ML070440046

Proposed Change Number (PCN) - 574 Degraded Voltage Setpoints

ML070440046
Person / Time
Site:	San Onofre
Issue date:	02/08/2007
From:	Katz B Southern California Edison Co
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
PCN 574
Download: ML070440046 (88)

Text

SSOTHERN CALIFORNIA Brian Katz j

EVice President An EDISON INTERNATIONAL Company February 8, 2007 U. S. Nuclear Regulatory Commission Attention: Document Control Desk Washington D.C. 20555

Subject:

San Onofre Nuclear Generating Station, Units 2 and 3 Docket Nos. 50-361 and 50-362 Proposed Change Number (PCN) - 574 Degraded Voltage Setpoints

References:

1.

Letter from Brian Katz (SCE) to Document Control Desk (NRC), dated May 27, 2005,

Subject:

"San Onofre Nuclear Generating Station, Units 2 and 3, Docket Nos.

50-361 and 50-362, Proposed Change Number (PCN) 561, Degraded Voltage Setpoints."

2.

Letter from B. Pham (NRC) to Harold B. Ray (SCE), dated July 1, 2005,

Subject:

San Onofre Nuclear Generating Station, Units 2 and 3 - Issuance of Amendments on Degraded Voltage Setpoints (TAC Nos. MC7190 and MC7191)

Dear Sir or Madam:

Pursuant to 10 CFR 50.90, Southern California Edison (SCE) hereby requests the following amendments to operating licenses NPF-10 and NPF-15 for San Onofre Nuclear Generating Station Units 2 and 3 (SONGS 2&3), respectively. In Technical Specification (TS) 3.3.7, "Diesel Generator (DG) - Undervoltage Start,"

revise Surveillance Requirement (SR) 3.3.7.3.a to lower the allowable value for dropout and raise the allowable value for pickup of the degraded voltage function. In addition, in TS 3.8.1, "AC Sources - Operating," revise SRs 3.8.1.2,

.7,.9,.11,.12,.15,.16,.17,.19, and.20 to lower the allowable minimum DG steady state voltage for the lowered values of the degraded function.

The 2005 changes made to the Class 1 E degraded grid voltage relays made aggressive assumptions in relay performance (References 1 and 2). SONGS completed six months of calibration checks to verify the assumptions in the setpoint calculation would not be exceeded. Subsequently, SCE determined that SONGS 2&3 should be modified to establish a greater operating band while P.O. Box 128 San Clemente, CA 92674-0128 0Df 949-368-9275 Fax 949-368-9881

Document Control Desk February 8, 2007 maintaining adequate conservatism in the relay setting. SCE is modifying the two limiting power feeders to reduce voltage drop which will facilitate lowering the analytical voltage limit.

If these proposed amendments are approved on or after May 1, 2007, SCE is prepared implement the amendments within 60 days.

If you have any questions or require any additional information, please contact Mr. A. E. Scherer at (949) 368-7501.

Sincerely,

Enclosures:

1. Notarized Affidavits

2. Licensee's Evaluation Attachments A. Existing Technical Specification Pages, Unit 2 B. Existing Technical Specification Pages, Unit 3 C. Proposed Technical Specification Pages, Redline and Strikeout, Unit 2 D. Proposed Technical Specification Pages, Redline and Strikeout, Unit 3 E. Proposed Technical Specification Pages, Unit 2 F. Proposed Technical Specification Pages, Unit 3 G. Proposed Bases Pages, Unit 2 (for information only)

H. List of Regulatory Commitments cc:

B. S. Mallett, Regional Administrator, NRC Region IV N. Kalyanam, NRC Project Manager, San Onofre Units 2 and 3 C. C. Osterholtz, NRC Senior Resident Inspector, San Onofre Units 2 and 3 S. Y. Hsu, Department of Health Services, Radiologic Health Branch Page 1 of 2 UNITED STATES OF AMERICA NUCLEAR REGULATORY COMMISSION Application of SOUTHERN CALIFORNIA EDISON COMPANY, ET AL. for a Class 103 License to Acquire, Possess, and Use a Utilization Facility as Part of Unit No. 2 of the San Onofre Nuclear Generating Station

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Docket No. 50-361 Amendment Application No. 248 SOUTHERN CALIFORNIA EDISON COMPANY, ET AL. pursuant to 10 CFR 50.90, hereby submit Amendment Application No. 248. This amendment application consists of Proposed Change Number (PCN)-574 to Facility Operating License NPF-10. PCN-574 is a request to revise Surveillance Requirement (SR) 3.3.7.3.a to lower the allowable value for dropout and raise the allowable value for pickup of the degraded voltage function. This change will also revise SRs 3.8.1.2,.7,.9,.11,.12,.15,.16,.17,.19, and.20 to lower the allowable minimum Diesel Generator (DG) steady state voltage for the lowered values of the degraded function.

State of California County of San Diego Brian Katz, Vie resrdn-t Subscribed and sworn to (ef-afirmed) before me on this I-Ilk day of

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personally known to me or-proved to heasesfatfacto-evidence-to-be the person who appeared before me.

Notary Public DAWN A. FARRELL

-I Mal Commission # 1623105 Notary Public - California San Diego County 1 I My Comm. Expires Nov 20. 2009k Page 2 of 2 UNITED STATES OF AMERICA NUCLEAR REGULATORY COMMISSION Application of SOUTHERN CALIFORNIA EDISON COMPANY, ETAL. for a Class 103 License to Acquire, Possess, and Use a Utilization Facility as Part of Unit No. 3 of the San Onofre Nuclear Generating Station

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Docket No. 50-362

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Amendment Application No. 233 SOUTHERN CALIFORNIA EDISON COMPANY, ET AL. pursuant to 10 CFR 50.90, hereby submit Amendment Application No. 233. This amendment application consists of Proposed Change Number (PCN)-574 to Facility Operating License NPF-15. PCN-574 is a request to revise Surveillance Requirement (SR) 3.3.7.3.a to lower the allowable value for dropout and raise the allowable value for pickup of the degraded voltage function. This change will also revise SRs 3.8.1.2,.7,.9,.11,.12,.15,.16,.17,.19, and.20 to lower the allowable minimum Diesel Generator (DG) steady state voltage for the lowered values of the degraded function.

State of California County of San Diego Brian Katz, Vice Pre nt Subscribed and sworn to (or-affýmed) before me on this 2day of rkY-uoar ui

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J br'IaumJ<x by personally known to me or-pfeved-to-rne-on-the-basis-ef-satsfactory-evidence-to be the person who appeared before me.

Notary Public DAM A. FAMML Com"*don# 1623105 NOWY PtAft - Caftffdo Son DMW Courdy MYCOM-80"NOV20.

ENCLOSURE 2 LICENSEE'S EVALUATION PCN 574 Degraded Voltage Setpoints

4.0 TECHNICAL ANALYSIS

5.0 REGULATORY SAFETY ANALYSIS 5.1 No Significant Hazards Consideration 5.2 Applicable Regulatory Requirements/Criteria

7.0 REFERENCES

Attachments A.

Existing Technical Specification Pages, Unit 2 B.

Existing Technical Specification Pages, Unit 3 C.

Proposed Technical Specification Pages, Redline and Strikeout, Unit 2 D.

Proposed Technical Specification Pages, Redline and Strikeout, Unit 3 E.

Proposed Technical Specification Pages, Unit 2 F.

Proposed Technical Specification Pages, Unit 3 G.

Proposed Bases Pages, Unit 2 (for information only)

H.

List of Regulatory Commitments 1

1.0 INTRODUCTION

This letter is a request to amend Operating Licenses NPF-10 and NPF-15 for San Onofre Nuclear Generating Station Units 2 and 3 (SONGS 2&3),

respectively.

This license amendment request will (1) revise Technical Specification (TS)

Surveillance Requirement (SR) 3.3.7.3.a to lower the allowable value for dropout and raise the allowable value for pickup of the degraded voltage function, and (2) revise TS SR 3.8.1 to lower the Diesel Generator (DG) minimum output voltage due to lower settings for the degraded voltage function.

2.0 PROPOSED CHANGE

Southern California Edison (SCE) is modifying the two limiting power feeders to reduce voltage drop which will facilitate lowering the analytical voltage limit of the 4.16 kV Class 1E bus. This new allowance will be used to widen the operating band of the degraded grid relays.

Currently, SR 3.3.7.3.a, "Degraded Voltage Function," states that the dropout voltage allowable value is > 4123.0 V and that the pickup voltage allowable value is *ý 4144.6 V. This proposed change will revise these allowable values to

>_ 4109.0 V and _* 4153.1 V for dropout and pickup, respectively. These changes are summarized in the following table (the Analytical Limits are also shown for information as well as the existing and proposed Technical Specification Limits):

Item Proposed Existing Analytical Limit Upper 4161.0 V 4161.0 V Technical Max. Pickup A4153.1 V

• 4144.6 V Specification Limit Technical Min. Dropout

>4109.0 V

>4123.0 V Specification Limit Analytical Limit Lower 4 100.0 V 4106.0 V In addition, a footnote will be removed for these allowable values which stated, "Dropout and pickup values will be set to >4151.0 V and *<4172.8 V, respectively, until actions identified in SCE submittal dated May 27, 2005 are completed" as all the required actions were completed.

For TS 3.8.1, "AC Sources - Operating," this proposed change will revise SRs 3.8.1.2,.7,.9,.11,.12,.15,.16,.17,.19, and.20 to lower the DG minimum output voltage. The value of 4161 V as the minimum voltage available at the 4.16 kV Class 1E buses was established in Attachment K to PCN-561 (Reference 10) and used for the degraded relay setpoints. This proposed change adjusts the DG voltage range in the DG surveillances while retaining sufficient margin (more than 119 V) to the 4161 V limit.

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In summary, these proposed changes will maintain adequate conservatism for the degraded voltage relay settings and required performance. The degraded voltage protection circuits prevent transfer of the 4.16 kV Class 1 E buses to the DG standby power source when voltage on the offsite transmission network (normal preferred power source) is at or above 218 kV. In addition, the change to TS 3.8.1 SRs will allow the DG voltage regulator to be reset closer to nominal design (4360 +/- 80 V instead of 4460 +/- 80 V).

Approval of this proposed change will widen the operating band while maintaining adequate conservatism in the setting for the degraded voltage relays and implement 4161 V as the minimum DG voltage necessary to support operability of the DG.

3.0 BACKGROUND

Existing Design Configuration Undervoltage relay protection for the SONGS 2&3 4.16 kV Class 1 E buses is described in Updated Final Safety Analysis Report (UFSAR) Section 8.3.1.1.3.13.B. The NRC staff reviewed and approved the protection scheme in a Safety Evaluation Report issued March 17, 1995 (Reference 1) in support of Facility Operating License Amendment Nos. 118 (Unit 2) and 107 (Unit 3). SCE had requested these Amendments in a submittal dated September 30, 1993 (Reference 2), supplemented in correspondence dated November 16, 1993, February 8, 1994, January 18, 1995, and February 2, 1995 (References 3 through 6).

The NRC staff reviewed and approved the current degraded voltage allowable values in a Safety Evaluation Report issued July 1, 2005 (Reference 12) in support of Facility Operating License Amendment Nos. 174 (Unit 2) and 165 (Unit 3). SCE had requested these Amendments in a submittal dated May 27, 2005 (Reference 10).

Each of the two 4.16 kV Class 1E buses per Unit is equipped with undervoltage relays to permit automatic transfer to the alternate preferred power source and for DG starting. The undervoltage relaying scheme is designed to perform the following functions:

1. Loss of Voltage Protection Four undervoltage relays (Westinghouse CV-2 induction disc relays with inverse time characteristics) 127F1, F2, F3, and F4 are provided on each 4.16 kV Class 1 E bus. The output contacts of the relays are combined in a two-out-of-four logic to generate a Loss of Voltage Signal (LOVS) with a time delay of approximately 1 second for complete loss of voltage.

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LOVS performs the following:

a. LOVS with a Safety Injection Actuation Signal (SIAS) will transfer the 4.16 kV Class 1 E bus to the standby power source (i.e., the DG);

b. LOVS without SIAS will transfer the 4.16 kV Class 1 E bus to the alternate preferred power source, if available. If the alternate power source is not available, it will transfer the 4.16 kV Class 1 E bus to the standby power source.

2. Degraded Voltage Protection

a. Sustained Degraded Voltage Protection Four undervoltage relays (ASEA Brown Boveri ABB 27N, definite time delay solid state relay), 127D1, 2, 3, and 4, along with four timing relays, 162D1, 2, 3, and 4, are provided on each 4.16 kV Class 1E bus for the degraded voltage detection scheme.

The voltage and time delay settings are such that the connected Class 1 E loads will not be damaged due to a degraded voltage condition. The existing 127D relays are set to operate at 4132.1 V, with a response time of 2 seconds. The 162D relays are set at 110 seconds. As such, a sustained degraded voltage signal will be generated within approximately 112 seconds. This signal will be blocked when the 4.16 kV Class 1E bus is powered from the DG. These signals are combined in a two-out-of-four logic, and the resulting signal is referred to as the Sustained Degraded Voltage Signal (SDVS).

The SDVS performs the following:

(1) SDVS with SIAS will transfer the 4.16 kV Class 1 E bus to the DG; (2) SDVS without SIAS will transfer the 4.16 kV Class 1 E bus to the alternate preferred power source, if available. If the alternate preferred power source is not available, SDVS without SIAS will transfer the 4.16 kV Class 1E bus to the DG.

b. Degraded Grid Voltage with SIAS Signal (DGVSS)

One output contact from each of the 127D1, 2, 3, and 4 undervoltage relays is used in a sustained degraded voltage protection scheme along with a set of timing relays for degraded grid voltage protection concurrent with a SIAS.

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The voltage and time delay settings are such that signals will be generated with an intentional definite time delay upon initiation of a SIAS along with the degraded bus voltage as sensed by the 127D1, 2, 3, and 4 relays during the first load sequencing cycle only. This scheme is designed to actuate in the event of a SIAS with a degraded grid condition.

These signals are combined in a two-out-of-four logic, and the resulting signal is referred to as DGVSS. The 4.16 kV Class 1E buses are transferred directly to the DG rather than to the alternate preferred power source, which is likely to be experiencing a degraded voltage condition as well.

The time delay for this signal is chosen to ride through the voltage transients and to ensure that adequate voltage is available on the 4.16 kV Class 1E bus during post accident Engineered Safety Features (ESF) load sequencing. This time delay is initiated by SIAS and is independent of the time delay chosen for SDVS. Following the acceleration of the first load group during post accident ESF load sequencing, the degraded voltage scheme will have a brief duration in which to sense the voltage on the 4.16 kV Class 1 E bus. If the voltage is below the minimum analyzed value, the 4.16 kV Class 1E bus will separate from the preferred power source and transfer to the DG.

Proposed Resolution of Problem SCE has performed calculations to demonstrate that operability of plant equipment can be supported at lower than existing voltages on the 4.16 kV Class 1 E buses after modifying the power feeders. The minimum bus voltage required will be 4100.0 V instead of 4106.0 V after the proposed modifications. This proposed change lowers the setpoint and expands the allowable values band for the degraded voltage protection relays to reflect the new minimum required voltage levels. The proposed allowable values are > 4109.0 V and _* 4153.1 V for dropout and pickup, respectively. This will widen the operating band while maintaining adequate conservatism in the settings for the degraded voltage relays and implement 4161 V as the minimum DG voltage necessary to support operability of the DG.

SCE has been testing at increased frequencies because of the tighter band due to over-conservatism. Increasing the operating band allows SCE to return to the TS surveillance interval of 24 months.

Modifications Required for Implementation SCE has identified the following modifications that will be necessary in order to implement the proposed lower setpoints of the degraded voltage relays:

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1. Add feeder cable to MCC 2BD in parallel with the existing feeder from Load Center 2B04 to reduce the voltage drop in the feeder.

2. Increase 120 VAC power feeder size to 120 VAC panel 2L541 from MCC Panel 2Q039 by replacing the feeder cable from #12 AWG to

1. 8 AWG for reducing voltage drop in the feeder circuit.

The proposed modifications will be completed before implementation of the proposed degraded voltage allowable values.

4.0 TECHNICAL ANALYSIS

Existing protection scheme During surveillance testing, it is important to measure both the dropout voltage, at which the relay actuates upon sensing degraded bus voltage, and the pickup voltage, at which the relay resets to enable sequencing loads onto the bus. This ensures operability of the relay to both protect the ESF loads against degraded voltage and to enable ESF load sequencing with an analytical limit of 4106.0 V to 4161.0 V as established by analysis for the 4.16 kV bus.

The existing degraded voltage protection scheme is designed to ensure that the 4.16 kV Class 1 E buses separate from the grid and transfer to the DG when 4.16 kV Class 1 E bus voltage may be degraded. The existing allowable values are

_> 4123.0 V and < 4144.6 V for dropout and pickup, respectively.

Proposed Protection Scheme The proposed degraded voltage protection scheme is designed to ensure that the 4.16 kV Class 1 E buses (1) do not separate from the normal preferred power source and do not transfer to the DG when the switchyard voltage is above 218 kV, and (2) provide adequate voltage to support operability of plant equipment.

To meet these requirements after the proposed modifications, the new analytical limits will be from 4100.0 V to 4161.0 V for the 4.16 kV bus.

The SCE calculation contains the SCE methodology to determine total loop uncertainty, pickup and dropout settings, and allowable pickup and dropout values of the degraded voltage protection relay. The allowable value for the measured relay dropout voltage in accordance with the proposed SR 3.3.7.3.a is

> 4109.0 V and the pickup voltage is __ 4153.1 V. The proposed allowable value is lower than the existing allowable value for dropout and higher than the existing allowable value for pickup. Thus, the range between dropout and pickup for the proposed allowable values is larger than the range between dropout and pickup for the existing allowable values. This was accomplished by increasing the power feeders' effective size to reduce the voltage drop in the limiting feeders.

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Per the proposed protection schemes, the analysis shows that:

1. When the switchyard voltage is 218 kV or above, the degraded voltage protection scheme with the new settings will not transfer the 4.16 kV Class 1E buses to the DG from the normal preferred power source, and

2. The new analytical dropout limit will be adequate to support operability of plant electrical equipment at the 4160 V, 480 V, and 120 V levels. For Emergency Safety Features (ESF) motors that are required to mitigate the consequences of a Design Basis Accident, motor terminal voltages during the starting and accelerating period are adequate such that the corresponding motor torque is constantly more than the load requires.

Conclusion The safety function of the degraded voltage protection signals is to ensure operability of Class 1 E equipment. The effect of this proposed change would be to allow continued operation while the 4.16 kV Class 1E buses remain on the offsite sources of AC power when offsite voltage is as low as 218 kV. To determine the acceptability of this proposed change, SCE has evaluated the voltages that would occur for Class 1 E equipment based on the proposed changes. This evaluation determined that acceptable voltages could be maintained at the 4160 V, 480 V, and 120 V safety buses.

All identified modifications will be implemented before the degraded voltage protection settings are changed. Therefore, operation in accordance with this proposed change will continue to support operability of plant equipment.

5.0 REGULATORY SAFETY ANALYSIS 5.1 No Significant Hazards Consideration Southern California Edison (SCE) has evaluated whether or not a significant hazards consideration is involved with the proposed amendments by focusing on the three standards set forth in 10 CFR 50.92, Issuance of Amendment, as discussed below:

1.

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

Response

No.

This proposed change revises the Technical Specification (TS)

Surveillance Requirement (SR) 3.3.7.3.a allowable values of the 7

Degraded Voltage Function and SRs 3.8.1.2,.7,.9,.11,.12,.15,.16,.17,

.19, and.20 for Diesel Generator (DG) minimum operable voltage. This proposed change will allow Southern California Edison (SCE) to widen the operating band while maintaining adequate conservatism for the degraded relay settings and overall loop uncertainties while keeping 218 kV as the minimum voltage on the offsite transmission grid necessary to support operability of the immediate access offsite power source (also referred to as the normal preferred power source). This will be accomplished by lowering the dropout and increasing the pickup settings of the degraded voltage protection relays. Following approval of this proposed change, the 4.16 kV Class 1E buses would remain on the normal preferred power source at or above a grid voltage of 218 kV while protecting all Class 1E equipment from degraded grid conditions.

The degraded voltage protection circuits are designed to protect electrical equipment against the effects of degraded voltage on the offsite transmission networks. Therefore, these circuits are generally not considered to be accident initiators. However, spurious actuation of the degraded voltage protection relays could result in the loss of the preferred power source (offsite source of alternating current (AC) power). The proposed change lowers the allowable value for dropout and raises the allowable value for pickup for the degraded voltage protection relays. This results in an increase in operating band and a lower probability of spurious actuation of these degraded voltage signals. Therefore, there is no increase in the probability of a Loss of Offsite Power (preferred power source) as a result of this proposed change.

The safety function of the degraded voltage protection circuits is to ensure the operability of Class 1 E equipment. SCE has performed calculations that demonstrate that operation in accordance with this proposed change will not result in operation of plant equipment at degraded voltages.

Therefore, there is no increase in the consequences of any accident previously evaluated.

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

2.

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

Response

No.

The proposed allowable values of the degraded voltage relays and the DG minimum operating voltage will provide an acceptable level of protection for plant equipment.

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This proposed change affects only the voltage settings of the degraded voltage protection relays and voltage regulator setting of the DG for lowering the required bus voltage. There is no other change to the degraded voltage function. There are no physical modifications necessary to the degraded voltage protection relays or the DG. There are no changes to the actions performed by the relays or the DG following actuation. Therefore, there are no new failure modes or effects introduced by this proposed change.

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

3.

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

Response

No.

The proposed degraded voltage protection schemes are designed to ensure that plant equipment will not operate at a degraded voltage and the DG Automatic Voltage Regulator (AVR) is set to provide adequate voltage for resetting of the relays and satisfactory operation of the Safety Related equipment. The proposed degraded voltage allowable values will not affect the existing protection criterion for plant equipment. This maintains the existing margin of safety for plant equipment.

Therefore, there is no significant reduction in a margin of safety as a result of the proposed amendment.

Based on the above, SCE concludes that the proposed amendments present no 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.

5.2 Applicable Regulatory Requirements/Criteria General Desiqn Criterion (GDC) 17, "Electric Power Systems" GDC 17 states in part:

"Electric Power Systems - An onsite electric power system and an offsite electric power system shall be provided to permit functioning of structures, systems, and components important to safety. The safety function for each system (assuming the other system is not functioning) shall be to provide sufficient capacity and capability to assure that (1) specified acceptable fuel design limits and design conditions of the reactor coolant pressure boundary are not exceeded as a result of anticipated operational 9

occurrences and (2) the core is cooled and containment integrity and other vital functions are maintained in the event of postulated accidents...

Electric power from the transmission network to the onsite electric distribution system shall be supplied by two physically independent circuits (not necessarily on separate rights of way) designed and located so as to minimize to the extent practical the likelihood of their simultaneous failure under operating and postulated accident and environmental conditions. A switchyard common to both circuits is acceptable. Each of these circuits shall be designed to be available in sufficient time following a loss of all onsite alternating current power supplies and the other offsite electric power circuit, to assure that specified acceptable fuel design limits and design conditions of the reactor coolant pressure boundary are not exceeded. One of these circuits shall be designed to be available within a few seconds following a loss-of-coolant accident to assure that core cooling, containment integrity, and other vital safety functions are maintained.

Provisions shall be included to minimize the probability of losing electric power from any of the remaining supplies as a result of, or coincident with, the loss of power generated by the nuclear power unit, the loss of power from the transmission network, or the loss of power from the onsite electric power supplies."

Currently, the San Onofre Units 2 and 3 switchyard minimum voltage that supports plant safety equipment operability is 218 kV for the normal preferred power source. The most limiting condition for offsite grid voltage (i.e., the condition that would approach 218 kV) involves one San Onofre unit shut down and a trip of the remaining San Onofre unit.

This proposed change will allow Southern California Edison (SCE) to increase the operating band while maintaining adequate conservatism for the degraded relay settings and overall loop uncertainties while keeping 218 kV as the minimum voltage on the offsite transmission grid necessary to support operability of the immediate access offsite power source (also referred to as the normal preferred power source). This will be accomplished by lowering the allowable value for dropout and raising the allowable value for pickup of the degraded voltage protection relays. Following approval of this proposed change, the 4.16 kV Class 1 E buses would remain on the normal preferred power source at or above a grid voltage of 218 kV while protecting all Class 1E equipment from degraded grid conditions.

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 10

issuance of the amendment will not be inimical to the common defense and security or to the health and safety of the public.

6.0 ENVIRONMENTAL CONSIDERATION

A review has determined that the proposed amendment would change a requirement with respect to installation or use of a facility component located within the restricted area, as defined in 10 CFR 20, or would change an inspection or surveillance requirement. However, the proposed amendment does not involve (i) a significant hazards consideration, (ii) a significant change in the types or significant increase in the amounts of any effluent that may be released offsite, or (iii) a significant increase in individual or cumulative occupational radiation exposure. Accordingly, the proposed amendment meets the eligibility criterion for categorical exclusion set 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.

7.0 REFERENCES

1. Letter from Mel B. Fields (NRC) to Harold B. Ray (SCE) dated March 17, 1995,

Subject:

"Issuance of Amendment for San Onofre Nuclear Generating Station, Unit 2 (TAC No. M87830) and Unit 3 (TAC No.

M87831)."

2. Letter from Richard M. Rosenblum (SCE) to Document Control Desk (NRC) dated September 30, 1993,

Subject:

"Docket Nos. 50-361 and 50-362, Amendment Application Nos. 136 and 120, Change to Technical Specifications 3/4.3.2, 'Engineered Safety Features Actuation Systems,'

San Onofre Nuclear Generating Station, Units 2 and 3."

3. Letter from W. C. Marsh (SCE) to Document Control Desk (NRC) dated November 16, 1993,

Subject:

"Docket Nos. 50-361 and 50-362, Additional Information for Amendment Applications 136 and 120, Degraded Grid Voltage Protection, San Onofre Nuclear Generating Station, Units 2 and 3"

4. Letter from W. C. Marsh (SCE) to Document Control Desk (NRC) dated February 8, 1994,

Subject:

"Docket Nos. 50-361 and 50-362, Additional Information for Amendment Applications 136 and 120, Offsite Power Compliance with General Design Criterion 17, San Onofre Nuclear Generating Station, Units 2 and 3."

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5. Letter from W. C. Marsh (SCE) to Document Control Desk (NRC) dated January 18, 1995,

Subject:

"Docket Nos. 50-361 and 50-362, Additional Information for Amendment Application Nos. 136 and 120, 'Degraded Grid Voltage,' San Onofre Nuclear Generating Station, Units 2 and 3."

6. Letter from Richard M. Rosenblum (SCE) to Document Control Desk (NRC), dated February 2, 1995,

Subject:

"Docket Nos. 50-361 and 50-362, Supplement 1 to Amendment Application Nos. 136 and 120, Change to Technical Specifications 3/4.3.2, "Engineered Safety Features Actuation Systems," San Onofre Nuclear Generating Station, Units 2 and 3."

7. Letter from L. Raghavan (NRC) to Harold B. Ray (SCE), dated November 29, 2000,

Subject:

"San Onofre Nuclear Generating Station, Units 2 and 3

- Issuance Of Amendments Re: Degraded Voltage And Loss Of Voltage Setpoints (TAC Nos. MA9641 and MA9642)."

8. Letter from D. E. Nunn (SCE) to Document Control Desk (NRC) dated July 20, 2000,

Subject:

"Docket Nos. 50-361 and 50-362, Supplement 1 to Proposed Technical Specification Change Number NPF-10/15-488, Degraded Voltage and Loss Of Voltage Setpoints, San Onofre Nuclear Generating Station (SONGS) Units 2 and 3."

9. Letter from D. P. Breig (SCE) to Document Control Desk (NRC), dated May 11, 2005,

Subject:

"Docket Nos. 50-361 and 50-362, Licensee Event Report No. 2005-03, San Onofre Nuclear Generating Station, Units 2 and 3."

10. Letter from Brian Katz (SCE) to Document Control Desk (NRC), dated May 27, 2005,

Subject:

"San Onofre Nuclear Generating Station, Units 2 and 3, Docket Nos 50-361 and 50-362, Proposed Change Number (PCN) 561, Degraded Voltage Setpoints."

11. Letter from Brian Katz (SCE) to Document Control Desk (NRC), dated June 24, 2005,

Subject:

"San Onofre Nuclear Generating Station, Units 2 and 3, Docket Nos 50-361 and 50-362, Additional Information regarding Proposed Change Number (PCN) 561, Degraded Voltage Setpoints."

12. Letter from B. Pham (NRC) to Harold B. Ray (SCE), dated July 1, 2005;

Subject:

San Onofre Nuclear Generating Station, Units 2 and 3 - Issuance of Amendments on Degraded Voltage Setpoints (TAC Nos. MC7190 and MC7191).

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ATTACHMENT A Proposed Change Notice (PCN) 574 Degraded Voltage Setpoints San Onofre Nuclear Generating Station, Units 2 and 3 Existing Technical Specifications pages, Unit 2

DG-Undervoltage Start 3.3.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.7.1 Perform CHANNEL CHECK.

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SR 3.3.7.2 Perform CHANNEL FUNCTIONAL TEST.

24 months SR 3.3.7.3 Perform CHANNEL CALIBRATION with Allowable Values as follows:

setpoint 24 months

a.

Degraded Voltage Function:

i.

Dropout 2 4123.0 V*

ii.

Pickup

• 4144.6 V*

SDVS (Sustained Degraded Grid Voltage Signal):

Time i.

ii.

delay:

127D < 2.17 seconds.

162D > 78 seconds and <

seconds.

128 with SIAS DGVSS (Degraded Grid Voltage Signal):

Time delay:

i.

127D Ž 1.83 seconds and

• 2.17 seconds.

ii.

162S 2 4.16 seconds and

• 4.44 seconds.

iii.

162T 2 0.88 seconds and

• 1.62 seconds.

b.

Loss of Voltage Function Ž 3554 V and

• 3796 V Time delay:

Ž 0.75 seconds and

• 1.0 seconds at 0 V.

• Dropout and pickup values will be set to Ž4151.0 V and *4172.8 V, respectively, until actions identified in SCE submittal dated May 27, 2005 are completed.

SAN ONOFRE--UNIT 2 3.3-34 Amendment No.

4-74-,196 I

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY 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.

3.

A modified DG start involving idling and gradual acceleration to rated speed may be used for this SR as recommended by the manufacturer.

When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.7 must be met.

4.

To ensure Operability of an AVR, it must have been aligned to the DG during the performance of SR 3.8.1.2 and SR 3.8.1.3 within the last 60 days, plus any allowance per SR 3.0.2.

Verify each DG starts from standby conditions and achieves:

As specified in Table 3.8.1-1

a.

Steady state voltage

Ž

< 4576 V; and

b.

Steady state frequency

• 61.2 Hz.

4297 V and

Ž 59.7 Hz and I

(continued)

SAN ONOFRE--UNIT 2 3.8-5 Amendment No. 127,158, 179

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.7

---

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

1.

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

2.

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG starts from standby condition and:

a.

In < 9.4 seconds, achieves voltage

> 4297 V and frequency

Ž 59.7 Hz;

,b. Maintains steady state voltage

> 4297 V and

• 4576 V; and

c.

Maintains steady state frequency

> 59.7 Hz and < 61.2 Hz.

184 days SR 3.8.1.8

---

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

I.

Credit may be taken for unplanned events that satisfy this SR.

2.

Testing to satisfy this SR shall include actual automatic and manual transfer to at least one alternate offsite circuit.

The other alternate offsite circuit may be verified by overlapping circuit tests.

Verify capability of automatic and manual transfer of AC power sources from the normal offsite circuit to each alternate required offsite circuit.

24 months (continued)

SAN ONOFRE--UNIT 2 3.8-7 Amendment No. --3-6, 158

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.9

---

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

1. Credit may be taken for unplanned events that satisfy this SR.

2.

To ensure Operability of an AVR, it must have been aligned to the DG during the performance of either SR 3.8.1.9, SR 3.8.1.10, or SR 3.8.1.19 within the last 24 months,

plus any allowance per SR 3.0.2.

Verify each DG rejects a load greater than 24 months or equal to its associated single largest post-accident load, and:

a.

Following load rejection, the frequency is

• 66.75 Hz;

b.

Within 4 seconds following load rejection, the voltage is

Ž 4297 V and

< 4576 V; and

c.

Within 4 seconds following load rejection, the frequency is

Ž 59.7 Hz and < 61.2 Hz.

SR 3.8.1.10 -------------------NOTE----------------

1.

Credit may be taken for unplanned events that satisfy this SR.

2.

To ensure Operability of an AVR, it must have been aligned to the DG during the performance of either SR 3.8.1.9, SR 3.8.1.10, or SR 3.8.1.19 within the last 24 months, plus any allowance per SR 3.0.2.

Verify each DG,. when connected to its bus 24 months in parallel with offsite power and operating with inductive loading that offsite power conditions permit, during and following a load rejection of > 4450 kW and

< 4700 kW:

a.

Does not trip; and

b. Voltage is maintained _ 5450 V.

(continued)

SAN ONOFRE--UNIT 2 3.8-8 Amendment No. 151, -18, 179

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.11

---

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

1.

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

2.

Credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated loss of offsite power signal:

a.

De-energization of emergency buses;

b.

Load shedding from emergency buses;

c.

DG auto-starts from standby condition and:

1.

energizes permanently connected loads and resets the 4.16kV bus undervoltage relay logic in

< 10 seconds;

2.

maintains steady state voltage

> 4297 V and

• 4576 V;

3.

maintains steady state frequency

> 59.7 Hz and < 61.2 Hz; and

4.

supplies permanently connected loads for > 5 minutes.

24 months (continued)

SAN ONOFRE--UNIT 2 3.8-9 Amendment No. +2-7-,

158

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

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

1.

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

2.

Credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated SIAS, each DG auto-starts from standby condition and:

a.

In < 9.4 seconds, achieves voltage

Ž 4297 V and frequency Ž 59.7 Hz;

b.

Maintains steady state voltage

Ž 4297 V and < 4576 V;

c.

Maintains steady state frequency 59.7 Hz and

• 61.2 Hz; and

d.

Operates for Ž 5 minutes.

24 months SR 3.8.1.13

---

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

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG automatic trip is bypassed on actual or simulated SIAS except:

a.

Engine overspeed;

b.

Generator differential current; and

c.

Low-low lube oil pressure.

24 months (continued)

SAN ONOFRE--UNIT 2 3.8-10 Amendment No.

+2-4, 158

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

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

1.

Momentary transients outside the load range does not invalidate this test.

2.

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG, when connected to its bus in parallel with offsite power and operating with inductive loading that offsite power conditions permit, operates for Ž 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />s:

a.

For > 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> loaded Ž 4935 kW and

• 5170 kW; and

b.

For the remaining hours of the test loaded > 4450 kW and

• 4700 kW.

24 months 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 <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> loaded > 4450 kW and

• 4700 kW.

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

2.

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

Verify each DG starts and:

a.

In

• 9.4 seconds, achieves voltage 2 4297 V and frequency

Ž 59.7 Hz;

b.

Maintains steady state voltage 2 4297 V and < 4576 V;

c.

Maintains steady state frequency

Ž 59.7 Hz and

• 61.2 Hz; and

d.

Operates for Ž 5 minutes.

24 months (continued)

SAN ONOFRE--UNIT 2 3.8-11 Amendment No. -,

158

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.16 NOTE-----------------

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG:

a.

Is capable of being synchronized with offsite power while loaded with emergency loads upon a simulated restoration of offsite power;

b.

Transfers loads to offsite power source; and

c.

Returns to ready-to-load operation, with:

1.

steady state voltage Ž 4297 V and 4576 V;

2.

steady state frequency

Ž 59.7 Hz and

• 61.2 Hz; and

3.

the DG output breaker open.

24 months SR 3.8.1.17

---

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

Credit may be taken for unplanned events that satisfy this SR.

Verify, with a DG operating in test mode and connected to its bus in parallel with offsite power, an actual or simulated SIAS overrides the test mode by:

a.

Returning the DG to ready-to-load operation, with:

1.

steady state voltage Ž 4297 V and

< 4576 V;

2.

steady state frequency Ž 59.7 Hz and

• 61.2 Hz; and

3.

the DG output breaker open; and

b.

Automatically energizing the emergency loads from offsite power.

24 months (continued)

SAN ONOFRE--UNIT 2 3.8-12 Amendment No. 7-,

158

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE I

FREQUENCY SR 3.8.1.19 -------------------

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

1.

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

2.

Credit may be taken for unplanned events that satisfy this SR.

3.

To ensure Operability of an AVR, it must have been aligned to the DG during the performance of either SR 3.8.1.9, SR 3.8.1.10, or SR 3.8.1.19 within the last 24 months, plus any allowance per SR 3.0.2.

Verify on an actual or simulated loss of 24 months offsite power signal in conjunction with actual or simulated ESF actuation signals:

a.

De-energization of emergency buses;

b.

Load shedding from emergency buses;

c.

DG auto-starts from standby condition and:

1.

energizes permanently connected loads and resets the 4.16 kV bus undervoltage relay logic in

< 10 seconds;

2.

• energizes auto-connected emergency loads through the programmed time interval load sequence;

3.

achieves steady state voltage 4297 V and 4576 V;

4.

achieves steady state frequency

> 59.7 Hz and < 61.2 Hz; and

5.

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

(continued)

SAN ONOFRE--UNIT 2 3.8-14 Amendment No.

1i27, 5*--,--

179 1

AC Sources -Operating 3.8.1 SURVEILLANCE :REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.20 NOTE-----------------

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

Verify, when started simultaneously from 10 years standby condition, each DG:

a.

In

• 9.4 seconds, achieves voltage 4297 V and frequency

Ž 59.7 Hz;

b.

Maintains steady state voltage

> 4297 V and

• 4576 V; and

c.

Maintains steady state frequency

> 59.7 Hz and

• 61.2 Hz.

SAN ONOFRE--UNIT 2 3.8-15 Amendment No.

+/-2-- 158

ATTACHMENT B Proposed Change Notice (PCN) 574 Degraded Voltage Setpoints San Nuclear Generating Station, Units 2 and 3 Existing Technical Specifications pages, Unit 3

DG-Undervoltage Start 3.3.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.7.1 Perform CHANNEL CHECK.

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SR 3.3.7.2 Perform CHANNEL FUNCTIONAL TEST.

24 months SR 3.3.7.3 Perform CHANNEL CALIBRATION with setpoint Allowable Values as follows:

a.

Degraded Voltage Function:

i.

Dropout 2 4123.0 V*

ii.

Pickup

• 4144.6 V*

SDVS (Sustained Degraded Grid Voltage Signal):

24 months Time i.ii delay:

127D

• 2.17 seconds.

162D 2 78 seconds and seconds.

128 with SIAS DGVSS (Degraded Grid Voltage Signal):

Time delay:

i.

127D

Ž 1.83 seconds.

ii.

162S

Ž 4.16 seconds.

iii.

162T

Ž 0.88 seconds.

seconds and

• 2.17 seconds and

• 4.44 seconds and < 1.62

b.

Loss of Voltage Function

• 3796 V

> 3554 V and Time delay: 2 0.75 seconds and

< 1.0 seconds at 0 V.

• Dropout and pickup values will be set to Ž4151.0 V and *4172.8 V, respectively, until actions identified in SCE submittal dated May 27, 2005 are completed.

SAN ONOFRE--UNIT 3 3.3-34 Amendment No. 6-5,-187 1

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY 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.

3.

A modified DG start involving idling and gradual acceleration to rated speed may be used for this SR as recommended by the manufacturer.

When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.7 must be met.

4.

To ensure Operability of an AVR, it must have been aligned to the DG during the performance of SR 3.8.1.2 and SR 3.8.1.3 within the last 60 days, plus any allowance per SR 3.0.2.

Verify each DG starts from standby As specified in conditions and achieves:

Table 3.8.1-1

a.

Steady state voltage Ž 4297 V and 4576 V; and

b.

Steady state frequency Ž 59.7 Hz and 61.2 Hz.

(continued)

SAN ONOFRE--UNIT 3 3.8-5 Amendment No. 1*,-149, 170 1

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.7 NOTES-----------------

1.

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

2.

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG starts from standby condition and:

a.

In

• 9.4 seconds, achieves voltage

Ž 4297 V and frequency

Ž 59.7 Hz;

b.

Maintains steady state voltage

> 4297 V and < 4576 V; and

c.

Maintains steady state frequency

Ž 59.7 Hz and

• 61.2 Hz.

184 days SR 3.8.1.8

---

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

1.

Credit may be taken for unplanned events that satisfy this SR.

2.

Testing to satisfy this SR shall include actual automatic and manual transfer to at least one alternate offsite circuit.

The other alternate offsite circuit may be verified by overlapping circuit tests.

Verify capability of automatic and manual transfer of AC power sources from the normal offsite circuit to each alternate required offsite circuit.

24 months (continued)

SAN ONOFRE--UNIT 3 3.8-7 Amendment No.

+2-8, 149

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.9

---

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

1.

Credit may be taken for unplanned events that satisfy this SR.

2.

To ensure Operability of an AVR, it must have been aligned to the DG during the performance of either SR 3.8.1.9, SR 3.8.1.10, or SR 3.8.1.19 within the last 24 months, plus any allowance per SR 3.0.2.

Verify each DG rejects a load greater than 24 months or equal to its associated single largest post-accident load, and:

a.

Following load rejection, the frequency is

< 66.75 Hz;

b.

Within 4 seconds following load rejection, the voltage is

Ž 4297 V and

< 4576 V; and

c.

Within 4 seconds following load rejection, the frequency is

Ž 59.7 Hz and

• 61.2 Hz.

SR 3.8.1.10 ------------------- NOTE----------------

1.

Credit may be taken for unplanned events that satisfy this SR.

2.

To ensure Operability of an AVR, it must have been aligned to the DG during the performance of either SR 3.8.1.9, SR 3.8.1.10, or SR 3.8.1.19 within the last 24 months, plus any allowance per SR 3.0.2.

Verify each DG, when connected to its bus 24 months in parallel with offsite power and operating with inductive loading that offsite power conditions permit, during and following a load rejection of > 4450 kW and

< 4700 kW:

a.

Does not trip; and

ýb. Voltage is maintained < 5450 V.

(continued)

SAN ONOFRE--UNIT 3 3.8-8 Amendment No.

143,-

,4-9, 170 1

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.11

---

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

1.

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

2.

Credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated loss of offsite power signal:

a.

De-energization of emergency buses;

b.

Load shedding from emergency buses;

c.

DG auto-starts from standby condition and:

1.

energizes permanently connected loads and resets the 4.16kV bus undervoltage relay logic in

< 10 seconds;

2.

maintains steady state voltage

> 4297 V and

• 4576 V;

3.

maintains steady state frequency

> 59.7 Hz and

• 61.2 Hz; and

4.

supplies permanently connected loads for Ž 5 minutes.

24 months (continued)

SAN ONOFRE--UNIT 3 3.8-9 Amendment No. -6, 149

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.12

---

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

I.

All IDG starts may be preceded by an engine prelube period.

2.

Credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated SIAS, each DG auto-starts from standby condition and:

a.

In < 9.4 seconds, achieves voltage

Ž 4297 V and frequency Ž 59.7 Hz;

b.

Maintains steady state voltage

> 4297 V and

• 4576 V; and

c.

Maintains steady state frequency

Ž 59.7 Hz and

• 61.2 Hz.

d.

Operates for

• 5 minutes.

24 months SR 3.8.1.13

---

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

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG automatic trip is bypassed on actual or simulated SIAS except:

a.

Engine overspeed;

b.

Generator differential current; and

c.

Low-low lube oil pressure.

24 months (continued)

SAN ONOFRE--UNIT 3 3.8-10 Amendment No.

+1-6, 149

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

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

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

1.

Momentary transients outside the load range does not invalidate this test.

2.

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG, when connected to its 'bus in parallel with offsite power and operating with inductive loading that offsite power conditions permit, operates for > 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />s:

a.

For > 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> loaded Ž 4935 kW and

• 5170 kW; and

b.

For the remaining hours of the test loaded Ž 4450 kW and

• 4700 kW.

24 months 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 <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> loaded Ž 4450 kW and

• 4700 kW.

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

2.

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

Verify each DG starts and:

a.

In < 9.4 seconds, achieves voltage

Ž 4297 V and frequency Ž 59.7 Hz;

b.

Maintains steady state voltage

Ž 4297 V and

• 4576 V;

c.

Maintains steady state frequency

> 59.7 Hz and

• 61.2 Hz; and

d.

Operates for 2 5 minutes.

24 months (continued)

SAN ONOFRE--UNIT 3 3.8-11 Amendment No.

+2-5, 149

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.16 -------------------

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

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG:

24 months

a.

Is capable of being synchronized with offsite power while loaded with emergency loads upon a simulated restoration of offsite power;

b.

Transfers loads to offsite power source; and

c.

Returns to ready-to-load operation, with:

1.

steady state voltage Ž 4297 V and

< 4576 V;

2.

steady state frequency ý 59.7 Hz and

• 61.2 Hz; and

3.

the DG output breaker open.

SR 3.8.1.17

---

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

Credit may be taken for unplanned events that satisfy this SR.

Verify, with a DG operating in test mode 24 months and connected to its bus in parallel with offsite power, an actual or simulated SIAS overrides the test mode by:

a.

Returning the DG to ready-to-load operation, with:

1.

steady state voltage Ž 4297 V and

< 4576 V;

2.

steady state frequency

Ž 59.7 Hz and

• 61.2 Hz; and

3.

the DG output breaker open; and

b.

Automatically energizing the emergency loads from offsite power.

(continued)

SAN ONOFRE--UNIT 3 3.8-12 Amendment No.

4-4-6, 149

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.19 -------------------

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

1.

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

2.

Credit may be taken for unplanned events that satisfy this SR.

3.

To ensure Operability of an AVR, it must have been aligned to the DG during the performance of either SR 3.8.1.9, SR 3.8.1.10, or SR 3.8.1.19 within the last 24 months, plus any allowance per SR 3.0.2.

Verify on an actual or simulated loss of 24 months offsite power signal in conjunction with actual or simulated ESF actuation signals:

a.

De-energization of emergency buses;

b.

Load shedding from emergency buses;

c.

DG auto-starts from standby condition and:

1.

energizes permanently connected loads and resets the 4.16 kV bus undervoltage relay logic in

< 10 seconds;

2.

energizes auto-connected emergency loads through the programmed time interval load sequence;

3.

achieves steady state voltage

> 4297 V and

• 4576 V;

4.

achieves steady state frequency 59.7 Hz and

• 61.2 Hz; and

5.

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

(continued)

SAN ONOFRE--UNIT 3 3.8-14 Amendment No. 116,

-49, 170 1

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.20

---

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

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

Verify, when started simultaneously from standby condition, each DG:

a.

In

• 9.4 seconds, achieves voltage

Ž 4297 V and frequency Ž 59.7 Hz;

b.

Maintains steady state voltage

Ž 4297 V and

• 4576 V; and

c.

Maintains steady state frequency

Ž 59.7 Hz and

• 61.2 Hz.

10 years SAN ONOFRE--UNIT 3 3.8-15 Amendment No.

4+/-1-6, 149

ATTACHMENT C Proposed Change Notice (PCN) 574 Degraded Voltage Setpoints San Onofre Nuclear Generating Station, Units 2 and 3 Proposed Technical Specifications pages, Redline and Strikeout, Unit 2

DG-Undervoltage Start 3.3.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.7.1 Perform CHANNEL CHECK.

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SR 3.3.7.2 Perform CHANNEL FUNCTIONAL TEST.

24 months SR 3.3.7.3 Perform CHANNEL CALIBRATION with Allowable Values as follows:

a.

Degraded Voltage Function:

i.

Dronout _> 4-1-2-3-.O V* 41 setpoint 24 months I09.0 V

i. Droout

ýI412.

V*

19 ii.

Pickup

-4144.. 6-V-4153.1 V SDVS (Sustained Degraded Grid Voltage Signal):

Time i.

ii.

delay:

127D

• 2.17 seconds.

162D Ž 78 seconds and 128 seconds.

DGVSS (Degraded Grid Voltage Signal):

with SIAS Time delay:

i.

127D Ž 1.83 seconds seconds.

ii.

162S

Ž 4.16 seconds seconds.

iii.

162T 2 0.88 seconds seconds.

b.

Loss of Voltage Function

• 3796 V and

• 2.17 and < 4.44 and

• 1.62

> 3554 V and Time delay:

Ž 0.75 seconds and

< 1.0 seconds at 0 V.

,Dropout and pickup values will be set to t4151.0 V and t4172.8 V, peetiv-ly, until a.tiors identified in SCC submittal dated,ay 27, 2005 are-compl eted.

SAN ONOFRE--UNIT 2 3.3-34 Amendment No. 174,-96

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY 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.

3.

A modified DG start involving idling and gradual acceleration to rated speed may be used for this SR as recommended by the manufacturer.

When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.7 must be met.

4.

To ensure Operability of an AVR, it must have been aligned to the DG during the performance of SR 3.8.1.2 and SR 3.8.1.3 within the last 60 days, plus any allowance per SR 3.0.2.

Verify each DG starts from standby As specified in conditions and achieves:

Table 3.8.1-1

a.

Steady state voltage

Ž 4-2-9 4161 V and

• 4576 V; and

b.

Steady state frequency > 59.7 Hz and 61.2 Hz.

(continued)

SAN ONOFRE--UNIT 2 3.8-5 Amendment No. 127,158, 179

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.7

---

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

1.

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

2.

Credit may be taken for unplanned 184 days events that satisfy this SR.

Verify each DG starts from standby condition and:

a.

In

• 9.4 seconds, achieves voltage S4-22-9-T 4161 V and frequency ý 59.7 Hz;

b.

Maintains steady state voltage 2 4-2-9 4161 V and

• 4576 V; and

c.

Maintains steady state frequency

Ž 59.7 Hz and

• 61.2 Hz.

SR 3.8.1.8

---

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

1.

Credit may be taken for unplanned events that satisfy this SR.

2.

Testing to satisfy this SR shall 24 months include actual automatic and manual transfer to at least one alternate offsite circuit.

The other alternate offsite circuit may be verified by overlapping circuit tests.

Verify capability of automatic and manual transfer of AC power sources from the normal offsite circuit to each alternate required offsite circuit.

(continued)

SAN ONOFRE--UNIT 2 3.8-7 Amendment No. 136, Io8

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

.1.

SR 3.8.1.9 NOTE----------------

1.

Credit may be taken for unplanned events that satisfy this SR.

2.

To ensure Operability of an AVR, it must have been aligned to the DG during the performance of either SR 3.8.1.9, SR 3.8.1.10, or SR 3.8.1.19 within the last 24 months, plus any allowance per SR 3.0.2.

Verify each DG rejects a load greater than or equal to its associated single largest post-accident load, and:

a.

Following load rejection, the frequency is

• 66.75 Hz;

b.

Within 4 seconds following load reiection, the voltage is 2 4-2-9-;-

4161 V and : 4576 V; and

c.

Within 4 seconds following load rejection, the frequency is Ž 59.7 Hz and

• 61.2 Hz.

24 months 4-SR 3.8.1.10 NOTE----------------

i.

Credit may be taken for unplanned events that satisfy this SR.

2.

To ensure Operability of an AVR, it must have been aligned to the DG during the performance of either SR 3.8.1.9, SR 3.8.1.10, or SR 3.8.1.19 within the last 24 months, plus any allowance per SR 3.0.2.

Verify each DG, when connected to its bus in parallel with offsite power and operating with inductive loading that offsite power conditions permit, during and following a load rejection of > 4450 kW and

< 4700 kW:

a.

Does not trip; and

b.

Voltage is maintained

• 5450 V.

24 months (continued)

SAN ONOFRE--UNIT 2 3.8-8 Amendment No. 151, 158, 179

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.11

---

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

1.

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

2.

Credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated loss of offsite power signal:

a.

De-energization of emergency buses;

b.

Load shedding from emergency buses;

c.

DG auto-starts from standby condition and:

1.

energizes permanently connected loads and resets the 4.16kV bus undervoltage relay logic in

< 10 seconds;

2.

maintains steady state voltage

> 4-2-9-7 4161 V and < 4576 V;

3.

maintains steady state frequency

> 59.7 Hz and

• 61.2 Hz; and

4.

supplies permanently connected loads for Ž 5 minutes.

24 months (continued)

SAN ONOFRE--UNIT 2 3.8-9 Amendment No. 127, 15o

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.12

---

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

1.

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

2.

Credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated SIAS, each DG auto-starts from standby condition and:

a.

In < 9.4 seconds, achieves voltage

Ž 4-2 4161 V and frequency 2 59.7 Hz;

b.

Maintains steady state voltage Ž 4-2-9 4161 V and

• 4576 V;

c.

Maintains steady state frequency

Ž 59.7 Hz and

• 61.2 Hz; and

d.

Operates for Ž 5 minutes.

24 months SR 3.8.1.13

---

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

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG automatic trip is bypassed on actual or simulated SIAS except:

a.

Engine overspeed;

b.

Generator differential current; and

c.

Low-low lube oil pressure.

24 months (continued)

SAN ONOFRE--UNIT 2 3.8-10 Amendment No. 127, 158

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.14

---

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

1.

Momentary transients outside the load range does not invalidate this test.

2.

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG, when connected to its bus in parallel with offsite power and operating with inductive loading that offsite power conditions permit, operates for > 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />s:

a.

For > 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> loaded Ž 4935 kW and

< 5170 kW; and

b.

For the remaining hours of the test loaded Ž 4450 kW and

• 4700 kW.

24 months

-t 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 <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> loaded Ž 4450 kW and

• 4700 kW.

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

2.

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

Verify each DG starts and:

a.

In

• 9.4 seconds, achieves voltage

Ž 4-2-9-7 4161 V and frequency

Ž 59.7 Hz;

b.

Maintains steady state voltage

Ž 42-9-T 4161 V and

• 4576 V;

c.

Maintains steady state frequency

Ž 59.7 Hz and

• 61.2 Hz; and

d.

Operates for 2 5 minutes.

24 months (continued)

SAN ONOFRE--UNIT 2 3.8-11 Amendment No. *27*

158

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.16 -------------------

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

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG:

24 months

a.

Is capable of being synchronized with offsite power while loaded with emergency loads upon a simulated restoration of offsite power;

b.

Transfers loads to offsite power source; and

c.

Returns to ready-to-load operation, with:

1.

steady state voltage Ž 4-2-9-7 4161 V and < 4576 V;

2.

steady state frequency

Ž 59.7 Hz and < 61.2 Hz; and

3.

the DG output breaker open.

SR 3.8.1.17

---

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

Credit may be taken for unplanned events that satisfy this SR.

Verify, with a DG operating in test mode 24 months and connected to its bus in parallel with offsite power, an actual or simulated SIAS overrides the test mode by:

a.

Returning the DG to ready-to-load operation, with:

1.

steady state voltage ý 4-2-9-- 4161 V and < 4576 V;

2.

steady state frequency

Ž 59.7 Hz and

• 61.2 Hz; and

3.

the DG output breaker open; and

b.

Automatically energizing the emergency loads from offsite power.

(continued)

SAN ONOFRE--UNIT 2 3.8-12 Amendment No. +/-27. -58

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.19 ------------------- NOTES----------------

1.

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

2.

Credit may be taken for unplanned events that satisfy this SR.

3.

To ensure Operability of an AVR, it must have been aligned to the DG during the performance of either SR 3.8.1.9, SR 3.8.1.10, or SR 3.8.1.19 within the last 24 months, plus any allowance per SR 3.0.2.

Verify on an actual or simulated loss of 24 months offsite power signal in conjunction with actual or simulated ESF actuation signals:

a.

De-energization of emergency buses;

b.

Load shedding from emergency buses;

c.

DG auto-starts from standby condition and:

1.

energizes permanently connected loads and resets the 4.16 kV bus undervoltage relay logic in

< 10 seconds;

2.

energizes auto-connected emergency loads through the programmed time interval load sequence;

3.

achieves steady state voltage

> 42-9-7-4161 V and :

4576 V;

4.

achieves steady state frequency

> 59.7 Hz and

• 61.2 Hz; and

5.

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

(continued)

SAN ONOFRE--UNIT 2 3.8-14 Amendment No. 127, 158, 179

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.20 NOTE-----------------

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

Verify, when started simultaneously from 10 years standby condition, each DG:

a.

In

• 9.4 seconds, achieves voltage

Ž 4-2-9-T 4161 V and frequency 2 59.7 Hz;

b.

Maintains steady state voltage

Ž 4-2z9-7 4161 V and

• 4576 V; and

c.

Maintains steady state frequency

Ž 59.7 Hz and

• 61.2 Hz.

SAN ONOFRE--UNIT 2 3.8-15 Amendment No.

127, I58

ATTACHMENT D Proposed Change Notice (PCN) 574 Degraded Voltage Setpoints San Onofre Nuclear Generating Station, Units 2 and 3 Proposed Technical Specifications pages, Redline and Strikeout, Unit 3

DG-Undervoltage Start 3.3.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.7.1 Perform CHANNEL CHECK.

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SR 3.3.7.2 Perform CHANNEL FUNCTIONAL TEST.

24 months SR 3.3.7.3 Perform CHANNEL CALIBRATION with setpoint Allowable Values as follows:

a.

Degraded Voltage Function:

i.

Dropout > 4123.0 V* 4109.0 V ii.

Pickup

< 4144.6 V* 4153.1 V SDVS (Sustained Degraded Grid Voltage Signal):

24 months Time i.ii delay:

127D

• 2.17 seconds.

162D Ž 78 seconds and seconds.

128 with SIAS DGVSS (Degraded Grid Voltage Signal):

Time delay:

i.

127D

Ž 1.83 seconds seconds.

ii.

162S

Ž 4.16 seconds seconds.

iii. 162T 2 0.88 seconds seconds.

b.

Loss of Voltage Function

< 3796 V and

• 2.17 and < 4.44 and

• 1.62

> 3554 V and Time delay:

Ž 0.75 seconds and

< 1.0 seconds at 0 V.

Dr"pou and piekuip valu..

s will be set to t4151.0 V and

,172.8 V,

..speetv-ly, until actions identified in SC'[ submittal dated May 27, 2005 are

,,mpleted.

(continued)

SAN ONOFRE--UNIT 3 3.3-34 Amendment No. 165,187

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY 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.

3.

A modified DG start involving idling and gradual acceleration to rated speed may be used for this SR as recommended by the manufacturer.

When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.7 must be met.

4.

To ensure Operability of an AVR, it must have been aligned to the DG during the performance of SR 3.8.1.2 and SR 3.8.1.3 within the last 60 days, plus any allowance per SR 3.0.2.

V..

As specified in Table 3.8.1-1 Verify each DG starts from standby conditions and achieves:

a.

Steady state voltage 4576 V; and

b.

Steady state frequency

< 61.2 Hz.

424-4161 V and

Ž 59.7 Hz and (continued)

SAN ONOFRE--UNIT 3 3.8-5 Amendment No. 116,149, 170

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.7

---

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

1.

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

2.

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG starts from standby condition and:

a.

In

• 9.4 seconds, achieves voltage

> 4494 4161 V and frequency Ž 59.7 Hz;

b.

Maintains steady state voltage

Ž 4-2-9 4161 V and

• 4576 V; and

c.

Maintains steady state frequency

Ž 59.7 Hz and < 61.2 Hz.

184 days SR 3.8.1.8

---

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

1.

Credit may be taken for unplanned events that satisfy this SR.

2.

Testing to satisfy this SR shall include actual automatic and manual transfer to at least one alternate offsite circuit.

The other alternate offsite circuit may be verified by overlapping circuit tests.

Verify capability of automatic and manual transfer of AC power sources from the normal offsite circuit to each alternate required offsite circuit.

24 months, (continued)

SAN ONOFRE--UNIT 3 3.8-7 Amendment No. 12-8,149

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

.4 SR 3.8.1.9 NOTE----------------

1.

• Credit may be taken for unplanned events that satisfy this SR.

2.

To ensure Operability of an AVR, it must have been aligned to the DG during the performance of either SR 3.8.1.9,, SR 3.8.1.10, or SR 3.8.1.19 within the last 24 months, plus any allowance per SR 3.0.2.

Verify each DG rejects a load greater than or equal to its associated single largest post-accident load, and:

a.

Following load rejection, the frequency is

• 66.75 Hz;

b.

Within 4 seconds following load reiection, the voltage is

Ž 42 4161 V and < 4576 V; and

c.

Within 4 seconds following load rejection, the frequency is

Ž 59.7 Hz and < 61.2 Hz.

24 months SR 3.8.1.10 NOTE----------------

I.

Credit may be taken for unplanned events that satisfy this SR.

2.

To ensure Operability of an AVR, it must have been aligned to the DG during the performance of either SR 3.8.1.9, SR 3.8.1.10, or SR 3.8.1.19 within the last 24 months, plus any allowance per SR 3.0.2.

Verify each DG, when connected to its bus in parallel with offsite power and operating with inductive loading that offsite power conditions permit, during and following a load rejection of > 4450 kW and

< 4700 kW:

a.

Does not trip; and

b.

Voltaqe is maintained

• 5450 V.

24 months (continued)

SAN ONOFRE--UNIT 3 3.8-8 Amendment No. 143, 149, 1l7

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.11

---

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

1.

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

2.

Credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated loss of offsite power signal:

a.

De-energization of emergency buses;

b.

Load shedding from emergency buses;

c.

DG auto-starts from standby condition and:

1.

energizes permanently connected loads and resets the 4.16kV bus undervoltage relay logic in

< 10 seconds;

2.

maintains steady state voltage

> 42-9-T 4161 V and ! 4576 V;

3.

maintains steady state frequency

> 59.7 Hz and

• 61.2 Hz; and

4.

supplies permanently connected loads for > 5 minutes.

24 months (continued)

SAN ONOFRE--UNIT 3 3.*8-9 Amendment No. 116, 149

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.12

---

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

1.

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

2.

Credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated SIAS, each DG auto-starts from standby condition and:

a.

In < 9.4 seconds, achieves voltage

> 42-9-7 4161 V and frequency

Ž 59.7 Hz;

b.

Maintains steady state voltage

Ž 4-2-9 4161 V and

• 4576 V; and

c.

Maintains steady state frequency

Ž 59.7 Hz and

• 61.2 Hz.

d.

Operates for Ž 5 minutes.

24 months SR 3.8.1.13

---

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

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG automatic trip is bypassed on actual or simulated SIAS except:

a.

Engine overspeed;

b.

Generator differential current; and

c.

Low-low lube oil pressure.

24 months (continued)

SAN ONOFRE--UNIT 3 3.8-10 Amendment No.

116,-- 149

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

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

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

1.

Momentary transients outside the load range does not invalidate this test.

2.

'Credit may be taken for unplanned events that satisfy this SR.

Verify each DG, when connected to its bus 24 months in parallel with offsite power and operating with inductive loading that offsite power conditions permit, operates for > 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />s:

a.

For > 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> loaded > 4935 kW and

< 5170 kW; and

b.

For the remaining hours of the test loaded > 4450 kW and

• 4700 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 Ž 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> loaded

Ž 4450 kW and

• 4700 kW.

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

2.

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

Verify each DG starts and:

24 months

a.

In < 9.4 seconds, achieves voltage S4-2 4161 V and frequency > 59.7 Hz;

b.

Maintains steady state voltage Ž 4-2 4161 V and

• 4576 V;

c.

Maintains steady state frequency

> 59.7 Hz and

• 61.2 Hz; and

d.

Operates for > 5 minutes.

(continued)

SAN ONOFRE--UNIT 3 3.8-11 Amendment No.

12-5, 149

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.16 NOTE-----------------

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG:

a.

Is capable of being synchronized with offsite power while loaded with emergency loads upon a simulated restoration of offsite power;

b.

Transfers loads to offsite power source; and

c.

Returns to ready-to-load operation, with:

1.

steady state voltage

Ž 42-9-- 4161 V and < 4576 V;

2.

steady state frequency ý 59.7 Hz and < 61.2 Hz; and

3.

the DG output breaker open.

24 months I

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

Credit may be taken for unplanned events that satisfy this SR.

Verify, with a DG operating in test mode and connected to its bus in parallel with offsite power, an actual or simulated SIAS overrides the test mode by:

a.

Returning the DG to ready-to-load operation, with:

1.

steady state voltage Ž 4-2-9 4161 V and

• 4576 V;

2.

steady state frequency

Ž 59.7 Hz and

• 61.2 Hz; and

3.

the DG output breaker open; and

b.

Automatically energizing the emergency loads from offsite power.

24 months (continued)

SAN ONOFRE--UNIT 3 3.8-12 Amendment No.

116, 149

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.19 -------------------

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

1.

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

2.

Credit may be taken for unplanned events that satisfy this SR.

3.

To ensure Operability of an AVR, it must have been aligned to the DG during the performance of either SR 3.8.1.9, SR 3.8.1.10, or SR 3.8.1.19 within the last 24 months, plus any allowance per SR 3.0.2.

Verify on an actual or simulated loss of 24 months offsite power signal in conjunction with actual or simulated ESF actuation signals:

a.

De-energization of emergency buses;

b.

Load shedding from emergency buses;

c.

DG auto-starts from standby condition and:

1.

energizes permanently connected loads and resets the 4.16 kV bus undervoltage relay logic in

< 10 seconds;

2.

energizes auto-connected emergency loads through the programmed time interval load sequence;

3.

achieves steady state voltage

> 4-2-9-7 4161 V and ! 4576 V;

4.

achieves steady state frequency

> 59.7 Hz and

• 61.2 Hz; and

5.

supplies permanently connected and auto-connected emergency loads for Ž 5 minutes.

(continued)

SAN ONOFRE--UNIT 3 3.8-14 Amendment No. 116, 149, 170

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.20

---

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

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

Verify, when started simultaneously from standby condition, each DG:

a.

In

• 9.4 seconds, achieves voltage

> 42-9-ý 4161 V and frequency > 59.7 Hz;

ýb. Maintains steady state voltage 2 4-29 4161 V and

• 4576 V; and

c.

Maintains steady state frequency 2 59.7 Hz and

• 61.2 Hz.

10 years SAN ONOFRE--UNIT 3 3.8-15 Amendment No. 116, 149

ATTACHMENT E Proposed Change Notice (PCN) 574 Degraded Voltage Setpoints San Onofre Nuclear Generating Station, Units 2 and 3 Proposed Technical Specifications pages, Unit 2

DG-'Undervoltage Start 3.3.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.7.1 Perform CHANNEL CHECK.

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SR 3.3.7.2 Perform CHANNEL FUNCTIONAL TEST.

24 months SR 3.3.7.3 Perform CHANNEL CALIBRATION with setpoint Allowable Values as follows:

a.

Degraded Voltage Function:

i.

Dropout Ž 4109.0 V ii.

Pickup

• 4153.1 V SDVS (Sustained Degraded Grid Voltage Signal):

24 months Time i.

ii.

delay:

127D

• 2.17 seconds.

162D > 78 seconds and <

.seconds.

128 with SIAS DGVSS (Degraded Grid Voltage Signal):

Time delay:

i.

127D 1.83 seconds and

• 2.17 seconds.

ii.

162S ! 4.16 seconds and

• 4.44 seconds.

iii. 162T > 0.88 seconds and

• 1.62 seconds.

b.

Loss of Voltage Function

< 3796 V

> 3554 V and Time delay:

Ž 0.75 seconds and

< 1.0 seconds at 0 V.

SAN ONOFRE--UNIT 2 3.3-34 Amendment No.

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY 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.

3.

A modified DG start involving idling and gradual acceleration to rated speed may be used for this SR as recommended by the manufacturer.

When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.7 must be met.

4.

To ensure Operability of an AVR, it must have been aligned to the DG during the performance of SR 3.8.1.2 and SR 3.8.1.3 within the last 60 days, plus any allowance per SR 3.0.2.

Verify each DG starts from standby conditions and achieves:

As specified in Table 3.8.1-1

a.

Steady state voltage

• 4576 V; and

b.

Steady state frequency

• 61.2 Hz.

4161 V and

Ž 59.7 Hz and (continued)

SAN ONOFRE--UNIT 2 3.8-5 Amendment No.

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.7

---

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

1.

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

2.

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG starts from standby condition and:

a.

In < 9.4 seconds, achieves voltage 2 4161 V and frequency Ž 59.7 Hz;

b.

Maintains steady state voltage

Ž 4161 V and

• 4576 V; and

c.

Maintains steady state frequency

Ž 59.7 Hz and

• 61.2 Hz.

184 days SR 3.8.1.8

---

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

1.

Credit may be taken for unplanned events that satisfy this SR.

2.

Testing to satisfy this SR shall include actual automatic and manual transfer to at least one alternate offsite circuit.

The other alternate offsite circuit may be verified by overlapping circuit tests.

Verify capability of automatic and manual transfer of AC power sources from the normal offsite circuit to each alternate required offsite circuit.

24 months (continued)

SAN ONOFRE--UNIT 2 3.8-7 Amendment No.

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

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

1.

Credit may be taken for unplanned events that satisfy this SR.

2.

To ensure Operability of an AVR, it must have been aligned to the DG during the performance of either SR 3.8.1.9, SR 3.8.1.10, or SR 3.8.1.19 within the last 24 months, plus any allowance per SR 3.0.2.

Verify each DG rejects a load greater than or equal to its associated single largest post-accident load, and:

a.

Following load rejection, the frequency is

• 66.75 Hz;

b.

Within 4 seconds following load rejection, the voltage is

Ž 4161 V and

• 4576 V; and

c.

Within 4 seconds following load rejection, the frequency is

Ž 59.7 Hz and < 61.2 Hz.

24 months IL SR 3.8.1.10 NOTE----------------

1. Credit may be taken for unplanned events that satisfy this SR.

2.

To ensure Operability of an AVR, it must have been aligned to the DG during the performance of either SR 3.8.1.9, SR 3.8.1.10, or SR 3.8.1.19 within the last 24 months, plus any allowance per SR 3.0.2.

Verify each DG, when connected to its bus in parallel with offsite power and operating with inductive loading that offsite power conditions permit, during and following a load rejection of > 4450 kW and

< 4700 kW:

a.

Does not trip; and

b.

Voltaqe is maintained

• 5450 V.

24 months (continued)

SAN ONOFRE--UNIT 2 3.8-8 Amendment No.

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.11

---

:NOTES----------------

1.

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

2.

Credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated loss of offsite power signal:

a.

De-energization of emergency buses;

• b. Load shedding from emergency buses;

c.

DG auto-starts from standby condition and:

1.

energizes permanently connected loads and resets the 4.16kV bus undervoltage relay logic in

< 10 seconds;

2.

maintains steady state voltage

> 4161 V and

• 4576 V;

3.

maintains steady state frequency

> 59.7 Hz and < 61.2 Hz; and

4.

supplies permanently connected loads for > 5 minutes.

24 months (continued)

SAN ONOFRE--UNIT 2 3.8-9 Amendment No.

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.12

---

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

1.

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

0

2.

Credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated SIAS, each 24 months DG auto-starts from standby condition and:

a.

In < 9.4 seconds, achieves voltage

Ž 4161 V and frequency 2 59.7 Hz;

b.

Maintains steady state voltage

> 4161 V and

• 4576 V;

c.

Maintains steady state frequency

Ž 59.7 Hz and

• 61.2 Hz; and

d.

Operates for Ž 5 minutes.

SR 3.8.1.13 -------------------NOTE----------------

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG automatic trip is bypassed 24 months on actual or simulated SIAS except:

a.

Engine overspeed;

b.

Generator differential current; and

c.

Low-low lube oil pressure.

(continued)

SAN ONOFRE--UNIT 2 3.8-10 Amendment No.

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

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

1.

Momentary transients outside the load range does not invalidate this test.

2.

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG, when connected to its bus in parallel with offsite power and operating with inductive loading that offsite power conditions permit, operates for Ž 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />s:

a.

For > 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> loaded

Ž 4935 kW and

• 5170 kW; and

b.

For the remaining hours of the test loaded Ž 4450 kW and < 4700 kW.

24 months 4-SR 3.8.1.15

---

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

1.

This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated > 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> loaded Ž 4450 kW and

• 4700 kW.

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

2.

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

Verify each DG starts and:

a.

In < 9.4 seconds, achieves voltage

Ž 4161 V and frequency Ž 59.7 Hz;

b.

Maintains steady state voltage

> 4161 V and

• 4576 V;

c.

Maintains steady state frequency

Ž 59.7 Hz and < 61.2 Hz; and

d.

Operates for > 5 minutes.

24 months (continued)

SAN ONOFRE--UNIT 2 3.8-11 Amendment No.

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.16 -------------------

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

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG:

24 months

a.

Is capable of being synchronized with offsite power while loaded with emergency loads upon a simulated restoration of offsite power;

b.

Transfers loads to offsite power source; and

c.

Returns to ready-to-load operation, with:

1.

steady state voltage Ž 4161 V and 4576 V;

2.

steady state frequency

Ž 59.7 Hz and

• 61.2 Hz; and

3.

the DG output breaker open.

SR 3.8.1.17

---

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

Credit may be taken for unplanned events that satisfy this SR.

Verify, with a DG operating in test mode 24 months and connected to its bus in parallel with offsite power, an actual or simulated SIAS overrides the test mode by:

a.

Returning the DG to ready-to-load operation, with:

1.

steady state voltage Ž 4161 V and 4576 V;

2.

steady state frequency Ž 59.7 Hz and

• 61.2 Hz; and

3.

the DG output breaker open; and

b.

Automatically energizing the emergency loads from offsite power.

(continued)

SAN ONOFRE--UNIT 2 3.8-12 Amendment No.

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.19 -------------------

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

1.

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

2.

Credit may be taken for unplanned events that satisfy this SR.

3.

To ensure Operability of an AVR, it must have been aligned to the DG during the performance of either SR 3.8.1.9, SR 3.8.1.10, or SR 3.8.1.19 within the last 24 months, plus any allowance per SR 3.0.2.

Verify on an actual or simulated loss of 24 months offsite power signal in conjunction with actual or simulated ESF actuation signals:

a.

De-energization of emergency buses;

b.

Load shedding from emergency buses;

c.

DG auto-starts from standby condition and:

1.

energizes permanently connected loads and resets the 4.16 kV bus undervoltage relay logic in

< 10 seconds;

2.

energizes auto-connected emergency loads through the programmed time interval load sequence;

3.

achieves steady state voltage

> 4161 V and 4576 V;

4.

achieves steady state frequency

> 59.7 Hz and

• 61.2 Hz; and

5.

supplies permanently connected and auto-connected emergency loads for Ž 5 minutes.

(continued)

SAN ONOFRE--UNIT 2 3.8-14 Amendment No.

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

• 1-SR 3.8.1.20 NOTE-----------------

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

Verify, when started simultaneously from standby condition, each DG:

a.

In

• 9.4 seconds, achieves voltage

> 4161 V and frequency

Ž 59.7 Hz;

b.

Maintains steady state voltage

> 4161 V and

• 4576 V; and

c.

Maintains steady state frequency

Ž 59.7 Hz and

• 61.2 Hz.

10 years SAN ONOFRE--UNIT 2 3.8-15 Amendment No.

ATTACHMENT F Proposed Change Notice (PCN) 574 Degraded Voltage Setpoints San Onofre Nuclear Generating Station, Units 2 and 3 Proposed Technical Specifications pages, Unit 3

DG-Undervoltage Start 3.3.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.7.1 Perform CHANNEL CHECK.

12 'hours SR 3.3.7.2 Perform CHANNEL FUNCTIONAL TEST.

24 months SR 3.3.7.3 Perform CHANNEL CALIBRATION with setpoint Allowable Values as follows:

a.

Degraded Voltage Function:

i.

Dropout 2 4109.0 V ii.

Pickup

• 4153.1 V SDVS (Sustained Degraded Grid Voltage Signal):

24 months Time i.

ii.

delay:

127D

• 2.17 seconds.

162D > 78 seconds and <

seconds.

128 DGVSS (Degraded Grid Voltage with SIAS Signal):

Time delay:

i.

127D Ž 1.83 seconds and

• 2.17 seconds.

ii.

162S

Ž 4.16 seconds and

• 4.44 seconds.

iii.

162T > 0.88 seconds and

• 1.62 seconds.

b.

Loss of Voltage Function

• 3796 V Time delay: > 0.75 seconds

• 1.0 seconds at 0 V.

3554 V and and SAN ONOFRE--UNIT 3 3.3-34 Amendment No.

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY 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.

3.

A modified DG start involving idling and gradual acceleration to rated speed may be used for this SR as recommended by the manufacturer.

When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.7 must be met.

4.

To ensure Operability of an AVR, it must have been aligned to the DG during the performance of SR 3.8.1.2 and SR 3.8.1.3 within the last 60 days, plus any allowance per SR 3.0.2.

As specified in Table 3.8.1-1 Verify each DG starts from standby conditions and achieves:

a.

Steady state voltage 4576 V; and

b.

Steady state frequency

• 61.2 Hz.

4161 V and

Ž 59.7 Hz and (continued)

SAN ONOFRE--UNIT 3 3.8-5 Amendment No.

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.7 NOTES-----------------

1.

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

2.

Credit may be taken for unplanned 184 days events that satisfy this SR.

Verify each DG starts from standby condition and:

a.

In

• 9.4 seconds, achieves voltage

Ž 4161 V and frequency

Ž 59.7 Hz;

b.

Maintains steady state voltage 4161 V and

• 4576 V; and

c.

Maintains steady state frequency

Ž 59.7 Hz and

• 61.2 Hz.

SR 3.8.1.8

---

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

1.

Credit may be taken for unplanned events that satisfy this SR.

2.

Testing to satisfy this SR shall 24 months include actual automatic and manual transfer to at least one alternate offsite circuit.

The other alternate offsite circuit may be verified by overlapping circuit tests.

Verify capability of automatic and manual transfer of AC power sources from the normal offsite circuit to each alternate required offsite circuit.

(continued)

SAN ONOFRE--UNIT 3 3.8-7 Amendment No.

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

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

1.

Credit may be taken for unplanned events that satisfy this SR.

2.

To ensure Operability of an AVR, it must have been aligned to the DG during the performance of either SR 3.8.1.9, SR 3.8.1.10, or SR 3.8.1.19 within the last 24 months, plus any allowance per SR 3.0.2.

Verify each DG rejects a load greater than or equal to its associated single largest post-accident load, and:

a.

Following load rejection, the frequency is

• 66.75 Hz;

b.

Within 4 seconds following load rejection, the voltage is

Ž 4161 V and

• 4576 V; and

c.

Within 4 seconds following load rejection, the frequency is Ž 59.7 Hz and

• 61.2 Hz.

24 months SR 3.8.1.10

---

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

1.

Credit may be taken for unplanned events that satisfy this SR.

2.

To ensure Operability of an AVR, it must have been aligned to the DG during the performance of either SR 3.8.1.9, SR 3.8.1.10, or SR 3.8.1.19 within the last 24 months, plus any allowance per SR 3.0.2.

Verify each DG, when connected to its bus in parallel with offsite power and operating with inductive loading that offsite power conditions permit, during and following a load rejection of > 4450 kW and

< 4700 kW:

a.

Does not trip; and

b.

Voltage is maintained

• 5450 V.

24 months (continued)

SAN ONOFRE--UNIT 3 3.8-8 Amendment No.

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

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

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

2.

Credit may be taken for unplanned events that satisfy this SR.

24 months Verify on an actual or simulated loss of offsite power signal:

a.

De-energization of emergency buses;

b.

Load shedding from emergency buses;

c.

DG auto-starts from standby condition and:

1. energizes permanently connected loads and resets the 4.16kV bus undervoltage relay logic in

< 10 seconds;

2.

maintains steady state voltage

> 4161 V and

• 4576 V;

3.

maintains steady state frequency

> 59.7 Hz and < 61.2 Hz; and

4.

supplies permanently connected loads for > 5 minutes.

(continued)

SAN ONOFRE--UNIT 3 3.8-9 Amendment No.

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

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

1.

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

2.

Credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated SIAS, each DG auto-starts from standby condition and:

a.

In < 9.4 seconds, achieves voltage

> 4161 V and frequency > 59.7 Hz;

b.

Maintains steady state voltage

> 4161 V and < 4576 V; and

c.

Maintains steady state frequency

>Ž 59.7 Hz and < 61.2 Hz.

d.

Operates for > 5 minutes.

24 months

.5-SR 3.8.1.13

---

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

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG automatic trip is bypassed on actual or simulated SIAS except:

a.

Engine overspeed;

b.

Generator differential current; and

c.

Low-low lube oil pressure.

24 months (continued)

SAN ONOFRE--UNIT 3 3.8-10 Amendment No.

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

• 1-SR 3.8.1.14

---

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

1.

Momentary transients outside the load range does not invalidate this test.

2.

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG, when connected to its bus in parallel with offsite power and operating with inductive loading that offsite power conditions permit, operates for > 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />s:

a.

For > 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> loaded Ž 4935 kW and

• 5170 kW; and

b.

• For the remaining hours of the test loaded > 4450 kW and

• 4700 kW.

24 months SR 3.8.1.15 -------------------

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

1.

This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated > 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> loaded

Ž 4450 kW and

• 4700 kW.

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

2.

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

Verify each DG starts and:

a.

In

• 9.4 seconds, achieves voltage

> 4161 V and frequency Ž 59.7 Hz;

b.

Maintains steady state voltage 4161 V and

• 4576 V;

c.

Maintains steady state frequency 2 59.7 Hz and < 61.2 Hz; and

d.

Operates for > 5 minutes.

24 months (continued)

SAN ONOFRE--UNIT 3 3.8-11 Amendment No.

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.16 NOTE-----------------

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG:

a.

Is capable of being synchronized with offsite power while loaded with emergency loads upon a simulated restoration of offsite power;

b.

Transfers loads to offsite power source; and

c.

Returns to ready-to-load operation, with:

1.

steady state voltage Ž 4161 V and 4576 V;

2.

steady state frequency Ž 59.7 Hz and

• 61.2 Hz; and

3.

the DG output breaker open.

24 months SR 3.8.1.17 NOTE-----------------

Credit may be taken for unplanned events that satisfy this SR.

Verify, with a DG operating in test mode and connected to its bus in parallel with offsite power, an actual or simulated SIAS overrides the test mode by:

a.

Returning the DG to ready-to-load operation, with:

1.

steady state voltage Ž 4161 V and

< 4576 V;

2.

steady state frequency 2 59.7 Hz and < 61.2 Hz; and

3.

the DG output breaker open; and

b.

Automatically energizing the emergency loads from offsite power.

24 months (continued)

SAN ONOFRE--UNIT 3 3.8-12 Amendment No.

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.19 ------------------

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

1.

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

2.

Credit may be taken for unplanned events that satisfy this SR.

3.

To ensure Operability of an AVR, it must have been aligned to the DG during the performance of either SR 3.8.1.9, SR 3.8.1.10, or SR 3.8.1.19 within the last 24 months, plus any allowance per SR 3.0.2.

Verify on an actual or simulated loss of 24 months offsite power signal in conjunction with actual or simulated ESF actuation signals:

a.

De-energization of emergency buses;

b.

Load shedding from emergency buses;

c.

DG auto-starts from standby condition and:

1.

energizes permanently connected loads and resets the 4.16 kV bus undervoltage relay logic in

< 10 seconds;

2.

energizes auto-connected emergency loads through the programmed time interval load sequence;

3.

achieves steady state voltage

> 4161 V and

• 4576 V;

4.

achieves steady state frequency

> 59.7 Hz and < 61.2 Hz; and

5.

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

(continued)

SAN ONOFRE--UNIT 3 3.8-14 Amendment No.

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.20

---

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

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

Verify, when started simultaneously from standby condition, each DG:

a.

In < 9.4 seconds, achieves voltage

Ž 4161 V and frequency

Ž 59.7 Hz;

b.

Maintains steady state voltage

Ž 4161 V and < 4576 V; and

c.

Maintains steady state frequency 2 59.7 Hz and

• 61.2 Hz.

10 years SAN ONOFRE--UNIT 3 3.8-15 Amendment No.

ATTACHMENT G Proposed Change Notice (PCN) 574 Degraded Voltage Setpoints San Onofre Nuclear Generating Station, Units 2 and 3 Proposed Bases pages (for information only), Unit 2

AC Sources - Operating B 3.8.1 BASES (continued)

LCO (continued) sequence intervals, and continue to operate until offsite power can be restored to the ESF buses.

These capabilities are required to be met from a variety of initial conditions such as:

DG in standby with the engine hot, DG in standby with the engine at ambient conditions, and DG operating in a parallel test mode.

A DG is considered already operating if the DG voltage is

Ž 42-9-7 4161 V and < 4576 volts and the frequency is

> 59.7 and

• 61.2 Hz.

Proper sequencing of loads, including tripping of nonessential loads on a SIAS, is a required function for DG OPERABILITY.

The AC sources in one train must be separate and independent (to the extent possible) of the AC sources in the other train.

For the DGs, separation and independence are complete.

For the offsite AC sources, separation and independence are to the extent practical.

A circuit may be connected to more than one ESF bus, with transfer capability to the other circuit, and not violate separation criteria.

APPLICABILITY The AC sources and associated automatic load sequence timers are required to be OPERABLE in MODES 1, 2, 3, and 4 to ensure that:

a.

Acceptable fuel design limits and reactor coolant pressure boundary limits are not exceeded as a result of AOOs or abnormal transients; and

b.

Adequate core cooling is provided and containment OPERABILITY and other vital functions are maintained in the event of a postulated DBA.

The AC power requirements for MODES 5 and 6 are covered in LCO 3.8.2, "AC Sources-Shutdown."

ACTIONS A.1 To ensure a highly reliable power source remains with the one offsite circuit inoperable, it is necessary to verify the OPERABILITY of the remaining required offsite circuit on (continued)

SAN ONOFRE--UNIT 2 B 3.8-5 Amendment No. 127 19/%#/-9

AC Sources -Operating B 3.8.1 BASES (continued)

SURVEILLANCE REQUIREMENTS (continued)

Where the SRs discussed herein specify voltage and frequency tolerances, the following is anDlicable.

The minimum steady state output voltage of 4-2-9 4161 V is above the maximum reset voltage of the 4.16 kV bus undervoltaqe relays (Ref.

SR 3.3.7).

Achieving a voltage at or above 4-2-9 4161 V ensures that the LOVS/SDVS/DGVSS relay logic will reset allowing sequencing of the ESF loads on to the ESF bus if one or more ESF actuation signals is present.

This minimum voltage limit, which is consistent with ANSI C84.1-1982 (Ref.

11),

is above the allowed voltage drop to the terminals of 4160 V motors whose minimum steady state operating voltage is 3744 V (90% of 4160 V).

This minimum voltage requirement also ensures that adequate voltage is provided to motors and other equipment down through the 120 V level.

The specified maximum steady state output voltage of 4576 V ensures that, for a lightly loaded distribution system, the voltage at the terminals of 4160 V motors is no more than the maximum allowable steady state operating voltage (110% of 4160V).

The specified minimum and maximum frequencies of the DG are 59.7 Hz and 61.2 Hz, respectively.

The upper frequency limit is equal to + 2% of the 60 Hz nominal frequency and is derived from the recommendations given in Regulatory Guide 1.9 (Ref.

3).

The lower frequency limit is equal to

- 0.5% of the 60 Hz nominal frequency and is based on maintaining acceptable high pressure safety injection system performance as assumed in the accident analyses.

During a DG surveillance test, steady state DG voltage of 42-9-7 4161 to 4576 volts and steady state frequency of 59.7 to 6.1.2 Hz shall be verified.

For the lower voltage and frequency limits, the Total Loop Uncertainty (TLU) of the measurement device (Reference Calculation E4C-098 and E4C-130) shall be considered.

SR 3.8.1.1 This SR assures proper circuit continuity for the offsite AC electrical power supply to the onsite distribution network and availability of offsite AC electrical power.

The breaker alignment verifies that each breaker is in its correct position to ensure that distribution buses and loads are connected to their preferred power source, and that availability of independent offsite circuits is maintained.

The 7 day Frequency is adequate since breaker position is not likely to change without the operator being aware of it and because its status is displayed in the control room.

(continued)

SAN ONOFRE--UNIT 2 B 3.8-14 Amendment No. 12i 10-O/-99

AC Sources -Operating B 3.8.1 BASES (continued)

SURVEILLANCE SR 3.8.1.2 and SR 3.8.1.7 (continued)

REQUI REMENTS The normal 31 day Frequency for SR 3.8.1.2 (see Table 3.8.1-1, "Diesel Generator Test Schedule," in the accompanying LCO) and the 184 day Frequency for SR 3.8.1.7 are consistent with Regulatory Guide 1.9 (Ref.

3).

These frequencies provide adequate assurance of DG OPERABILITY, while minimizing degradation resulting from testing.

Note 4 - This note discusses operability of the diesel generator subcomponent Automatic Voltage Regulator (AVR).

The AVR is an integral part of the DG, however, each DG has 2 AVRS that are 100% redundant to each other.

Only one AVR may be inservice at any one time.

To ensure operability of each AVR, the AVRs must have been in service during the performance of SR 3.8.1.2 and SR 3.8.1.3 within the last 60 days plus any allowance per SR 3.0.2.

SR 3.8.1.2 is modified by NOTE 1 to indicate that SR 3.8.1.7 satisfies all of the requirements of SR 3.8.1.2.

This note is applicable for AVR operability.

Also, each AVR must have been in service for either SR 3.8.1.9, SR 3.8.1.10, or SR 3.8.1.19 within the last 24 months plus any allowance per SR 3.0.2.

During the 24 month test dynamic performance of the AVR is measured to confirm it is acceptable for all required AVR transients.

Based on the design of the AVR, its intended function and the maintenance history, the above specified surveillance schedule will assure the AVRs are capable of performing their intended function.

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 listed in Reference 2.

This capability is verified bv Derforminc a load test between 90 to 100% of rated lead test eauivalent to 90% to 100% of the continuous duty rating of the DG, for an interval of not less than 60 minutes, consistent with the requirements of Regulatory Guide 1.9 (Ref.

3).

The lower load limit of 4450 kW is 94.7%

of the DG continuous rating (4700 kW).

The 94.7% limit is based on design basis loading and includes instrument uncertainty plus margin.

Instrument uncertainty is not applied to the upper load limit.

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 surveillance is pertormed with DG kVAR output that offsite power system conditions permit during testing without exceeding equipment ratings (i.e., without creating an overvoltage condition on the ESF buses, over excitation condition on the ESF buses, over excitation condition in the enerator, or overloading the DG main feeder).

The kVAR oading requirement during this test is met, and the equipment ratings are not exceeded, when the DG kVAR output is increased such that:

(continued)

SAN ONOFRE--UNIT 2 B 3.8-16 Amendment No.

127 06/*o-4+

ATTACHMENT H Proposed Change Notice (PCN) 574 Degraded Voltage Setpoints San Onofre Nuclear Generating Station, Units 2 and 3 List of Regulatory Commitments

List of Regulatory Commitments

1.

(NONE).