8.1.15 Note 1 is revised from:

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

1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated _>2 hours loaded > 2340 kW and < 2600 kW.

to:

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

1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated __2 hours loaded _>2475 kW and _ 2750 kW.

In summary, the DG load band is revised in TS 3.8.1 SR 3.8.1.3. The DG power factor and load band are revised in SR 3.8.1.10 and a new note is added addressing the power factor limit when testing with the DG synchronized with offsite power. The DG power factor and load values, except the peak load value, are revised in SR 3.8.1.14 and a new note is added addressing the power factor limit when testing with the DG synchronized with offsite power. The DG load band is revised in Note 1 of SR 3:8.1.15.

The TS 3.8.1 Bases are revised to reflect the revised load and power factor values and the addition of the new notes to SR 3.8.1.10 and 3.8.1.14.

The TS Bases changes are included for information only.

The proposed TS changes are noted on the marked-up TS page provided in . The proposed retyped TS is provided in Attachment 2. The revised TS Bases is contained for information only in Attachment 3.

Alternate Current (AC) Electrical Power Distribution System AC Sources The DCPP AC Electrical Power Distribution System AC sources consist of offsite power sources (normal and alternate), and the onsite standby power sources (three DGs for each unit). The design of the AC electrical power system provides independence and redundancy to ensure an available source of power to the Engineered Safety Feature (ESF) systems.

The onsite Class 1E AC Distribution System for each unit is divided into three load groups so that the loss of any one group does not prevent the minimum safety functions from being performed. Each load group has connections to two offsite power sources and a single DG.

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Enclosure PG&E Letter DCL-10-018 Offsite power is supplied to the 230 kV and 500 kV switchyards from the transmission network by two 230 kV transmission lines and three 500 kV transmission lines. These'two electrically and physically separated circuits provide AC power, through auxiliary and standby startup transformers, to the 4.16 kV ESF buses. A detailed description of the offsite power network and the circuits to the Class 1E buses is found in the Final Safety Analysis Report Update (FSARU) Chapter 8.

Certain required unit loads are returned to service in a predetermined sequence in order to prevent overloading the transformer supplying offsite power to the onsite Class 1 E Distribution System. Within 1 minute after the initiating signal is received, all automatic and permanently connected loads needed to recover the unit or maintain it in a safe, condition are returned to service via the load sequencer timers (auto transfer timers). Each ESF component is provided with its own sequencing timer.

The onsite standby power source for each 4.16 kV ESF bus is a dedicated DG.

For Unitl, DGs 1-1, 1-2, and 1-3 are dedicated to ESF buses H, G, and F, respectively. For Unit 2, DGs 2-1, 2-2, and 2-3 are dedicated to ESF buses G, H, and F. A DG starts automatically on a safety injection (SI) signal (e.g., low pressurizer pressure or high containment pressure signals), undervoltage on the offsite standby startup source, or on an ESF bus degraded voltage or undervoltage signal. After the DG has started, it will automatically tie to its respective bus after offsite power is tripped as a consequence of ESF bus undervoltage or degraded voltage, independent of or coincident with an SI signal.

The DGs will also start and operate in the standby mode without tying to the ESF bus on an SI signal alone or if voltage recovers. Following the trip of offsite power, an undervoltage signal strips nonpermanent loads from the ESF bus.

When the DG is tied to the ESF bus, loads are then sequentially connected to their respective ESF bus by the load sequencing timers (ESF timers). The sequencing logic controls the permissive and starting signals to motor breakers to prevent overloading the DG. Each ESF component is provided with its own load sequencing timer.

In the event of a loss of preferred power, the ESF electrical loads are automatically connected to the DGs in sufficient time to provide for safe reactor shutdown and to mitigate the consequences of a Design Basis Accident (DBA) such as a loss of coolant accident (LOCA).

Certain required unit loads are returned to service in a predetermined sequence in order to prevent overloading the DG in the process. Within 1 minute after the initiating signal is received, all loads needed to recover the unit or maintain it in a safe condition are returned to service.

4

Enclosure PG&E Letter DCL-10-018 The 4.16 kV/480 V load center transformer loading is required to be less than the self-cooled 1000 kVA rating.

DG Desiqn The six DGs for Units 1 and 2 are essentially identical, self-contained units housed in individual compartments at the 85 foot elevation in the turbine-generator building. Three are located in the northwest or Unit 1 portion, and three are located in the southwest or Unit 2 portion of the structure. The compartments separate each DG and its accessories from the adjacent units and conform to Design Class I requirements.

The DGs have a net continuous electrical output rating of 2600 kW at 0.8 PF (continuous rating), and are rated for 2752 kW at 0.8 PF and 60 Hz for up to 2000 hours0.0231 days 0.556 hours 0.00331 weeks 7.61e-4 months of operation per year (2000-hour rating). Short-term ratings of the DGs are 3000 kW at 0.8 PF for 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months per year, 2860 kW at 0.8 PF for 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months per 24-hour period (2-hour per 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months rating), and 3250 kW at 0.8 PF for 30 minutes per 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period (30-minute per 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months rating). During the starting sequence for the safeguard loads, these machines can also carry short-time overloads.

During a design basis-loading scenario with nominal timer interval, these machines maintain the electric power frequency within 5 percent; hold voltages to a minimum of 75 percent, and recover successfully by complying with Safety Guide (SG) 9 in all respects except for DG frequency recovery criteria. The frequency recovery meets the applicable criteria of Regulatory Guide (RG) 1.9, Revision 2, Section C, Position 4. This exception to SG 9 was performed under 10 CFR 50.59.

In addition to testing and analysis to demonstrate performance for nominal timer intervals, preoperational tests and computer simulation were performed for a design basis-loading scenario with the worst case timer drift and tolerances.

During this scenario, for the last load block, frequency dipped below 95 percent and recovery times in excess of 60 percent of the timer interval were observed.

The frequency recovery times exceeding 60 percent of timer interval were justified by analysis following the guidelines of RG 1.9, Revision 2. The frequency dip below 95 percent was for a fraction of a second and the DG showed strong recovery capability, demonstrating that the objectives of SG 9 were met.

Each DG unit consists of a self-contained diesel engine directly connected to an alternating current generator, and the separate accessories needed for proper operation, all mounted on a common structural steel skid-type base. Mechanical power is provided by an 18 cylinder, four-cycle, 3630 horsepower at 900 rpm, turbocharged and aftercooled, heavy-duty, stationary-type diesel engine.

5

Enclosure PG&E Letter DCL-10-018 The generator is rated at 3250 kVA, 0.8 PF, 4160 V, and 60 Hz. The exciter is a static series, boost-type exciter controlled by a static solid-state voltage regulator.

The DG units were supplied by the ALCO Engine Division of White Industrial Power, Inc. The sixth DG, DG 2-3, was manufactured by General Electric Locomotives. In most respects, this DG is similar to the other five DGs.

Calculation for DG Loadinq for Vital Bus Loads The current calculation that determines the DG loading for the vital bus loads is Calculation No. 9000037760, Revision 20, Which is contained in Attachment 5.

The current calculation that determines the worst case accident for the rotating equipment mechanical loads is Calculation No. 9000040769, Revision 0, which is contained in Attachment 6.

The DG loading calculation determines the DG load and power factor for each of the three DGs for DCPP Unit 1 and 2 for the worst case frequency and voltage tolerances (61.2 Hz and 110 percent voltage). The assumptions of the DG loading calculation are described in Section 3.0 of the calculation. A summary of the significant assumptions of the DG loading calculation are as follows:

Single failure criteria relative to DG loading were considered

The worst case postulated accident scenario is the large break loss-of-coolant accident

" The highest brake horsepower demand for each pump is assumed regardless of the relative transient time at which the highest demand occurs

For single pump operation, the highest brake horsepower demand is used and for parallel pump operation for those pumps with shared discharge flowpaths lower brake horsepower demand is used based on system operation

The maximum demand for nonrotating equipment that automatically connects to the bus is conservatively used without consideration as to when in scenario the peak load occurs

" Redundant 480 V loads are assumed to be operating independently regardless of shared fluid systems to maximize load on each component and the DG

Diversity factors were applied to account for the noncontinuous loads

Momentary loads, which may consist of transformer inrush, motor starting inrush, motor operated valves, and inrush associated with control circuits components that change state are not included because they do not operate continuously and are within the short-time capability of the engine generators

The final steady state load at the conclusion of the automatic loading sequence for DG automatic loads are considered and manual addition 6

Enclosure PG&E Letter DCL-10-018 of other loads post accident are not considered since they are procedurally controlled and plant Operators are responsible to ensure the DG rating is not exceeded when initiating manual loads 0 Cable and transformer losses were considered 0 The alternate feed to loads equipped with manual transfer switches that are administrative controlled by procedure are assumed to be unloaded

A maximum frequency tolerance of 2 percent and voltage tolerance of 10 percent are considered based on the TS 3.8.1 SR limits

KVAR loading was considered on a component by component basis The results of the DG load calculation are contained in Section 8.0 of the calculation. The limiting DG is Unit 2 Bus F DG 2-3, which has a margin of 45 kW to the 2000-hour rating of 2752 kW (rating based.on at 60 Hz) at the worst case frequency and voltage variation of 61.2 Hz and 110 percent voltage. Since tests for SRs 3.8.1.3, 3.8.1.10, and 3.8.1.14 are performed with the DG synchronized with the offsite electrical system, operation at other than 60 Hz is not feasible during the testing. Therefore, a value of 2750 kW based on the DG 2000-hour rating (rounded down) has been determined for DG testing at 60 Hz for SRs 3.8.1.3, 3.8.1.10, and 3.8.1.14. A load value of 2750 kWfor DG testing at 60 Hz for SRs 3.8.1.3, 3.8.1.10, and 3.8.1.14 and bounds the maximum expected accident load.

The calculation determined the limiting DG power factor is 0.858 for Unit 1 Bus F DG 1-3 at 60 Hz and 100 percent voltage. This is greater than the DG power factor limit of grater than or equal to 0.8.

Purpose for Proposed Amendment The current TS 3.8.1 SRs contain load and power factor values that are nonconservative compared to the worst case design basis accident loading conditions contained in the existing calculations. The DG load values contained in current SRs 3.8.1.3, 3.8.1.10, 3.8.1.14, and 3.8.1.15 are based on the continuous rating of the DG, which is less than the maximum expected accident loads. In addition, the power factor values contained. in SRs 3.8.1.10 and 3.8.1.14 are greater than the minimum expected accident power factors. The changes proposed in this LAR correct the nonconservative DG load and power factor values contained in the current TS 3.8.1 SRs.

During investigation to respond to NRC resident inspector observations related to the inspector implementation of NRC Temporary Instruction 2515/176, "Emergency Diesel Generator Technical Specification Surveillance Requirements Regarding Endurance and Margin Testing," dated May 16, 2008, PG&E determined the DG load calculations needed to be revised. -In response to the inspectors' observations on the DG load calculations, PG&E entered the 7

C

Enclosure PG&E Letter DCL-10-018 condition in the corrective action program in Notification 50179082 on January 19, 2009, and performed an operability evaluation and concluded that the DGs were capable of performing their intended safety function and remained operable.

To address the NRC observations on the DG load calculations, PG&E created calculations 9000037760, Revision 20, and calculation 9000040769, Revision 0.

The revised required DG load values were verified to be bounded by the load values required by the surveillance test procedures.

During the course of revising calculations'9000037760, Revision 20, and calculation 9000040769, Revision 0, PG&E determined that the overall calculated power factor of the vital.busses F, G, and H could be as low as 0.85, that the power factor is lower than the 0.87 value contained in the current TS 3.8.1 SRs, and that the 0.87 value used in the TS 3.8.1 SRs is nonconservative.

This condition was entered into the PG&E corrective action program on April 9, 2009, in Notification 50231656. A prompt operability assessment was performed and determined the DGs are capable of performing their intended safety function and are capable of carrying the worst-case calculated load. Technical Specification SR 3.0.3 was entered as a result of the TS SR 3.8.1.10 and SR 3.8.1.14 not being met. The surveillance test procedures STP M-9D1 for SR 3.8.1.10 and STP M-9G for SR 3.8.1.14 were updated to include a maximum power factor value of 0.85 including instrument uncertainty. STP M-9D1 and STP M-9G were performed on all six DGs to verify SR 3.8.1.10 and SR 3.8.1.14 were met for a power factor of 0.85.

This LAR does not include any proposed changes to DCPP compliance with Safety Guide 9. The maximum load limit for the remaining hours of the SR 3.8.1.14.b endurance test is based on the DG 2000-hour rating, which envelopes the maximum expected accident load and is greater than the continuous duty rating of the DG as specified by Regulatory Guide 1.108, Revision 1.

No change is proposed to the power factor value of less than or equal to 0.9 in SR 3.1.8.9 Note 2 because SR 3.8.1.9 is performed in isochronous mode with the DG separated from offsite power.

3. TECHNICAL EVALUATION SR 3.8.1.3 Revision The current SR 3.8.1.3 load band of 2340 kW to 2600 kW is based on 90 to 100 percent of the DG continuous rating of 2600 kW. The maximum expected accident load is greater than the DG continuous rating. The proposed maximum load limit of 2750 kW for SR 3.8.1.3 bounds the maximum expected accident load.

8

Enclosure PG&E Letter DCL-10-018 The proposed minimum load limit of 2475 kW for SR 3.8.1.3 is 90 percent of the maximum load limit value, consistent with the current SR 3.8.1.3 minimum load limit, which is 90 percent of the maximum load limit. Operation during testing within a load band of 90 to 100 percent of the maximum load limit value of 2750 kW without anomalies will provide adequate assurance of the DG ability to carry 100 percent of maximum expected accident load and avoid routine exceeding of the DG 2000-hour rating. Routine exceeding of the DG 2000-hour rating may result in more frequent teardown inspections in accordance with vendor recommendations in order to maintain DG operability. Verification that the DG is able to carry greater than 100 percent of maximum expected accident load is ensured through performance of the proposed SR 3.8.1.14.a.

SR 3.8.1.10 Revision A new Note 1 is added to SR 3.8.1.10 to address DG testing while the DG is synchronized with offsite power. For DCPP, SR 3.8.1.10 is performed with the DG synchronized with offsite power. The note specifies the test shall be performed at a power factor less than or equal to 0.85, however, if grid conditions do not permit, the power factor limit is not required to be met and under this condition the power factor shall be maintained as close to the limit as practicable.

The Note moves the power factor limit from the SR to the Note.

The DG power factor limit of less than or equal to 0.85 proposed in Note 1 is less than the minimum expected accident power factor of 0.858. The proposed DG power factor limit of less than or equal to 0.85 is greater than the DG power factor limit of greater than or equal to 0.8.

The proposed Note 1 is consistent with NUREG-1431, Revision 3.1, SR 3.8.1.10 Note 2. The proposed Note 1 ensures that the DG is tested under load conditions that are as close to design basis conditions as possible. When synchronized with offsite power, testing should be performed at a power factor of less than or equal to 0.85. This power factor is representative of the actual inductive loading a DG would see under design basis accident conditions". Under certain conditions, however, Note 1 allows the Surveillance to be conducted at a power factor other than less than or equal to 0.85. These conditions occur when grid voltage is high, and the additional field excitation needed to get the power factor to less than or equal to 0.85 results in voltages on the emergency busses that are too high. Under these conditions, the power factor should be maintained as close as practicable to 0.85 while still maintaining acceptable voltage limits on the emergency busses. In other circumstances, the grid voltage may be such that the DG excitation levels needed to obtain a power factor of 0.85 may not cause unacceptable voltages on the emergency busses, but the excitation levels are in excess of those recommended for the DG. In such cases, the.power factor shall be maintained as close as practicable to 0.85 without exceeding the DG excitation limits.

9

Enclosure PG&E Letter DCL-10-018 When the DGs are operating synchronized to the grid, increasing the exciter current increases the generator reactive load (kVAR) and also increases the voltage of the associated bus. Increasing the reactive load at a given real load (kW) increases the apparent load (kVA) and decreases the power factor. The maximum apparent load at which a DG operates is dependent on the corresponding safeguards bus voltage that results from increasing the exciter current to attain the apparent load. The safeguards buses are limited to 4400 V (approximately 105.8 percent of the bus-nominal 4160 Volts) to protect the safeguards motors. To achieve a test power factor of 0.85 requires 1704 kVAR on a DG at 2750 kW. As a result of the decreased proposed power factor of less than or equal to 0.85 combined with the increased maximum load limit value of 2750 kW under certain grid conditions, the required kVAR may not be attainable due to the bus voltage limitations. During these situations, the provisions of the proposed Note 1 would be invoked. Additional guidance will be provided to operators in the surveillance procedures :as part of implementation of the license amendment request to provide guidance to the operators on use of the new Note added to SR 3.8.1.10 and SR 3.8.1.14.

The current SR 3.8.1.10 load band of 2340 kW to 2600 kW is based on 90 to 100 percent of the DG continuous rating of 2600 kW. The maximum expected accident load is greater than the DG continuous rating. The proposed maximum load limit value of 2750 kW for SR 3.8.1.10 bounds the maximum expected accident load.

The proposed minimum load limit value of 2475 kW for SR 3.8.1.10 is 90 percent of the maximum load limit value, consistent with the current SR 3.8.1.10 minimum load limit which is 90 percent of the maximum load limit. Operation during testing within a load band of 90 to 100 percent of the maximum load limit value of 2750 kW without anomalies will provide adequate assurance of the DG ability to carry 100 percent of maximum expected accident load and avoid routine exceeding of the DG 2000-hour rating. Routine exceeding of the DG 2000-hour rating may result in more frequent teardown inspections in accordance with vendor recommendations in order to maintain DG operability. Verification that the DG is able-to carry greater than 100 percent of maximum expected accident load is ensured through performance of the proposed SR 3.8.1.14.

SR 3.8.1.14 A new Note 2 is added to SR 3.8.1.14 to address DG testing while the DG is synchronized with offsite power. For DCPP, SR 3.8.1.14 is performed with the DG synchronized with offsite power. The note specifies the test shall be performed at a power factor less than or equal to 0.85, however, if grid conditions do not permit, the power factor limit is not required to be met and under this condition the power factor shall be maintained as close to the limit as practicable.

The Note moves the power factor limit from the SR to the Note.

10

Enclosure PG&E Letter DCL-10-018 The DG power factor limit of less than or equal to 0.85 proposed in Note 2 is less than the minimum expected accident power factor of 0.858. The proposed DG power factor limit of less than or equal to 0.85 is greater than the DG power factor limit of greater than or equal to 0.8. The proposed Note 2 is consistent with NUREG-1431, Revision 3.1, SR 3.8.1.14 Note 3. The proposed Note 2 ensures that the DG is tested under load conditions that are as close to design basis conditions as possible. The technical justification for the Note is the same as previously described for proposed SR 3.8.10 Note 1.

RG 1.108, Revision 2, Position 2.a.(3) states to demonstrate the full load carrying capability for an interval of not less than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months of which 22 hours2.546296e-4 days 0.00611 hours 3.637566e-5 weeks 8.371e-6 months should be at a load equivalent to the continuous rating of the DG, and 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months at the load equivalent to the 2-hour rating of the DG. The current maximum load limit value of 2860 kW in SR 3.8.1.14.a meets RG 1.108, Revision 2, Position 2.a.(3) since it is the 2-hour per 24-hour rating of the DG.

The proposed minimum load limit value of 2750 kW for SR 3.8.1.14.a will provide assurance of the DG ability to carry 100 percent of maximum expected accident load since it bounds the maximum expected accident load.

The load band with the proposed minimum load limit value is 2750 kW to 2860 kW and results in a reduction in the current surveillance load band magnitude from 260 kW to 110 kW. A load band magnitude of 110 kW will continue to be adequate for the surveillance test procedure to utilize a test load value for the minimum 2750 kW limit that includes instrument uncertainty in order to account for instrument uncertainties. The surveillance test procedure will use a test load value without instrument uncertainty applied to verify the current maximum SR 3.8.1.14.a load limit of 2860 kW is met because a load band magnitude of 110 kW is too small to apply instrument uncertainties to the test load value when the test load value includes instrument uncertainty to ensure the minimum 2750 kW limit is met. The use of a test load value without instrument uncertainty applied to verify the current maximum SR 3.8.1.14.a load limit of 2860 kW is met is acceptable because the load limit of 2860 kW is based on 110 percent of the DG continuous rating at a power factor of 0.8 and the surveillance test is performed at a DG power factor greater than 0.8.

The propbsed maximum load limit of 2750 kW for the remaining hours of the SR 3.8.1.14.b endurance test is based on the 2000-hour rating, which envelopes the maximum expected accident load and is greater than the continuous duty rating of the DG as specified by Regulatory Guide 1.108, Revision 1. The proposed minimum, load limit value of 2475 kW for SR 3.8.1.14.b is 90 percent of the maximum load limit value, consistent with the current SR 3.8.1.14 minimum load limit, which is 90 percent of the maximum load limit. Operation during testing within a load band of 90 to 100 percent of the maximum load limit value of 2750 kW without anomalies will provide adequate assurance of the DG ability to 11

Enclosure PG&E Letter DCL-10-018 carry 100 percent of maximum expected accident load and avoid routine exceeding of the DG 2000-hour rating. Routine exceeding of the DG 2000-hour rating may result in more frequent teardown inspections in accordance with vendor recommendations in order to maintain DG operability. Verification that the DG is able to carry greater than 100 percent of maximum expected accident load is ensured through performance of the proposed SR 3.8.1.14.a. The proposed maximum load limit value of 2750 kW meets RG 1.108, Revision 2, Position 2.a.(3) since it is greater than the 2600 kW continuous rating of the DG.

SR 3.8.1.15 The proposed load limit range of greater than or equal to 2475 kW and less than or equal to 2750 kWfor SR 3.8.1.15 Note 1 is the same as the proposed SR 3.8.1.14.b load limit range since SR 3.8.1.15 is performed after SR 3.8.1.14 is performed. The proposed load limit range provides consistency with the load limit range in proposed SR 3.8.1.14.b.

Summary In summary, the proposed revisions to the TS 3.8.1 SRs ensure the DG load and power factor values used in SRs 3.8.1.3, 3.8.1.10, 3.8.1.14, and 3.8.1.15 bound the maximum expected accident load and minimum expected accident power factor. The proposed DG load values meet RG 1.108, Revision 2, Position 2.a.(3).

4. REGULATORY ANALYSIS 4.1 Applicable Recqulatory Requirements/Criteria As stated in Section 3.1 of the DCPP FSARU, the DCPP units are designed to comply with the Atomic Energy Commission (AEC) (now the Nuclear Regulatory Commission, or NRC) General Design Criteria (GDCs) for Nuclear Power Plant Construction Permits, published in July 1967. The construction permits were issued by the AEC for DCPP Unit 1 in April 1968 and for DCPP Unit 2 in December 1970. The full power operating licenses were issued for DCPP Unit 1 on November 2, 1984 and for Unit 2 on August 26, 1985. A discussion of the DCPP conformance to the GDCs is contained in FSARU Section 3.1.2, "Overall Plant Requirements," with more details given in the applicable FSARU sections. The AEC published the final rule that added Title 10 of the Code of Federal Regulations (10 CFR) Part 50, Appendix A, "General Design Criteria for Nuclear Power Plants," in the Federal Register (36 FR 3255) on February 20, 1971, with the rule effective on May 21, 1971. In accordance with an NRC staff requirements memorandum from S. J. Chilk to J. M. Taylor, "SECY-92-223 -Resolution of Deviations Identified During the Systematic Evaluation Program," dated September 18, 1992, the Commission 12

Enclosure PG&E Letter DCL-10-018 decided not to apply the 10 CFR 50, Appendix A, GDC to plants with construction permits issued prior to May 21, 1971. Therefore, the GDC which constitute the licensing bases for DCPP are those described in the FSARU.

PG&E has made changes to the DCPP facilities over the life of the units that have committed to some of the GDCs from 10 CFR 50, Appendix A.

The extent to which the 10 CFR 50, Appendix A, GDC have been invoked can be found in specific sections of the FSARU and in other DCPP licensing basis documentation such as license amendments.

The applicable July 1967 GDCs to the proposed amendment, as stated in Section 3.1.2 of the DCPP FSARU, are 24 and 39. GDC 24 states "In the event of loss of all offsite power, sufficient alternate sources of power shall be provided to permit the required functioning of the protection systems,"

and GDC 39 states "Alternate power sources shall be provided with adequate independence, redundancy, capacity, and testability to permit the functioning required of the engineered safety features. As a minimum, the onsite power system and offsite power system shall each, independently, provide this capacity assuming a failure of a single active component in each power system."

FSARU Section 3.1.8.3, for GDC 39 states that DCPP conforms to 10 CFR Part 50, Appendix A, General Design Criteria 17, "Electric Power Systems."

FSARU Section 8.1.4.3 states that DCPP is committed to SG 9, for DG steady state loading capability; RG 1.9, Revision 2, for DG frequency and voltage dip and recovery; and RG 1.9, Revision 3, for DG test scope and test interval frequency.

RG 1.9, Revision 2, is referenced since DCPP incorporated the DG frequency dip and recovery criteria of RG 1.9, Revision 2 Section C, Position 4 under 10 CFR 50.59. This is an exception to SG 9, Section C, Position 4.

RG 1.9, Revision 3, is referenced because the NUREG-1431, Revision 3.1, TS 3.8.1 DG SRs for demonstrating the OPERABILITY of the DGs are in accordance with the recommendations of RG 1.9, Revision 3 for the types of surveillance tests that are incorporated in the SRs. The use of RG 1.9, Revision 3 for demonstrating the OPERABILITY of the DGs is not an exception to SG 9 because SG 9 did not specify the types of surveillance tests that need to be incorporated in the surveillance procedures. The reference to RG 1.9, Revision 3, in the TS 3.8.1 Bases was adopted as part of adoption of the NUREG-1431 TS approved by the 13

Enclosure PG&E Letter DCL-10-018 NRC in License Amendment 135 to Facility Operating License Nos. DPR-80 and DPR-82, respectively for DCPP.

The TS 3.8.1 Bases reference RG 1.108, Revision 1 for the scope of SRs 3.8.1.11, 3.8.1.14, 3.8.1.16. RG 1.9, Revision 3, incorporated RG 1.108, however the DCPP licensing basis does not fully meet all the criteria contained in RG 1.9, Revision 3, and therefore RG 1.108, Revision 1 is listed separately in the TS 3.8.1 Bases.

Paragraph 50.36(c)(2)(ii) of 10 CFR, "Technical specifications," requires that "[a] TS limiting condition for operation [LCO] of a nuclear reactor must be established for each item meeting one or more of the [criteria set forth in 10 CFR 50.36(c)(2)(ii)(A)-(D)]." Paragraph 50.36(c)(3) of 10 CFR, "Technical specifications," requires that TSs include SRs, which "are requirements relating to test, calibration, or inspection to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met."

The proposed revisions to the DCPP TS are in accordance with the requirements of July 1967 GDCs 24 and 39 and 10 CFR 50.36 and do not adversely affect the compliance of SRs 3.8.1.11, 3.8.1.14, 3.8.1.16 with RG 1.108, Revision 2. 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 inimical to the common defense and security or to the health and safety of the public.

4.2 Precedent In Amendment No. 259 to Facility Operating License No. DPR-26 for the Indian Point Nuclear Generating Unit No. 2, Entergy Nuclear Operations, Inc., obtained approval to use a DG load less than the peak loading conditions in the limiting design basis accident for the remainder of the endurance test surveillance. The proposed minimum load limit of 2475 kW for the remaining hours of the SR 3.8.1.14.b endurance test is less than the peak loading conditions in the limiting design basis accident.-

4.3 Significant Hazards Consideration PG&E has evaluated whether or not a significant hazards consideration is involved with the proposed amendment by focusing on the three 14

Enclosure PG&E Letter DCL-10-018 standards set forth in 10 CFR 50.92, "Issuance of amendment," as discussed below:

1. Does the proposed change involve a significant increase in the probability or consequences of an accident previously evaluated?

Response: No.

The proposed change revises the acceptance criteria to be applied to an existing Technical Specification (TS) surveillance test of the facility diesel generators (DGs). Performing a surveillance test is not an accident initiator and does not increase the probability of an accident occurring.

The proposed new acceptance criteria will assure that the DGs are capable of carrying the peak electrical loading assumed in the various existing safety analyses, which take credit for the operation of the DGs.

Establishing acceptance criteria that bound existing analyses validates the related assumption used in those analyses regarding the capability of equipment to mitigate accident conditions.

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

2. Does the proposed change create the possibility of a new or different accident from any accident previously evaluated?

Response: No.

The proposed change revises the test acceptance criteria for a specific performance test conducted on the existing DGs. The proposed change does not involve installation of new equipment or modification of existing equipment, so no new equipment failure modes are introduced. The proposed revision to the DG surveillance test acceptance criteria also is not a change to the way that the equipment or facility is operated and no new accident initiators are created.

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

3. Does the proposed change involve a significant reduction in a margin of safety?

Response: No.

The conduct of performance tests on safety-related plant equipment is a means of assuring that the equipment is capable of maintaining the margin of safety established in the safety analyses for the facility. The 15

Enclosure PG&E Letter DCL-10-018 proposed change in the DG TS surveillance test acceptance criteria is consistent with values assumed in existing safety analyses and is consistent with the design rating of the DGs.

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

Based on the above evaluation, PG&E concludes that the proposed change does not involve a significant hazards consideration under the standards set forth in 10 CFR 50.92(c), and accordingly, a finding of "no significant hazards consideration" is justified.

4.4 Conclusions 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 inimical to the common defense and security or to the health and safety of the public.

5. ENVIRONMENTAL CONSIDERATION PG&E has evaluated the proposed amendment and has determined that the proposed amendment does not involve (i) a significant hazards consideration, (ii) a significant change in the types or significant increase in the amounts of any effluents that may be released offsite, or (iii) a significant increase in individual or cumulative occupational radiation exposure. Accordingly, the proposed amendment meets the eligibility criterion for categorical exclusion set forth in 10 CFR 51.22(c)(9). Therefore, pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the proposed amendment.

6. REFERENCES

1. Safety Guide 9, "Selection of Diesel Generator Set Capacity for Standby Power Supplies," dated March 10, 1971.

2. Regulatory Guide 1.9, Revision 2, "Selection, Design, and Qualification of Diesel-Generator Units Used as Standby (Onsite) Electric Power Systems at Nuclear Power Plants," dated December, 1979.

3. Regulatory Guide 1.9, Revision 3, "Selection, Design, and Qualification of Diesel-Generator Units Used as Standby (Onsite) Electric Power Systems at Nuclear Power Plants," dated July 1993.

16

Enclosure PG&E Letter DCL-10-018

4. Regulatory Guide 1.108, "Periodic Testing of Diesel Generator Units Used as Onsite Electric Power Systems at Nuclear Power Plants,"

Revision 1, August 1977.

5. SECY-92-223 "Resolution of Deviations Identified During the Systematic Evaluation Program," dated September 18, 1992.

6. PG&E Calculation No. 9000037760, Revision 20, "Diesel Generator Loading for Vital Bus Loads Units 1 and 2."

7. PG&E Calculation No. 9000040769, Revision 0, "Maximum EDG Mechanical Loading."

8. NRC Temporary Instruction 2515/176, "Emergency Diesel Generator Technical Specification Surveillance Requirements Regarding Endurance and Margin Testing," dated May 16, 2008.

9. NUREG-1431, Revision 3.1, "Standard Technical Specifications Westinghouse Plants," dated December 1, 2005.

10. Amendment No. 135 to Facility Operating License Nos. DPR-80 and DPR-82, "Conversion to Improved Technical Specifications for Diablo Canyon Power Plant, Units 1 and 2 - Amendment No. 135 to Facility

.Operating License Nos. DPR 80 and DPR-82 (TAC Nos. M98984 and M98985)," dated May 28, 1999.

11. Amendment No. 259 to Facility Operating License No. DPR-26 for the

- Indian Point Nuclear Generating Unit No. 2, "Indian Point Nuclear Generating Unit No. 2 - Issuance of Amendment RE: Emergency Diesel Generator Surveillance Test (TAC No. MD9214)," dated April 22, 2009.

17

Enclosure Attachment 1 PG&E Letter DCL-10-018 Proposed Technical Specification Changes (marked-up)

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated power In accordance with availability for each required offsite circuit. the Surveillance Frequency Control Program SR 3.8.1.2 -------------------- NOTES----

1. Performance of SR 3.8.1.7 satisfies this SR.

2. All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.

Verify each DG starts from standby conditions and In accordance with achieves speed _> 900 rpm, steady state voltage the Surveillance

> 3785 V and < 4400 V, and frequency > 58.8 Hz and Frequency Control

< 61.2 Hz. Program SR 3.8.1.3 --------------------- NOTES----------------

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

2. Momentary transients outside the load range do not invalidate this test.

3. This Surveillance shall be conducted on only one DG at a time.

4. This SR shall be preceded by and immediately follow without shutdown a successful performance - '7 5 of SR 3.8.1.2 or SR 3.8.1.7. t

-7 50' "Verify 1 each DG is synchronized and loaded and In accordance with erates for > 60 minutes at a load >

-<zeekW.

W and

Frequency the Surveillance Program Control I SR 3.8.1.4 Verify each day tank contains > 250 gal of fuel oil. In accordance with the Surveillance Frequency Control Program t-,

SR 3.8.1.5 Check for and remove accumulated water from each In accordance with day tank. the Surveillance Frequency Control Program SR 3.8.1.6 Verify the fuel oil transfer system operates to transfer In accordance with fuel oil from storage tanks to the day tank. the Surveillance Frequency Control Program (continued)

DIABLO CANYON - UNITS 1 & 2 3.8-4 Unit 1 - Amendment No. 4-35, '*86 8S91DN08.DOA- R8 4 Unit 2 - Amehdment No. 4-35, 2941,

AC Sources 7 Operating 3.8.1 REQUIREMENTS (continu(

SURVEILLANCE A

SR 3.8.1.10 Verify each DG spar1ting at a pow;r ftogr -G".. In accordance with I does not trip and voltage is maintained < 5075 V the Surveillance

'75ri0n and following a load rejection of >_E23,4e'kW Frequency Control and < S6ekW. - Li75- Program SR 3.8.1.11 ----------------

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

1. All DG starts may be preceded by an engine prelube period:

2. This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

Verify on an actual or simulated loss of offsite power In accordance with signal: the Surveillance Frequency Control

a. De-energization of emergency buses; Program

b. Load shedding from emergency buses;

c. DG auto-starts from standby condition and:

1. energizes permanently connected loads in

<10 seconds,

2. energizes auto-connected loads through auto-transfer sequencing timers,

3. maintains steady state voltage > 3785 V and <_4400 V,

4. maintains steady state frequency

> 58.8 Hz and _<61.2 Hz, and

5. supplies permanently connected and auto-connected loads for > 5 minutes.

(continued)

DIABLO CANYON - UNITS 1 & 2 3.8-6 Unit I - Amendment No. 4-35,474-4,2GOa-8S91DN08.DOA - R8 6 Unit 2 - Amendment No. 4-1-35,-76,114

AC Sources - Operating 3.8.1 SURVEILCNCE REQUIREMENTS (continued)

/SURVEILLANCE FREQUENCY S R 3.8.1.{14 -------- NO TES ---------------

1k: 1.- Momentary transients outside the load and power

factor ranges do not invalidate this test.

I Verify each DG op@rating at a pe'.&' facto-r _0.8' operates for > 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s: 750 In accordance with the Surveillance 1

IV Frequency Control

a. For Ž2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded A

2860 kW; and kW and Fre ny tr I

7 b. For the remaining hours of the test loaded 5t 750 kWand V I

SR 3.8.1.15 -------------------- NOTES ----------------

1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated Ž 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded Ž'3,kW and < 6 kW.

Momentary transients outside of load range do not invalidate this test.

" -2 -"

1 I

2. All DG starts may be preceded by an engine.

prelube period.

Verify each DG starts and achieves: In accordance with

a. in < 10 seconds, speed > 900 rpm; and the Surveillance

b. in <13 seconds, voltage >3785 V, and Frequency Control Program

< 4400 V and frequency >58.8 Hz and

_<61.2 Hz.

SR 3.8.1.16 -------------------- NOTE -----------------

This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

Verify each DG: In accordance with

a. Synchronizes with offsite power source while the Surveillance loaded with emergency loads upon a simulated Frequency Control restoration of offsite power; Program (continued)

DIABLO CANYON - UNITS 1 & 2 3.8-8 Unit 1 - Amendment No. 41-,4-74,iel 8S91DN08.DOA - R8 8 Unit 2- Amendment No. 435-17-6,

Technical Specification 3.8.1 Inserts Insert 1

NOTE ----------- ............

If performed with DG synchronized with offsite power, it shall be performed at a power factor

-<0.85. However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable.

Insert 2

2. If performed with DG synchronized with offsite power, it shall be performed at a power factor

< 0.85. However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable.

Enclosure Attachment 2 PG&E Letter DCL-10-018 Proposed Technical Specification Changes (retyped)

Remove Page Insert Page 3.8-4 3.8-4 3.8-6 3.8-6 3.8-8 3.8-8 3.8-9 3.8-9

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated power In accordance with availability for each required offsite circuit. the Surveillance, Frequency Control Program SR 3.8.1.2 --------------------- NOTES----------------

1. Performance of SR 3.8.1.7 satisfies this SR.

2. All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.

Verify each DG starts from standby conditions and In.accordance with achieves speed _>900 rpm, steady state voltage the Surveillance

Ž3785 V and _< 4400 V, and frequency _Ž58.8 Hz and Frequency Control

61.2 Hz. Program SR 3.8.1.3 --------------------- NOTES----------------

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

2. Momentary transients outside the load range do not invalidate this test.

3. This Surveillance shall be conducted on only one DG at a time.

4. This SR shall be preceded by and immnediately follow without shutdown a successful performance of SR 3.8.1.2 or SR 3.8.1.7.

Verify each DG is synchronized and loaded and In accordance with operates for _>60 minutes at a load >_2475 kW and the Surveillance

_ 2750 kW. Frequency Control Program SR 3.8.1.4 Verify each day tank contains Ž_250 gal of fuel oil. In accordance with the Surveillance Frequency Control Program SR 3.8.1.5 Check for and remove accumulated water from each In accordance with day tank. the Surveillance Frequency Control Program SR 3.8.1.6 Verify the fuel oil transfer system operates to transfer In accordance with fuel oil from storage tanks to the day tank. the Surveillance Frequency Control Program (continued)

DIABLO CANYON - UNITS 1 & 2 3.8-4 Unit 1 - Amendment No. 4-35, 200, Unit 2 - Amendment No. 435, 2-04,

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.10 --

NOT r--------------------------------

If performed with DG synchronized with offsite power, it shall be performed at a power factor < 0.85.

However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable.

Verify each DG does not trip and voltage is In accordance with maintained _<5075 V during and following a load the Surveillance rejection of _>2475 kW and < 2750 kW. Frequency Control Program I

SR 3.8.1.11 NOTES ----------------

1. All DG starts may be preceded by an engine prelube period.

2. This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

Verify on an actual or simulated loss of offsite power In accordance with signal: the Surveillance Frequency Control

a. De-energization of emergency buses; Program

b. Load shedding from emergency buses;

c. DG auto-starts from standby condition and:

1. energizes permanently connected loads in

<10 seconds,

2. energizes auto-connected loads through auto-transfer sequencing timers,

3. maintains steady state voltage _>3785 V and _< 4400 V,

4. maintains steady state frequency

>_58.8 Hz and

61.2 Hz, and

5. supplies permanently connected and auto-connected loads for _>5 minutes.

(continued)

DIABLO CANYON - UNITS 1 & 2 3.8-6 Unit 1 - Amendment No. 4-,5,4-74,200, Unit 2 - Amendment No. 4-45,1-7-&,,2-Q4,

)

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.14 -------------------- NOTES ----------------

1. Momentary transients outside the load and power factor ranges do not invalidate this test.

2. If performed with DG synchronized with offsite power, it shall be performed at a power factor

< 0.85. However, if grid conditions do not permit, the power factor limit is not required to.

be met. Under this condition the power factor shall be maintained as close to the limit as practicable.

Verify each DG operates for 2!24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s: In accordance with hours loaded Ž 2750 kW and the Surveillance

a. For _2802 hr

a. Ž! and Frequency Control

_<2860 kW; and Program

b. For the remaining hours of the test loaded

_ 2475 kW and _<2750 kW.

SR 3.8.1.15 ----- ------------- NOTES ----------------

1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated >_2 hours loaded _>2475 kW and _<2750 kW.

Momentary transients outside of load range do not invalidate this test.

2. All DG starts may be preceded by an engine prelube period.

Verify each DG starts and achieves: In accordance with

a. in < 10 seconds, speed _> 900 rpm; and the Surveillance

b. in <13 seconds, voltage Ž3785 V, and Frequency Control Program

_4400 V and frequency _58.8 Hz and

61.2 Hz.

SR 3.8.1.16 --------------------- NOTE ------------------

This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

(continued)

DIABLO CANYON - UNITS 1 & 2 3.8-8 Unit 1 - Amendment No. 4-35,4-74,2-W, Unit 2 - Amendment No. 4-5,4-7-6,20-1-,

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.16 Verify each DG: In accordance with (continued) the Surveillance

a. Synchronizes with offsite power source while Frequency Control loaded with emergency loads upon a simulated Program restoration of offsite power;

b. Transfers loads to offsite power source; and

c. Returns to ready-to-load operation.

SR 3.8.1.17 -------------------- NOTE ------------------

This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

Verify, with a DG operating in test mode and In accordance with connected to its bus, an actual or simulated Safety the Surveillance Injection signal overrides the test mode by: Frequency Control

a. Opening the auxiliary transformer breaker; and Program

b. Automatically sequencing the emergency loads onto the DG.

SR 3.8.1.18 -------------------- NOTE ------------- ----

This Surveillance shall notnormally be performed in MODE 1, 2, 3, or 4. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

Verify each ESF and auto-transfer load sequencing In accordance with timer is within its limits. the Surveillance Frequency Control Program SR 3.8.1.19 -------------------- NOTES ----------------

1. All DG starts may be preceded by an engine prelube period.

2. This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

(continued)

DIABLO CANYON - UNITS 1 & 2 3.8-9 Unit 1 - Amendment No. 4-45,4-74,200, Unit 2 - Amendment No. 435,47-6,201-,

Enclosure Attachment 3 PG&E Letter DCL-10-018 Changes to Technical Specification Bases Pages (For information only)

AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.2 and SR 3.8.1.7 (continued)

REQUIREMENTS SR 3.8.1.7 requires that the DG starts from standby conditions and achieves required speed within 10 seconds and required voltage and frequency within 13 seconds. The 10 second start requirement reflects the point during the DG's acceleration at.which the DG is assumed to be able to accept load. The 13 second start requirement reflects the point at which the DG is assumed to have reached stable operation.

These stability points represent the recovery of the DG and the power distribution system following a transient. This assures the ability ofthe system to undergo further transients. Actual steady state operation is expected to achieve a level of stability closer to the nominal 60 Hz value. The 10 and 13 second start requirements support the assumptions of the design basis LOCA analysis in the FSAR, Chapter 15 (Ref. 5).

Since SR 3.8.1.7 requires a timed start, it is more restrictive than SR 3.8.1.2, and it may be performed in lieu of SR 3.8.1.2. This is the intent of Note 1 of SR 3.8.1.2.

The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program.

SR 3.8.1.3 This Surveillance verifies that the DGs are capable of synchronizing with the offsite electrical system and accepting loads greater than or equal to the equivalent of the maximum expected accident loads. A minimum run time of 60 minutes is required to stabilize engine temperatures, while minimizing the time that the DG is connected to the offsite source.

Although no power factor requirements are established by this SR, the DG is normally operated at a power factor between 0.8 lagging and 1.0. The 0.8 value is the design rating of the machine, while the 1.0 is an operational limitation to ensure circulating currents are minimized.

19)Pe,*c..

COJep0RATIONThe load bandwithin is provided to rangqe the load avoid routine to 100%/ f f th' of 90% everleadi.g load r

without anomalies will provide adequate-a ce e machine's

6. CC' UIt A ý,abilit to car 100% of oad if required.

The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program.

(continued)

DIABLO CANYON - UNITS 1 & 2 Revision 5 8S91EA05.DOA - R5b 14

AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.9 (continued)

REQUIREMENTS In order to ensure that the DG is tested under load conditions that are as close to design basis conditions as possible, Note 2 requires that, if synchronized to offsite power, testing must be performed using a power factor < 0.9 lagging. This power factor is chosen to be representative of the actual design basis inductive loading that the DG would experience.

SR 3.8.1.10 This Surveillance demonstrates the DG's capability to reject a full load without overspeed tripping or exceeding the predetermined voltage limits. The DG full load rejection may occur because of a system fault or inadvertent breaker tripping. This Surveillance ensures proper engine generator load response under the simulated test conditions.

This test simulates the loss of the totalconnected load that the DG would experience following a full load rejection and verifies that the DG does not trip upon loss of the load. These acceptance criteria provide for DG damage protection. While the DG is not expected to experience this transient during an event and continue to be available, this response ensures that the DG is not degraded for future application, including reconnection to the bus if the trip initiator can be corrected or isolated.

In order to ensure that the DG is tested under load conditions that are as close to design basis conditions as ossible, testing must be 0, 7,-- performed usin a.power factor - . lagging. This power factor is chosen to be represen ative o e actual design basis inductive loading that the DG would experience.

The Surveillance Frequency is based on operating experience, equipment~reliability, and plant risk and is controlled under the Surveillance Frequency Control Program.

'ýontinued)

DIABLO CANYON - UNITS I & 2 Revision 5 8S9IEA05.DOA.- R5b 19

AC Sources - Operating B 3.8.1 REQUIREMENTS Preplanned maintenance that would require the performance of this SR to demonstrate operability following the maintenance shall only be performed in Modes 3, 4, 5, or 6.

SR 3.8.1.13 This Surveillance demonstrates that DG noncritical protective functions are bypassed when the diesel engine trip cutout switch is in the cutout position and the DG is aligned for automatic operation. The noncritical trips include directional power, loss of field, breaker overcurrent, high jacket water temperature, and diesel overcrank. These noncritical trips are bypassed during DBAs and provide an alarm on an abnormal engine condition. This alarm provides the operator with sufficient time to react appropriately. The DG availability to mitigate the DBA is more critical than protecting the engine against minor problems that are not immediately detrimental to emergency operation of the DG.

The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program.

SR 3.8.1.14 The refueling outage intent of Regulatory Guide 1.108 (Ref. 9),

paragraph 2.a.(3), requires demonstration that the DGs can start and run continuously at full load capability for an interval of not less than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , > 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months of which is at a load equivalent to 1+e14-Wthe _ e

-rating and the remainder of the time aa 3laiY equivalent to the continuous duty rating of the DG.W-he DG starts for this Surveillance can be performed either from standby or hot conditions. The provisions for prelubricating and warmup, discussed in SR 3.8.1.2, and for gradual loading, discussed in SR 3.8.1.3, are applicable to this SR.

(continued)

DIABLO CANYON - UNITS 1 & 2 Revision 5 8S9IEA05.DOA - R5b 23

AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.14 (continuted)

REQUIREMENTS in order to ensure that the DG is tested under load conditions that are as close to design conditions as possible, testing must be performed using a power factor of < 0.87 lagging. This power factor is chosen to be representative of the actual design basis inductive loading that the DG would experience. The load band is provided to avoid routine overloading of the DG. Routine overloading may result in more

frequent teardown inspections in accordance with vendor

[recommendations in order to maintain DG OPERABILITY.

e urveillance Frequency is base on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program.

IWO ,"This

' Surveillance is modified byNote 1 W"I.Iistates that momentary transients due to changing bus loads do not invalidate this test.

Similarly, momentary power factor transients above the power factor lim it w ill not invalidate the test. 04. ...... L I/

Administrative controls for performing this SR in MODES 1 or 2, with the DG parelleled to an offsite power supply, ensure or require that:

a. Weather conditions are conducive to performing this SR.

b. The offiste power supply and switchyard conditions support performing this SR, including communicating with the transmission group responsible for the 230 kV and 500 kV switchyards to ensure that, during the DG testing, vehicle access to these switchyards is controlled and no elective maintenance or testing on the offsite power sources is performed potentially affecting:

230 kV and 500 kV systems (Exceptions are to be authorized by Operations Management)

Either units' 12 kV startup bus o Transformers or insulators

c. No equipment or systems assumed to be available for supporting the performance of the SR are removed from service.

(continued)

DIABLO CANYON - U*ITS 1 & 2 Revision 5 8S91EA05.DOA - R5b 24

AC Sources - Operating B 3.8.1 BASES.

SURVEILLANCE SR 3.8.1.15 REQUIREMENTS This Surveillance demonstrates that the diesel engine can restart from (continued) a hot condition, such as subsequent to shutdown from normal Surveillances, and achieve stability by reaching the required voltage and frequency within 13 seconds. The 13 second time is derived from the requirements of the accident analysis to respond to a design basis accident. The acceptance criteria represents the recovery of the DG and the power distribution system following a start and load transient.

This assures the ability of the system to undergo further transients.

Actual steady state operation is expected to achieve a level of stability closer to the nominal 60 Hz value. The Surveillance Frequency is ,

based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program.

This SIR is modified by two Notes. Note I ensures that the test is

.Ti, s e r*/ . fauld with the diesel ofuffnh 0(9-. 9 erfo u- ed ,,vuveroaaing d Vine overloads may result in rnmore frequent teardown inspections in accordance with ven r**ecommendatio~ns in order to raintain.DG OPERABILITY The requirement that the diesel has operated for at eas ours at full load conditions prior to performance of this Surveillance is based on test data and manufacturer recommendations for achieving hot conditions.

Momentary transients due to changing bus loads do not invalidate this test. Note 2 allows all DG starts to be preceded by an engine prelube period to minimize wear and tear on the diesel during testing.

SR 3.8.1.16 As required by Regulatory Guide 1.108 (Ref. 9), paragraph 2.a.(6), this Surveillance ensures that the manual synchronization and load transfer from the DG to the offsite source can be made and the DG can be returned to ready to load status when offsite power is restored. It also ensures that the autostart logic is reset to allow the DG to reload if a subsequent loss of offsite power occurs. The DG is considered to be in ready to load status when the DG is at rated speed and voltage, the output breaker is open and can receive an auto close signal on bus undervoltage, and the load sequencing timers are reset.

The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program.

(continued)

.DIABLO CANYON - UNITS 1 & 2 Revision 5 8S91EA05.DOA - R5b 25

Technical Specification 3.8.1 Bases Inserts Insert 1 exceeding of the DG 2000-hour rating. Routine exceeding of the DG 2000-hour rating may result in more frequent teardown inspections in accordance with vendor recommendations in order to maintain DG OPERABILITY.

Insert 2 This SR has been modified by a Note. The Note ensures that the DG is tested under load conditions that are as close to design basis conditions as possible. When synchronized with offsite power, testing should be performed at a power factor of < 0.85. This power factor is representative of the actual inductive loading a DG would see under design basis accident conditions. Under certain conditions, however, the Note allows the Surveillance to be conducted at a power factor other than

<50.85, These conditions occur when grid voltage is high, and the additional field excitation needed to get the power factor to < 0.85 results in voltages on the emergency busses that are too high.

Under these conditions, the power factor should be maintained as close as practicable to 0.85 while still maintaining acceptable voltage limits on the emergency busses. In other circumstances, the grid voltage may be such that the DG excitation levels needed to obtain a power factor of 0.85 may not cause unacceptable voltages on the emergency busses, but the excitation levels are in excess of those recommended for the DG. In such cases, the power factor shall be maintained as close as practicable to 0.85 without exceeding the DG excitation limits.

Insert 3 The maximum load limit value of 2750 kW for the remaining hours of the test is based on the DG 2000-hour rating which envelopes the maximum expected accident load and is greater than the continuous duty rating of the DG as specified by Regulatory Guide 1.108 (Ref. 9).

Insert 4 Note 2 ensures that the DG is tested under load conditions that are as close to design basis conditions as possible. When synchronized with offsite power, testing should be performed at a power factor of < 0.85. This power factor is representative of the actual inductive loading a DG would see under design basis accident conditions. Under certain conditions, however, Note 2 allows the Surveillance to be conducted as a power factor other than < 0.85. These conditions occur when grid voltage is high, and the additional field excitation needed to get the power factor to < 0.85 results in voltages on the emergency busses that are too high. Under these conditions, the power factor should be maintained as close as practicable to 0.85 while still maintaining acceptable voltage limits on the emergency busses. In other circumstances, the grid voltage may be such that the DG excitation levels needed to obtain a power factor of 0.85 may not cause unacceptable voltages on the emergency busses, but the excitation levels are in excess of those recommended for the DG. In such cases, the power factor shall be maintained close as practicable to 0.85 without exceeding the DG excitation limits.

The load band is provided to avoid routine exceeding of the DG 2-hour per 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months rating for the > 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months portion of the test and the DG 2000-hour rating during the remaining hours of the test.

Routine exceeding of the DG 2-hour per 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and 2000-hour ratings may result in more frequent teardown inspections in accordance with vendor recommendations in order to maintain DG OPERABILITY.

Technical Specification 3.8.1 Bases Inserts (continued)

Insert 5 The load band of 2475 kW to 2750 kW is based on the load band required for SR 3.8.1.14.b. The load band is provided to avoid routine exceeding of the DG 2000-hour rating. Routine exceeding of the DG 2000-hour rating may result in more frequent teardown inspections in accordance with vendor recommendations in order to maintain DG OPERABILITY.

Enclosure Attachment 4 PG&E Letter DCL-10-018 Commitments Commitment 1 Additional guidance will be provided to operators in the surveillance procedures as part of implementation of the license amendment request to provide guidance to the operators on use of the new Note added to SR 3.8.1.10 and SR 3.8.1.14.

Enclosure Attachment 5 PG&E Letter DCL-10-018 PG&E Calculation No. 9000037760, Revision 20

DCPP Form 69-20132 (08122108) CF3.1D4 Attachment 4 Page 1 of 2 Design Calculation Cover Sheet Unit(s): 1&2 File No.: Responsible Group: EDE Calculation No.: 9000037760-20 Design Calculation: Z YES El NO System No.: 63 (4kv), 21 (DG) Quality Classification: Q Structure, System or Component: Diesel Generator

Subject:

Diesel Generator Loading for Vital Bus Loads Units 1 and 2 Computer/Electronic Calculation: El YES Z NO Computer ID Application Name and Version Date of Latest Installation/Validation Test Registered Engineer Stamp: Complete A or B A. Insert PE stamp or seal below: B. Insert stamp directing to the PE stamp or seal:

NO. E772e¶,

Expiration Date: 9/30/10 Update DCI promptly after approval.

Forward electronic calculation file to CCG for uploading to EDMS, only if the calculation is complete and can be used from EDMS.

015-DC-r20-Cvr.DOC 0618.1136

DCPP Form 69-20132 (08122/08) CF3.1D4 Attachment 4 Design Calculation Cover Sheet Page 2 of 2 Calculation No.: 9000037760-20 RECORD OF REVISIONS Rev Status No. of Reason for Revision Prepared LBIE LBIE Check LBIE Checked Supervisor Registered Owner's No. Pages By Screen Method* Approval Engineer Acceptance per CF3.1D1 7 Remarks Signature/ Yes/ Yes/ Yes/ PSRC PSRC Signature Signature/ Signature/ Signature/

LAN ID! No/ No/ No/ Mtg Mtg LAN ID/ LAN ID/ LAN ID! LAN ID/

Date NA NA NA No. Date Date Date Date Date 20 F 46 SAP Not. 50179082, GAR0! DYes ]Yes P A tPr2 D N/A 50207912, 50232181 DElIF 529,21 ((N!/A

[]No N)No

[IN/A [ ]B

[]C Is _-o

[]Yes []Yes I ]A

[]No []No []B

[]N/A []NIA []C

[]Yes []Yes []A

[]No []No []B

[]N/A []N/A [ -C--

[]Yes []Yes []A

[]No []No []B

[]N/A []N/A []C

Check Method: A = Detailed Check B Alternate Method (note added pages) C = Critical Point Check Input Reference Output Reference Calc/Procedure No. Comments Calc/Procedure No. Comments 357A-DC, Rev. 12 M-786 M-1141, Rev. 0 STP M-9A STP M-9M EOP ECA-0.3 015-DC-r2G-Cvr.DOC 0618.1134

REASON FOR REVISION Calculation No. 9000037760 (015-DC)

REVISION DESCRIPTION OF REVISION NO.

20 Scope of the calculation expanded to include both Units 1 and 2 (Unit 2 was formerly addressed in a separate calculation, 125-DC and 125-DC will now .be superseded by revision 20 of this calculation); Frequency and Voltage variation loading impacts are incorporated as summarized in NRC .2008 4th Quarter Report; Clarification of the worst case accident; Update of brake horsepower requirements based on new Mechanical Calc M-1141; Refinements in power factor determination.

015-DC-r20.DOC Page iii of 45

Form 69-10430 (08/20/07) TS3.1D2 Attachment 8.1 Page I of 3 LBIE Screen - Applicability Determination

1. Proposed Activityllmplementing Document No: Unit: Imp Doc Rev No:

Calculation Update / 9000037760 (015-DC) Ell El 2 01 &2 20 Briefly describe what is being changed and why:

The scope of Calculation 15-DC has been expanded to include the diesel generators of both units. Prior revisions were limited to Unit 1 DG's only and Unit 2 was addressed in a separate calculation (i.e. 125-DC). Since the Unit 2 calculation was dependent upon assumptions and computations in the Unit 1 calc, they were combined to reduce administrative overhead. Technical changes include: 1) Incorporation of frequency and voltage variation impacts on the connected loads as summarized in NRC 2008 4e Qtr Inspection Report; 2) Clarification of worst case accident; 3) Update pump brake horse power requirements based on new Mechanical Calc M-1141; and 4) Refine the power factor determination.

2. Applicability Determination (refer to TS3.1D2, Appendix 7.1 Section 2 for general guidance) Ref. TS3.1D2 Does the proposed activity involve: Appendix 7.1 2.a A change to the Facility/ISFSI Operating License (OL), Environmental Protection 21 Y El N Block 2.a Plan (EPP) or Technical Specifications (TS)?

2.b A change to the Quality Assurance Program? El Y H N Block 2.b 2.c A change to the Security Plan? El Y- M N Block 2.c 2.d A change to the Emergency Plan? El Y 0 N Block 2.d 2.e A change to the Inservice Testing (IST) Program Plan? El Y M N Block 2.e 2.f A change to the Inservice Inspection (ISI) Program Plan? El Y 0 N Block 2.f 2.g A change to the Fire Protection Program? El Y Ml N Block 2.g 2.h A noncompliance with the Environmental Protection Plan or may create a situation El Y N N Block 2.h adverse to the environment?

2.1 A change to the FSARU (including documents incorporated by reference) excluded El Y M] N Block 2.i from the requirement to perform a 50.59172.48 review?

2.j Maintenance that restores SSCs to their original or newly approved designed ElY N N Block 2.j condition? (Check "No" if activity is related to ISFSI.)

2.k A temporary alteration supporting maintenance that will be in effect during at-power lY M N Block 2.k operations for 90 days or less? (Check "No' if activity is related to ISFSI.)

2.1 Managerial or administrative procedure/process controlled under 10 CFR 50, App. B? [E Y MN Block 2.1 2.m Regulatory commitment not covered by another regulatory based change process? [I Y Z N Block 2.m 2.n An impact to other plant specific programs (e.g., the ODCM) that are controlled by El Y N Block Blck2.

___ON 2.n regulations, the OL, orTS?

3. Applicability Determination

Conclusions:

El A 10 CFR 50.59 or 72.48 screen is NOT required because ALL aspects of the activity are controlled by one or more of the processes listed above, or have been approved by the NRC, or covered in full in another LBIE review.

[ A 10 CFR 50.59 or 72.48 screen will be completed because some or all the aspects of the activity are not.

controlled by any of the processes listed above or cannot be exempted from the 10 CFR 50.59/72.48 screen.

4. Does the proposed activity Involve a change to the plant where the change requires a safety assessment? I El Y N 1

5. Remarks: (Use this section to provide justification of determination instep 2 as needed.) J 2.a Screen for Changes to the Facility License: Tech Spec Bases 3.8.1 states that the DG rating is based on Regulatory Guide 1.9, Rev. 0. As-documented in DCM S-21, DG automatic loading is designed to ensure the actual loads do not exceed the smaller of the 2000 hour0.0231 days 0.556 hours 0.00331 weeks 7.61e-4 months rating or 90 percent of the 30 minute rating of each set. The conclusion of the subject calculation revision is that the maximum steady state loadings are within this limit (i.e. 2750 KW) which does not change the Tech Spec Bases for this parameter. Tech Spec Bases 3.8.1 also states inSR 3.8.1.10 to verify each DG is operating at a power factor

<_0.87. Engineering calculation 015B-DC Rev 1 (reference Notification 50232181), has previously determined that the Tech Specs are non-conservative with respect to power factor. The results of this calculation are in agreement with the conclusions of engineering calculation 015B-DC Rev 1 with respect to this DG parameter. Specifically, the worst case power factor for this calculation is 85.8%. The issuance of this master calculation provides a basis for a licensing amendment request (LAR). The issuance of this calculation does not change existing SSC's, but quantifies what currently exists by incorporating the results of revised.motor loading as a result of the issuance of Calculation M-1 141 Rev 0, and refinements in the calculation which 015-DC-r20 Page 4 of 45 PG&E Diablo Canyon

Form 69-10430 (08120107) TS3.1D2 Attachment 8.1 LBIE Screen - Applicability Determination Page 2 of 3 include the DG loading and capacity effects of elevated frequency and voltage, which in total provide more accurate results for both kilowatt (KW), kilovar (KVAR) and resultant power factor worst case loading for each DG. Therefore, the answer to this question is yes.

2.b Screen for Changes to the Quality Assurance Program: The Quality Assurance Program as described inthe FSAR Update, Chapter 17, does not address electrical analysis. Therefore, the answer to this question is no.

2.c Security Plaris Screen: The changes discussed inthis revision of the subject calculation do not have any impact on the Security Plan since they are documentation changes only. They do not affect the location of safety related equipment or change any security barriers, systems, or features of DCPP or other security impacts. Therefore, the answer to this question is no.

2.d Emergency Plan Screen: The changes discussed in this revision of the subject calculation-do not have any impact on the Emergency Plan since they are documentation changes only. They do not alter system, equipment, facilities, or capabilities relied upon or described inthe plan or other EP impacts. Therefore, the answer to this question is no.

2.e Inservice Testing Program (lST) Plan Screen: This calculation revision does not involve inservice testing of ASME Code Class 1, 2, and 3 pumps and valves. Therefore, the answer to this question is no.

2.f Inservice Inspection Program (ISI) Plan Screen: This calculation revision does not involve inservice inspection of ASME Code Class 1, 2, and 3 pumps and valves. Therefore, the answer to this question is no.

2.g Fire Protection Program Screen: The changes discussed in this revision of the subject calculation are used solely to confirm the adequacy of existing diesel generator capacity. There are no physical changes or component classification changes. Therefore, the answer to this question is no.

2.h Environmental Protection Screen: The changes discussed in this revision of the subject calculation are documentation changes only and do not Involve any effluent discharges, land alteration, increase in hazardous materials, or other environmental impacts. Therefore, the answer to this question is no.

2.i Change to the FSARU: FSAR update will be performed under separate cover in accordance with X13.ID2, which will contain a separate 50.59 review (reference Notification 50248352).

2.j Screen for Maintenance Activities: This calculation revision is a documentation configuration control update. No design or maintenance activities are involved. Therefore, the answer to this question is no.

2.k Temporary Alteration Screen: This calculation revision is a documentation configuration control update. No temporary alteration activities are involved. Therefore, the answer to this question is no.

2.1 Managerial or Administrative Procedure/Process Screen: This calculation revision is a documentation configuration control update. No Managerial or Administrative Procedures/Processes governing the conduct of facility operations are changed by updating and refining this calculation. Therefore, the answer to this question is no.

2.m Screen for Regulatory Commitments and Obligations: The revision is not the result of any periodic inspection/surveillance commitments. The PCD was searched for implementing documents Caic 15-DC and 125-DC, no hits were found. The PCD was searched for implementing documents STP M-9A and M-9M, none found for M-9M, 9 found for M-9A. Of these hits, three could not be eliminated by title: T19179, T35507 and T34173. T19179 pertains to Accumulated water in the DG Day Tank, not applicable. T35507 pertains to test DG to be declared inoperable when paralleled to offsite power source with only one offsite source available, not applicable. T34173 pertains to precautions outlining actions to be taken on a loss of normal feed to a bus while the DG is paralleled to the bus for testing, not applicable. The PCD was searched for implementing document EOP ECA 0.3, two hits were found. Of these two, one could not be eliminated by title:

T3501 B.T3501 8 pertains to the review and modification of plant and dispatcher procedures to meet the guidelines in NUMARC 87-00, Section 4. The impact of Calc 15-DC Rev 20 on EOP ECA 0.3 is to update Appendix Q Equipment Load Table 1 for new loading information, and to make clarifications to Appendix Q Figure I Diesel Generator Load Limits, which does not affect this regulatory commitment. Therefore, the answer to this question is no.

2.n Screen for Impacts to Other Plant Specific Programs: No other plant specific programs including the Offsite Dose Calculation Manual (ODCM) that are controlled by the operating license (OL) or the technical specifications (TS) are impacted by the revision of this calculation which provides updated DG loading information. Therefore, the answer to this question is no.

015-DC-r20 Paae 5 of 45 PG&E Diablo Canyon

Form 69-10430 (08120/07) TS3.1D2 Attachment 8.1 LBIE Screen - Applicability Determination Page 3 of 3 015-DC-r20 Page 6 of 45 PG&E Diablo Canyon

Form 69-21097 (08120/07) TS3.1D2 Attachment 8.9 Page I of 3 LBIE Screen - 10 CFR 50.59172.48 Screen

1. Proposed Activity/Implementing Document No: Unit: Imp Doc Rev No:

Calculation Update / 9000037760 (015-DC) E]I 1E] 2 2] 1&2 20 Briefly describe what is being changed and why:

The scope of Calculation 15-DC has been expanded to Include the diesel generators of both units. Prior revisions were limited to Unit I DG's only and Unit 2 was addressed in a separate calculation (i.e. 125-DC). Since the Unit 2 calculation was dependent upon assumptions and computations in the Unit 1 calc, they were combined to reduce administrative overhead. Technical changes include: 1) Incorporation of frequency and voltage variation impacts on the connected loads as summarized in NRC 2008 4 "eQtr Inspection Report;,2) Clarification of worst case accident; 3) Update pump brake horse power requirements based on new Mechanical Calc M-1 141; and 4) Refine the power factor determination.

All of the above described changes are analysis enhancements. This scope of this LBIE screen does not include any physical changes to the plant

2. The screen performed is for (check one or both as applicable):

0 10 CFR 50.59 (Facility Operating License)

E] 10 CFR 72.48 (Independent Spent Fuel Storage Installation (ISFSI)

Identify SSC(s) described in the FSARU (including subcomponents) and the applicable section(s) in the FSARU affected by the proposed activity (use remarks section for overflow):

Applicable SSC's are: EDG1I, EDG12, EDG13, EDG21, EDG22, and EDG23.

Affected FSAR Sections are:

8.3.1.1.8.1, Dedicated Diesel Generators: This Section identifies the DG continuous rating only. Requires update to state design basis rating.

8.3.1.1.9, Operation of Emergency Power System: Starting inrush and momentary loads handled by DG short time overload capability (not impacted by these changes) 8.3.1.1.10(3), Emergency Loads Supplied by Diesel Generators: Worst case DG loading based on LOOP/LOCA scenario (not Impacted by these changes) 8.3.1.1.11, Momentary Loads: (Same as 8.3.1.1.9 above) 8.3.1.1,12, Maximum Demand: Does not address impact of frequency and voltage variations on DG loading. Per NEI 98-03, this is "new information requested by the NRC" (Ref. Integrated Inspection Report 0500027512008005, 05000323/2008005, and 0720002612008001) and should be added to the FSAR.

8.3.1.1.13.1, Diesel Generator Unit

Description:

This Section identifies various DG ratings. Requires update to state which rating is the design basis.

Table 8.3-3: Maximum Steady State Load Demand - No Safety Injection Signal. Requires data update.

Table 8.3-5: Diesel Generator Loading Maximum Steady State Load Demand Following a Loss of Coolant Accident.

Requires data update Table 8.3-6: Vital 4160/480 Volt Load Center Loading. Requires data update.

Table 8.3J7: Vital 480V Load Center Maximum Demand. Requires data update.

Describe the design function(s) of the above identified SSC(s) directly or indirectly affected by this proposed activity (use remarks section for overflow):

Each of the six diesel-generator sets is designed to supply the maximum demand of the safe shutdown loads for its associated 4160V vital bus, without exceeding the diesel generating ratings (Ref. DCM S-21, Section 4.3.4(a)).

In order to meet the requirements of an alternate AC power source, at least one Diesel Generator per unit shall be available within 10 minutes that has the capacity to carry the required shutdown loads during a 4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months station blackout (Ref. DCM S-63, Section 4.3.3.4).

The diesel-generator units are sized to supply the maximum demand of the engineered safety feature loads connected to their respective buses, and any Non-Class 1E loads not automatically disconnected (Ref. DCM S-63, Section 4.3.3.4).

The diesel-generator automatic load sequencing is designed to ensure the actual loads do not exceed the smaller of the 2000 hour0.0231 days 0.556 hours 0.00331 weeks 7.61e-4 months ratine or 90 c3ercent of the 30 minute ratina of each set Ref. DCM S-21. Section 4.3.1 (o)).

PG&E Diablo Canyon 015-DC-r20 Page 7 of 45

Form 69-21 097 (08/20/07) TS3.1D2 Attachment 8.9 Page 2 of 3 LBIE Screen - 10 CFR 50.59/72.48 Screen Ref. TS3.D2 Determine whether the proposed activity/change, test, or experiment (CTE): Appendix 7.8 2.a Involves.a change to an SSC that adversely affects an FSARU described design ElY O N Block 2.a function?

2.b Involves a change to a procedure that adversely affects how FSARU described ElY O N Block 2.b SSC design functions are performed or controlled?

2.c Involves a change that adversely revises or replaces an FSARU described El Y ON Block 2.c evaluation methodology that is used in establishing the design bases or that is used in the safety analyses?

2.d Involves a test or experiment not described in the FSARU, where an SSC is utilized ElY O N Block 2.d or controlled in a manner that is outside the reference bounds of the design for that SSC or is inconsistent with analyses or descriptions in the FSARU?

2.e Relies on a vendor 10 CFR 50.59 or 72.48 evaluation that has NOT been reviewed ElY O N Block 2.e by the PSRC?

3. Justification, References, and Materials:

3.a Justification for the 10 CFR 50.59/72.48 screen determinations in steps 2.a thru 2.e:

2a) This calculation computes DG loading, and makes no changes to any SSC and therefore does not involve a change to an SSC that adversely affects an FSARU described design function. The purpose of this calculation Is design basis sizing of the DG unit. Power factor variation has negligible impact on engine performance. Relative to the generator a lower power factor is more demanding (i.e. more generator heating) for a given KW loading. The power factor operating point is not a generator design.property. Power factor results from the connected loads. The benefit of knowing the expected power factor is to establish appropriate test conditions. Also, revisions of this calculation quantify DG loading for the purpose of tracking Operating Margin, and to assure that it is maintained within pre-establish limits based on the ratings of the DG, and it is not adverse to do so. Rather, it is conservative to track changes in Operating Margin to ensure that they are within these pre-established limits.

2b) The preparation of this calculation did not require any procedural changes. The impact of the calculation does require revision of procedures; however these revisions are not adverse, as they only provide clarification and more updated Information for use in the affected procedures. The purpose of this calculation is design basis sizing of the DG unit. Also, revisions of this calculation quantify DG loading for the purpose of tracking Operating Margin, and to assure that it is maintained within pre-establish limits based on the ratings of the DG, and it is not adverse to do so.

Rather, it is conservative to track changes in Operating Margin to ensure that they are within these pre-established limits.

2c) There are two distinct aspects to this calculation revision. Neither have an adverse impact on the FSAR described design functions listed above. The first change involves the addition of voltage and frequency variation impacts on the loading of connected equipment The second change is a document change only update of the connected loading data. Design Bases, as defined by reference document NEI 98-03 Rev. I can be restraints derived from generally accepted "state-of-the-art" practices, or requirements derived from analysis (calculations).

The addition of this analysis to the calculation is a transition from an evaluation based on restraints derived from generally accepted "state-of-the-art' practices to a more refined analysis which more clearly demonstrates design margin. Thus this is not a change to, but a refinement of the existing evaluation methodology, which provides more accurate information. There is no adverse impact because both these changes and the resulting computed expected loads more accurately evaluate design margin. The results of the calculation revision indicate an increase in the available margin based on the same design basis rating of the DG.

2d) This calculation does not involve any test or experiment not described-in the FSARU where any SSC is utilized or controlled in a manner that is outside the reference bounds of the design for that SSC or is inconsistent with the analyses or descriptions in the FSARU. It provides input to the periodic surveillance testing that is done by determining worst case DG loading. This input ensures that this periodic testing has values to test for that encompass worst case loading, and describes design margin for the DG.

2e) No vendor evaluation is involved in this calculation.

3.b List references used in this screen:

FSARU, Chapter 8, Section 8.3 Onsite Power Systems; NEI 98-03 Rev. 1 Guidelines for Updating Final Safety Analysis Reports; Tracking Notification for Calc 015-DC (50035755); Tracking Notification for Calc 125-DC (50234771)

PG&E Diablo Canyon 015-DC-r20 Page 8 of 45

Form 69-21097 (08/20/07) TS3.1D2 Attachment 8.9 Page 3 of 3 LBIE Screen - 10 CFR 50.59172.48 Screen 3.c List all materials attached to this screen:

None 10 CFR 50.59/72.48 Screen

Conclusions:

[ A 10 CFR 50.59/72.48 evaluation Is NOT required because ALL answers to steps 2.a thru. 2.e are NO.

1.

E] A 10 CFR 50.59)72.48 evaluation is to be completed because one or more of the answers in steps 2.a thru. 2.e are YES, Complete LBIE Sections 0, 1, and 3.

5. Remarks (use this section to provide additional information as 015-DC-r20 Page 9 of 45 PG&E Diablo Canyon

NUCLEAR POWER GENERATION CALCULATION TITLE: Diesel Generator Loading for 4160V Vital Buses Calc No. 9000037760 (015-DC) Rev. Part 20 / Version 0 Unit: 1/2 Table Of Contents 1.0 Purpose 11 2.0 Background 11 3.0 Assumptions 11 4.0 Inputs 17 5.0 Methodology .17 6.0 Acceptance Criteria 23 7.0 Calculation 24 8.0 Results 26 9.0 Margin Assessment 27 10.0 Conclusions 28 11.0 Impact Evaluations 29 12.0 References 30 12.1 Input References 30 12.2 Output References 32 12.3 Other 33 Pages Attachment A, Typical Motor Efficiency Graph - Standard Handbook for Electrical Engineering 015-DC-r20.DOC Page 10 of 45

NUCLEAR POWER GENERATION CALCULATION TITLE: Diesel Generator Loading for 4160V Vital Buses Cale No. 9000037760 (015-DC) Rev. Part 20 / Version 0 Unit: 1/2 1.0 PURPOSE The purpose of this design calculation is to establish that the Unit 1 and Unit 2 diesel generators (DG) have sufficient capacity and margin to fulfill the onsite power source requirements of General Design Criterion 17 (GDC-17) (Ref. 12.1.1). This is accomplished by demonstrating the DG has sufficient capacity and margin to "... supply continuously the sum of the loads needed to be powered at any given time." (Ref. 12.1.2).

2.0 BACKGROUND

The DG's are designed as Class lE standby power sources to provide AC electric power to the onsite AC Electrical Distribution System during and following the shutdown of the reactor when the offsite power sources are not available. This is a fundamental requirement of GDC-17 (Ref. 12.1.1). Adequate DG capability means that each DG has sufficient capacity to 1) Start and accelerate the required ESF loads in the prescribed sequence, and 2) Continuously supply the sum of the loads needed to be powered at any given time. The scope of this calculation addresses the latter capability requirement. For DCPP, the transient response capability of the DG (i.e. transient voltage dips, frequency dips, and associated recovery times) to start from standby, accelerate to rated voltage and frequency, and then start and accelerate the loads is evaluated by test. Both NRC Safety Guide 9 (Ref. 12.1.2) and IEEE 387 (Ref. 12.3.3) acknowledge that testing is preferred over analysis for this purpose (Note: IEEE 387 is not a DCPP licensing basis reference).

Regarding the continuous load capability, the DCPP DG's were sized and licensed in accordance with NRC Safety Guide 9 (Ref. 12.1.3). That regulatory position (i.e. DCPP License and design basis) stated that the predicted loads should not exceed the smaller of the 2000 hour0.0231 days 0.556 hours 0.00331 weeks 7.61e-4 months rating, or 90 percent of the 30 minute, machine rating (Ref. 12.1.2). As described in Section 6.1 of this calculation, the 2000 hour0.0231 days 0.556 hours 0.00331 weeks 7.61e-4 months rating is the smaller of the two. Present day DG sizing guidelines suggest a minimum 5 percent margin between the maximum design basis loading and the continuous rating of the DG (Ref. 12.1.4). It is noted that DCPP license basis is not committed to Reference 12.1.4.

The NRC has developed a Temporary Instruction (TI) (Ref. 12.3.1) for their review of DG designs and testing. A secondary goal of this calculation is to document the DG analysis methodology, assumptions, and conclusions in sufficient detail to facilitate a review based on this TI.

3.0 ASSUMPTIONS 3.1 Assumptions Requiring Validation None.

015-DC-r20.DOC Page 11 of 45

NUCLEAR POWER GENERATION CALCULATION TITLE: Diesel Generator Loading for 4160V Vital Buses Cale No. 9000037760 (015-DC) Rev. Part 20 / Version 0 Unit: 1/2 3.2 Validated Assumptions 3.2.1 The electrical loading associated with a postulated large break design basis loss of coolant accident (LOCA) envelopes the other postulated DBE accidents (e.g.

small break LOCA, steam generator tube rupture, main steam line break, or a station blackout).

Basis: Mechanical Calculation M-1 141 (Ref. 12.1.6) determined that a large break LOCA is in fact the worst case for mechanical loads (i.e. electrical rotating equipment), including ECCS and containment heat removal systems.

For the remaining ESF support functions, the equipment performance requirements are generally independent of the accident type. Therefore, this assumption is considered conservative.

3.2.2 The maximum demand for non-rotating equipment that automatically connects to the bus is non-mechanistically used without consideration as to when in the scenario the peak occurs or how long it lasts.

Basis: This is conservative and eliminates the need to develop time dependent load profiles.

3.2.3 Brake horsepower single failure impacts on parallel pump operation of the large pumps (i.e. driven by 4 kV motors) is addressed in Reference 12.1.6. However, redundant 480 Volt loads are assumed to be operating independently regardless of shared fluid systems.

Basis: This addresses single failure and maximizes the load on each component /

DG. Therefore, this assumption is considered conservative.

3.2.4 The BHP loading of motors driving pumps and fans is assumed to vary based on the cube of the per unit speed of the motor.

Basis: Steady state DG frequencies other than 60 Hz can cause speed changes in rotating equipment. Based on the pump affinity law (Ref. 12.1.6), a speed change results in a load change. The actual load change is some what less than the cube of the per unit speed change because in addition to the motor synchronous frequency change, the motor slip also changes as a result of the load change. This change in slip opposes the synchronous frequency change.

Therefore, this assumption is considered conservative.

3.2.5 The following diversity factors are assumed:

a. (A)utomatic: Load is automatically connected to the bus. Diversity factor equals 100 percent.

015-DC-r20.DOC Page 12 of 45

NUCLEAR POWER GENERATION CALCULATION TITLE: Diesel Generator Loading for 4160V Vital Buses CalcNo. 9000037760 (015-DC) Rev. Part 20 / Version 0 Unit: 1/2

b. (P)rocedure / Manunal: Load is required to be manually started by an Operator. Diversity factor equals zero percent.

c. (I)ntermittent: Load is automatically started, but has a definite on/off duty cycle. A 50 percent diversity factor is assumed.

d. (L)oad Shed: Operating loads are automatically disconnected. Diversity factor equals zero percent.

e. (M)omentary: Loads manually started by an Operator are assumed to be not operating. A zero diversity factor is assumed.

f. MO(V): Motor operated valves manually or automatically operated. These are a type of momentary load with a duty cycle usually in seconds. A zero diversity factor is assumed.

g. (-): Miscellaneous circuits without any load (e.g. spare). A zero diversity factor is assumed.

Basis: A diversity factor of 100 percent is worst case for operating loads and does not introduce any conservatism. A diversity factor of zero percent is a mechanism to turn off loads that will not be operating. A diversity factor of 50 percent is reasonable for redundant loads that either alternately cycle on and off or share a function (e.g. compressors and heaters). The duty cycle of these load types is typically less than 50 percent (e.g. compressors have multiple stages of loading/unloading). Establishing demand factors less than 100 percent is a common industry technique to account for the amount of time the load is actually operating. Additionally, not all intermittent loads cycle at the same time. Therefore, this assumption is considered reasonable.

3.2.6 Momentary loads, which may consist of transformer inrush, motor starting inrush, motor operated valves (MOV), and the inrush associated control circuit components that change state (e.g. relays and solenoid valves) need not be considered as part of the DG continuous loading.

Basis: Short duty cycle loads by definition do not operate continuously. The Acceptance Criteria of this calculation are based on the DG manufacturer's ratings for extended operation with a high availability confidence factor. The operating time of momentary loads is typically measured in seconds. By definition, they are not within the scope of this continuous loading calculation.

The 1 minute rating of the DG is 150 percent of the continuous rating for this purpose. However, to validate this position, the following arguments are provided.

015-DC-r20.DOC Page 13 of 45

NUCLEAR POWER GENERATION CALCULATION TITLE: Diesel Generator Loading for 4160V Vital Buses Calc No. 9000037760 (015-DC) Rev. Part 20 / Version 0 Unit: 1/2

a. Transformer Inrush: The duration of transformer inrush current is measured in cycles, which is not a continuous load. Additionally, the 4.16 kV /480 V load center transformer is the first component energized by the DG (i.e. the DG is initially unloaded). This phenomenon is part of the DG integrated load sequencing test (Ref. 12.1.8).

b. Motor Starting: Motor starting is an electrical transient and the times are measured in seconds. The starting of the large motors is staggered to ensure locked rotor conditions do not overlap. This phenomenon is part of the DG integrated load sequencing test (Ref. 12.1.8) and is not considered as part of the DG continuous loading.

c. Motor Operated Valves: MOV stroke times are generally measured in seconds, which is not a continuous load. Additionally, the pump associated with the fluid system the valve is controlling would not be at its worst case operating point until the MOV is in the required position. Therefore, assuming worst case pump brake horsepower is considered conservative.

d. Relays and Solenoid Valves: This would only be applicable to components powered by Motor Control Center (MCC) control power transformers (CPT). Components powered via battery chargers or the uninterruptible 120 VAC power supplies (i.e. inverters) are already accounted for in their.

respective power sources. The inrush times of these types of devices would also be in cycles, which is not a continuous load. In addition to being small loads compared to the 3.25 MVA generator, the operation of these loads would be staggered over the entire load sequencing period. Therefore, the aggregate impact of these loads are considered negligible.

e. Auxiliary Lube Oil Pumps: These pumps only operate for the short time frame necessary for the primary pump to come up to speed.

3.2.7 The final steady state load at the conclusion of the automatic loading sequence corresponds to the maximum continuous load. Therefore, it is not necessary to analyze multiple time steps to address manually initiated loads.

Basis: Throughout.the DG automatic loading sequence, loads are added. All load shedding occurs prior to connecting the DG to the bus. The manual addition of other loads post accident is procedurally controlled and it is the responsibility of the Operator to ensure the DG rating is not exceeded (Ref..12.1.9 through 12.1.11, 12.1.13, 12.1.19, and 12.2.2). Therefore, this assumption is reasonable.

015-DC-r20.DOC Page 14 of 45

NUCLEAR POWER GENERATION CALCULATION TITLE: Diesel Generator Loading for 4160V Vital Buses Calc No. 9000037760 (015-DC) Rev. Part 20 / Version 0 Unit: 1/2 3.2.8 Cable and transformer losses are assumed to be 3.0percent of the DG continuous rating of 3250 kVA at a power factor of 34 percent.

Basis: Per Reference 12.1.7, LOCA Run 004, the losses associated with Load Center Transformer IF are 2.3 kW no-load plus 16.9 kW+58.5 kVAR under LOCA loading conditions. This yields 19.2 kW+58.5 kVAR for a typical 4.16 kV / 480 V transformer. The transformer losses alone (61.6 kVA) equal 1.9 percent of the DG rating. Per LOCA Run 010-LO, the overall power factor of the losses for the Class 1E distribution is 34 percent. A total loss of 3 percent, to account for cables losses in addition to the transformer yields 33.2 kW+91.7 kVAR per train. This assumption is considered conservative.

3.2.9 The alternate feed to loads equipped with manual transfer switches that are administratively controlled by procedure (Ref. 12.1.19) are assumed to be unloaded.

Basis: The normal plant alignment is the initial condition for this calculation.

Reference 12.1.19, besides identifying backup power supplies, also references other Operating Procedures applicable to the scheme. These procedures include precautions and limitations as, appropriate.

3.2.10 The spent fuel pit pump is assumed unloaded.

Basis: The spent fuel pit pump has momentary push-button controls with a seal-in contact. The contactor will drop out on the temporary loss of bus voltage during transfer to the DG and will require operator action to restart the pump.

Also, this load is not required for mitigation of postulated plant accidents. As such, this load is 'not considered to have an impact in the diesel generator loading (Ref. 12.1.34).

3.2.11 The hydrogen recombiner is assumed unloaded.

Basis: The hydrogen recombiner is manually controlled and is only used long after the initial LOCA. Electrical load would be significantly reduced at this time (Ref. 12.1.14). Therefore, this assumption is reasonable.

3.2.12 Containment hydrogen purge fans are assumed unloaded.

Basis: Containment hydrogen purge fans have spring return control switch with seal-in. The contactor will drop out on the temporary loss of bus voltage during transfer to the DG and will require operator action to start (Ref. 12.1.35).

Electrical load would be significantly reduced at this time (Ref. 12.1.14).

Therefore, this assumption is reasonable.

015-DC-r20.DOC Page 15 of 45

NUCLEAR POWER GENERATION CALCULATION TITLE: Diesel Generator Loading for 4160V Vital Buses Calc No. 9000037760 (015-DC) Rev. Part 20 / Version 0 Unit: 1/2 3.2.13 Backup Battery Chargers are assumed unloaded.

Basis: Reference 12.1.12, LCO 3.8.4 specifies that the 125 VDC buses shall be energized from its associated (normal) full-capacity charger. Surveillances are performed at least once per 7 days to assure proper alignment. Also, the time that more than one full-capacity charger can receive power from a single 480V vital bus is limited to 14 days. Therefore, the technical specifications provide assurance that only one battery charger will be connected to a single bus except during an abnormal operating condition and further limits the time that this condition can exist.

3.2.14 Load Center Transformer Fans are assumed not to be running.

Basis: The non-Class 1E transformer cooling fans are not assumed to not be available. The transformer is rated for 1000 kVA without the fans (Ref. 12.1.15, 12.1.16,12.1.17, 12.1.26, 12.1.27 and 12.1.28 ). Also see Acceptance Criterion 6.4. Therefore, this assumption is reasonable.

3.2.15 Spurious operation of non-Class 1E loads. powered from a DG supplied vital bus is not assumed to occur.

Basis: Non-Class 1E loads that may start due to balance-of-plant process signal demands (i.e. non-SI/LOOP) are already assumed to be operating. This assumption is reasonable.

3.2.16 The battery sizing calculations (Refs. 12.1.20 through 12.1.25) were used to determine the Battery Charger loading for operating Battery Chargers. The battery chargers are sized to recharge a fully discharged battery, supply the vital uninterruptible power supplies upon the loss of vital 480 Volts, and supply numerous DC control circuits. For the purpose of this calculation the vital uninterruptible power supplies are fed from the 480 Vac (i.e. not the charger) and the battery is fully charged in standby.

Basis: This calculation is based on the DG and associated buses being energized and operating; therefore, the vital uninterruptible power supplies are already accounted for with respect to DG loading. A failure within the DC system that results in a discharged battery would constitute the "Single Failure" which is equivalent to losing the entire train. Therefore, this assumption is reasonable.

015-DC-r20DOC Page 16 of 45

NUCLEAR POWER GENERATION CALCULATION TITLE: Diesel Generator Loading for 4160V Vital Buses Calc No. 9000037760 (015-DC) Rev. Part 20 / Version 0 Unit: 1/2 3.2.17 Motor power factor is assumed constant versus frequency within the 2 percent range of this calculation (See Attachment A).

Basis: Motor operation above nominal frequency actually results in a slight improvement in the motor power factor. This assumption is considered conservative.

3.2.18 Diesel engine rated torque is assumed constant within 2 percent of the rated speed. Since horsepower varies directly proportional to rotational speed, this facilitates correcting the DG mechanical rating for other than nominal frequencies.

Basis: Common engine analysis practice, per discussion with ALCO owner's group representative. Theriefore, this assumption is reasonable.

3.2.19 The brake horsepower loading of the Centrifugal Charging Pumps is assumed to increase 2 percent from the value determined in Reference 12.1.6.

Basis: Reference 12.1.6 does not address the losses associated with the speed increaser as described in Reference 12.1.29.

4.0 INPUTS 4.1 The load list for each bus shall be developed from the appropriate electrical single line diagram (Ref. 12.1.15, 12.1.16, 12.1.17, 12.1.26, 12.1.27, 12.1.28).

4.2 The mechanical brake horsepower load on electrical motors shall be from Reference 12.1.6.

4.3 The loading of non-rotating electrical equipment should be obtained from Reference 12.1.7. Other equipment specific drawings or other calculations may be used as appropriate.

4.4 Motor power factor and efficiency data should be obtained from Reference 12.1.7 or motor data sheets as applicable.

5.0 METHODOLOGY As previously stated, the purpose of this calculation is to demonstrate that each DG has sufficient capacity and margin to continuously supply the sum of the loads needed to be powered at any given time. The DG's automatically start and load in response to a loss (or degradation) of offsite power voltage. There are two automatic load sequencing schemes, if separation from the offsite power is the only initiator, the LOOP loading sequence is invoked. If a concurrent Safety Injection actuation signal is present, the LOCA loading sequence is invoked.

015-DC-r20.DOC Page 17 of 45

NUCLEAR POWER GENERATION CALCULATION TITLE: Diesel Generator Loading for 4160V Vital Buses Cale No. 9000037760 (015-DC) Rev. Part 20 / Version 0 Unit: 1/2 The FSAR Chapter 15 accident scenarios affected by the DG (i.e. assume loss of offsite power) are listed below.

5.1 Loss of Normal Feedwater: The motor driven AFW Pumps auto start as part of the LOOP DG loading sequence (FSAR Section 15.2.8).

5.2 LOOP (FSAR Section 15.2.9) 5.3 Small Break LOCA Coincident With a LOOP: A Small break LOCA does result in a SI actuation; however, the Containment Spray pumps are not started (FSAR Section 15.3.1).

5.4 Large Break LOCA Coincident With a LOOP (TSARSection 15.4.1) 5.5 Main Steam Line Break Coincident With a LOOP (PSAR Section 15.4.2) 5.6 Station Blackout (SBO): The term "Station Blackout" means the loss of both the offsite and onsite AC power sources. However, the DCPP SBO analysis credits one of the Class 1E DG's as an "Alternate AC" power source (Ref. 12.1.5, Section 1.2.2).

Except for the SBO scenario, Revision 19, and earlier, of this calculation was based on an implied assumption that the large break LOCA was the worst case loading scenario of any anticipated operational occurrence. This has been confirmed in" Reference 12.1.6 and is no longer an assumption of this calculation.

The SBO event is initially electrically the same as the LOOP event (i.e. no SI signal) with respect to the DG. However, if the DG associated with Bus H is functioning as the SBO "Alternate AC Source," then the associated Safety Injection (SI) Pump may be manually started during the SBO coping period. The Residual Heat Removal (RIIR) and Containment Spray (CSP) pumps are not required and would not start (Ref. 12.1.5). Additionally, the Centrifugal Charging Pumps (CCP) would be operating at a significantly reduced mechanical load (Ref. 12.1.29). Therefore, the large break LOCA coincident with a LOOP is the "worst case" and envelopes all the other scenarios listed above.

It is acknowledged that the mechanical demand on ECCS pumps varies with time, based primarily upon RCS pressure. However, the basic approach used to date has been to assume that all ECCS pumps are at maximum brake horsepower demand at the same time. The same is also true for all auxiliary support equipment that automatically connects to the DG.

The basic approach is to analyze each DG to determine the peak operating load of each piece of equipment that would automatically connect to the DG; sum the resultant kilowatts and kilovars; determine the associated power factor. The total kilowatts is then compared to the 2000 hour0.0231 days 0.556 hours 0.00331 weeks 7.61e-4 months per year rating and 30 minute per 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months rating of the DG set for operating and design margin, respectively. The overall power factor is compared to the generator 0.8 power factor rating.

015-DC-r20.DOC Page 18 of 45

NUCLEAR POWER GENERATION CALCULATION TITLE: Diesel Generator Loading for 4160V Vital Buses Calc No. 9000037760 (015-DC) Rev. Part 20 / Version 0 Unit: 1/2 5.7 Single Failure It is recognized that the single failure of a Class 1E component can impact the loading of redundant equipment, and thereby redundant DG's. To account for single failure, the following approach is used to determine the load factor of each load.

5.7.1 Redundant loads that share a common discharge fluid path shall all be running at a load level based on the minimum number of pumps necessary to achieve the safety function [e.g. total of three 50%' capacity parallel pumps are all running at a brake horsepower loading corresponding to two pump operation] (Ref. 12.1.6).

5.7.2 Redundant non-rotating loads (i.e. loads not in the scope of Reference 12.1.6) shall all be operating at the design basis load level corresponding to single component operation.

The following describes the application of this methodology in more detail and is applicable to all six DG's (i.e. three per unit).

5.8 Data Requirements 5.8.1 DG rating

a. Continuous

b. 2000 Hour per year

c. 30 Minute per 24 Hours 5.8.2 Connected Loads 5.8.3 Load Type (e.g. induction motor driven, heater, regulated electronic device such as battery charger or uninterruptible power supply) 5.8.4 Load Characteristics (e.g. rated load, maximum operating load, power factor, and efficiency) 5.9 Determine maximum LOCA/LOOP continuous loading for each DG bus.

5.9.1 Identify the worst case loading for each individual circuit.

5.9.2 Perform data analysis to determine the cumulative continuous loading of each DG in accordance with Tables 2 through 7:

015-DC-r20.DOC Page 19 of 45

NUCLEAR POWER GENERATION CALCULATION TITLE: Diesel Generator Loading for 4160V Vital Buses Calc No. 9000037760 (015-DC) Rev. Part 20 / Version 0 Unit: 1/2

a. Each DG supplies a single 4 kV vital bus and its corresponding 480 Volt load center. List each load, including nameplate rating (in horsepower or KVA as appropriate), efficiency and power factor as applicable.

b. For each load, compute the rated KW and KVAR steady state loading based on the nameplate data.

c. Identify the load type:

1. (R)otating for all motor driven loads. Motors are basically constant power devices for a given frequency. However, motors are susceptible to speed changes resulting from off-nominal DG frequency operation. The actual load placed on the DG by a motor should be increased based on the cube of the maximum per unit DG frequency (See Assumption 3.2.4).

2. (K)VA for all constant power non-rotating loads (e.g. electronic devices such as a battery charger).

3. (Z)impedance for all constant impedance loads (e.g. resistive heating). These devices are susceptible to power changes resulting from off-nominal DG voltage operation. An increase in voltage results in an increase in current, which in tum results in increased power. Therefore, the actual load placed on the DG by a constant impedance load should be increased based on the square of the maximum per unit DG voltage.

d. Review the control functions for each load and determine the applicable "Demand Category" for each scenario. The following "Demand Categories" are defined and each has an assumed diversity factor for the load (See Assumption 3.215).

1. (A)utomatic: Load is automatically connected to the bus. This can be via a loading sequencing signal, a signal initiated by the process associated with the connected load, or via a maintained "run" signal.

2. (P)rocedure / Manual: Load is procedurally required to be manually started.

3. (I)ntermittent: Load is automatically started, but has a definite on/off duty cycle and/or alternates with a redundant load.

015-DC-r20.DOC Page 20 of 45

NUCLEAR POWER GENERATION CALCULATION TITLE: Diesel Generator Loading for 4160V Vital Buses Calc No. 9000037760 (015-DC) Rev. Part 20 / Version 0 Unit: 1/2

4. (L)oad Shed: Load is automatically disconnected from the bus when the bus is aligned to the DG.

5. (M)omentary: Load that may automatically start, but for a very short period of time or limited duty cycle relative to the DG rating.

6. MO(V): Motor operated valve is a specific type of "Momentary" load.

e. For mechanical loads, enter the brake horsepower (bhp), if data is available; otherwise, enter the assumed loading factor.

f. Compute the actual KW and KVAR steady state loading based on the nameplate data and the scenario loading factor. Include worst case frequency or voltage correction factors as applicable. For loads susceptible to increases due to off nominal frequency operation, use a maximum frequency of 61.2 Hz (Ref. 12.1.12, SR 3.8.1.2 & 3.8.1.11). For loads susceptible to increases due to off nominal voltage operation, use a maximum DG voltage of 4,400 Volts (i.e. 110 %) (Ref. 12.1.12, SR 3.8.1.2

& 3.8.1.11).

g. Sum the KW and KVAR steady state loading for each bus. Compute the associated KVA and power factor.

h. Sum the KW and KVAR steady state loading of the 4 kV and 480 Volt buses to determine the DG loading. Compute the associated KVA and power factor.

i. Summary of equations used in Tables 2 through 7:

1. Conversion from HP to input KW/KVAR/KVA:

KW - (HP X0.746)

Eff KVAR = KW

Tan(Cos-1(Pf))

KVA = VKW 2 + KVAR 2

2. Conversion from KVA to KW:

KW=KVA*Pf 015-DC-r20.DOC Page 21 of 45

NUCLEAR POWER GENERATION CALCULATION TITLE: Diesel Generator Loading for 4160V Vital Buses Calc No. 9000037760 (015-DC) Rev. Part 20 / Version 0 Unit: 1/2

3. Demand factor:

Damand Factor bhp or - kVALad hPRated kVARated

4. Conversion of KWRatd to KWActual for rotating machines:

KWAC.,ld = KWRaed

Demand Factor* Diversity Factor

Frequency CorrectionFactor,

5. Conversion of KWated to KWActual for constant power devices:

KWA,0 t1 = KWRated

Demand Factor* Diversity Factor

6. Conversion of KWRated to KWActual for constant impedance devices:

KWAc,,al = KWRated

Demand Factor* Diversity Factor

Voltage CorrectionFactor

7. Determine the KW margin:

KWMARGIN - KWRated New Speed - Z KWAItual

8. Determine the KVAR margin based on ZKWActual:

If the ZKWACtuaI < KWpate then, limit the maximum KVAR based on the minimum generator power factor of 0.8.

KVARMARGIN Km l

Tan (Cos-'(0.8)))- Z KVARActual If the YKWActua1 > KWRated then, limit the maximum KVAR based on the constant kVA rating of the generator.

KVARMARGIN = KVAR.ted Sin Cos-, jKVAoue. I- KVARAc,, l 015-DC-r20 (2).DOC Page 22 of 45

NUCLEAR POWER GENERATION CALCULATION TITLE: Diesel Generator Loading for 4160V Vital Buses Calc No. 9000037760 (015-DC) Rev. Part 20 / Version 0 Unit: 1/2

9. Scaling the diesel engine rating for off-nominal speeds: The diesel engine ratings listed in Section 6.0 are based on operating at 60 Hz (i.e. 900 rpm). The available engine horsepower varies with engine speed. The specific relationship is:

i) hp

rpm 5252 Conservatively assuming that the engine speed torque curve is flat (i.e. constant torque) for operation near 60 Hz, a 2 percent speed increase will result in a 2 percent power increase for the same torque. (Note: In actuality, the engine speedtorque curve would be expected to have a slight positive slope at an engine speed corresponding to 60 Hz.). Therefore, for operation at frequencies other than 60 Hz, the following relationship can be used to correct the DG rating to the new base frequency:

ii) KWRated NewSpeed = K*Pý.ted 60 Hz

Hz 6 60.0

10. Frequency correction factor for rotating machines (i.e. pumps and fans):

Frequency CorrectionFactor= (fP.U. Ac,,,at

11. Voltage correction factor for constant impedance devices:

Voltage CorrectionFactor= (Vp.u. Acual

12. Combining 9-11, aboVe, yields the following generic formula to determine that the total DG load is within the rating at a given voltage and frequency:

kWco,1,, kVA+ Z (V'u )2 (kWcolst z @*00%v) + Z (f , )3(k Wm,,o,. @60Hz)) < (fpu )(kW1 .,ý @60Hz) 6.0 ACCEPTANCE CRITERIA 6.1 2000 Hour per Year Rating:

6.1.1 The generator rating is 3440 kVA at an 80 percent power factor (Ref. 12.1.3, Section 4.3.6.1).

015-DC-r20.DOC Page 23 of 45

NUCLEAR POWER GENERATION CALCULATION TITLE: Diesel Generator Loading for 4160V Vital Buses Calc No. 9000037760 (015-DC) Rev. Part 20 / Version 0 Unit: 1/2 6.1.2 The engine is rated for 2752 kW at the generator output (i.e. includes generator efficiency) at 60 Hz for up to 2000 hours0.0231 days 0.556 hours 0.00331 weeks 7.61e-4 months of operation per year (Ref. 12.1.3, Section 4.3.2).

6.2 30 Minute per 24 Hour Period Rating:

6.2.1 The generator rating is 4062.5 kVA at an 80 percent power factor (Ref. 12.1.3, Section 4.3.6.1).

6.2.2 The engine is rated for 3250 kW at the generator output (i.e. includes generator efficiency) at 60 Hz for up to 30 minutes of operation per 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period (Ref. 12.1.3, Section 4.3.2).

6.3 Based on the above individual component ratings, the diesel generator set steady state loading resulting from automatically connected loads shall not exceed 2752 KW 60 H Base and the power factor shall be greater than or equal to 80 percent. This load limit corresponds to the smaller of the 2000 hour0.0231 days 0.556 hours 0.00331 weeks 7.61e-4 months rating and 90 percent of the 30 minute rating.

6.4 The 4.16 kV / 480 V load center transformer loading shall be less than the self cooled 1000 kVA rating.

7.0 CALCULATION See the attached Tables 2 through 7 for DG operation at:

7.1 Nominal 7.1.1 60 Hz 7.1.2 100% Voltage 7.2 Technical Specification allowable frequency and maximum voltage (Ref. 12.1.12) 7.2.1 61.2 Hz

.7.2.2 110% Voltage 7.3 The results of this calculation may be used to justify surveillance endurance testing load levels. The purpose of an endurance test is to prove operation as close to design conditions as possible (Ref. 12.1.12 Bases SR3.8.1.14). However, caution must be used to preclude routine DG overloading. Since the endurance tests are performed with the DG paralleled to offsite power, operation at other than 60 Hz is not feasible. Therefore, the expected loading levels computed for operation at 61.2 Hz should not be used directly as the basis for surveillance test conditions.

015-DC-r20.DOC Page 24 of 45

NUCLEAR POWER GENERATION CALCULATION TITLE: Diesel Generator Loading for 4160V Vital Buses Calc No. 9000037760 (015-DC) Rev. Part 20/ Version 0 Unit: 1/2 Per equation 10 (Ref. Assumption 3.2.4), pump horsepower demands would increase by 6.12% (i.e. 1.02^3) for operation at 61.2 Hz. Increasing the test load by 6.12% at 601Hz would require a 6.12% torque increase (Ref. Equation 9(i)), potentially overloading the engine. Since for the same engine torque, the engine can produce 2% more horsepower at 61.2 Hz Versus 60.0 Hz, the actual load factor to be applied to the 60.0 Hz test condition would be:

61.2 Hz - 60.0 Hz C61.2

.,60.0Hz Hz )3 60.0 Hz -1.0412 Using equation 10 to convert the above 1.0412 load factor to an equivalent frequency yields:

fz= 11 3 1.0412

601 = 60.8Hz Therefore, evaluate DG operation (Tables 2 through 7) at the following conditions to support DG surveillance testing goals:

7.3.1 60.8 Hz 7.3.2 110% Voltage 7.4 The Control Room Ventilation and Pressurization System (i.e. Circuits 52-1F-55, 52-1H-55, 52-2F-61, and 52-2H-55) consists of numerous loads comprised of fans, compressor, heaters, and dampers (Ref. 12.1.30). Train A is typical of the four trains and is used to determine the over all demand factor per train.

Load Nominal kW Diversity Factor DG Load (kW)

OS-98 7.52 1.0 7.52 EH-27B 5.0 0.5 2.50 S-39 3.19 1.0 3.19 S-35 7.52 1.0 7.52 CR-35 8.19 0.5 4.10 CP-35 40.96 0.5 20.48 Total 72.4 45.3 015-DC-r20.DOC Page 25 of 45

NUCLEAR POWER GENERATION CALCULATION TITLE: Diesel Generator Loading for 4160V Vital Buses Calc No. 9000037760 (015-DC) Rev. Part 20 / Version 0 Unit: 1/2 A DG load of 45.3 kW / 72.4 kW yields an overall diversity factor of 63 percent.

7.5 The Diesel Generator Auxiliary Panels feed numerous loads comprised of compressors, pumps, and heaters (Ref. 12.1.31, 12.1.32, and 12.1.33). Demand factors are based on:

Load Nominal kW Diversity Panel A (kW) Panel B (kW)

Factor Diesel Start Air 13 1.0 13 13 Compressor (15hp)

Pre-Circ Lube Oil 3 0.0 0 --

Pp (3hp)

Diesel Turbo Air 13 1.0 -- 13 Compressor (15hp) -

Jacket Water Heater 9 0.0 0 ---

Lube Oil Heater 12 0.0 0 Control Pwr Xfmr 3 1.0 3 ---

Gen Space Heater 1.6 0.0 -- 0 Total Coincident / 16/40 26/27.6 Connected The demand factors are 40% and 95% for DG Auxiliary Panels A and B, respectively.

8.0 RESULTS Table 1 summarizes the results.

01 5-DC-r20.DOC P Page 26 of 45

NUCLEAR POWER GENERATION CALCULATION TITLE: Diesel Generator Loading for 4160V Vital Buses Calc No. 9000037760 (015-DC) Rev. Part 20 / Version 0 Unit: 1/2 Table 1: Worst Case Diesel Generator Loading Operating Margin Condition DG Load Pf Operating Design LC Xfmr

-Unit Bus DG Hz V(%) (kW) (%) kW % kW % kVA F 13 60.0 100% 2601 85.8% 151 5.5% 649 20.0% 747 61.2 110%, 2759 85.9% 48 1.7% 556 16.8% 793 60.8 110% 2707 85.9% 82 2.9% 587 17.8% 779 G 12 60.0 100% 2366 85.9% 386 14.0% 884 27.2% 614 61.2 110% 2506 86.0% 301 10.7% 809 24.4% 647 60.8 110% 2460 85.9% 329 11.8% 834 25.3% 636 H 11 60.0 100% 2504 87.4% 248 9.0% 746 23.0% 816 61.2 110% 2650 87.5% 157 5.6% 665 20.1% 859 60.8 110% 2602 87.5% 187 6.7% 692 21.0% 845 2 F 23 60.0 100% 2604 85.9% 148 5.4% 646 19.9% 746 61.2 110% 2762 86.0% 45 1.6% 553 16.7% 791 60.8 110% 2710 86.0% 79 2.8% 584 17.7% 777 G 21 60.0 100% 2358 85.9% 394 14.3% 892 27.5% 594 61.2 110% 2498 86.0% 309 11.0% 817 24.6% 626 60.8 110%. 2452 86.0% 337 12.1% 841 25.6% 616 H 22 60.0 100% 2473 87.5% 279 10.1% 777 23.9% 781 61.2 110% 2620 87.6% 188 6.7% 695 21.0% 823 60.8 110% 2572 87.6% 217 7.8% 721 ,21.9% 811 9.0 MARGIN ASSESSMENT 9.1 Operating Margin The operating limit is 2752 kW (at 60 Hz), which corresponds to the 2000 hour0.0231 days 0.556 hours 0.00331 weeks 7.61e-4 months per year DG rating. The ,results of this calculation indicate that the minimum operating margin at the expected DG operating condition of 60 Hz and 100 percent voltage is 148 kW (5.4%).

Should continuous operation at the maximum allowable frequency and voltage occur the worst case loading will still have positive margin (1.6%).

015-DC-r20 (2).DOC Page 27 of 45

NUCLEAR POWER GENERATION CALCULATION TITLE: Diesel Generator Loading for 4160V Vital Buses Cale No. 9000037760 (015-DC) Rev. Part 20 / Version 0 Unit: 1/2 The present day practice is to require a minimum operating margin of 5 percent, including frequency and voltage'variation impacts (Ref. 12.1.4). Although the minimum margin is not a DCPP requirement, it is achieved for expected operating conditions.

9.2 Design Margin The design limit is 3250 kW (at 60 Hz), which corresponds to the 30 minute per 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months DG rating. The results of this calculation indicate that the minimum operating margin at the expected DG operating condition of 60 Hz and 100 percent voltage is 646 kW (19.9%). Should operation at the maximum allowable frequency and voltage occur the worst case loading will still have positive margin (16.7%)..

10.0 CONCLUSION

S 10.1 The. maximum steady state expected loading of the Unit I and Unit 2 emergency DG's is within the capabilities and licensed limits as stated in Acceptance Criterion 6.3.

Additionally, consistent with present day practice, a minimum 5 percent margin is available. When the worst case (i.e. not expected) frequency and voltage tolerances (61.2 Hz and 110percent voltage respectively) are considered, compliance with Acceptance Criterion 6.3 is still achieved.

10.2 The worst case power factor is greater than the 0.8 generator rating as stated in Acceptance Criterion 6.3.

10.3 The load center 4.16kV/480V transformers are operating within their self-cooled rating of 1000 kVA as stated in Acceptance Criterion 6.4.

10.4 During the review of Order 60015038, the Table 2 through 7 results for the 60.8 Hz and 110% voltage condition should be used when considering the worst case loading for endurance testing purposes.

10.5 Technical Specification SR3.8.1.14 (Ref. 12.1.12) specifies the operating conditions for the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months endurance test. The first 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months are at a power level based on the DG 2 Hr per 24 Hr rating of 2860 kW. The remaining 22 hours2.546296e-4 days 0.00611 hours 3.637566e-5 weeks 8.371e-6 months of the test are at a power level based on the DG continuous rating of 2600 kW. This calculation is based on 2000 I-Hr per year rating of 2752 kW. If the same percentages as presently used to develop the T.S.

testing ranges (i.e. 2hrs @ 100-110% and 22hrs @ 90-100%) are applied to the 2752 kW rating, sufficient overlap exists to permit testing using the current ýT.S.

Additionally, the 2 Hr per 24 Hr rating of 2860 kW envelopes the worst case predicted loading including considerations for frequency and voltage variations (See Table 1

@60.8 Hz).

015-DC-r20.DOC Page 28 of 45

NUCLEAR POWER GENERATION CALCULATION TITLE: Diesel Generator Loading for 4160V Vital Buses Calc No. 9000037760 (015-DC) Rev. Part 20 / Version 0 Unit: 1/2 11.0 IMPACT EVALUATIONS 11.1 DCM's 11.1.1 DCM S-21, Diesel Engine System: Clarify that the DG rating is engine limited-as illustrated in Reference 12.3.4, Appendix 8.2. Correct the typographical error regarding the DG 30 minute kVA rating (i.e. 4062.5 kVA versus 462.5 kVA) in Section 4.3.6.1(c) (Notification 50248283).

11.1.2 DCM T-42, Station Blackout (Notification 50248284)

a. Delete reference to Calculation 125-DC as it is superseded by this calculation.

b. Revise Table 4.2-1 and the applicable sections that reference it. The objective is to move design basis, calculation inputs to Mechanical Calculation M-1 141 for configuration control. [e.g. Move individual pump SBO brake horsepower determinations to the calculation. Table 4.2-1 can list motor rated horsepower and SBO operating status (i.e. On/Off)]

11.1.3 DCM S-63, 4160V System: Delete reference to Calculation 125-DC as it is superseded by this calculation (Notification 50248285).

11.2 Procedures 11.2.1 STP M-9A, Diesel Engine Generator Routine Surveillance Test, Appendix 8.2 figure is not impacted by this calculation; however, the 0.8 Pf (power factor) line was observed to be in error. Also, it is recommended that the "Maximum Operating Limit" and "Normal Operating Limit" be defined in terms of DG rating. The allowable and abnormal areas of operation should be identified (Notification 50248286).

11.2.2 STP M-9M, Verification of Auto-Connected Loads Less than 2750 kW: Delete references to FSAR Tables 8.3-3, 8.3-5, and 8.3-7. For Unit 2, reference to Electrical Calculation 015-DC instead of 125-DC. As a minimum, the kW loading of individual loads should be reviewed and updated as appropriate.

However, it is recommended that this surveillance procedure be restructured to eliminate duplicate configuration control of load kW values (Notification 50248287).

11.2.3

EOP ECA-0.3, Restore 4 kV Buses: Update Appendix Q, Table 1, Equipment Loads, as appropriate. Revise Appendix Q, Figure 1, to distinguish between normal operating, design, and ultimate capability limits (Notification 50248288).

015-DC-r20.DOC Page 29 of 45

NUCLEAR POWER GENERATION CALCULATION TITLE: Diesel Generator Loading for 4160V Vital Buses Calc No. 9000037760 (015-DC) Rev. Part 20 / Version 0 Unit: 1/2 11.2.4 The impact of all DG surveillance test procedures is being coordinated through the DG System Engineer (Notification 50248289). It should be noted that the analytical results associated with operation at 61.2 Hz are not intended to define testing conditions. Worst case loading test conditions should be based on the 60.8 Hz and 110% voltage analytical results.

11.3 Calculations 11.3.1 Mechanical Calculation M-1 141, Maximum EDG Mechanical Loading: Update to include mechanical bhp loading for a Station Blackout Scenario. Include DCM T-42 revision under .same LBIE (Ref. 11.1.2). Also, delete Electrical Calculation 125-DC from the output reference list (Notification 50248350).

11.3.2 Mechanical Calculation M-786, EDG Fuel Oil Storage: Review Assumptions and Tables 2 through 7 for impacts on M-786 inputs (Notification 50248351).

11.4 Other 11.4.1 The results of this calculation may be used as input to resolve Order 60015038, Non-Conservative Tech Spec 3.8.1. It is stated in Operation 20 of the subject Order taht DCPP is committed to R.G. 1.9, Rev. 0, (Ref. 12.1.2) for steady state loading capability, which is the subject of this calculation. Revision 0 does not specify any steady state testing. Power factor was first introduced in Revision 3, which stipulated a power factor range of 0.8-0.9, which is the DCPP commitment for testing scope. Therefore, one could interpret the DCPP Tech Spec 0.87 power factor value as already conservative.

11.4.2 FSAR: Tables 8.3-3, 8.3-5, 8.3-6, and 8.3-7 are impacted by this calculation revision. Update accordingly (Notification 50248352).

12.0 REFERENCES

12.1 Input References 12.1.1 10 CFR Part 50, Appendix A, GDC-17, Electric Power Systems 12.1.2 NRC Regulatory Guide 1.9 / AEC Safety Guide 9, Selection of Diesel Generator Set Capacity for Standby Power Supplies, March 10, 1971 12.1.3 DCM S-21, Rev. 21A, Diesel Engine System 12.1.4 NRC Regulatory Guide 1.9, Rev. 4, Application and Testing of Safety Related Diesel Generators In Nuclear Power Plants 12.1.5 DCM T-42, Rev. 9, Station Blackout 015-DC-r2023OC Page 30 of 45

NUCLEAR POWER GENERATION CALCULATION TITLE: Diesel Generator Loading for 4160V Vital Buses Calc No. 9000037760 (015-DC) Rev. Part 20 / Version 0 Unit: 1/2 12.1.6 Calculation 9000040769 (M-1141), Rev. 0, Maximum EDG Mechanical Loading 12.1.7 Calculation 357A-DC, Rev. 12, Load Flow, Short Circuit, and Motor Starting 12.1.8 STP M-15, Rev. 42, Integrated Test of Engineered Safeguards and Diesel Generators 12.1.9 Emergency Procedure EOP E-0.1, Rev. 33/24, Reactor Trip Response 12.1.10 Emergency Procedure EOP E-1, Rev. 27/19, Loss of Reactor or Secondary Coolant 12.1.11 Emergency Procedure EOP E-1.1, Rev. 25/17A, SI Termination 12.1.12 T.S. 3.8.1, AC Sources Operating, Unit 1&2 Amendments 174 & 176 12.1.13 Operating Procedure OP A-4A:I, Rev. 25/18, Pressurizer - Make Available 12.1.14 Operating Procedure OP H-9, Rev. 10/6, Inside Containment H2 Recombination System 12.1.15 Single Line Drawing 437916, Rev. 45, Single Line Meter and Relay Diagram 480V System Bus 1F 12.1.16 Single Line Drawing 437542, Rev. 49, Single Line Meter and Relay Diagram 480V System Bus IG 12.1.17 Single Line Drawing 437543, Rev. 46, Single Line Meter and Relay Diagram 480V System Bus 1H 12.1.18 Operating Procedure OP H-5:11, Rev. 17/15, Control Room Ventilation System

- Alignment Verification 12.1.19 Operating Procedure OP 0-13, Rev. 26, transferring Equipment To/From Alternate Power Source 12.1.20 Calculation 235A-DC, Rev. 9, Battery 11 Sizing 12.1.21 Calculation 235B-DC, Rev. 9, Battery 12 Sizing 12.1.22 Calculation 235C-DC, Rev. 9, Battery 13 Sizing 12.1.23 Calculation 235D-DC, Rev. 9, Battery 21 Sizing 015-DC-r20.DOC Page 31 of 45

NUCLEAR POWER GENERATION CALCULATION TITLE: Diesel Generator Loading for 4160V Vital Buses Cal No. 9000037760 (015-DC) Rev. Part 20/Version 0 Unit: 1/2 12.1.24 Calculation 235E-DC, Rev. 9, Battery 22 Sizing 12.1.25 Calculation 235F-DC, Rev. 9, Battery 23 Sizing 12.1.26 Single Line Drawing 441237, Rev. 34, Single Line Meter and Relay Diagram 480V System Bus 2F 12.1.27 Single Line Drawing 441238, Rev. 42, Single Line Meter and Relay Diagram 480V System Bus 2G 12.1.28 Single Line Drawing 441239, Rev. 42, Single Line Meter and Relay Diagram 480V System Bus 2H 12.1.29 Calculation M-786, Rev. 16, EDG Fuel Oil Storage 12.1.30 Single Line Drawing 433130, Rev. 16, Single Line Diagram Control Room Pressurization System 12.1.31 Single Line Drawing 437674, Rev. 28, Single Line Diagram 4kV Diesel Generator Auxiliary Motors (Unit 1) 12.1.32 Single Line Drawing 441359, Rev. 20, Single Line Diagram 4kV Diesel Generator Auxiliary Motors (Unit 2) 12.1.33 Single Line Drawing 496282, Rev. 13, Single Line Diagram 4kV Diesel Generator 23 Auxiliary Motors 12.1.34 Schematic Diagram 437654, Rev. 14, Fuel transfer System 12.1.35 Schematic Diagram 448920, Rev. 13, Containment Hydrogen Purge and Monitor System 12.2 Output References 12.2.1 UFSAR Section 8.3, Onsite Power Systems 12.2.2 Emergency Procedure EOP ECA-0.3, Restore 4 kV Buses 12.2.3 STP M-9M, Verification of Auto-Connected Loads Less than 2750 kW 12.2.4 Mechanical Calculation M-786, EDG Fuel Oil Storage 015-DC-r20.DOC Page 32 of 45

NUCLEAR POWER GENERATION CALCULATION TITLE: Diesel Generator Loading for 4160V Vital Buses Calc No. 9000037760 (015-DC) Rev. Part 20 / Version 0 Unit: 1/2 12.3 Other 12.3.1 Temporary Instruction (TI), 2515/176, Emergency Diesel Generator Technical Specification Surveillance Requirements Regarding Endurance and Margin Testing 12.3.2 ACE Order 60010397, GreenNCV - EDG- Load Calcs vs Ch 15 12.3.3 IEEE 387-1995, Criteria for Diesel- Generator Units Applied as Standby Power Supplies for Nuclear Power Generating Stations 12.3.4 STP M-9A, Diesel Engine Generator Routine Surveillance Test 015-DC-r20.DOC Page 33 of 45

Table 2: DG 13 Unit 1 Bus F LOOPCoiocldentwiLhLOCA Nameplate Load Demand Mechnical Load Unite Efticency Power , Voltage Type Category Load, Load Demand 60.0 Ha 100%V 61.2 Ha 110% V 60.5Hz 110%V Rated Load KW (VAR KVA KW iVAR KVA KW KVAR KVA KW (000 Breaker ID Description ootes Rating (KVAIHP) (%) Facor(%) (RV) (RPJIZ) (AP/IJMNV/S) (bhp) Basis Factor(%)

Unrti 4.15VW BuoF 52-HF-08 ASP1 AmoSagwtaerPo 11 400 HP 02.7% 88.8% 4.00 R A 465 C 116% 274.2 193.8 421.4 397.1 205.6 447.2 389.4 201.6 438.5 321.9 166.7 52-HF-09 AFWP3 A. Foedwataer Pp 13 600 HP 95.5% 90.5% 4.00 R A 600 C 100% 468.7 220.3 517.9 497.4 233.8 549.0 487.7 229.2 538.9 468.7 220.3 52-HF-10 - Load'CenterXdnr8 CableLosses See Assumptaon3.2.8 3250 KVA 34.0% K A A 3% 33.2 91.7 97.5 33.2 91.7 97.5 33.2 91.7 97.5 1105.0 3056.4 52-HF-11 CCPI ChargingPp 11 See Assurnptlon3.2.10 600 HP 94.2% 90.5% 4.00 R A 650 C 108% 514.5 241.9 560.6 546.0 250.7 603.4 535.4 251.7 591.6 475.2 223.4 52-HF-12 CCWPI ComponentCoolingWalerPplo -- 400 HP 95.0% 59.0% 4.00 R A 425 C 106% 333.7 171.0 375.0 354.2 181.4 397.9 347.3 177.9 390.2 314.1 160.9 52-HF-15 SIPI Safety Irection Ppl I 400 OP 94.0% 90.4% 4.00 R. A 323 C 98% 311.0 147.5 345.0 331.0 106.5 326.1 324.5 153.5 359.0 317.4 150.1 Bus Total 20306 1060 2298 2159 1120 2430 21117 1106 2328.7 PowerFan/or 08.6% 88.7% 08.6%

U/nil1400V BaaP 52-IF-00 THF 480 Bus F LoadCenterXrmrFaon Se. Assumption3.2.14 3 KVA 90.0% 0.24 R A 0% 2.7 1.3 52-IF-01 CFC1-2 Cordatnment Fan Cooler12 100HP 81.4% 54.2% 0.45 R 103 C 103% 04.1 130.3 155.1 69.2 138.3 164.0 87.5 135.6 161.4 01.6 126.6 52-1F-02 CFCI-i ContainmlentFanCoolterl 100 HP 91.4% 54.2% 0.46 R 103 C 103% 64.1 130.3 155.1 89.2 130.3 164.6 67.5 .135.6 161.4 81.6 126.6 52-CF-04 E43 480VSwgrExhaustFan E43 so HP 93.4% 83.4% 0.46 R Sit NP 100% 39.9 26.4 47.9, 42.4 2R.0 50.8 41.6 27.5 40.0 39.0 26.4 52-1F-05 043 480VSwgrSupplyFan S43 50 HP 93.4% 83.4% 0.40 R 50 . NP 100% 39.9 26.4 47.9 42.4 20.0 50.8 41.6 27.5 49.8 39.9 26.4 52-1F-06 RHRSPI RHRSutmp Ppl I 1.5HP 78.0% 63.0% 0.48 R 1.5 NP 100% 0.7 0.9 1.1 0.0 0.6 1.2 0.7 0.9

1.2 1.4 1.8 52-IF-07 . 8107 Cold LegLoopChargrngVLVI 1 HP R 0%

52-1F-0H E-1 Am BldgExhaustFan E-1 150 HP 94.5% 8R.5% 0.46 R 160 C 107% 126.0 60.4 142.7 134.0 - 70.5 151.5 131.4 69.1 140.5 118.4 021 52-1F-OR CVCS-8106 ChargingPp 11112Recnhn Line I HP 0%

52-1F-10 Spare R 0%

52-IF-11 FCV-430 CCWHx1-1 Otalet HdrA 1.6 HP 0%

R 52-IF-12 LCV-112B VolContol Tank OutntVlvI 0.68 HP 0%

R 52-1F-13 i-1-1 Cota H2Purge SupplyFan 1-1 See Assumption3.2.12 7.5 HP 0%

52-1F-14 TG1i FW PplI TurningGear I HP 48A.0/ 55.0% 0.46 R 1 NP 100% 1.6 1.0 1.8 1.0 1.0 1.9 1.6 1.0 1.0 1.0 1.0 52-IF-15 RHRSP3 RHRBompPpl3 1.5 HP 78.0% 63.0% 0.46 R 1.5 NP 100% 0.7 0.9 1.1 0.6 0.9 1.2 0.7 0.0 1.2 1.4 1.6 52-1F-16 SI-BO61A ChargingInjec~on 3.2 HP R 0%

52-IF-17 Si-803A Charging tnjecaon 3.2 HP R 0%

52-1F-18 SI-8807A RHRDlseh To SI Pps 0.66 HP R 0%

52-IF-19 SI-88O6A RefuelingWaterSupplyI 1.33 HP R 0%

0%

52-1F-20 Spam i2-IF-21 Spare 0%

52-IF-22 FW-FCV-A41 S0G14 FW Isolaln 5.3 HIP R 0%

02-IF-23 CCW-FCV-750 RCP BarrierSeal CCWReturn 0.67 HP R 0%

52-iF-24 FW*-CV-40 S/G 11FW Isolation 5.3 HP R 0%

Not R 0%

52-1F-25 SFPPI Feed Spen Fel Pit Pp 11(Alt Sea Aoawrrpilen3.20. 100 HP 52-1F-20 Spare 0%

52-1F-27 TYBU Non-Vital InstrACBaeckup Rat .o0mr 15 KVA K 0%

52-lF-28 MPF28 DG12AuxPnll 32.5 KVA 85.0% 0.48 R C 95% 13.1 8.1 15.4 13.9 5.0 16.4 13.7 6.5 16.1 27.8 17.1 52-1F-29 Spare 0%

0%

52-iF-OS MS-FCV-35 Am FW Pp 11Steam Lead3 1.3 HP R 52- F-31 SI-R88O- RefUelingWaterTORHRSari 5.2 HP R 0%

52-1F SI-8974A Safety InjectonFPSReclmLire,To RWST 1 HP R 0%

52-1F-33 SFPP2 Feed FpeotFuelPit Pp 12(At See Assumption3.2.9 75 HP R 0%

52-IF-34 SW-i-H ASWPp,11 nlt Geta 1-8 4 HP R 0%

52-1F-35 CS-H992 Spray AdditiveTank olget 0.7 HP R 0%

52-1F-3 S-69 4kV SwgtrSupplyFan S5 1B HP 85.5% 786% 0.48 R 1.5 NP

100% 1.3 1.0 1.7 1.4 1.1 1.8 1.4 1:11- 1.7 1.3 1.0 52-1F-37 Spare 0%

15 HP 66.9% 89.6% 0.46 R 15 NP 100% 12.9 0.4 52-1F-38 PWMUP1 PdmaryMakeupWaterPpa l Page 34 of45 Ce. 9000037760(Copyotf015-DC-,20,ds)

Table 2: DG 13 Unit I Bus F LOOPCoincidentwMth LOCA Nameplate Load Demand Mechanical Load Units Efidency Power Voltage Type Category Load, Load Demand 60.0 Ho100%V B1.2HAf10% V 00.0 Ha 110%V RaledLoad Breaker IS Description RNotes atlrig (KVA/HP) (%) Fautor(%) (kV) (PJKWZ)

(AJP0IJMIVIS) (blop) Bas0s Facort(I%) KW KVAR KVA KW WVAR KVA NW KV69 (VA KW KWAR 52-IF-39 E-103 IntakeSion ASWPp 11 Exlaust Fan 1 HP 87.8% 85.0% 0.46 R A 1 NP 100% 60.8 0.5 1.0 0.9 0.n 1.1 0.9 0.5 1.0 0.6 0.6 52-IF-40 RCS-8000A PF RaelefVio 1-1 0.7 HP R V 0%

52-1F-41 SW-FCV-601 Unite1 & 2 ASWPump Croos-TIe 1 HP R V 0%

52-1F-42 E 11 BaetteyCharger11 70.0 KVA 94.6% 74.0% 0.48 K A C 20% 12.0 10.9 10.2 12.0 10.9 16.2 12.0 10.9 16.2 59.9 54.6 52-IF-43 Spare 0%

52-IF-44 CCWAPI CCWPp11Am LubeOil Pp 0.5 HP 72.3% 66.6% 0.46 R M 0.5 NP 100% 0.5 0.6 62-1F,-45 TRPI Rod Positon IndicatlonReg XfourTRPI 10 KVA 00.0% 0.48 Z A 100% 6.0 0,0 10.0 6.7 7.3 12.1 6.7 7.3 12.1 0.0 6.0 52-IF-40 S1-68808A AnUm InjecdonCold Loop 5.2 HP R V 0%

52-1F147 FP1. Fire Pp 0-1 See Assmpton3,2.15 200 HP 94.6% 09.9% 0.46 R A A 0% 157.7 76.8 52-1F-A4 SI-8002A SI Pp 11Dlscharge(HotLeg) 2 HP R V 0%

52-1F-49 01-8821A SI Pp I I Discharge(ColdLeg) 1 HP R V 0%

532-IF-50 BATP1 Bodc Add TransferPpl1 (FAST) 15 HP 09.4% 89.0% 0.40 R I 13 C 67% 5.4 2.8 6.1 5.6 2.e 6.5 5.6 2.9 0.3 12.5 8.4 52-1F-51 TRY12 InstrRag XfmrInvUPS 12 (Alt typass) Sao Assumpion 3.2.9 20 KVA 81.0% 80.0% K P C B0% 19.8 14.8 52-IF-52 ED131 BaStiryCharger131 SeeoAssotumdon3.2.13 76.6 KVA 64.6% 74.0% 0.48 K P A 0% 60.9 54.5 52-IF-53 Spare 0%

52-iF-54 FW-LCV-1131115AFWPp DischHdr Loev ControlSIG13 0.68 HP R V 0%

52-1F-55 " EPCE2 ControlRmVenllation"E"Tooln 60 KVA 60.0% 0.46 R A C 63% 45A4 22.0 50.4 48.1 23.3 53.5 47.2 22.9 52.4 72.0 34.9 52-7F-56 MPF56 DG13AoPrd A 47 KVA 85.0% 0.46 R I C 40% 8.0 5.0 9.4 8.5 5,3 10.0 8.3 5.2 9.6 40.0 24.8 62-1F-57 TRY1I InotrRfg XfStr unvUPS 12 (Bypass) 20 KVA 8140% 60.0% K A 0% 19.8 14.8 52-IF-U5 TH1A BoSe Add Heat T.e. 30 KVA 100.0% 0.21 Z I OP 46% 6.9 6.9 8.3 8.3 8.3 8.3 30.0 52-1F-59 Spom 0%

52-1F-60 AP1 ChargingPpll ArmLubeOIlOp 2 HP 71.1% 05.0% 0.46 R M 2 NP 100% 2.1 1.3 52-IF-St THSA BoricAdd Hear Trece 15 KVA 100.0% 0.48 Z I C 36% 3.2 3.2 3.9 3.9 3.6 3.9 18.0 52-1F-62 TRY14 fnstrRegXtrr Ilo UPS 14 (AltBypasrs) SeeAssumption 3.2.9 20 KVA 81.0% 60.0% K P C 80% 19.8 14.6 52-IF-63 Sf-8923A SI Pp 11 SuctonFrom RWST 1 HP R V 0%

52-1F-64 Spare 0%

52-iF-65 VAC-FCV-6-5 H2ReobnWrl o) t (Oa Conut) 0.67 HP R V 0%

52-1F-m66 E- FuelHandoing BldgExhaustFan Ek 75 HP 91.8% . 87.8% 0.46 R A 70 NP 100% 60.9 33.2 69.4 64.7 -35.3 73.7 63.4 34.6 72.2 60.0 33.2 52-1F-67 TSC Techrdoal Support CenterAltFeed SeeAssumption3.2.9 187 KVA 80.0% 0.48 K P C 71% 149.6 112.2 52-IF-68 IYii NuclearIn5ehniestUPS 11 20 KVA 57.2% 80.0% 0.48 K A C 80% 22.4 16.6 28.0 22.4 16.8 28.0 22.4 116. 26.0 28.0 21.0 52-rF-69 Spare

-- 0%

Bus Total 5065 489 747 600 516 793 000 00 7.79 Power Factor 75.6% 75.7% 75.7%

OGTotal 2601 1555 3030. 2759 1644 3211 2707 1614 3152 PowerFactor 85.8% Po-enFactor 85.9% Power Factor a5.9%

OperatingMargin 151 396 46 411 82 416 5.5% 1.7% 2.9%

DesignMargln 640 396 556 425 587 416 20.0% 16.8% 17.8%

Cale 9000037760(Copyof015-DC-r2O.xls) Page 35 of45

Table 3: DG 12 Unit 1 Bus G Nameletae Load Denand Mechacical Load Units Efficiency Power Voltage Type Category Load, Load Demand 60.0 Hz 100%V F1.2Hz110%e V 60.6 HN110%V Rated Load Breaker ID Dceocp"oo Notes Rating (KVAJHP) (%) Fentor(%) (WV) (RUKfZ) (AIPVLIMNNIS)(bhp) Basls Factor(%) KW BUAR KVA KO WKVABVy W KW WAR KVA KW KVAR Untie I4.11kVusG d45* C i1o% 374.2 193., 421.4 397.1 205.6 447.2 380.4 201.n 430.6 321.9 166.7 52o-k-OB ASP2 AonSaItwater Pp 12 400 HIP 92.7% 00.0% 4.00 R. A 109%

524HG-O7 CSPI Containent sprayPp 10 400HP 9.4% 60.9% 4.00 R A 435 C 347.4 159.3 3820 361.7 109.1 405.0 361.5- 165.0 307.7 310.0 1400 52-HC--M RHRPI PolutantHeat Removl Pp yl 40BHP 93.7% 93.5% 4.00 R A 410 C 103% 320.4 123.8 349.1 346.4 1314 370.6 339.7 120.8 363.3 310.5 120.6 52-HG.S2 CCP2 SeeAssumption 32161 000HP 94.2% 90.5% 4.00 R A 650 C 108% 14.6 2410.0 500.6 540.0 000.7 603.4 cONA4 261.7 501.0 4702. 223.4 otargingPp 12 52-HG-11310 3260KVA LoadCenterMnma & Cabletosses SeaAssumption 3.20. 34.0% K A A 3%

70% 33.2 91.7 97.0 332 01.7 97.5 33.2 91.7 07.0 1106.0 3050.4 52-HC-11 CCP3 Boo0HP 471.2 199.3 Charging Pp 13 95.0% c2.1% 4.00 R L 434 C 72%

n 52-HG-12 C 106%

Component CoolingWaterPp 12 400 HP 95.0% 89.0% 4.00 R A 425 333.7 171.0 375O 35,.2

181.4 397.0 347.3 177.0 390.2 314.1 M10.6 1930 601 2165 2046 1038 2293 2DO6 Iola 225O SunTotal PowerFactor 0 89% 09%

4802VuS G Unitne 52-IG-00 THm 480Bus GLoadcenter Xfmr Fae Seet.ssumduo3.2014 3 KVA 00.0% 0.40 R A A 0% 2.7 13 CFCI-3 Containment Fan Cocier13 100HP 91.4% 04.2% 0.46 R A 103 C 103% "4.0 13D.3 155.1 89.2 038.3 104e5 87.5 036.0 161.4 01.6 126.6 52o-ee-o 52-1G0*2 CFC1-5 Contninment Fan Coo.In15 O1.4% 54.2% 0.46 R A 103 C 103% 94.4 130.3 15.1 896.2 036.3 104.6 87e. 13,8 101.4 81.6 120.6 5c-n1-04 OATP2 Baltic AcidTeneferPp 12(FAST) 106HP 09.4% 89.0% 0.40 R - 13 C 60% 5.4 2.8 6.1 0.8 2.9 0.5 5.6 2.0 . 6.3 1206 6.4 52-10-060 S"8B080 Accum14tnjet Conild Loop4 0.2HP R V RHRIumpPp 52 1.5Hip 780% 63.0% 040 R I i's NP 100% 0.7 . 0.9 1.1 0.0 0.0 1.2 0.7 0.6 1.2 0.4 1.8" 52-10-00 RHRSP2 52-1",7 SI-88011B Acue 12InjecttoColdLoop2 5.2HP R V 0%

152-1G,08 BOPAC1 R A S0 NP 100% 48.0 30.2 07.4 51.7 32.1 60.0 00.7 31.4 69.7 48.8 30.2 TGBeSting 00 Pp o HeP 91.6% n5.0% 0.46 lO%

g52-1-0o CVCS-0o60 CHG Pp I and2 Minow Vl 2 I HIP R V 0%

52g-10-n CVCS-8108 Normal CHGtoRegan,HdSeop%W2 I HP R V 52-ne-11 LCV-112C Volume Ctnot TankOugte VI, 2 0.67 HIP R V 0%

82-1G-12 Sl-8609A RHRInject toLoops nend2 Hti Leg 0.2HIP R V 0%

Gig electOuget Viv2 3.2HP R V 0%

O2-1G-13 nt Si-aol 52-no-14 St-MOON V0v2 1.33HIP R V MgPp RekfelWaterSupply 0%

c2-nG-15 RHR-8tO- A RHRPp IISuctionV, 1.6HIP R V 1.2HW 0o%

co2-s-1n St-004A RHRDcihnargetoChgPp R V D%

10%

62-1G-17 III 25HIP 07.8% 83.1% 0.48 R A 25 C 21.2 14.2 25.0 225 10.1 27.1 22.1 14.8 2tB0 21.2 14.2 SupplyFan Sn FuelHandling Bldg.

1,5HP l00%

52-1ne-1 RHRFPP4 RHRSumnn Pp 14 78.0% 63.0% 0.46 R I 1.5 NP 0.7 0.0 1.1 0.6 0.9 12 0.7 0.6 1.2 1.4 1.a 52-ne-1n Spae 0%

52HIP 5n-nG-20 Spree 0%

2 HP c2-ne-21 CS-y001A SprayPp enDischargeStopMtvI R U 0%

52-1G-22 EH20 54 KVA z P 64.0 Charcoal FalterPretteter 100.0% 0.48 100%

52-0--23 FCV-303 RCPCooting Wta.e Retuon Io. ii 2 0.13HIP V 0%

RR V 52-no-24 SI-0835 0I PpDichargaColdLeg 0%

2.6HP R V 52-1C--25 RHR-8701 RHRSuctioninanLoop4 HatL.0 V!, 2 0%

52-10-2o CvCS-oniO RCPSeatWaie(,Flte rtnoN I 0.67 HP R UV 0%

52-1G.21 FI-603B Charginglec SupplyVt, 2 3.2HIP R V 0%

1.6HP U 52-nG-t2 FCV-431 CCOW Ht Oulei W.e R AV 0%.

52-ne-29 FCV-641A RHRPp II RectcVIc 0.7HIP 0%

52-10-80 TLE11 Ecergency -11n Mar TLE1 o 25KVA 00.0% ' 0.48 K C 50% 10.0 7.0 12.5 00.0 7.5 125 101.0 7.5 12.0 00.0 1S.0 4 KVA 00,0% 0.45 R 52-ne-3n hIPGon DGI2 A. PniA C 400,% 6.0 5.0 9.4 8.5 0.3 10.0 23 5.2 - 9.0 401 24.8 520-nG32 BATHAH BoWe AcidTank12HeaterA 7.5KVA 100,0% OA4S z No 100% 3z 3.0 4.5 4.6 40 4.0 7.,5 2o1-n-34 Spen - - 0%

62-10-35 M2 NuclearIstument UPS12 B 20 KVA 7.2% -0.0% 0.48 K A C 50% 22.4 1.8 28.0 22.4 16.8 2t.0 22.4 16.8 2080 .0 0 21.0 52-no-3g FCV-355 RCPCamp ConlngWaterSupply Viv 0.13 tIp R V 0%

52-ne-37 TRY13 tIncRegXtnoInvUPS13(AltBypass) OeaAssumption 3.20. 20KVA 81.0% 80.0% O.4o K P C 0% 19.8 14.8 52-1G-38 TLE18 EmraencyUghoInXfc TLE1B 20 KVA 80.0% 0.40 K A C 60% 12.0 S0 15.0 12.0 6I0 00 1200.0 0 15.0 00.0 15.-

- 5c-3n Ryns Containment RadMonilcPp RYI o no HP 07.8% 6 85.0% R 0.46 A 1.0 NP 100% 1.3 0.8 1.5 1.4 0.8 1.8 0.3 0.6 " 1.3 0.6 52c-n-40 DFOTP2 OiesalFuelTransferPp 2 (AitFeed) SeeAs.u..poon 302. o HP 01,0% 600.% 0.46 R P 0 NP 100% 4.6 2.0 c2-Ie-1 CCWAP2 CCWAucoLubeOitPp1-2 0.6HP 7.3% 60.6% 0.40 R M I0t Np 100% 0.0 0.0 52-10G42 ED12 cattery Charger12 7.0 BUA 04.0% 74.0/ 0.48 K A A 20% 12.0 10.0 16.2 12.0 10.0 16.2 10. 10B 16.2 0g.0 64.0 5241043 Ty11 nvaderBackupX vy WJI 7.5KVA 00.0% 0.40 K P 0% 6.0 44 Colc9000037760(Copy of015*DC.OgaS) P99436,1415

Table 3: DG 12 Unit I Bus G LOOPColincident WO,LOCA Nameplate Lead Darid Mechanical Load U55W Efgdany Poer Voltage Type Category Load, Lead Demand 60.0 He 100% V 61.2Mc110%V 60.8H. 110D%V Rate Load Breaker ID Descdpfln Nal,, Raf]tg (K<VA1HP) 11 Falctor

(%1) (kV) (621111(AJpIISLMU S) (bhp) Earle Fedor((%) lW WAR KVA KW WVAR KVA KW WAR KVA KW W-AR 6210G44 i LCV-108 IGAFWSupply VSl11 0.33HP R V 0%

52-1G-45 5HR.8716A RHRHs 1I to ROBLoopI &Z HolLeg 0.3 HP R V 0%

02-10-46 RCS--00B Pressurzer PowerRealf Vly2 0.7HP R V 0%

52-1G047 FCV-439 SIG1-2FW SolVlu 53 HP R V 0%

52-1G-48 CB-9003A RHRPp II ToSpty Hdr,153 3.2HP R V 0%

62-1G-49 Spare 0%

52-10-50 TH2A Bue AcidHealTruceXfmrTH2A 110.0%

30 KVA CAB Z I OP 22% 3.3 3.3 4C 4.0 4.0 4.0 20.0 52-10-51 AT14AI BodrAdd Tack11HaslerA 7.5 KVA 100.0% DAB Z I NP 600% 3.8 3.8 4.5 4.5 4.5 4.5 7.6 52-1G-52 PWMUP2 PimaryWalerMakeUpPp 12 15 HP 8669% 09.6% DAB R I 15 NP 100% 6.4 3.0 7.2 6.B 3.4 7.6 6.7 3.5 7.5 12.9 6.4 52-1G-53 S1-2 CurlH2Purge Sys. SupplyFai12 3.2.12 Sue AssampUon 7.5 HP 85.5% 09.0% 0D46 P 0% .S 3.4 52-10-54 SW-1-g ASWPp 12Gate Operalor10 4 HP R V 0%

52:10-55 cS-8S94A SprayAddRgea TarkTK u0a.VWb 1 07 HP R V 0%

52-1G-56 R5R-8703 RHRReck ,oCdd Loop3 & 4 5.3 HP R V 0%

52-G-57 CVCS0-1I4 Errurger y BOuteVSi 0.7 HP R v 0%

62-10-5 SI-6O52A Crt R0dmSuurrpOdut VIv I 5.3 HP R V 0%

52-10-59 MIJVTP2 MakeUpWaterTlraner Pp 2 30 HP e.5% 86.0% 0.4A R A 31 C 103% 28.7 15.8 31.1 25.4 16.8 33.0 27.8 16.6 32.3 25.8 15.4 52-10-50 E-101 ASWPp 12VaultBehcat FanE-101 1 HP 57.8% 85,O% 0.40 R A 1 NP 105% 0.8 0.5 1.0 0.9 0.5 1.1 .0.6 0.5 1.0 0.A 0.5 52-1G041 lY1i. Iustrum Traisforerr T18 1tA 15 85.0% 0.48 K A C 57% 7.3 4.5 8.6 7.3 4.5 8,6 7.3 4.5 8.6 12.0 7.9 52-0-DO2 MPG62 DO13A.UPri B 32.5 KVA 55.0% 0.48 R f C 95% 130. 5,1 185.4 13e9 a.s 1114 13.7 0,5 - 18.1 27.8 17.1 52-10-63 568 4Kv gal Bus0 Supply Fan SS0 1.5HP 84.0% 70.0% 0D4A R A 1.5 NP 100% 1.3 1.1 1.5 1.4 1.2 1.9 1.4 1.2 1.8 1.3 1.1 62-10.84 AP2 ChgPp 12A. Lutd GOPp 2 HP 71.1% 85.0% 0.46 R M 2 NP 120% 2.1 1.3 52-1G-65 S3 SupplyFPe 331Aux.Bldg 60 HP 91.8% 55.0% 0.48 R A 60 NP 100% 46.8 30.2 57.4 61.7 32.1 80.9 50.7 31.4 09.7 48.8 301 52-10-66 SFPPI Spot FuelPhe PplI Ge.Assuaplgon 3.10 100HP 9221% 90B5% 0.46 R P 90 C 9O% 1I1. 38.1 52-19-87 ERS-1 icerral H2RecobdlnerSys Grouep I SeeAsumoplair 3.-11 75 4VA 100.0% DAB Z P 0% 75.0 52-1G,-00 LCV-1O7 BIG 12AFWSupplyValva 0.33HP R V 0%

52-10-69 LCV-100 SfG13AFWSupplyValve 0.33 HP R V 0%

52-1G-70 LCV-1O9 SfG14AFWSupplyVaSle 0133HP R V 0%

52-10-72 EPPH12 PrissurizerHit Groap12 AftSupply So. Assumpl~o.

32.2 483 KVA 100.0% 046 Z P OP 95% 483.0 52-1G-73 FCV-650 E H2 0 Racomblr CHPS1-2led V1, 0.671HP R V 0%

52-1G-74 CEC13O'rO21SCarlalamn H2 Marur Parl P 210 3 KVA 85.0% D,4A Z I NP 85% 1.1 0.7 1.3 1.3 B.B 15 1.3 0.8 1s 2.6 1.8 52-rC-70 TPRM1I RadadanMoueltra OyeXf06r I 15 KVA 80.0% 0A48 K A C 80% 95. 72 12.0 6.4 7.2 12.0 9.6 7.2 12.0 12.0 8.0 52-1G-78 RM5-120 RadaaonMorgtoring Sys Xfmr(Future) 7.54KVA 5.0% . 0.48 K - 0% ' 64 4.0 52-1G-77 EPC32 Cudrcol Ru VarrtaosrrE"Trakr All. SeeAssumpuowi 3.2.9 62 KVA 0.0% 0.4 R P A 63% 72.0 34.9 52-1G-78 TRY12 Ir RuOXep hk UPS12(Bype,) 20 KVA 81.0% 50.0% 0.48 K A C 0% 19.8 14.8 52-1G-79 TRYlI sItb-RegXfaIv UPS11(ANBypas) See Asumpe 3.2.9 20KVA 81.0% 80.0% 0A6 K p C 60% 19.6 14.8 BusToral 437 431 014 461 454 547 453 446 636 Pow-rFast. 71.2% 71.2% 71.3%

DGTotl 0230 1412 2756 2506 1495 2916 2460 1464 2052 PowerFactor 85.9% PowerFacior 66.0% Powr Factor 85.9%

OpemUag Margin 320 362 301 390 329 381 14.0% 10.7% 11.8%

Gastr Margin 664 320 0g8 300 634 351 2720% 24.4% 25.3%

Coal9000037760 (Copyolf 15-DC-r20,la) Page 37 of46

Table 4: G11 Unit I Bus H LOOPConsndentvdthLOCA Nameplate Load Demand Medtraniat Load Units Etolaency Power Voltage Type Categoty Load, Load Demand 60.0Hf 100% V 61.2 Hc110%V 60.8Ho110%V RatedLoad BreK- 1D Deacdpa Notes Rationg 9 V.1P) (%.) Factor(%) jkV) 60WZ)(AtPILdJMNIt) (bhp) Bases Factor(.) KW KVAR KVA K0 KVAR KVA KW KVAR KVA 6W 60AR 11.111-1.61, oa 02-HO-os AFWP2 Ae Feedwarter Pp 12 500HP 95.6% 90.0% 4.00 R A 6000 C 100% 4680.7 220.3 517.0 497.4 233.8 549.6 407.7 U29.2 53a.0 468.7 220.3 CoalalnmerlSprayPp 12 400 HP 93.4% 00.9% 4.00 R A 440 C 110% 351A 101.1 386.6 272.9 171.0 410.2 269.7 167.7 402.3 319.5 1465 52-H-I09 CSP2 K A A 52-HH-10 THH LoadCarler Xmr& CablaL .ases SaeAssapona 3.2.8 3250 KVA 34.0% 3% 33,2 61.7 97.5 33.2 91.7 97.5 33.2 61.7 97.0 1109.0 3006.4 52-HH-11 RHRP2 Rertduoe 400 HP 93.6% 93.4% A 424 C 10N. 337.0 129.3 361.5 350.6 137.0 384.0 351.6 134,5 376.6 318.8. 121.8 HeatRemoal Pp 12 4.00 R A C 62-HH-12 CCWP3 Comnepn.rt Cocng WaterPp 13 400 HP 95.D% 69.0% 425 108% 333.7 171.0 375.0 354.2 161.0 307.9 347.3 177.9 2092. 314.1 160.9 40.0 R A 303 C 345.0 331.0 156.5 . 360.1 324.5 153.5 358.0 317.4 150.1 52-HH-15 SIP2 SafetyhIjatlonPp 12 400 HP 94.0% 90.4% 9B% (311.9 147.5 BuoToot 18037 921 2055 1847 972 2176 1910 605 2135 P-werFactor 89% 68% 89%

Soft1400V BusH 52-iH.00 TIS-TH1H0 480Bus H Loedcenter Xfl Fare Sea Aoeruplon32.14 3 KVA 90.0% 0.24 R A A." 0% 2.7 1.0 100 HP 52-1H01 CFCI- Contolanment F Cocto 14 91.4% 54.2% 0.48 R A 103 C 103% 84.1 130.3 1S5.1 89.2 136.2 164.8 87.5 135.8 161.4 61.8 126.6 52-11-13 FP2 FirePp0-2 See AssumpOor32.15 200HP 94.6% 89.6% 0.48 R A A 0% 157.7 76.8 52-1H604 E44 4800VSwgrExhaustFan044 so HIP 93.4% 83.4% 0.46 R A 50 NP 100% 39.9 26.4 47.0 42.4 28.0 50.8 41.c 27.6 49.8 20. 206.4 52-10-05 MUWnoI MakeUpWaterTransferPp 01 30 HP 865.% B6.0% 0.46 R A 31 C 103% 20.7 10.9 31.1 28.4 18.6 33.0 27.8 1I.5 22.2 26.0 15.4 52.1H-06 0S-9003B R1R PP 12toSprayHDR62 &4 3.3 HP R V 0%

52-1H-07 8-44 Ao BldgSwtchgr.Rre.Supply Fan 6844 OHOP MA.4% 83.4% 0.46 R A 50 NP 100% 20.8 26.4 47.0 42.4 25.0 60.0 41.8 27.5 49.8 39.9 06.4 52-1H-08 S-2 FH9Supply Fan S-2 25 HP 07.8% 83.1% 0.46 R A 25 NP 100% 21.2 14.2 25.6 22.5 15.1 27.1 22.1 14.0 26.6 21.2 14.2 82-1H-09 Spara .- -0%

60-1H-10 T12 FWPP 12Turning Bear I HP 58.0% 00.0% 0.48 R A 1 NP 100% 1.3 0.8 1.6 1.4 0.8 1.6 1.3 048 1.6 1.2 0.6 52-110-11 0-0001B SprayPP 12Dlsch StopMY I 2 HP R 0 0%

52-10-na2 61-89820 C.1 RooksSumpDOutlMY2 6.3 HP R 0 0%

2-1H-13 Spar S

- 0%

52-1H-14 S1-80008C Acourn ll.e.[ to Cold 13 Loop3 .2HP R V 0%

62-1H-15. FCV-0418 RHRPP 12RleoiMc 0.7 HP R V 0%

62-1H-16 FCV-355 CDp Cootlng HeaderC sOlcdon VIM I HP R V 0%

02-10-17 FCV-357 RC0BerderCOWRoto . 0.7HP R V 0%

50-16-18 FCV-749 RCPBearfing OilCoo0ng ReturnMY1 0.26 HP R V 0%

002.1-19 RHR-6702 RHRSuction oroe Loop4 HotLeg 0 I1 2.60HP R V 0%

52-1H-20 S1-8976 SlopSauconfromRefuelWaler 1.2 HP R V 0%

02-10-26 Spaca 0%

52-1H-22 TLE13 EmergencyLtg.Dorr.TLE61 376 K'VA 80.0% 0.40 K A OP 101% 30.3 22.7 37.9 30.3 22.7 27.9 30.2 22.7 37.0 30.0 22.5 52-1H-23 MPH23 DelI A- PndA 47 KVA 05.0% 0.48 R I O 40% 6.0 5.3 9.4 8B. 5.2 10.0 0.3 5.2 0.8 40.0 24.8 52-10-24 S-32 AO BldgS*pplyFon S-32 60 HP 09.3% 80.0% 0.48 R A 60 No 100% 50.1 31.1 59.0 532 33.0 62.6 02.2 32.3 61.4 50.1 31.1 62-16-25 S08048 RHRAX12ItoS Pi Sudon 3.2 Hp R V 0%

52-16-25 91-8302B S6PP 12DlidtargeHo0Leg 2HP R V 0%

52-1H-27 CVCS9-112 RCPSeal WaterRoe, Isolodon 2 VMY 0.608HP R V 0%

02-1H-26 FCV-440 Maeem Gen 13FW n IsolOn VIa 8.3HP V 0%

RR 52-1H-28 P-HR-7196 R4X12to RCLoopI A 2 HotLeg 6.3HP V 0%

R 62-1H-30 FCV-37 AFWTurbinelI Lead2SteamoSpplylo 1.3HP R V 0%

52-1H-31 S1.08210 SI Pp12 DiscrhrgeColdLegLoop I HP R V 0%

52-1H-32, 08"8075 RHRDiactergeto81Pp 0.67HP V G%

R 52-1H-33 RCS08000C PresurederPowerReflol MYo 13 0.7HP V 0%

02-1-H34 ED132 BatteryCharger132 76.6 0/A 94,6% 74.0% 0.48 K C 20% 12.0 10.9 19.2 12.0 10.9 16.2 12.0 10.9 16.2 509.0 4.0 02-10-25 EHRS-2 Internal H2 Raromblners 75 KV.A lOO.0% 0.48 z H SysGrop 2 See Assompon3.2.11 100% 70.0 52-10H-3 CCWAP3 CCWPP 13AuxLubeCA Pp 0.6 Hp 70.0% 58.6% 0G4G R M 0.0 NP 100% 0.5 0.8 62-1H-37 0-67 V0414KVSoIlohgeerBooH Supply Fan 1.6HP 85.5% 77.0% 0.48 R A 1.5 No 100% 1.3 1.1 1.7 1.4 1.2 1.5 14 1.1 1.8 1.3 1.1 52-1H-39 TLE15 Emergency LUS.Xfar.*LIE5 25 KVA 80.0% 0.48 K 0 45% 8.0 6, . 11.3 9.0 8.9 11.3 9.0 056 11.2 20.0 16.0 62-1H-40 Cs0B904B SprayAddlJoe TankOutletMYIo 2 R 0.7 HP V 0%

50-1041 FCV0495 ASWPp 12CmsrUoeaVl 1 HP R 0%

V FCV*490 ASWPp11 CD eoeVOY 1 HP R 0%

92-1H-42 V 52-10-43 RH6-67000 RHRPp 12SuctonVIa 1.6 HP R 0%

V 02-10-44 S1-80749 SlPp ReclncStopMla 1 HP R 0%

Ca0e90D0037760(Copyol015-00-20,sts) Page00of45

Table 4: DG 11 Unit 1 Bus H Narneate Load Deannsd Mtehralral 80.0HzI00%V Load Unite Load Demand EIfdneery P-er Voltage Type Category Load. 61.2HN110%V O.8 Hz 110%V RatedLoad Break.er ID OeadrpiUon Notes Ratng (KVAtHP) (%) Factor(%) 5kV6 (R0,Z) (A/PP IS) )lrhp) Basts Fater (%) KW 8AR KVA KW 85AR 88A KW 0AR KVA KW 885 52-1HU-45 S-f8OOB RHRinjet toLoop3 5 4 HotLeg 52 UP 0%

62-1H-46 Spree 0%

7BHP 92.0% 90.0% 0.40 R P 75 C 100% 61.8 28.8 62-11-47 SFPP12 SpentFuelPit Pp 12 See Assumprton 3.2.10 150 HP 02.1% 90.5% 0.40 R A 160 C 107% 123.6 0.9 143.2 137.5 54.8 162.0 134.9 63A 149.0 121.5 57.1 02-1H-48 E-2 OverallExhaustFan E-2 32.5 KVA 85.0% 0.48 N I C 95% 13.1. 0.1 15.4 13.9 8.6 18.4 13.7 8.5 16.1 27.6 17.1 52-1H-49 MPH40 DG3 AHu P.I B 20KVA 81.0% 80.0% 0.48 K A C 0% 19.8 14.8 62-1H-5O TRY14 ]nsarRepXfmrInvUPS14(Bypass)

See.Agurpton 3.2.12 7.5 HP P 7.6 NP 100% 8.8 4.1 62-1U-51 EI-2 ContalroentH2Purge EnhFan 1-2 "4.5% 08.0% 0.A6 R

21H-52 s Spar- 0%

30 KVA 0.4B Z I O 40% 0.0 9.8 7.3 7.3 7.3 7.3 30.0 52-lH-64 THIU BorcAidHeatTraoeltenrlHtr 100.0%

00 KVA 90.0% 0.4C R A O 63% 45.4 22U 15.4 48.1 23.3 00.5 47.2 22.9 52A 7.0 35.8 52-1H-S5 EPCH2 Cenot Re VenSl00n HATrai 81.0% W0.0% 0.48 K A C 0% 19.8 14.8 62-1H-58 TRY13 ltstr RegXfnntIn, UPS13(Bypass) 20KWA 52-1H-57 Spare 0%

7.5 KVA I00.0% 0.48 z I NP 115% 3.8 3.8 4.5 4.5 4.8 4.5 7.5 52-11-58 BATH82 BodoAddTanr 12HeaterB 7.5 ]8VA 100.0% GAB Z "1 NP 100% 3.8 3.8 4.5 4.5 4.9 4.6

7.5 62-11-59 BATHBI BoSalAcidTard 11Heate.

Sen AsuerpUon32-13 76.6 8VA 94.6% 74.0% 0.48 K P C 20% 59.9 54.5 52-1H6-0 ED121 BatteryCharger121 20KVA 57.2% 80.0% 0.4B K A 80% 22.4 18.6 28.0 22.4 18.8 28.0 nA 18. 28.0 28.0 21.0 62-1H-61 014 Nuclearrnsim-itrt UPS14 52-18-62 LCV-110111 BIG i1 &12AFHW Supply Vaeles 0.6 HP R V 0%

30 KVA 0.48 Z I C 24% 3.6 310 4.4 4.4 4.4 4A 30.0 52-11-63 TH2B BoricAcidHeetTrsacXfmrrTH2B 100.0%

52-1H-64 Spare 0%

5.UHP 81.0% 05.0% 0.46 R I 5 NP 100% 2.3 1.4 2.7 2.4 1.5 2.9 2.4 1.5 2.8 4.6 2.N 2-1H-B5 DFOTP1 StesedPFeTransfar PP 1 15KVA 00.0% 0.48 K A NP 60% 0.0 4.8 7.5 5.0 4.8 7.8 8.0 4.5 7.5 12.0 9.0 52-11-16 TCR Cor. Rn. Transeoerne 15KVA 80.0% 0.48 K A C 80% 8.6 7.2 - 12.0 8.6 7.2 12.0 9.8 7.2 12.0 12.0 9.0 52-IH-US TRY15 InstrumentACRegulalsg*nlrTRY15 152-I-6O TH3B BoriHAod HeatTraceXfrmTH3B 30KVA 100.0% 0.45 K I C 22% 3.3 3.3 3.3 3.3 3.3 3.3 30.0 75 HP 91.6% 8711% 0.46 R A 75 NP 100% 00.9 33.3 69.4 64.7 35.3 73.2 63.4 34.6 72.2 00.8 33.2 52-1H-70 E-6 todie Rereoat Fen E-0 52-lH-71 S31-6230 SlPP 12RyWter Supply -I HP R V 0%

62-IK-72 FCV-065 ot.H2RecamblterCHPS1-2teatVHW 0.67 HP R V 0%

62-18-73 FCV-659 Eot.H2Rwnsemtaer CUPS1-1tadVON 0.87 HP R V Q%

100.0% 0.48 Z P OP 90% 483.0 62-18-74 EPPH13 Pnserbta Hnsterl Group13 Se, Assumpkoo3.2.0 483 KVA I NP 805% 1.1 0.7 1.3 1.3 0.8 1.5 13 0.8 1.6 2.0 1.6 52-1H-75 CELS21TH209 Cwltrlnmenl H2Monitoring Pd. PM209 3 KVA 85.0% 0.48 Z AbandonedInplans 5 KVA 80.0% 0.48 K - 0% 4.0 3.0 52-16H-75 rP14 LoedresterPJlSG r.TPH Nuclear etsnsstm t UPS 13 20KVA 67,2% 00.0% 0.45 K 00% 22.4 18.8 28.0 22.4 18.6 28.0 22A 16.8 28.0 28.0 21.0 52-1H-f7 tel3 52-1H-78 Spaen 0%

82% 9.8 7.2 12.0 9.0 7.2 12.0 8.8 7.2 12.0 12.0 6.0 52-1H-79 "TRM12 Red.MoH.Sy..Xfrr-. 2 15KVA 80.0% CAB K A 7.5 KVA 80.0% 0A4 K 0%

6.0 4.8 52.1H-40 (FUTURE) Red.MoHe..y. Xfr. (FUTURE)

ROrVene2aeo'W TrainAit 3.2.9 Sea Assumption BO 8VA 90.0% OAS R P C 83% 22.0 34.8 52-161 EPCD2 Control BoaTotld '667 470 818 703 494 659 692 480 845 PooerFadeer 01.7% 91.0% 91.5%

013Total 2504 1391 2834 2600 1400 3028 2602 1440 2974 Poser Factor 87.4% Poewer FPctor 87.5% PaeraFactor 87.5%

Op Unarg Martin 248 485 157 522 187 911 9.0% 5.6% 6.7%

DesignMaergl 748 486 665 822 852 511 23.0% 20.1% 21.0%

(Copy Cale9220037760 olOI1-SC-r20.xls) page039oi41

Table 5: DG 23 Unit 2 Bus F LOOPCoinddentwithLOCA Nihreplate Load BDend Mochnitrca Load Units U Efflcoency Power Voltage Type Category Load. Load Gerand d0.yHzI100%' V1.2HzO110%V 60.8 He 110% V Rated Load Brooks, ID Dadiption Notes R-ayng (KVA/HP) (%) Factor(%) (kV) (R/0/Z) (AIP/JL/UMIS) (Lohp) Basis Factor(%) KW KVAR KVA KW KVAR KVA KW. KVAR WiVA OW KVAR Unit2 4.16 kV Bus F 52-HF-0B ASPI Am SaltwaterPp 21 400 HP 92.7% 86.8% 4.00 R A 465 C 116% 374.2 193.8 421.4 397.1 205.6 447.2 369.4 201.6 436.5 321.9 166.7 52-HF-09 AFWP3 Am Feedwter Pis23 600 HP 95.5% 90.5% 4.00 R A 0oo C 100% 468.7 220.3 517.9 4974 233.0 549.0 487.7 229.2 538.9 468.7 220.3 52-HF-10 - LoadCenterXamr & CableLosses Sao Assumption3.2.6 3250 KVA 34.0% 0K A A 3% 33.2 61.7 97.5 33.2 91.7 97.5 332 91.7 97.5 1105.0 3056.4 52-HF-11 CCP1 ChargingPp 21 See Assumpton3.2.10 600 HP 94.2% 90.5% 4.00 R A 65O C 105% 514.5 241.9 568.6 546.0 256.7 603.4 535.4 251.7 591.6 47652 223.4 52-4F-12 CCWPI Corpaoont CooingWater Pp2t 400 HP 95.0% 89.0% 4.00 R A 425 C 106% 333.7 171.0 375.0 354.2 181.4 397.9 347.3 177.0 3902 314.1 160.9 B2-IF-15 SIP1 Safetylneoefton Pp21 400 HP 94.0% 90.4% 4.04 R A 393 C 98% 311.9 147.5 345.0 331.0 106.5 306.1 324.5 153.5 359.0 317.4 150.1 BusToatl 2036 1006 2268 2159 1128 2435 2117 1108 2389 Poer Facor 89% Posera ctor 89% 89%

Unit2 480 V Bus F 52-2F-00 THF 400 Bus F LoadCenterXororFans Seo Assumptony3.2.14 3 KVA 00.0% 0.24 R A A 0% 2.7 1.3 52-2F-01 CFC2-2 Cotdlnmer FanCooler 22 100 HP 01.4% 54.2% 0.40 R A 103 C 103% 04.1 130.3 155.1 80.2 136.3 184.6 67.5 135.6 181.4 61.6 126.6 52-2F-02 CFC2-1 Cornttimert Fao Cooler 21 100 HP 91.4% 04.2% 0.46 R A 103 C 103% 84.1 130.3 155.1 09.2 130.3 164.6 67.5 135.6 161.4 81.6 126.6 52-2F.04 2E-5 FuelHandlingBldg ExhaustFan 2-E5 75 HP 91.8% 87.5% 0.40 R A 75 NP 100% 60.9 33.2 69.4 64.7 35.3 73.7 63.4 34.0 72.2 60.9 33.2 52-2F-OB RHRSP1 RHRSrep Pp11 1.5 HP 78.0% 63.0% 0.45 R I 1.5 NP 100% 0.7 0.0 1.1 0.6 0.6 1.2 0.7 0.9 1.2 1.4 1.0 52-2F-07 6107 Cold LogLoopChargingVLV1 t HP A V 0%

52-2F-08 2E-1 Air BldgExahaust Fan Eo- 150 HP 92.1% 90.5% 0.46 R A 160 C 107% 129.6 60.9 143.2 137.5 64.6 1502.0 134.9 63.4 149.0 121.0 07.0 52-2F-0S CVCS-8100 ChargingPp 21122Resor Linelost 1 HP R V 0%

52-2F-10 Sparem 0%

52-2F-11 FCV-430 CCWHx2-1Ousat Hdr0A 1.5HP R 0%

52-2F-12 LCV-112B VroCordolTankOudotVv 1 0.66 HP R 0%

52-2F-13 Spare 0%

OP 100% 1.3 O.B 1.0 1,4 90. 0.0 0.3 0.0 1.6 52-2F-14 TG1 FWpp21TuirdngGear 1 HP 58.0% 85.0% 0.46 R 1.3 0.6 52-OF-15 RHRSP3 RHRSup Pp23 1.5 HP 78.0% 63.0% 0.46 R 1.5 NP 150% 0, 0 0.1 0.0 0.0 0.2 01 0.9 1.2 1A4 1.

52-2F-1B S1-8801A Borer Injecoon 2.6 HP R 0%

52-2F-17 0l-0003A osroen Ielrlson 2.6 HP R 0%

52-2F.16 S1-6057A RHRDIGoh To SI Ppo 0.66 HP R 0%

52-2F-19 S31-005A RefuetlingWater Supply1 1.33 HP R 0%

52-2F-20 Spare 0%

52-2F-21 Spare 0%

52-2F-22 FW-FCV-441 SIG24 FW Nsotaton 5.3 HP. R 0%

52-2F-23 CCW-FCV-750 RCP BanderSeolCCWReturnIsol 0.67 HP R 0%

52-2F-24 FW-FCV-438 SIG21 FWIsolation 563HP R 0%

52-OF-2F5 -45 460VSwgrSupply Fan 045 50 HP 93.4% 83.4% 0.46 R so NP 100% 39.9 20.4 47.0 42.4 26.0 50.8 41.0 27.5 49.6 356 20.4 52-2F-26 E-45 480VSwgrExhaustFan E45 50 HP 93.4% B3.4% 0.46 50 NP 100% 39.9 26.4 47.9 42.4 20.0 50.8 41.6 27.5 49.6 39.9 20.4 R

52-2F-27 70BU N90-VldIantr ACBackupRagXtour Seo Ai-*ainpioe3.2.9 15 KVA K 0%

52-2F-.2 MPF28 DG20AmeP0l6 .32.5 OVA 85.0% 0.48 R C 05% 13.1 6.1 15.4 13,1 0.6 10.4 13.7 5.5 16.1 a' 27.6 17.1 52-2F-29 S-2-1 CortH2Purge SupplyFan 2-1 See Assumption3.2.12 7.5 HP R R 0%

52-2F-s3 MS-FCV-36 Am FWPp 21 Steam Lead3 1.3 HP 52-2F-31 St-B9O8 RofuetingWatsrTo RHRSuctlon 5.2 HP R 0%

52-2F-32 0108974A Safety Ir4ection PPS Reitre LineTo RWST I HP R 0%

52-2F-33 VAC-FCV-669 H2Recomdnterasct Vtv(OutCord) 0.7 HP R 0%

52-2F-34 SW-2-8 ASWPp 21tDiotGate 2-5 4 HP R 0%

52-2F-35 CS0-992 SprayAdditbeo Tank Outet 0.7 HP R 0%

52-2F-35 20-69 4W S.gr SupplyFan S69 1.5 HP 65,5% 78.3% .0.45 R 1.5 NP 100% 1.3 1.0 1.7 1.4 1.1 0.6 1.4 1.1 1.7 1.3 1.0 52-2F-37 Spare 0%

52-2F-38 PWMUPI PrtimryMakeupWaterPp21 15 HP .. ,a% 89.0% 0.48 R 15 NP 100% 12.9 6.4 52-2F-39 5-104 IntakeStewASWPp 21 ExhaustFan I HP 87.6% 85.0% 0.46 R 1 NP 100% 0.8 0.5 1.0 0.9 0.0 1.1 0.9 0.0 1.0 0.8 0,6 52-2Fo40 RCS8000A PrrRe~efVu 1-1 0.7 HP R 0%

6 Cale9000037760(Copyof 01 -D rOCAd) Page 40 of45

Table 5: DG 23 Unit 2 Bus F Neaeplate Load Demand Me.Obooal Load Units Enfaency Power Voftage Type Category Load, Load Demand 00.0Hz100%V 61.2 HD110%V 60.81-.110%V Rated Load Breaker ID Desacrpon Notes RaUng (KVADOP) (%) Faotor(%) (kV) (RIZ) (AIP/ILJMNIS) (bhp) Basis tor(%) KW KVAR KVA KW WVAR KVA KW WVAR KVA KW WKAR 52-2F-41 Spam 0%

52-2F-42 ED21 Batery Charger21 76.6 KVA 94.6% 74.0% 0.48 K A C 20% 12.0 10.9 10.2 12.0 10.9 16.2 12.0 10.9 16.2 50.9 54.5 52-2F-43 SFPP2 ADt Feed SpentFuel PHPp 22 Sea Aseumption3.2.9 75 HP R P 0%

52-D2F-A CCWAPI CCWPp21 A.a LubeOilPp 0.5 HP 72.3% 68.6% 0.4O R M 0.5 NP 100% 0.5 0.6 53-2-A45 TRP! Rod Poorloon indictiaonRag Xmr oRPI 10 KOVA 50.0% 0.48 Z A 1013% 5.0 0.0 10.0 9.7 7.3 12.1 9.7 7.3 12-1 a.0 6,0 62-2K-46 SI-4D8A Accue toecon ColdLoop 5.2 HP R V 0%

52-2F-47 TSC TechatcalSupportCenterAnlFeed See Assumpton 3.2.9 107 KVA 80.0% 0D48 K P C 71% 149.0 112.2 52-2FF-4 SI-8D02A SI Pp 21 Distharge (HotLeg) 2 HP R V 0%

52-2F-9 S-18821A StPp 21 Discharge(ColdLeg) I HP R V 0%

52-2F-50 BATP1 BodeAcddTmr*a rPp2l (FAST) 15 HP 00,4% 89.0% 0.46 R I 13 NP 87% 5.4 2.8 6.1 5.8 2.9 6.5 5.0 20 .3 12.5 .4 52-2K-51 TRY24 XtolnstUPS 24(AllBypass) 1rroatReg SneAauMnptlon3.2.9 20 KVA 01.0% 80.0% 0.48 K P C 80% 19.8 14.0 52-2F-52 ED231 BatteryCharger231 Sea Assumption3.2.t3 7B.6 KVA 94.0% 74.0% 0.40 K P C 20% 59.9 54.3 52-2F-53 Snare 0%

52-2F-54 FW-LCV-113/115 AFWPp DiStoHdr LeaetControlSDG 23124 0.O0 NP R V 0%

52-2KF-5 Spare 0%

52-2F-56 MPF56 DG23Are Pp A 47 KVA 85.0% 0.48 R I C 40% as0 5.0 9.4 8.5 5.3 15.0 6.3 5.2 0.0 40.0 24.0 52-2F-57 Spare 0%

52-2FK-5 THI. Bode AcidHeat Trace 30 KVA 100.0% 0.21 Z I OP 67% 10.1 10.1 12.2 12.2 12.2 12.2 30.0 52-2F-59 IY21 NuceaNr ntlararentUPS21 20 KVA 57.2% 60.0% 0.48 K A C 80% 224 16.8 28.0 22.4 16.8 28.0 22.4 16.0 28.0 28.0 21.0 52-2F-80 AP1 ChaooingPp2l ADALubeOtiPp 2 HP 71.1% 85.0% D.46 R I 2 NP 100% 2-1 1.3 52-2F-61 EPCB2 ControlRmVentlation"B"Traln 80 OVA 89.9% 0.48 R A C 63% 45.3 22.1 50.4 40.1 23.4 53.5 47.1 23.0 52.4 71.9 35,0 IstroRag XftrrIto UPS 21 (Bypass) 20 KVA B1.0% 80.0% 0.40 K A 0% 19.8 14.8 52-2F-N2 TRY21 52-2K-63 S,-8923A St Pp 21 SueoonFrom RWST I HP R V 0%

02-2F.64 Spare 0%

52-2F-65 Spare 0%

52-2K-66 spare 0%

52-2F-67 TRY22 InstrRagXfor Ito UPS22 (AltBypass) See Assumption 3.2.9 20 KVA K P 0%

52-2F-68 SFPP1 Alt Feed Spent FuelPit Pp 21 See Assumption 3.2.9 100 HP R P 0%

Bus Total 508 483 746 603 512 791 592 503 777 PoweFnator 76% Power Factor 76% 70%

2604 1550 3303 2702 1038 3211 2710 109 3151 0O Total Power FaCtor 85.9% Proer Factor 06.0% 06.0%

Operetng Margin 148 403 45 413 79 424 A4% 1.6% 2.8%

VeIS.oMargin 040 403 903 433 584 424 19.9% 16.7% 17.7%

Cale9000037760(Copy of01a5-DC-r20,s) Page 41of 45

Table 6: DG 21 Unit 2 Bus G LOOPCotneldeuWuth LOCA na-ll toad Gooroct lMoohartuat Load Units Effitienoy Por Voltage Type Category Load. Loead Deorod 60.0 H. 100%V 61.2 HzIlI% V 0.8Hz 110%V Rated Load eacrilpton Notes Rorng (KVAtHP) (%) Factor(%) (kV) (AIP/LJMNV/S)(bhp)

(RVAWt) Soat, Factar(%) KW <VAR KVA KW KVAR KVA KW WPAR KVA IM W'AR .

Breaker ID Unitr24.1kVBusG 62-HG-O5 ASP2 A- Satwator Pp22 400 HP 52.7% 88.8% 4.00 R A 465 C 11n% 374.2 183.8 421.4 397.1 205.5 447.2 389.4 201.6 438.5 " 321.9 168.7 400 HP 93.4% 9.19% 4.00 R A 440 C 110% 351.4 161.1 386.6 372.9 171.0 410.3 305.7 167.7 402.3 319.5 146.5 52-HG-0V CSPI ContalonoatSprayPp 21 RHRPI ResldualHeatRooroal Pp 21 400 HP 23.7% 93.5% 4.00 R A 413 C 103% 320.8 124.7 351.7 344.9 132.4 373.2 342.1 125.8 305.9 318.5 120.8 52-HG-08 CharorggPp 22 Sea Aseumption3,2.10 600 HP 94.2% 50.2% 4.00 R A 650 C 108% 514.5 241.9 558.6 546.0 258.7 503.4 535.4 251.7 591.8 475.2 223.4 52-HG.0- CCP2 LoadCardarXfpr &CableLos.es Sea Assurptton32.8 3250 KVA 34.0% K A A 3% 33.2 91.7 97.5 33.2 91.7 97.5 33.2 91.2 97.5 1105.0 3056.4 52-HG-10 500 HP 95.0% 92.1% 4.00 R L 434 C 72% 471.2 199.3 52-HG-11 . CCP3 ChargingPp 23 52-HG-1j CCWP2 ComponenlCooting WatarPp 22 400 HP 90.0% 89.0% 4.00 R A 420 C 106% 333.7 171.0 375.0 354.2 181.4 397.9 347.3 107.9 3S0.2 314.1 160.9 1936 884 2172 0052 1039 . 2300 2013 1020 2257 BoaTota Power Factor 89% 8a% O9%

2.7 1.3 52.20-00 FHG 480 BusGLtodoDa. XS.,Foan SIDasomryion3.2.14 3 KVA 90.0% 0.24 R A A 0%

C 103% 84.1 130.3 155.1 89.2 138.3 164.6 87.5 135.6 181.4 81.8 126.6 52-2G-01 CFC2-3 ContruirmeoFanCooler23 100 HP 91.4% 54.2% 0.46 R A 103 84.1 130.3 155.1 89.2 138.3 164.6 87.5 135.6 1061.4 81.8 128.8 52-20-02 CFC2-S ContainmentFailCooler25 120 HP 91.4% 54.2% 0.4S R A 103 C 003%

C 807% 5.4 2.8 6.1 5,8 2.8 6.5 5.6 2.9 6.3 12.5 0.4 52-2G-04 BATP2 BortnAtd TransferPp 22 (FAST) 15 HP 88.4% 85.0% 0.46 R I 13 Aoour 24 ojuect 1oColdLoop4 fil HP R V 5.2 52-;0005 91-88080 NP 100%

52-2G.00 RHRSP2 RHRSump Pp 22 1.0 HP 1 78.0% 3.0% 0.48 R I 1.5 0.7 0.9 1.1 0.8 0.9 1.2 0.7 0.9 1.2 .1.4 1.8 100%

52-20-07 SI-880OB Acoum22InJeotIoColdLoop2 5.2 HP R V 5.2 NP 100% 49.6 31.9 50.0 50.7 32.9 62.6 51.6 33.2 01.4 49.6 31.9 52-21-O0 BOPACI TGBearf.r 0 Pp 60 HP 90.2% 84.1% 0.46 R A 60 0%

52-30-09 CVCS-8100 CHGPp 21 and22 Mnrdifow VIv2 1 HP R V 0%

52-20-10 CVC0-H108 NorrmaCHGtoRagertHXStopVIA2 1 HP R V 0%

52-23-11 LCV-112C VolumeControlTort Outlet 1,o2 0.807HP R V 0%

5.2 HP . R V 52-20-12 SI-8809A RHRInreottoLoopsI and2 Hot Lag 2.6 HP R V 0%

52-20-13 S9-e801B CHG InjectOutat Mlv2 0%

52-2G-14 SI-8805B CHGPp RefudWaterSupply V5v2 1.33 HP R V 0%

52-2G-15 RR-8TtOOA RHOPP21 SuIlonýla . 1.OP 14 VR 0%

52-2G-1 St-8804A RHRDischargeto CHl Pp 3.2 HP R V NP 1O0%

52020-17 20-1 SupplyFan S1 FuelHandingBldg. 25 HP 87.8% 83.1% 0.46 R A 25 21.2 -14.2 25.6 22.5 1501 27.1 22.1 14.8 26.9 21.2 14.2 NP 100% 0.7 0.9 1.1 0.8 .0. 1.2 0.7 0.9 1.2 1.4 1.9 52-20-18 RHRSPP4 RHRSumpPp 24 1.5HP 78.0% 83.0% 0.49 R t 1.6 C 63% 72.0 34.9 52-2G-19 EPCE2 CoonoolRm Venilealon "ETrain All. So, Asturnplion 3.2.9 80 KVA -" 00.0% 0.46 R P 0%

52-2G-20 Spare R V 0%

52-2G-21 CS-9001A SprayPP 21DslchargeStopVivI 2 HP 0%

52-2G-22 TRY23 NuclearInstrurentXfr 23(AtBypass) 20 KVA 81.0% 80.0% 0.48 K P 15.8 14.8 52-20-23 FCV-383 RCPCoding WaterReturntao.VIv3 0.13 HP R V 0%

52-20-24 S1-8835 St Pp DischargeColdLag 2 HP R V 0%

52-30-25 RHR-8701" RHRSuctionfro Loop4 HotLeg VWo 2 2.8HP R V 0%

52-20-28 CVCS-H100 RCPSeat WaterRetumIse Vtv 0.67 HP R V 0%

52-40-27 St-65389 ChargingInjectionSupplyV\&2 2.6 HP R V 0%

52-2G-48 FCV-431 CCWHXOulet WV 1.6HP R V 0%

52-20-29 FCV-641A RHRPP 21 Redrc"vlv 0.7 HP R V 0%

52-2G-30 TLE21 EmergencyLSghting Xolr TLE21 25 OVA 80.0% 0.48 K A C 60% 12.0 9.0 15.0 12.0 8.0 15.0 . 12.0 9.0 15.0 20.0 15.0 35.0% 0.48 R C 40% 8.0 5.0 2.4 8.5 5.3 10.0 8.3 8.2 9.8 40.0 24.9 52-20-31 MPG31 D021An PnIA 47 KVA 100.0% 0.48 z NP 100% 3.8 3.8 4.5 4.5 4.5 4.5 7.5 52-20-32 SATHA2 SorteAcidTart 22HeaterA 7.5 OVA K 5.6 7.2 12.0 9.6 7.2 12.0 5.6 7.2 12.0 12.0 5.0 52-20-33 TPRM21 Rada~ton ManorIngSys XtorrI 15 OVA 80.D% 0.49 A C 80%

85.0% 0.48 Z I NP 85% 1.1 0.7 1.3 1.3 0.9 1.5 1.3 0,8 1.5 2.6 1,6 52-20-34 CEL83rIH210 Containment H2 MonitorPanelPM210 3 KVA 80.0% 048 K 22.4 16.8 28.0 22.4 18.8 28.0 22.4 16.0 28.0 208.0 21.0 52-2G-35 IY22 Nucler Intalrument UPS22 20 OVA 57.2% A. 04" 0.13 HP R V 0%

52-2G-36 FCV-356 RCPCoep CLGWaterSuopply Mv 52-20-37 FCV-055 EotH2RetoorllowCoPS-2t2ol NotI\ 1.9 HP R V 0%

25 KVA 80.0% 0.45 K A C 508% 11.8 8.7 14.5 11.6 8.7 14.5 11.6 8.7 14.5 20.0 15.0 52-20-38 TLE26 EmergencyUghtlngXSfrn TLE26 55.6% 52.0% 0.46 R A 1.0 HP 100% 1.7 1.2 2.1 1.8 1.3 2.2 1.B 1.2 2.2 1.7 1.2 52-2G-39 RY11 Contannment ROdMonlorPp RY1I 1.5HP 5 HP 87.8% 65.0% 0.40 R I NP 100% 2.1 1.3 2.5 2.3 1.4 2.7 2.2 1.4 2.0 4.2 2.6 52-20-40 OFOTP2 Close[FoulTransferpP2 Cal, 90O037750 (Copyof 015-DC-r2A)Pe) Page 42Dos 4

Table 6: DG 21 Unit 2 Bus G

. LOOPCorncadentwOhLOCA Nameplat Load Demand mechanicat Load Unsit Efclency Poca Votange Type Category Load. Load Demand 00.0 Hz 100%V B1,2Hz 110%V 60.BWz1 t% V RatedLoad Breaker ID Descrptiaon Notes Raetig (KVA/H P1) (%) Factor (%) (tV) (RS.ll) (AIP/0IUMNI)S(bhp) Basis Factor (%) KW KVAR KVA KW KVAR KVA KW KVAR lWKVA KVAR 52-2G-41 CCWAP2 COWAm51 Luea03 Pp2-2 0.5 HP 7Z3% 65.0% 0.40 R 0.5 NP 100% 0.5 0.-

52-2G42 ED22 BatteryCharger22 70.5 KVA 94.-56 74.0% 0.48 K C 20% 120 10.5 16.2 12.0 10.9 10.2 12.0 10.B 10.2 50.9 54.0 52-2G-43 TY21 frotrOaekup XftrrTY21 7.5 11./A 50.0% 0.48 K 0% 9.0 4.5 52-2G-44 LOy-l0O 0IGAFWrSupply Viv21 0.33 HP R 0%

52-20-45 RHR-5716A RHX 11 oRCLoop1&2H LotLg 5.3 HP R 0%

52-ZG-40 RC0-80009 PressurzlerPowerRBena Va 2 0.7 HP R 0%

52-2G-47 FCV-430 S0G2-2 FWtoo VW 5.3HP R 0%

62-2G-48 C3-90O3A RHRPp 21To $pray Hdrs1 &3 3.3HP R 0%

0.40 K 52-2G-40 RMS-120 RadatltaMerldorigOyPe2mo(Fu,*-) 7.5 OVA 0%

52-2G-50 TH2A ScaeAcidHeatTraceXfrwTH2A 3D KVA 100.0% 0.48 z C 03% 9.5 '0S 11A4 11.4 11.4 11.4 30.0 52-2G-51 BATHA1. BoetAcidTark 21HeaterA 7.5 KVA 100.0% 0.45 Z NP 10o% 3.B 3.8 4.5 4.5 4.5 4.5 7.5 52-2G-52 PWIA01P2 Pdtary WaterMakeUpPp 22 15 HP 80.9% 80.5% 0.40 R 15 NP 100% 6.4 3.2 7.2 5.8 3.4 7.0 0.7 3.3 7.5 12.9 6.4 52-2G-53 S-2-2 Coctainment H2Purge Sys.Fan 22 SeeAsasumpton3.2 12 7.5HP 80.5% 8B.0% 0.46 R 7.5 NP 100% 0.5 3.4 52-2G-54 SW-2-, ASWPp 22 Gate Operator29 4 HP R 0%

52-20-55 C,-8994A SwayAdditceTark TKOudtel Va I R '0%

0.7 HP 52-20-58 RHR-8703 RHRR0c0t5to HotLoop1&2 5.2 HP R 0%

52-2G-57 CVCO-104 EmergencyBorateVtv 0.7HIP R 0%

02-2G058 51-8582A CootRBckcSunpOulet Vol 5.3 HP R 0%

52-2G-6S EH30 Chrccal FilterPrecOeter 54 KVA 1oo.0% 0.48 z 100% 54.0 52-2G-00 E-102 ASWPp 22 VaultEahaustFan E-1i2 1 HP 87.6% 85.0% 0.46 R I NP 100% 0.8 0.5 1.0 0.0 0.B 1.1 0.9 0.5 1.0 0.0 0.5 52-2"--1 T1Y2 Instrment TransformerTY20 15 KVA 85.0% 0.40 K C 07% 7.3 4.5 8.0 7.3 4.0 8.5 7.3 4.5 8.6 - 129 7.9 52-2G-62 MPG62 OG22A.x Phd5] 32.5 KVA 85.0% 0OAS R C 95% 13.1 8.1 15.4 13.9 B.9 19.4 13.7 80. 16.1 27.6 17.1 52-2G-63 23-05 4K"V5Vta BueG SupplyFan S68 1.5 HP 87.9% 85.0% 0,16 R 1.5 NP 100% 1.3 0.9 1.5 1.4 0.5 1.0 1.3 0.8 1.9 1.0 C.9 52-2G-64 AP2 ChitPP 22Amo LubeOI Pp 2 HP 84.9% 77.5% 0.46 R 2 NP 100% 1.8 1.4 52-2G-05 S-53 SupplyFan033 0- Bld0 00 HP 00.4% 80.4% 0.40 R 00 NP 100% 49.5 28.9 57.3 52.5 30.0 50.5 .51.5 30.0 59.6 49.5 28.9 52-2G-00 SFPPI SpentFuelPit PP21 See Assumption3,2.10 -100 HP 92.0% 90.5% 0,48 R 90 C 00% 81.1 38.1 52-2"-17 EH5S-1 Intemral H2RecomblrerSy0 Group 1 SeeAssamptio 3.2.11 75 KVA 100.0% 0.48 z 0% 75.0 02-2G-05 LCV-107 S/G22AFWSupplyVaere 0.33 HP R 0%

02-2G0-9 LCV-100 S/G23AFWSupply Velce 0.33 HP R 0%

52-2G-70 LCV-109 S0G24AFWSupplyValoe 0.33 HP R 0%

52-20-71 TRY22 tin InstcRegXfmr UPS22(Bypens) 20 KVA 81,0% 9o.o% 0.48 K C 0% 19.8 14.8 02-2G-72 EPPH22 Pressuraer Hk Group22A1OSuppy See Assmptlaon3.2.9 403 KVA 1 oo.D% 0.48 Z OP 100% 413.0 52-2G-70 Spare 0%

InotrRogXftr Inc UPS21(.2t Bypase) 20 KVA . 81.0% 80.0% 0.48 K P C 80%

52-2G-74 TRY21 19.8 14.0 Bus, Total 422 418 594 440 440 929 439 433 919 PowearFactor 71% 71% 71%

0G0Total 2368 1402 2143 2498 1479 2903 2457 1453 2850 PoowrFactor 95.9% 00,0% 8a.0%

ap41t01 M,argin 394 360 390 394 337 306 14.3% 11.0% 12.1%

CostanMargin 092 365 817 394 841 380 27.5% 24.6% 25.,%

Table 7: DG 22 Unit 2 Bus H LOOP ColnddontMMlh LOCA N*leoate Load Demand Mhaoo9m1l Load Undo EffIooency Power VoLage Type Category Load. Load Dmand 60.0 Hz 100% V 61.2Hz 110%V willH. 0IU% V RatedLoad Sreakor ID Deripti.n Nobs Raong (KVAUJP) (%) FaenIoI%) (kV) (RI01Z)(MPSIJ.MN/IS) (Mhp) Buds Factor(%) KW WVAR KVA KW WVKVAKSA 090 WAR KVA 04 WVAR Unt2 4.l6kV RmeH 600 468.7 220.3 62-HH-F8 AFWP2 Am FeedwaterPp22 600HP 5.5% 90.5% 4.00 R A C 120% 400.7 220.3 517.9 497.4 233.8 649.0 467.7 229.2 538.6 4.00 R 440 C 110% 351,4 101.1 386.0 372.9 171.0 410.3 365.7 167.7 40223 319.6 140.5 92-HH-06 CSP2 SprayPp22 Contalrmoent 400 HP 93.4% 60.9% A

- K A 3% 33.2 91.7 07.5 33.2 61.7 97.6 33.2 91.7 97.5 1105.0 3058.4 02-HH-10 THH LoodCenterU ,&

CableLoe.s. See Assumpton3.2.6 3250UWA 34.0% A A 421 C 102% 335.2 120.2 326.6 355.7 136.1 380.8 348.8 133.4 373.4 316.6 121.6 52-HH-11 RHRP2 Residu.lHeetRemoval Pp 22 400 HP 93,7% 93.4% 4.00 R A 425 370.0 204.2 181.4 397.0 347.3 177.6 320.2 314.1 16.09 52-HH-12 CCWP3 Component Colmg Wate Pp 23 406 HP 95.0% 9.20% C 106% 333,7 171.0 4.00 R A 147.6 342.0 331.0 100.0 306.1 324.6 153.5 3590. 317.4 160.1 52-HH-15 SIP2 SafetyInrenooPp 22 400HP 94.0% 60.4% C 98% 311.9 1634 920 2252 1644 971 2173 1907 653 2132 BoaTotal P-owerFator 89% 89% 89%

Unit2 482V RueH 52-o2H00 T15-T11410 410 BusH Loodleor Xooo F.nt SeeAssurnpion32214 3 KVA 50.0% 0.24 R A 0% 2.7 1.3 100HP 0.46 R - 103 c 103% 81.0 120.6 52-2H-01 CFC24 ContalmmnntF.r Coder24 91.4% U4.2% 04.1 130.3 155.1 09.2 131.3 184.6 03.0 135.6 161.4 3-.2HP R 0%

52-21-00 CS-003U6 RHRPP 22toSprayHDR,2 &4 0%

62-2M87 Spore 25HP 87.6% 83.1% 2.40 R 21.2 14.2 20.6 225 15.1 27.1 22.1 14.6 20.6 212 142 02-2H-08 2S-2 FHBSupplyFan S-2 60.0% 2.46 R 1.3 0.8 1.5 1.4 0.0 1.0 1.3 0.6 1.M 1.3 0.0 52-29-10 T70 P0 PP 22Turing Geor I HP 08.0% I NP 12617 52-20-11 CS-9001B SprayPP 22OlechSlopMlV I 2 HP R 0%

Cort RekocSumpOudet"VV 2 5.3 HP R 0%

52-29-12 SF06020 52-2M-13 Spae 0%

02.2H14 02-29H-14 Spore11 SF06262 5.2 HP Accum23 111 toCoa Loop3 R 0%

52-24-105 FCV-641B RHRPP 22Renkclo, 0.7 HP R 0%

62-2M-16 FCV-355 Cmp CooingHederC Ilenooon VIV 1 HP 00%

02-21-17 FV-3157 RC0 8anterC2WRo*m 0.7 HP R 0%

52-2H-16 FCV-740 RCP Bearng09 Coosing RetunVV I 0.25HP R R 0%

52-2H-19 RHR-8702 RHRSuoon fromLoop4 HotLagVIVI 2.9HP R

1.4 HP 0%

52-20-20 S1-8976 SI Pp SuogonfromReOWetWaier 20HP 03.4% 03,4% OAS R 5 NlP 100% 39.0 28.4 47.9 42.4 26.0 60.0 41. - 27,6 49.8 39.9 26.4 52-20-21 E0-6 460VSwgrElrhust FonE46 C 112% 22.4 16.8 28.0 22.4 16.8 28.0 22A 16.6 280 20.0 15.0 52-2H-22 TLE23 Em-rgroy Ug,Xfr TLE23 2OKVA 00.2% 0.48 K 0.48 R c 40% a0 - 6.0 0.4 8.5 5.3 10.O 8.3 0.2 9.0 40.2 24.6 62-29-23 MPH23 DG21Au PNIA 470VA 86.0%

122% 49.6 31.9 69.0 62.7 33.9 6006 51.8 33.2 01.4 49.8 31.9 52-21-24 S-34 A00BldgSupplyFPnS-34 00HP 90.2% 84.1% 0.4 R 62 C 3.2 HP R 0%

62-21--25 $1-8040 RHRHX22 toSIPp S=umon SI-F00B SI PP 22 DIsChagoHalLeg 2 HP R 0%

52-29-26 RCP SealWaterR.-umIsolsaonr VIn2 0.67 HP 0%

52-2H-27 CVCS-8112 R FCV-440 St.am oGn 23FWIn oNa.on 'V 5.3 HP R 0%

52-29-28 5.3 HP 0%

56-2.-29 RHR-87180 RHX22toRC Loop1 & 2 HotLeg R AFWTrb 21Lead2 Stam SupplySVI 1.3 HP 0%

62-21--30 FCV-37 R 52-29-30 Sl-6821B SI Pp 22 Olsohorge ColdLegLoop 1 HP 0%

R Bl.0075 RHRDOsadrrge W21Pp 0.07 HP 0%

52-2H-42 R Pmseudos-poP- R"eMflo23 0.7HP R 0%

52-29-33 RC0-0000C 76.0 0VA 94.6% 74.0% 2.46 K C 20% 12.0 10.9 10.2 12.0 10.9 16.2 120 10.9 10.2 59.9 54.5 52-21-34 E0232 BoteryCharger232 75 KVA 156.0% .48 Z 0% 75.0 02-21-35 EHRS-2 kdem H, SysG610p R82coombnner 2 3.2.11 Sao AssOonpgon 0.0 HP 87.0% 15.0% 2.46 R 0.5 C 100% 0.4 0.3 52-29-32 CCWAP3 C2WPP 23 A.oLude06Pp 1.5 HP 54.2% 80.0% 2.46 R 1.5 c 16% 1.3 1.0 1.7 1.4 1.1 1.6 1.4 1.0 1.7 1.3 1.0 52-211-37 2S-07 VlIal4KVSgy Bus HSupplyFan 0%

62-21--36 Spor Emergen.yLIU.0616n.

TLE25 29 KVA 62.0% 0.46 K C 48% 9.0 7.2 12.0 9.6 7.2 12.0 9.6 7.2 12-0 202 12.0 52-20-309 1025 SprayAdd9JvaTbk Outlet'Ay2 0.7 HP R 0%

02-2H8.0 2060g4B ASWPp 22Cro-se. -V I HP R 0%

62.29-41t FCV405 ASWPp 21CroU.e'So 1 HP R 0%

02-2H842 FCV-460 RHR0-700B RHRPp 22Sucot "v2 1.6 HP R 0%

62-2-143 SIPp ReebcSlopVtv I HP R 0%

02-21-44 Sl-09748 15 S-6B RHRInJamlHoLoop3 &4 HolLeg 502HP R 0%

52-20-40 6S00P 93.4% 03.4% 0.46 R 41.6 27.5 49.6 00.0 20.4 52-261-40 S-4 AuxBldgSwgrRmSupply Fen S-44 60 NP 100% 39.0 20.4 47.9 42.4 20.0 00.9 81.0% 90.0% 0.48 K C % 19.8 14.8 52-2H1-47 TRY23 [nc,Reg fmr IHVUPS23(Bypass) 20 KVA Ps)

Page 44 (t45 Cola900003760 (Copyof016-5CýA20s

Table 7: DG 22 Unit 2 Bus H LOOPCoincdentWittLOCA Nameplate Load Demand Mechanipal Load Units Efficiency p'omr Votage Type Category Load, Load Demand 60.0 Hz 100% V 61.2 H 1106%V 60.8 H. l10%V RatedLoad Soeaker ID Descripton Not. Ratng (KVWAHP) (%) Factor(%) (kV) (RKJ/Z)(AiP/JJMNIS) (Obhp) Beats Factor(14) KW WAR KVA KW WVAR KVA KW WAR WWA PAR Wc too HP 92.1% 90.5% OAS R 160 C 107% 129.6 60.0 143.2 137.5 BA.B 152.0 134.9 63A 149.0 121.0 67.1 62-H-AS 2E-2 Overi PalhacetFanE-2 A 52P-H-AS MPH49 DG23A. Pnl B 32.5 WVA 65.0% 0D4 R C 05% 13.1 5.1 16A 13.9 0.6 16.4 13.7 .05 16.1 27P. 17.1 02-PB-50 Spaie 0%

524-2H-51 E-2-2 Containment H2PurgeSy, Fan2-2 SeeAssupOon 3.2.12 7.6 HP 84.5% O5.0% O.AB R 7.6 C 100% - P.B 4.1 67.2% 80.0% G4AG K C 2B.D 21.0 52-2H IY24 NuclearInstrumentUPS24 2P KVA A 00% 22.4 16.E 28.0 22.4 10. 28.0 22.4 1.6 25.D 0%

62-2H-53 Spare 30INA 100.0% 0.48 z - C 64% 9.6 9.P 11.0 11.0 11.6 11.6 30.0 P2-PH-54 THIS Bod. AcidHeatTrae YfiTHIrB 80 KVA 00.0% 0.45 R C 63% 45A 22.0 50.4 40.1 230 53.5 47.2 22.0 52.4 72.0 34.9 2-2PH-55 EPCD2 CortrolRmVenltteaon'MTrain P2P-H-56 (FUTURE) Red. Mon.Syp.Xf6P. (FUTURE) 7.5 KVA 0.48 K 62-2H-PP CEUL82TH209 Contadenent Pa.F HPMonito*ing PM209 3 KVA * .50% 0.46 Z NP 102% 1.3 U.S 1.2 1.5 1.0 1.6 1.5 1.0 1.8 2.S 1.5 A

52-21-1511 BATHS2 BSotaAcidTank22 Heaten B 7.6 KVA 100.0% 0G4 Z NP 100% 3.0 3,0 4.6 4.B 4.5 4.5 7.5 52.2H-5P BATHBP BodeAdd Tapi21 HeaterB 75.6tA 1000.% 0.48 Z NP 100% 3.B 3.8 4.P 4.5 4.5 4.6 7.5 P2-2H-60 ED221 Ml BatteryCharger SeaAseutnpcon3.2.13 76. KVA 94.P% 74.0% O.4A K C 20% 69., 64.6 52-2PA-A TPRM22 RBd.Mon.Sp. Xft. 2 15 KVA 80.0% 0.48 K A C 80% 9.6 7.2 12.0 B.6 7.2 12.0 E.8 7.2 12.0 12.0 S0 P2-PH-O2 Spate 0%

c2-P1-3R THAP e mrrTH2B Bric AcidHeetTraes 30 WA 100.6% 0.48 z C 03% 9.5 9.5 11.4 11.4 11. 11.4 0.B 52-2H-64 tY23 UPS23-Nudeas tracoumnent 20 KVA 57.2% 80.0% 0.40 K -A C 00% 22A. 16.6 28.0 22.4 16.8 2P.0 22.4 1.0 28.0 28.0 21.0 Ba-2P-65 DFOTPI DieselFuelTansferPP 1 5 HP 86.0% P5.0% 0.45 R P N 100% Z2 1.3 2.6 2,3 1.4 2.7 23. 1.4 2.7 4.3 2.7 62P-H-66 TCR Co. Rm.Transfomer SeeAeurmption3.2.9 15 KVA 80.0% OAS K NP 50% 6.0 4.5 7.5 6.0 4.6 7.5 6.0 4.E 7.5 12.0 9.0 62-2H-6T Sp.a 0%

A P2-PH-68 TRY25 ACRegduleUngmr Itrctatment TRY26 1P KVA 85,0% 0.48 K 10.2 03 12.0 10.2 6.3 12.0 10.2 6.3 12,0 12.8 7.9 52-2H-09 LCV-110111I SiG21&U2AFWSupplyVa.Iva 0.66 HP R C 00%

62P2H-70 2,-6 IodineRernopaFan ERS 76 HP 1.0% 87.0% 0.46 R V 820 33.2 69.4 64.7 0 35.3 1.7 63.4 34.6 72.2 60.9 33.2 0%

62-2H-71 Si-o923B SGPP 22 R-awWat.Supply I HP R R U 0%

P2-PH-72 FCV-6BB at.H2Recoathatior CHPS2-2IodrVi 0.7 HP R V 0%

P2-PH-73 FCVP-B9 ExtLH2R-P otn.er CHPS2-1[ee1VI, 1.9 HP P2-2H-74 EPPHAP HearerStoupP3 Presaurlaar SeeAe.utpgdo 3P2.9 4APEVA 100.0% .o.48 z P C . 76% 483.0 P2-PA-70 TPH LesdptenrPJ1GXfr. TPH Abandoned. Pa.e P <VA 80.0% 0.48 K , 0% 4.0 3.0 52-2P--7 Spae 0%

52-2P-78 Spare 0%

SeeAseumpton3.2.10 75 HP 020% 9D.0% 0A0 78 NP .100% 60.8 28.5 P52P2-H-17SFPP22 SpentFuelPP Pp22 P

2-2PH-81 EPCA2 Contoi RanVenriaeon'A'Trea A*L SeeAssuopeon3.2.9 80 KVA 90.0% 0.46 R 63% 720.6 4.8 52-2H-82 TRY24 RagXfmrIn UPS24 (Bypass)

InslB 20 KVA 01.0% 80.0% 0.48 K A C 0% 16.5 14.8 52-2H-83 Spoar 0%

So. Totat 63R 440 781 676 471 am2 665 B 4A4 11 PowerFactor 82% a2% 82%

2473 1369 2827 2020 1442 2990 2P72 1417 2937 DGTotal PoweorFeo., 87.5% P0.6% OPP%

OpataOngMargin 279 46 100 023 217 512 10.1% 6.7% 7.0%

DeoignMS"an 777 486 000 023 721 612 202.% 21.0% 21.0%

Caic9000037760(Copyof015-DC-rO0.sPA) Peg, 45 1'45

V('A11A OTht(1ISITI('HI OP I'Obl'PIASHh INTDUCTION M2OTORS Sec. 10-88 Table 1Mi. "General Effect of Voltage end Frequency Variation on hioirid-litrlus monitrasl, ratod 40"'C rise are always give. n "aervie factor"; e.il, Inlductlon-mnter Chraclterisllcs liti infititriturer gunrilnel sutn.wufnl iperatinn a. 1.15 thum raled hdiit, bint the

'1 tohliemtLro ril tuay lie hiigher, id the elficiency nad I.ower rhctir utay b. lower than Allornating-currnet (Induntlun) in,.turs sluirllid.

1 Standiahnrd tervieo factors inre 1.4 for lllturt ratedl .*n Ito lip, 1.35 for i to ji lil, Vtoltnag Fr~Eequencey 1.25 for 1(j tip I lip, 1.20 for I.3j to 2 lip, und 1.15 for m.ature 3 lip and lzrger, for-free-105% f 1111 tidnal hol-r-eewir, aid Delossign A, II, C, and F iitegial-hlrewpowet umilutrs.

Oipen inotuNr ratell 41l10 rise, antl drippruof nuttehr, it rnetd 4(10 rise, by tbhrntiml-iLr (tip the equivalenlt) arc usually given a "saervic rfacLr" ,if 1.15; i.e., the nimlu-Torque:@ llo allMul fllt-nrtlr guaranltle stimccw*fiul oimrastitl tat 1.15 times rated lized witlhout injurinos otailrl,, call =all[. ,iuiting,although tle ufllitonsiy mid power ructur iney vary slightly from the rated elu runaft,** flecreas. 10 W I luad vnhlis. 4 Dfoaew IT% Increase 23 % Increase r. I1..rreuw, 5% 80. Time Rmfing. Most imittur am rated on a "ctintumm" bhil; i.e.. they Par cent alit,. Little chiange Littla aetiengi will cairry Clitoir rated foal evrntintouity without exceediug thi ratedl eamleraturo rises.

Curtain speclnal types of moluw, Ilnwlvor, are given "ehurt-timl" rnlltItI tallltlis a l lim, Efilclerld liwerecal 0.5 to I Iercese. 2 Pollt tlilitit decrease 5g It, or I Ih, inldicatiig that ;they can curry their. rte*l lurnd for thiias peridl of timei, Dao MResii9 Littleele~ after which they muslt he allowed. ti cool to mnm temperaliro. Int sme cases a meotor Irecrteme Blight Incoremne Hliailittderenac palate poionto i* glven several differeunt P'ower (sctor. rntingit, encli for a differ- A

Full land ... IDecrnnTIEl potints I- g Increvase 1oInt IUlliht Inorin 181101li decreati. oniitperiodurtftime. iulrl- 9I.

Bliglht, inraeel 9C Inra to3 filight, decorec 'tLitle rated motors fire

= sra4 to a Blight, inar"M55 potao's pointo ,ito in homlo of u,, inter- -

Ctortngt ...... nititlwt nt*1 Mr, the Chii -iv- :2.-:

litereal to to tass D~eorei 101012% SlghtoO raci lfiereas~etofl% r atiog bneinigch os e nit o e-11eereaoa 7% Inrreane 111. filigltt increjus Diaaerba" 3to 4C lbzoegoo 6 to 70C Slilht. detreauo Blight increase 1irlorliF-llntilig equivalent - .

Inereciw 21 % flereue52 811,0h9 derease, to that, producred by Cleo e~apiyi........ filight. inric~ea 7 .

WeC4iLle new ....Ellight lectial Slight deerees. Blight deeraime Blight increnee atoual duty cycle of tie m iountimum rununeg torqune a4 U-c Idurllunt will Vary" aW amotrs till alunre of tie

111h. utirs

87. Efficiencies mad 11 1/7 i ..... . -1 I R. l.4.-. lofu.aelf motrW will .arydirectly titl fhrluenely Power Factors. Typical 10 - Ii WQ I SiMISIOM. 0 St fill-hilod effinlltcies and , 51 ID 1s 7 0 1' Typical frequencsm am 90, 120, 180, 2401, annd 3(01 c, giving motor sptedsc of 5,411!, plower factors or standard florslpoilr rlting I 7,200W, 9l0,001, 14,40D, Mid 21,600, rempectively, wi m two-pule iluotrg. Motors for iDassiiigl 1 slniirrel-cnge i ai-,

Fl-a.111l. Full-laudl oifflrlrla on r Dcmlgii II allulrrel-caga such Opapratin mus t of spe.oial p lesidl. Tiylicl npplicatiun inelude toxtile mianchutl- ihnctiumti motors are giVeilt motors, 22U- or14411-V 8-plhaou (10-c open typo. C -- tD esy, woodworking maclihuery, mnd portaluhe tools. It Ieigiw.I -*-20nid I I-211b, U. Temperature Rime. Thi d.i.dard tempemtur rises rifthe windilng of squirrel- ,eupactivoly. The variatinit of elficieney and power factor with hund far a typilnl ratiiig al and woun'd-retor induction motour are: ii shown in Fig. 18-31. The clifiencies of lDesign A motors are ementially the smite, while thto*u (f Jlo*dgt C and wound-tutor z15

- montors are generally slightly lower, slid thliose S.........................................Fnetoui bp Integral lip

of Ilesiga motors L4o.4niierahliy lwer. Tile power factors of Draigi "A squirrel-cael ii- 0. 0 toInee alas ......................... A A f fl ! T IN Z - -

2 duetion motoer am slightly higher, and Chume j or Design C are slightly lower.

hoamu,laeorna..t...................T R T IT T R0 T' T It -& Thee ellicielltme of all outputs will fald

- -j aon a straight line all the nomograph of Fig.

atluardJporpawl l icate ..................... 40 s00 40 no 70 - I- t"_7I..vA' 18-30. Thus, if the elliciencles at, any two Othqr opsen r~.l..........................5 s go .. ..

TO so so us -so 0 25i l-adi s are niowit, that of anty other load is Totally eeolwmd voltwentillitW..............5 U 75 5 75 a1 l(6 120 S.I

- - - imm'ediately obtained.

I Im " 25 1 O elekolagoez iS Full-load Current. With the eI$-

power- r*tt, or eciency and power factor of a 3-phase motor Where two matlwds of temiperature measurement* ae listed, a tempenrature rise Via.10-29D. Full-load krnown, its the full-load current may be calcu-lated from formula within thea value, lietedl in the table, reinsured by eit~her the thermonmeter method (T) or ir reistanceu nietlwe (11), dsriifalrte's, siionfomiy with the elendnrd. The vazlues _

litdfor the Ueer-ionetor* method "T1 are usually used for nameplate warkieg,* ir- 741 X lip rating (18-50)

Full-ltnd current t relpec~rt method of tiesornto .(f wmaurxement

. d above) lhp actual]y used. provided wth5 ra1ltano1-type er. u5ually 1.73 X efficiency X pf X voltug VuIy larg (2,00.

t hoet OrtlreaktnOm mitl wor ofdehd in the emh 1d() dmfltaafcnf4.yihtestnad windig s for delermHnin u their temperature

, ris, in hvle INLMA Motor anl Geriturtor Pltandsiale; PaW. P401-10511.

I Utiau. P. 1. madJoneatiN, T. Q. [lailtig of (teerll purposel leduilo Molars; Trott. AWRN.

withi o the ualovble ited pwur ri in 1111 bf hitbher thm tihat the ttlthlUroletrer j1 Seoptenibese 103lg,Vol. N8, it. 445.

e'lmoviusuau'61. Duty 4ycle, anid Motor Tinting;r TrSai. AFW, li~erstival 1932, Val,. 5%p.471L 4 lIhmnoeton Geintral Prlrialuam for listiall of Hisaterisal Atinisrtua for Hhtrt"iai. lazrialiseat 4x

Enclosure Attachment 6 PG&E Letter DCL-10-018 PG&E Calculation No. 9000040769, Revision 0

DCPP Form 69-20132 (08/22108) CF3.1D4 Attachment 4 Page 1 of 3 Design Calculation Cover Sheet Unit(s): $9Z.. File No.: Responsible Group: NCFM Calculation No.: 9*40769 Design Calculation: Z YES [] NO System No.: 21, 63, 64 Quality Classification: Q Structure, System or Component: Emergency Diesel Generators, 4kV System, 480V System

Subject:

Calculation 9000040769 (M-1141) defines the limiting postulated accident that results in the worst case emergency diesel generator (EDG) loading and evaluates single failure criteria relative to EDG loading. In addition, this calculation establishes the design basis maximum steady state load demand for all rotating equipment that loads onto each EDG during the limiting accident analyzed by the DCPP Final Safety Analysis Report Update.

Computer/Electronic Calculation: E] YES Z NO Computer ID Application Name and Version Date of Latest Installation/Validation Test Registered Engineer Stamp: Complete A or B A. Insert PE stamp elow: B. Insert stamp directing to the PE stamp or seal:

Expiratibn Date: \'*.-'\- oc ______________________________

M-1141 Cover Sheet69-20132.Doc 0422.1438

DCPP Form 69-20132 (08/22108) CF3.1D4 Attachment 4 Design Calculation Cover Sheet Page 2 of 3

.Update DCI promptly after approval.

Forward electronic calculation file to CCG for uploading to .EDMS, only, if the calculation is complete and can be used from EDMS.

Calculation No.: 9*40769 RECORD OF REVISIONS Reason for Revision Prepared LBIE LBIE Check LBIE Checked Supervisor Registered Owner's Rev Status No. of Pages By Screen Method* Approval Engineer Acceptance No. per CF3.DID7 Remarks Signature/ Yes/ Yes/ Yes/ PSRC PSRC Signature Signature/ Signature/ Signature/

LAN ID/ No/ No/ No/ Mtg Mtg LAN ID/ LAN ID/ LAN ID/ LAN ID!

Date NA NA NA No. Date Date Date Date Date

[] Yes [X] A N!A N!A N/X]Yes e-q*k N/A 0 F 18 Initial issue.

DDC1 []No [X]No [JB RALO 7 RALO 4/22/09 [ ]N/A [ ]N!A []C 4122/09 4/22/09

[ Yes []Yes []A

[]No []No []B

[]N/A [ N/A []C

[]Yes []Yes []A

[ No []No []B

[]N/A []N/A ]C

[]Yes []Yes []A

[ No []No []B

[]N/A []N/A []C

Check Method: A = Detailed Check B = Alternate Method (note added pages) C Critical Point.Check Input Reference Output Reference Calc/Procedure No. Comments Calc/Procedure No. Comments M-786 Input of ESF Max BHP 15-DC Output ESF Max BHP M-1017 CCWP flows 125-DC Output ESF Max BHP STA-034 SIP/CCP corrected speed STA-027/N-060 SIP/CCP flow rates M-1 141 Cover Sheet69-20132.Doc 0422.1438

CF3.1D4 Attachment 4 DCPP Form 69-20132 (08/22/08) Page 3 of 3 Design Calculation Cover Sheet HVAC 89-34 Fan BHP M-854 AFWP BHP W-829 Misc Pump BHP M-1 141 Cover Sheet69-20132.Doc 0423,1005

Form 69-10430 (08/20/07) TS3.1D2 Attachment 8.1' Page 1 of 2 LBIE Screen - Applicability Determination

1. Proposed Activity/Implementing Document No: Unit: Imp Doc Rev No:

9000040769 - Maximum EDO Mechanical Loading 1 [: 2 1I 11&2 0 Briefly describe what is being changed and why:

calculation defines the limiting postulated accident that results in the worst case emergency diesel generator (EDG) loading and evaluates single failure criteria relative to EDO loading. In addition, this calculation establishes the design basis maximum steady state load demand for all rotating equipment that loads onto each EDO during the limiting accident analyzed by the DCPP'Final Safety Analysis Report Update.

2. Applicability Determination (refer to TS3.1D2, Appendix 7.1 Section 2 for general guidance) Ref. TS3.1D2 Does the proposed activity involve: Appendix 7.1 2.a A change to the Facility/ISFSI Operating License (OL), Environmental Protection EL Y MN Block 2.a Plan (EPP) or Technical Specifications (TS)?

2.b A change to the Quality Assurance Program? ElY 0 N Block 2.b 2.c A change to the Security Plan? El Y ED N Block 2.c 2.d A change to the Emergency Plan? El Y 0 N Block 2.d 2.e A change to the Inservice Testing (IST) Program Plan? El Y 0 N Block 2.e 2.f A change to the Inservice Inspection (ISI) Program Plan? El Y 0 N Block 2.f 2.g A change to the Fire Protection Program? El Y N N Block 2.g 2.h A noncompliance with the Environmental Protection Plan or may create a situation El Y M N Block 2.h adverse to the environment?

2.i A change to the FSARU (including documents incorporated by reference) excluded ElY 0 N Block 2.i from the requirement to perform a 50.59/72.48 review?

2.j Maintenance that restoresSSCs to their original or newly approved designed El Y M N Block 2.j condition? (Check "No" if activity is related to ISFSl.)

2.k A temporary alteration supporting maintenance that will be in effect during at-power D Y 0 N Block 2.k operations for 90 days or less? (Check "No" if activity is related to ISFSI.)

2.1 Managerial or administrative procedure/process controlled under 10 CFR 50, App. B? ED Y 0 N Block 2.1 2.m Regulatory commitment not covered by another regulatory based change process? D] Y 0 N Block 2.m 2.n An impact to other plant specific programs (e.g., the ODCM) that are controlled by DY N N Block 2.n regulations, the OL, orTS?

3. Applicability Determination

Conclusions:

D A 10 CFR 50.59 or 72.48 screen is NOT required because ALL aspects of the activity are controlled by one or more of the processes listed above, or have been approved by the NRC, or covered in full in another LBIE review.

[ A 10 CFR 50.59 or 72.48 screen will be completed because some or all the aspects of the activity are not controlled by any of the processes listed above or cannot be exempted from the 10 CFR 50.59/72.48 screen.

4. Does the proposed activity involve a change to the plant where the change requires a safety assessment? I El Y Z N

5. Remarks: (Use this section to provide justification of determination in step 2 as needed.)

Form 69-10430 (08/20/07) TS3.1D2 Attachment 8.1 LBIE Screen - Applicability Determination Page 2 of 2 Refer to TS3.1D2, Section 6, for instructions on handling completed forms.

Form 69-21097 (08/20/07) TS3.1D2 Attachment 8.9 Page I of 2 LBIE Screen - 10 CFR 50.59/72.48 Screen

1. Proposed Activity/Implementing Document No: Unit: Imp Doc Rev No:

9000040769 - Maximum EDO Mechanical Loading ElI 12 E N1&2 0 Briefly describe what is being changed and why:

Initial issuance of this design calculation defines the limiting postulated accident that results in the worst case emergency diesel generator (EDG) loading and evaluates single failure criteria relative to EDG loading. In addition, this calculation establishes the design basis maximum steady state load demand for all rotating equipment that loads onto each EDG during the limiting accident analyzed by the DCPP Final Safety Analysis Report Update (FSARU).

2. The screen performed is for (check one or both as applicable):

LI 10 CFR 50.59 (Facility Operating License)

Mi 10 CFR 72.48 (Independent Spent Fuel Storage Installation (ISFSI)

Identify SSC(s) described in the FSARU (including subcomponents) and the.applicable section(s) in the FSARU affected by the proposed activity (use remarks section for overflow):

Emergency loads supplied by EDGS (Section 8.3.1.1.10) and emergency load listings (Tables 8.3-5 and 8.3-6)

Describe the design function(s) of the above identified SSC(s) directly or indirectly affected by this proposed activity (use remarks section for overflow):

M-1 141 defines mechanical load BHP requirements listed in Tables 8.3-5 and 8.3-6. This calc may indirectly affect these v~

. it m~v h* .*p~d tn nrnvidpA inni Ittn 1.5-DC* *nd 125-DC, whinh are the. orinin nf the.R F*ARl I tablh.*

Ref. TS3.1D2 Determine whether the proposed activity/change, test, or experiment (CTE): Appendix 7.8 2.a Involves a change to an SSC that adversely affects an FSARU described design LD Y [K N Block 2.a function?

2.b Involves a change to a procedure that adversely affects how FSARU described LI Y O N Block 2.b SSC design functions are performed or controlled?

2.c Involves a change that adversely revises or replaces an FSARU described LD Y [ N Block Z.c evaluation methodology that is used in establishing the design bases or that is used in the safety analyses?

2.d Involves a test or experiment not described in the FSARU, where an SSC is utilized EL Y 0 N Block 2.d or controlled in a manner that is outside the reference bounds of the design for that SSC or is inconsistent with analyses or descriptions in the FSARU?

2.e Relies on a vendor 10 CFR 50.59 or 72.48 evaluation that has NOT been reviewed EL Y 0 N Block 2.e by the PSRC?

3. Justification, References, and Materials:

3.a Justification for the 10 CFR 50.59/72.48 screen determinations in steps 2.a thru 2.e:

2.a - This calculation .does not change or alter the EDGs or any other electrical system SSCs as it only compiles maximum rotating equipment load requirements based on existing design inputs. Some of the affected loads listed in Tables 8.3-5 and 8.3-6 may increase or decrease based on the use of the results from this calculation in 15-DC and 125-DC. However, EDG loading margin impacts will be determined via 15-DC and 125-DC or equivalent calculations which will provide the basis for the appropriate FSARU changes.

2.b - The results of the calculation do change or impact any SSC design functions since it only list loads from existing design inputs and does not directly impact EDG loading margins.

2.c - The affected FSARU tables are load listings that do not involve or describe an evaluation methodology.

Therefore, this design calculation does not impact or alter any FSARU described evaluation methodology.

2.d - This calculation does not involve any change in plant equipment, testing or operation.

2.e - There have been no vendor safety evaluations performed and none are required.

3.b List references used in this screen:

None 3.c List all materials attached to this screen:

Form 69-21097 (08/20/07) TS3.1D2 Attachment 8.9 Page 2 of 2 LBIE Screen - 10 CFR 50.59/72.48 Screen None 10 CFR 50.59/72.48 Screen

Conclusions:

0 A 10 CFR 50.59/72.48 evaluation is NOT required because ALL answers to steps 2.a thru. 2.e are NO.

El A 10 CFR 50.59172.48 evaluation is to be completed because one or more of the answers in steps 2.a thru. 2.e 1 4. are YES, Complete LBIE Sections 0. 1. and 3.

5. Remarks (use this section to provide additional information as needed):

None Preparer Signature: (Qual: TLBIE Date: Print Last Name:

4/22/09 Christensen Reviewer Signature: (Qual: TLBIE) Date: Print Last Name:

4/22/09 Lovell Refer to TS3.1D2, Section 6, for instructions on handling completed forms.

Pacific Gas and Electric Company Engineering - Calculation Sheet CALC. NO. .9000040769 (M-1141)

Project: Diablo Canyon Unit ( )1 ( )2 (X )1&2 REV. NO. 0 SHEET NO 1 of 18 SUBJECT Maximum EDG Mechanical Loading Record of Revision:

Rev. 0 - Initial issue.

1. Purpose Consistent with the requirements of 10 CFR 50, Appendix A, General Design Criteria (GDC) 17, this design calculation defines the limiting postulated accident that results in the worst case emergency diesel generator (EDG) loading and evaluates single failure criteria relative to EDG loading. In addition, this calculation establishes the design basis maximum steady state load demand for all rotating equipment that load onto each EDG during the limiting accident analyzed by the DCPP Final Safety Analysis Report Update (FSARU).

2. Background A non cited violation (NCV) of 10 CFR 50, Appendix B, Criterion III was issued in DCPP NRC Inspection Report 2008005 (Reference 12.1.1)for failing to maintain adequate design control measures for the EDGs. The NCV identified, in part, that DCPP did not analyze for all postulated accidents as required by GDC 17 nor assume a single limiting failure as required by GDC 17. This calculation will address these GDC 17 issues as part of the corrective actions for the apparent cause evaluation initiated for the NCV per Order 60010397. In addition, for the limiting FSARU accident, this calculation will determine the maximum steady state BHP requirement for each of the pumps and fans that load onto each EDG.

3. Assumptions 3.1. The highest BHP demand for each pump is assumed for the limiting accident regardless of the relative transient time at which the highest demand occurs.

3.2. For single pump operation, the highest BHP demand is used. -For parallel pump operation for those pumps with shared discharge flow paths, lower BHP demands are used as appropriate.

3.3. 'For each set of pumps (e.g., SIPs 1-1, 1-2, 2-1 and 2-2), the vendor pump curve with the maximum BHP data and/or typical data will be used to conservatively determine maximum BHP demand for single and parallel pump operation for each pump in the set.

Pacific Gas and Electric Company Engineering - Calculation Sheet CALC. NO. 9000040769 (M-1141_)

Project: Diablo Canyon Unit ( )1 ( )2 ( X )1&2 REV. NO. 0 SHEET NO 2 of 18 SUBJECT Maximum EDG Mechanical Loading 3.4. The scope of this calculation only includes normal steady state load demand from rotating equipment that is expected to operate during the limiting postulated accident. This calculation does not consider or include momentary/brief loads (e.g., automatic valve respositioning following a safety injection signal), elevated equipment starting loads, or manually started equipment loads.

4. Design Inputs 4.1. All BHP values are rated and/or pump runout values from Reference 12.1.2 except as noted.

4.2. The maximum ECCS injection profile CCP flow rates during parallel pump operation are 477.2 gpm and 477.6 gpm from Reference 12.1.3, Attachment 1B, pages 9 and 10.

4.3. The maximum CCP BHP speed corrected values are 637 BHP for parallel pump operation and 630 BHP for single pump operation from Reference 12.1.4.

4.4. The maximum CCP flow rate is less than or equal to 560 gpm per Reference 12.1.5, page 15.

4.5. The maximum ECCS injection profile SIP flow rates during parallel pump operation are 503.1 gpm and 508.8 gpm from Reference 12.1.3, Attachment 1B, pages 11 and 12.

4.6. The maximum SIP BHP speed uncorrected values are 383 BHP for parallel pump operation and 394 BHP for single pump operation from Reference 12.1.6.

4.7. The average SIP speed correction data are from Reference. 12.1.7, sheet 6.

4.8. The maximum SIP flow rate is less than or equal to 675 gpm per Reference 12.1.5, page 16.

4.9. From full flow CCWP performance testing, maximum CCW heat exchanger flow rates are 10,823 gpm and 10,836 gpm per Reference 12.1.8, page ii.

5. Methodology 5.1. FSARU accident resulting in maximum steady state EDG loading

Pacific Gas and Electric Company Engineering -Calculation Sheet GALe. NO. 9000040769 (M-1 141)

Project: Diablo Canyon Unit ( )1 ( )2 (X)1&2 REV. NO. 0 SHEET NO 3 of 18 SUBJECT Maximum EDG Mechanical.Loading The FSARU analyzed event that maximizes the number and magnitude of EDG loads requires the following concurrent conditions:

A) Safety Injection, Signal (SIS) initiation which starts all emergency safeguards features (ESF) loads except the containment spray pumps B) Phase B (high-high containment pressure) isolation signal which starts the containment spray pumps C) Loss of offsite power (LOOP) which initiates ESF load transfer to the EDGs D) Minimum reactor coolant system (RCS) pressure which requires all ECCS pumps (including RHR) to inject at the maximum flow rates The only FSARU analyzed events that will result in sufficient mass and energy release to containment to result in a Phase B isolation are large main feedwater system breaks (MFLB), main steam system breaks (MSLB), or RCS large break Loss of Coolant Accidents (LBLOCA). Table 5-1 summarizes the relative system pressure response of the RCS, steam generators (SGs), and containment for these accidents and the resulting load demand for the associated ESF pump components.

Table 5 Comparison of FSARU Accident ESF Load Demands FSARU Accident System Response/ ESF LBLOCA MSLB MFLB Component (Press)

RCS Pressure 4- 1' SG Pressure 1 SG4 1 SGJ-3 SG-- 3 SG" Containment Pressure 1" " -- _

CCP (RCS) t t ->

SIP (RCS) t -+ -*

RHRP (RCS) I 4. 4-MDAFWP (SG) - 1 SG 1 SG T 3 SG -4 3 SG -4 CSP (Cont.) -- -

CFCU (Cont.) 1 1 "

1 = Maximum -> = Nominal 4I = Minimum All of these accidents will result in the same relative containment pressure response and load demand on the CS pumps and CFCUs. Although large secondary side breaks will result in significant SG depressurization and higher AFW flow, the RCS pressure remains above the SI pump discharge pressure and well above the RHR

Pacific Gas and Electric Company CALC. NO. 9000040769 (M-1141)

Engineering - Calculation Sheet Project: Diablo Canyon Unit ( )1 ( )2 ( X )1&2 REV. NO. 0 SHEET NO 4 of 18 SUBJECT Maximum EDG Mechanical Loading pump shutoff head. Although the large RCS breaks do not significantly depressurize the SGs, these breaks will result in a complete depressurization of the RCS and will result in all ECCS pumps injecting at the maximum flow rate. The minimum RCS pressure occurs following the largest analyzed LBLOCA as documented in FSARU Section 15.4.1. Each of these FSARU accidents including the LBLOCA analysis assume that a LOOP occurs and all EDGs load. Based on the above, the LBLOCA is the limiting FSARU analyzed event resulting in the maximum steady state EDG loading.

The theoretical maximum steady state loading for the EDGs would occur when the maximum number of electrical loads that can be transferred to the EDGs are simultaneously being powered by the EDGs and each load is operating at its maximum capacity. This loading configuration bounds all postulated events analyzed in the FSARU as Table 5-1 shows that it is not possible for all ESF components to experience runout (or near runout) conditions during any single accident.

5.2. BHP requirements for parallel and single pump operation during LBLOCA with LOOP As discussed in Section 5.1, the theoretical maximum steady state loading for the EDGs would occur when the maximum number of loads that can be transferred to the EDGs are simultaneously being powered by the EDGs and each load is operating at its maximum capacity. This theoretical loading includes the assumption that each pump is operating at maximum load demand which occurs at pump runout. However, since the ECCS pumps and other ESF pumps operate in parallel through common discharge flow paths (in which system resistances are designed to balance pump performance and prevent excessive runout conditions), the flow from each pump is less than runout flow. Thus, the total load demand for two pumps operating in parallel is less than the total load demand for both pumps operating independently at runout. This conclusion does not apply for some pumps in which BHP drops off at high flow rates.

5.3. Single failure evaluation for EDG loading The limiting failure in the context of this calculation is the single failure that maximizes the steady state demand on each EDG. As discussed in Section 5.2, the load demand for an ESF pump operating in parallel with another is normally maximized if the former is operating independently. Thus, the worst case single failure for each unit's EDGs is the assume failure of one EDG and the resultant load increase for each pair of operating EDGs. The total load increase on each of the two operating EDGs is the result of the collective load demand increases due to each ESF pump going to its maximum operating condition due to the loss of power

Pacific Gas and Electric Company CALC. NO. 9000040769 (M-1 141)

Enginee'-ing - Calculation Sheet CALC._NO._*_9000040 __9_(M-1141)

Project: Diablo CanyonUnit ( )1 (.)2 (X)1&2 REV. NO. 0 SHEET NO 5 of 18 SUBJECT. Maximum EDG Mechanical Loading to its counterpart on the failed EDG.

6. Acceptance Criteria None. This calculation defines the design basis maximum steady state load demand for all rotating equipment components on each EDG of each unit assuming all EDGs are operating, and assuming two EDGs are operating and the third EDG fails for all combinations.

7. Calculation 7.1. BHP requirements for parallel and single pump operation during LBLOCA with LOOP All BHP values used in this calculation are from Design Input 4.1 except as determined below.

CCPs - parallel pump operation From Design Input 4.2, the maximum calculated CCP flow rates during parallel pump operation are 477.2 gpm and 477.6 gpm. Using a rounded up value of 478 gpm in the DCPP speed corrected data of the CCP vendor pump performance curve data with the maximum BHP curve (CCP 1-1) yields a value of 637 BHP (Design Input 4.3). This value is used for each CCP in parallel pump operation in both units.

CCPs - sinqle pump operation From Design Input 4.4, maximum CCP flow rate is less than or equal to 560 gpm. Using a rounded up value of 560 gpm in the DCPP speed corrected data in the CCP 1-1 vendor pump performance curve data yields a value of 630 BHP (Design Input 4.3). This value is used for each CCP in single pump operation in both units.

SIPs - parallel pump operation From Design Input 4.5, the maximum calculated SIP flow rates during parallel pump operation are 503.1 gpm and 508.8 gpm. Using a rounded up value of 509 gpm in the SIP vendor pump performance curve with the maximum BHP curve (SIP 2-2) yields a value of 383 BHP (Design Input 4.6). Using 509 gpm in the SIP speed versus flow data from Design Input 4.7 yields a corrected speed of 3568 RPM. Applying the pump affinity rule to the SIP 2-2 vendor pump performance curve reference speed of 3570 RPM (typical for both

Pacific Gas and Electric Company Engineering - Calculation Sheet CALC. NO. 90_1_00040769 (M-1_141)

Project: Diablo Canyon Unit ( )1 ( )2 ( X )1&2 REV. NO. 0 SHEET NO 6 of 18 SUBJECT Maximum EDG Mechanical Loading unit's SIPs) with the corrected speed of 3568 RPM:

Corrected BHP = 383 * (3568/3570)^3 = 382.4 This value is rounded up to 383 BHP and is used for each SIP in parallel pump operation in both units.

SIPs - single pump operation From Design Input 4.8, maximum SIP flow rate is less than or equal to 675 gpm. Since the SIP 2-2 vendor pump performance curve BHP values peak at 600 gpm and drops off slightly above that flow rate, the peak value of 394 BHP (Design Input 4.6) is used. Using 600 gpm in the SIP speed versus flow data from Design Input 4.7 yields a corrected speed of 3566 RPM.

Applying the pump affinity rule to the SIP 2-2 vendor pump performance curve reference speed of 3570 RPM with the corrected speed of 3566 RPM:

Corrected BHP = 394 * (3566/3570)A3 = 392.7 BHP This value is rounded up to 393 BHP and is used for each SIP in single pump operation in both units.

2 CCWPs with 2 CCW HXs From Design Input 4.9 for the 100% pump performance case with all three CCWPs providing both CCW Heat Exchangers and Header C (CCW Flow Balance #12), the average of the heat exchanger flows is (10,823/10,836)/2 =

10,830 gpm. Using this value in the CCWP 2-1 vendor curve yields a value of 420 BHP. Since the maximum BHP from the CCWP 2-1 curve is bounded by 425 and this curve is typical for all CCWP vendor curves, 425 BHP is assumed for both units and is sufficiently conservative to encompass speed correction.

7.2. Single failure evaluation for EDG loading Tables 7-1 and 7-2 lists the mechanical loads for each EDGin Unit 1 and Unit 2, respectively, based on its associated vital 4kV bus. Tables 7-3, 7-4 and 7-5 list the loads and loading totals for each of the unaffected Unit 1 4kV vital buses assuming a failure of the associated EDG for Bus F, Bus G, and Bus H, respectively. Tables 7-6, 7-7 and 7-8 list the loads for each of the unaffected Unit 2 4kV vital buses assuming a failure of the associated EDG for Bus F, Bus G, and Bus H, respectively.

Pacific Gas and Electric Company Engineering - Calculation Sheet CAM NO. 9000040769 (M-1 141)

Project: Diablo Canyon Unit ( )1 ( )2 (X)1&2 REV. NO. 0 SHEET NO 7 of 18

-SUBJECT Maximum EDG Mechanical Loading

8. Margin Assessment There is no margin impact since this calculation establishes EDG loading design basis and therefore does not impact any margin.

9. Results Taking the highest load total from pach bus from Tables 7-1, 7-3, 7-4 and 7-5 yields the maximum Unit I mechanical loading total per vital 4kV bus as summarized in Table 9-1. The similar results for Unit 2 based on the highest load total from each bus from Tables 7-2, 7-6, 7-7 and 7-8 are presented in Table 9-2.

10. Conclusion The maximum EDG mechanical loading for Unit 1 and for Unit 2 occurs on Bus F assuming a failure of Bus G. The maximum load is 3095 BHP for each unit.

11. Impact Evaluation This calculation may be used to provide maximum steady state rotating equipment load demand input to electrical calculations (e.g., References 12.2.,1 and 12.2.2).

12. References 12.1. Input 12.1.1. DCPP NRC Inspection Report 2008005, dated February 6, 2009.

12.1.2. Calculation M-786, "EDG Fuel Oil Storage," Revision 16.

12.1.3. Calculation STA-027, "Best Estimate ECCS Flow Profiles,"

Revision 0.

12.1.4. CCP 1-1 Performance Curve, Diablo Canyon 2 /" RLIJ pump performance data dated 12/8/08, HydroAire Order No. NQ5648, PO

136834.

12.1.5. Calculation N-060, "ECCS STV V-15 Flow Limits," Revision 1.

Pacific Gas and Electric Company C 9000040769 (M-1 141)

Engineering - Calculation Sheet CALC. NO.

Project: Diablo Canyon Unit ( )1 ( )2 (X )1&2 REV. NO. 0 SHEET NO 8 of 18 SUBJECT Maximum EDG Mechanical Loading 12.1.6. Diablo Canyon Drawing DC663216-127-15, SIP 2-2 Performance Curve 12A1.7. STA-034, "SI Pump and Charging Pufmp Composite Curves,"

Revision 0.

12.1.8. Calculation M-1 017, "CCW Flow Balancing," Revision 3.

12.2. Output 12.2.1. Calculation 15-DC, "(Unit 1) Diesel Generator Loading for 4160V Vital Bus Loads."

12.2.2. Calculation 125-DC, "(Unit 2) Diesel Generator Loading for 4160V Vital Bus Loads."

Pacific Gas and Electric Company Engineering - Calculation Sheet CALC. NO. 9000040769 (M-1 141)

Project: Diablo CanyonUnit( )1 ( )2 (X)1&2 REV. NO.

0 SHEET NO 9 of 18 SUBJECT Maximum EDG Mechanical Loading Tables TABLE 7 Unit I Vital 4kV Maximum Mechanical Loading (No EDG/Bus Failures)

Load per Component Maximum Load per Bus (BHP)

Component (BHP) BusF I Bus I IG Centrifugal Charging Pumps 637 637 637 Safety Injection Pumps 383 383 383 Containment Spray Pumps 435 440 Residual Heat Removal Pumps 410 424 Containment Fan Coolers 103 206 206 103 Component Cooling Water 425 425 425 425 Pumps Auxiliary Saltwater Pumps 465 465 465 Auxiliary Feedwater Pumps 600 600 600 Exhaust Fans (Auxiliary Bldg. 160 160 160 including Fuel Handling Area)

Supply Fans (vital dc and low- 50 50 50 voltage ac equipment)

Exhaust Fans (vital dc and low- 50 50 50 voltage ac equipment)

Exhaust Fans (Auxiliary 1 1 1 Saltwater Pump Rooms)

Fuel Handling Area Exhausts 75 75 75 (Iodine Removal)

Supply Fans (Fuel Handling 25, 25 25 Area) - Fans S1 & S2 Supply Fans (Auxiliary Bldg.) 60 60 60 Fans S31& S32 Supply Fans (4kV Switchgear 1.5 1.5 1.5 1.5 Rooms)

Main Turbine-Generator 60 60 Lube Oil Pump" Auxiliary Lube Oil Pumps for 0.5 0.5 0.5 0.5 Component Cooling Water Pumps Feedwater Pump Turning 1 1 1 Gears Makeup Water Transfer Pumps 31 31 31 Primary Water Makeup Pumps 15 15 15 Boric Acid Transfer Pumps 13 13 13 Diesel Fuel Transfer Pumps 5 5 5 Charging Pump Auxiliary 2 2 2 Lube Oil Pumps Containment Air and Gas 1.5 1.5 Radiation Monitor Pump Total Load per Bus (BHP) 3085 2794 2834

Pacific Gas and Electric Company Engineering - Calculation Sheet CALC. NO. 9000040769 (M-1_141)

Project: Diablo CanyonUnit( )1 ( )2 (X)1&2 REV. NO. 0 SHEET NO 10 of 18 SUBJECT Maximum EDG Mechanical Loading TABLE 7 Unit 2 Vital 4kV Maximum Mechanical Loading (No EDG/Bus Failures)

Load per component Maximum Load per Bus (BHP)

Component (BHP) Bus F Bus G I I Bus H I Centrifugal Charging Pumps 637 637 637 Safety Injection Pumps 383 383 383 Containment Spray Pumps 440 440 440 Residual Heat Removal Pumps 413 421 Containment Fan Coolers 103 206 206 103 Component Cooling Water 425 425 425 425 Pumps Auxiliary Saltwater Pumps 465 465 465 Auxiliary Feedwater Pumps 600 600 600 Exhaust Fans (Auxiliary Bldg. 160 160 160 including Fuel Handling Area)

Supply Fans (vital dc and low- 50 50 50 voltage ac equipment)

Exhaust Fans (vital dc and low- 50 50 50 voltage ac equipment)

Exhaust Fans (Auxiliary 1 1 1 Saltwater Pump Rooms)

Fuel Handling Area Exhausts 75 75 75 (Iodine Removal)

Supply Fans (Fuel Handling 25 25 25 Area) - Fans S1 & S2 Supply Fans (Auxiliary Bldg.) 60 60 60 Fanf-S 31-&-$32 Supply Fans (4kV Switchgear 1.5 1.5 1.5 1.5 Rooms)

Main Turbine-Generator 60 60 Lube Oil Pump Auxiliary Lube Oil Pumps for 0.5 0.5 0.5 0.5 Component Cooling Water Pumps Feedwater Pump Turning 1 1 1 Gears Primary Water Makeup Pumps 15 15 15 Boric Acid Transfer Pumps 13 13 13 Diesel Fuel Transfer Pumps 5 5 5 Charging Pump Auxiliary 2 2 2 Lube Oil Pumps Containment Air and Gas 1.5 1.5 Radiation Monitor Pump Total Load per Bus (BHP) 3085 2771 2800

Pacific Gas and Electric Company Engineering - Calculation Sheet CALC. NO. 9000040769 (M-1 141)

Project: Diablo Canyon Unit ( )1 ( )2 (X )1&2 REV. NO. 0 SHEET NO 11 of 18 SUBJECT Maximum EDG Mechanical Loading TABLE 7 Unit I Vital 4kV Loading with Bus F Failure Load per component Maximum Load per Bus BHP)

Component (BHP) Bus F L Bus G IIBus H Centrifugal Charging Pumps 630 0 630 Safety Injection Pumps 393 0 393 Containment Spray Pumps 435 440 Residual Heat Removal Pumps 410 424 Containment Fan Coolers 103 0 206 103 Component Cooling Water 425 0 425 425 Pumps Auxiliary Saltwater Pumps 465 0 465 Auxiliary Feedwater Pumps 600 0 600 Exhaust Fans (Auxiliary Bldg. 160 .0 160 including Fuel Handling Area)

Supply Fans (vital dc and low- 50 0 50 voltage ac equipment)

Exhaust Fans (vital dc and low- 50 0 50 voltage ac equipment)

Exhaust Fans (Auxiliary 1 0 1 Saltwater Pump Rooms) 0 Fuel Handling Area Exhausts 75 75 (Iodine Removal)

Supply Fans (Fuel Handling 25 25 25 Area) - Fans S1 & S2 Supply Fans (Auxiliary Bldg.) 60 60 60 Fans S31& S32 Supply Fans (4kV Switchgear 1.5 0 1.5 1.5 Rooms)

Main Turbine-Generator 60 60 Lube Oil Pump Auxiliary Lube Oil Pumps for 0.5 0 0.5 0.5 Component Cooling Water Pumps Feedwater Pump Turning I 0 1 Gears Makeup Water Transfer Pumps 31 31 31 Primary Water Makeup Pumps 15 0 15 Boric Acid Transfer Pumps 13 0 13 Diesel Fuel Transfer Pumps 5 5 5 Charging Pump Auxiliary 2 0 2 Lube Oil Pumps Containment Air and Gas 1.5 1.5 Radiation Monitor Pump Total Load per Bus (BHP) 0 2787 2844

Pacific Gas and Electric Company Engineering - Calculation Sheet CALC. NO. 9000040769(M-1141)

Project: Diablo Canyon Unit( )1 ( )2 (X)1&2 HE0 REV. NO.

SHEET NO 12 of 18 SUBJECT Maximum EDG Mechanical Loading TABLE 7 Unit I Vital 4kV Loading with Bus G Failure Load per component Maximum Load per Bus (BHP)

Component (BHP) Bus F I L Bus I Bus H Centrifugal Charging Pumps 630 630 0 Safety Injection Pumps 383 383 383 Containment Spray Pumps 0 440 Residual Heat Removal Pumps 0 424 Containment Fan Coolers 103 206 0 103 Component Cooling Water 425 425 0 425 Pumps Auxiliary Saltwater. Pumps 465 465 0 Auxiliary Feedwater Pumps 600 600 600 Exhaust Fans (Auxiliary Bldg. 160 160 160 including Fuel Handling Area)

Supply Fans (vital dc and low- 50 50 50 voltage ac equipment)

Exhaust Fans (vital dc and low- 50 50 50 voltage ac equipment)

Exhaust Fans (Auxiliary 1 1 0 Saltwater Pump Rooms)

Fuel Handling Area Exhausts 75 75 75 (Iodine Removal)

Supply Fans (Fuel Handling 25 0 25 Area) - Fans S1 & S2 Supply Fans (Auxiliary Bldg.) 60 0 60 Fans $31 & S32 Supply Fans (4kV Switchgear 1.5 1.5 0 1.5 Rooms)

Main Turbine-Generator 60 0 Lube Oil Pump Auxiliary Lube Oil Pumps for 0.5 0.5 0 0.5 Component Cooling Water Pumps Feedwater Pump Turning 1 1 1 Gears Makeup Water Transfer Pumps 31 0 31 Primary Water Makeup Pumps 15 15 0 Boric Acid Transfer Pumps 13 13 0 Diesel Fuel Transfer Pumps 5 0 5 Charging Pump Auxiliary 2 2 0 Lube Oil Pumps Containment Air and Gas 1.5 0 Radiation Monitor Pump Total Load per Bus (BHP) 3078 0 12834

Pacific Gas and Electric CompanyCACNO Engineering - Calculation Sheet ACNO 9000040769 (M-1141)

Proj ect: Diablo Canyon Unit ( 1 ()2 ( X ) 1&2 REV. NO. 0 SHEET NO 13 of 18 SUBJECT Maximum EDG Mechanical Loading TABLE 7 Unit 1 Vital 4kV Loading with Bus H Failure Load per component Maximum Load per Bus (BHP)

Component (BHP) BusIF BusG L Bus Centrifugal Charging Pumps 637 637 637 Safety Injection Pumps 393 393 0 Containment Spray Pumps 435 0 Residual Heat Removal Pumps 410 0 Containment Fan Coolers 103 206 206 0 Component Cooling Water 425 425 425 0 Pumps Auxiliary Saltwater Pumps 465 465 465 Auxiliary Feedwater Pumps 600 600 0 Exhaust Fans (Auxiliary Bldg. 160 160 0 including Fuel Handling Area)

Supply Fans (vital dc and low- 50 50 0 voltage ac equipment)

Exhaust Fans (vital dc and low- 50 50 0 voltage ac equipment)

Exhaust Fans (Auxiliary 1 1 1 Saltwater Pump Rooms)

Fuel Handling Area Exhausts 75 75 0 (Iodine Removal)

Supply Fans (Fuel Handling 25 25 0 Area) - Fans S1 & S2 Supply Fans (Auxiliary Bldg.) 60 60 0 Fans S31 & S32 Supply Fans (4kV Switchgear 1.5 1.5 1.5 0 Rooms)

Main Turbine-Generator 60 60 Lube Oil Pump Auxiliary Lube Oil Pumps for 0.5 0.5 0.5 0 Component Cooling Water Pumps Feedwater Pump Turning 1 1 0 Gears Makeup Water Transfer Pumps 31 31 0 Primary Water Makeup Pumps 15 15 15 Boric Acid Transfer Pumps 13 13 13 Diesel Fuel Transfer Pumps 5 5 0 Charging Pump Auxiliary 2 2 2 Lube Oil Pumps Containment Air and Gas 1.5 1.5 Radiation Monitor Pump Total Load per Bus (BHP) 3095 2794 0

Pacific Gas and Electric Company Engineering - Calculation Sheet CALC. NO. 9000040769 (M-1 141)

Project: Diablo Canyon Unit ( )1 ( )2 (X)1&2 REV. NO. 0 SHEET NO 14 of 18 SUBJECT Maximum EDG Mechanical Loading TABLE 7 Unit 2 Vital 4kV Loading with Bus F Failure Load per component Maximum Load per Bus (BHP)

Component (BHP) F Bus F I I Bus G I Centrifugal Charging Pumps 630 0 630 Safety Injection Pumps 393 0 393 Containment Spray Pumps 440 440 440 Residual Heat Removal Pumps 413 421 Containment Fan Coolers 103 0 206 103 Component Cooling Water 425 0 425 425 Pumps Auxiliary Saltwater Pumps 465 0 465 Auxiliary Feedwater Pumps 600 0 600 Exhaust Fans (Auxiliary Bldg. 160 0 160 including Fuel Handling Area)

Supply Fans (vital dc and low- 50 0 50 voltage ac equipment)

Exhaust Fans (vital dc and low- 50 0 50 voltage ac equipment)

Exhaust Fans (Auxiliary 1 0 1 Saltwater Pump Rooms)

Fuel Handling Area Exhausts 75 0 75 (Iodine Removal)

Supply Fans (Fuel Handling 25 25 25 Area) - Fans SI &S2 Supply Fans (Auxiliary Bldg.) 60 60 60 Fans S31& S32 Supply Fans (4kV Switchgear 1.5 0 1.5 1.5 Rooms)

Main Turbine-Generator 60 60 Lube Oil Pump Auxiliary Lube Oil Pumps for 0.5 0 0.5 0.5 Component Cooling Water Pumps Feedwater Pump Turning 1 0 1 Gears Primary Water Makeup Pumps 15 0 15 Boric Acid Transfer Pumps 13 0 13 Diesel Fuel Transfer Pumps 5 5 5 Charging Pump Auxiliary 2 0 2 Lube Oil Pumps Containment Air and Gas 1.5 1.5 Radiation Monitor Pump Total Load per Bus (BHP) 0 2764 2810

Pacific Gas and Electric Company 9000040769 (M-1141)

Engineering - Calculation Sheet CALC. NO.

Project: Diablo Canyon Unit ( )1 ( )2 (X )1&2 REV. NO. 0 SHEET NO 15 of 18 SUBJECT Maximum EDG Mechanical Loading TABLE 7 Unit 2 Vital 4kV Loading with Bus G Failure Load per /

component Maximum Load per Bus (BHP)

Component (BHP) I Bus F I Bus G I I Bus H Centrifugal Charging Pumps 630 630 0 Safety Injection Pumps 383 383 383 Containment Spray Pumps 440 0 440 Residual Heat Removal Pumps 0 421 Containment Fan Coolers 103 206 0 103 Component Cooling Water 425 425 0 425 Pumps Auxiliary Saltwater Pumps 465 465 0 Auxiliary Feedwater Pumps 600 600 600 Exhaust Fans (Auxiliary Bldg. 160 160 160 including Fuel Handling Area)

Supply Fans (vital dc and low- 50 50 50 voltage ac equipment)

Exhaust Fans (vital dc and low- 50 50 50 voltage ac equipment)

Exhaust Fans (Auxiliary 1 1 0 Saltwater Pump Rooms)

Fuel Handling Area Exhausts 75 75 75 (Iodine Removal)

Supply Fans (Fuel Handling 25 0 25 Area) - Fans Sl & S2 Supply Fans (Auxiliary Bldg.) 60 0 60 Fans S31 & S32 Supply Fans (4kV Switchgear 1.5 1.5 0 1.5 Rooms)

Main Turbine-Generator 60 0 Lube Oil Pump Auxiliary Lube Oil Pumps for 0.5 0.5 0 0.5 Component Cooling Water Pumps Feedwater Pump Turning 1 1 1 Gears Primary Water Makeup Pumps 15 15 0 Boric Acid Transfer Pumps 13 13 0 Diesel Fuel Transfer Pumps 5 0 .5 Charging Pump Auxiliary 2 2 0 Lube Oil Pumps Containment Air and Gas 1.5 0 Radiation Monitor Pump Total Load per Bus (BHP) 3078 0 2800

Pacific Gas and Engineering Electric Company

- Calculation SheetCACNO CALC. NO. 9000040769 (M-1141)

Project: Diablo Canyon Unit ( )1 ( )2 (X )1&2 REV. NO. 0 SHEET NO 16 of 18 SUBJECT Maximum EDG Mechanical Loading TABLE 7 Unit 2 Vital 4kV Loading with Bus H Failure Load per component Maximum Load per Bus (BHP Component (BHP) Bus F Bus G

'Centrifugal Charging Pumps 637 637 637 Safety Injection Pumps 393 393 0 Containment Spray Pumps 440 440 0 Residual Heat Removal Pumps 413 0 Containment Fan Coolers 103 206 206 0 Component Cooling Water 425 425 425 0 Pumps Auxiliary Saltwater Pumps 465 465 465 Auxiliary Feedwater Pumps 600 600 '0 Exhaust Fans (Auxiliary Bldg. 160 160 0 including Fuel Handling Area)

Supply Fans (vital dc and low- 50 50 0 voltage ac equipment)

Exhaust Fans (vital dc arid low- 50 50 0 voltage ac equipment)

Exhaust Fans (Auxiliary 1 1 1 Saltwater Pump Rooms)

Fuel Handling Area Exhausts 75 75 0 (Iodine Removal)

Supply Fans (Fuel Handling, 25 25 0 Area) - Fans S1 & S2 Supply Fans (Auxiliary Bldg.) 60 60 0 Fans S31& S32 Supply Fans (4kV Switchgear 1.5 1.5 1.5 0 Rooms)

Main Turbine-Generator 60 60 Lube Oil Pump Auxiliary Lube Oil Pumps for 0.5 0.5 0.5 0 Component Cooling Water Pumps Feedwater Pump Turning I 1 0 Gears Primary Water Makeup Pumps 15 15 15 Boric Acid Transfer Pumps 13 13 13 Diesel Fuel Transfer Pumps 5 5 0 Charging Pump Auxiliary 2 2 2 Lube Oil Pumps Containment Air and Gas 1.5 1.5 Radiation Monitor Pump Total Load per Bus (BHP) 3095 27710

Pacific Gas and Electric Company CALO. NO. 9000040769 (M-1 141)

Engineering - Calculation Sheet Project: Diablo Canyon Unit ( )1 ( )2 (X)1&2 REV. NO. 0 SHEET NO 17 of 18 SUBJECT Maximum EDG Mechanical Loading Table 9 Unit I Maximum 4kV Loading Load per component Maximum Load per Bus.(BHP)

Component. (BHP) BusF II BusG H7I Centrifugal Charging Pumps 637 637 637 Safety Injection Pumps 393 393 393 Containment Spray Pumps 435 440 Residual Heat Removal Pumps 410' 424 Containment Fan Coolers 103 206 206 103 Component Cooling Water 425 425 425 425 Pumps Auxiliary Saltwater Pumps 465 465 465 Auxiliary Feedwater Pumps 600 600 600 Exhaust Fans (Auxiliary Bldg. 160 160 160 including Fuel Handling Area)

Supply Fans (vital dc and low- 50 50 50 voltage ac equipment)

Exhaust Fans (vital dc and low- 50 50 50 voltage ac equipment)

Exhaust Fans (Auxiliary 1 1 1 Saltwater Pump Rooms)

Fuel Handling Area Exhausts 75 75 75

. (Iodine Removal)

Supply Fans (Fuel Handling 25 25 25 Area) - Fans S1 & S2 Supply Fans (Auxiliary Bldg.) 60 60 60 Fans S31 & S32 Supply Fans (4kV Switchgear 1.5 1.5 1.5 1.5 Rooms)

Main Turbine-Generator 60 60 Lube Oil Pump Auxiliary Lube Oil Pumps for 0.5 0.5 0.5 0.5 Component Cooling Water Pumps Feedwater Pump Turning 1 1 1 Gears Makeup Water Transfer Pumps 31 31 31 Primary Water Makeup Pumps 15 15 15 Boric Acid Transfer Pumps 13 13 13 Diesel Fuel Transfer Pumps 5 5 5 Charging Pump Auxiliary 2 2 2 Lube Oil Pumps Containment Air and Gas 1.5 1.5 Radiation Monitor Pump Total Load per Bus (BHP) 3095 2794 2844

Pacific Gas and Electric Company Engineering - Calculation Sheet OALC. NO. 9000040769 (M-1141)

Project: Diablo CanyonUnit ( )1 ( )2 (X)1&2 REV. NO. 0 SHEET NO .18 of 18 SUBJECT Maximum EDG Mechanical Loading Table 9 Unit 2 Maximum 4kV Loading Load per component Maximum Load per Bus (BHP)

Component (BHP) Bus F I I G I I H Centrifugal Charging Pumps 630 637 637 Safety Injection Pumps 393 393 393 Containment Spray Pumps 440 440 440 Residual Heat Removal Pumps 413 421 Containment Fan Coolers 103 206 206 103 Component Cooling Water 425 Pumps 425 425 425 Auxiliary Saltwater Pumps 465 465 .465 Auxiliary Feedwater Pumps 600 600 600 Exhaust Fans (Auxiliary Bldg. 160 160 160 including Fuel Handling Area)

Supply Fans (vital dc and low- 50 50 50 voltage ac equipment)

Exhaust Fans (vital dc and low- 50 50 50 voltage ac equipment)

Exhaust Fans (Auxiliary 1 1 1 Saltwater Pump Rooms)

Fuel Handling Area Exhausts 75 ,75 75 (Iodine Removal)

Supply Fans (Fuel Handling 25 25 25 Area) - Fans S1 &S2 Supply Fans (Auxiliary Bldg.) 60 60 60 Fans S31& S32 Supply Fans (4kV Switchgear 1.5 1.5 1.5 1.5 Rooms)

Main Turbine-Generator 60 60 Lube Oil Pump Auxiliary Lube Oil Pumps for 0.5 0.5 0.5 0.5 Component Cooling Water Pumps Feedwater Pump Turning 1 1 1 Gears Primary Water Makeup Pumps 15 15 15 Boric Acid Transfer Pumps 13 13 13 Diesel Fuel Transfer Pumps 5 5 5 Charging Pump Auxiliary 2 2 2 Lube Oil Pumps Containment Air and Gas 1.5 1.5 Radiation Monitor Pump Total Load per Bus (BHP) 3095 2771 2810

DCL-10-018, License Amendment Request 10-01, Revision to Technical Specification 3.8.1, AC Sources - Operating.

Contents

Text

Dear Commissioners and Staff:

Enclosure:

SUMMARY

SUMMARY

Subject:

Conclusions:

Description:

Conclusions:

2.0 BACKGROUND

10.0 CONCLUSION

12.0 REFERENCES

Subject:

Conclusions:

Conclusions:

Navigation menu

DCL-10-018, License Amendment Request 10-01, Revision to Technical Specification 3.8.1, AC Sources - Operating.

Text

Dear Commissioners and Staff:

Enclosure:

SUMMARY

SUMMARY

Subject:

Conclusions:

Description:

Conclusions:

2.0 BACKGROUND

10.0 CONCLUSION

12.0 REFERENCES

Subject:

Conclusions:

Conclusions:

Navigation menu

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