Text

Response to Request for Additional Information and Submittal of Supplement 1 to Proposed Change Number NPF-10/15-564 License Amendment Request, Application for Technical Specification Improvement Regarding Steam Generator
	ML061530259
Person / Time
Site:	San Onofre
Issue date:	05/30/2006
From:	Katz B; Southern California Edison Co
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	TAC MC9236, TAC MC9237
	Download: ML061530259 (63)
	v • d • e

SOUTHERN CALIFORNIA Brian Katz

~

E DSON~Vice President EDISON" An EDISON INTERNATIONAL" Company May 30, 2006 U.S. Nuclear Regulatory Commission Attn: Document Control Desk Washington, DC 20555

Subject:

San Onofre Nuclear Generating Station, Units 2 and 3 Docket Nos. 50-361 and 50-362 Response to Request for Additional Information and Submittal of Supplement i to Proposed Change Number NPF-1011 5-564 License Amendment Request, "Application for Technical Specification Improvement Regarding Steam Generator Tube Integrity"

References:

1 Letter from Brian Katz (SCE) to Document Control Desk (NRC) Dated November 30, 2005,

Subject:

Docket Nos. 50-361 and 50-362, Proposed Change Number NPF-10/15-564, Application for Technical Specification Improvement Regarding Steam Generator Tube Integrity, San Onofre Nuclear Generating Station, Units 2 and 3 2 Letter from N. Kalyanam (NRC) to Richard M. Rosenblum (SCE) Dated April 21, 2006,

Subject:

San Onofre Nuclear Generating Station, Units 2 and 3 -

Request for Additional Information on the Proposed Technical Specification Improvement Regarding Steam Generator Tube Integrity Based on Technical Specification Task Force (TSTF)-449, "Steam Generator Tube Integrity" (TAC Nos. MC9236 and MC9237)

Dear Sir or Madam:

Southern California Edison (SCE) submitted Reference I on November 30, 2005 to request license amendments for San Onofre Units 2 and 3. The proposed amendments would revise the Technical Specification (TS) requirements related to steam generator (SG) tube integrity. On April 21, 2006 the NRC provided SCE a Request for Additional Information (RAI), Reference 2, to facilitate NRC Staff review of Reference 1. This letter provides the additional information and an associated supplement to the proposed amendment. is Supplement I to Reference 1. The supplement provides modifications to Reference I Technical Specification change pages that provide consistency with.

P.O. Box 128 San Clemente, CA 92674-012c 949-368-9275 Fax 949-368-9881

Document Control Desk May 30, 2006 is the response to the NRC RAI (Reference 2).

Should you have any questions, or require additional information, please contact Mr. Jack Rainsberry at (949) 368-7420.

Sincerely, d<L-9 Enclosures I

Notarized affidavit, Unit 2 2 Notarized affidavit, Unit 3 3 Supplement I to the Proposed License Amendment Request, Proposed Change Number NPF-10115-564, with Attachments A - F (modifications to Technical Specification change pages) 4 Response to NRC Request for Additional Information (RAI) (Reference 2) cc:

B.

N.

C.

S.

S.. Mallett, Regional Administrator, NRC Region IV

Kalyanam, NRC Project Manager, San Onofre Units 2 and 3 C. Osterholtz, NRC Senior Resident Inspector, San Onofre Units 2 and 3 Y. Hsu, Calif6rnia Department of Health Services, Radiologic Health Branch

Enclosure I 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)

)

Docket No. 50-361

)

Supplement 1 to

)

Amendment Application

)

No. 240 SOUTHERN CALIFORNIA EDISON COMPANY, ET AL. pursuant to 10 CFR 50.90, hereby submit Supplement I to Amendment Application No. 240. This amendment application consists of Supplement I to Proposed Change No. NPF-10-564 to Facility Operating License NPF-1 0. Proposed Change No. NPF-1 0-564 is a request to revise Facility Operating License NPF-10 to revise the TS requirements related to steam generator tube integrity.

State of California County of San Diego Brian Katz, Vice Preside&

Subscribed and sworn to (,or-'hffimed-)-before me on this,2di.

day of 14?-az

,2-goo&

By'brWarx I*d~

personally known to me OF.P "ed-,,

person who appeared before me.

im1 I L

-thebsso~aisatr-vde to be the Notary Public DAVM A. FARRM

- -Coff-M-ulo-n *-1623105 Nokxy Public - Calibmic sm Dimp courty My Conm EM*se Nov 12Ato Le WWWW4 I

UNITED STATES OF AMERICA NUCLEAR REGULATORY COMMISSION Application of SOUTHERN CALIFORNIA

)

EDISON COMPANY, ET AL. for a Class 103 )

Docket No. 50-362 License to Acquire, Possess, and Use

)

Supplement I to a Utilization Facility as Part of

)

Amendment Application Unit No. 3 of the San Onofre Nuclear

)

No. 224 Generating Station)

SOUTHERN CALIFORNIA EDISON COMPANY, ET AL. pursuant to 10 CFR 50.90, hereby submit Supplement I to Amendment Application No. 224. This amendment application consists of Supplement I to Proposed Change No. NPF-15-564 to Facility Operating License NPF-15. Proposed Change No. NPF-15-564 is a request to revise Facility Operating License NPF-15 to revise the TS requirements related to steam generator tube integrity.

State of California County of San Diego Brian Katz, Vice Presidei=lt' Subscribed and sworn to (e.aftrmed) before me on this 041n day of By r

K~1i personally known to me o poved to uR i

ut',

b o

o be the person who appeared before me.

otary Pub*ic DAWmioNg A FAoR r

Noly Pubft - Cafwomi j*)

scn QW00cou*

Q 1V Cahfb0Nov2%jp Supplement I to the Proposed License Amendment Request, Proposed Change Number NPF-1 0/15-564, with attachments A - F (modifications to Technical Specification change pages)

LICENSEE'S EVALUATION DESCRIPTION FOR PROPOSED CHANGE NPF-10/15-564 SUPPLEMENT 1 PROPOSED TECHNICAL SPECIFICATION CHANGE, APPLICATION FOR TECHNICAL SPECIFICATION IMPROVEMENT REGARDING STEAM GENERATOR TUBE INTEGRITY San Onofre Nuclear Generating Station Units 2 and 3 ORIGINAL PCN-564 PROPOSED TECHNICAL SPECIFICATION CHANGE (Original PCN-564 [Attachments E and F] Pages)

Unit 2: see Attachment A Unit 3: see Attachment B PCN-564 SUPPLEMENT 1 PROPOSED TECHNICAL SPECIFICATION CHANGE REVISIONS (highlight for additions, strikeout for deletions)

Unit 2: see Attachment C (To replace corresponding PCN-564 pages.)

Unit 3: see Attachment D (To replace corresponding PCN-564 pages.)

PCN-564 SUPPLEMENT 1 PROPOSED TECHNICAL SPECIFICATIONS PAGE CHANGES (with changes)

Unit 2: see Attachment E (To replace corresponding PCN-564 pages.)

Unit 3: see Attachment F (To replace corresponding PCN-564 pages.)

1.0 INTRODUCTION

This supplement to PCN-564 provides revised proposed Technical Specification change pages that provide consistency with the SCE responses to the NRC request for additional information (RAI) in NRC to SCE letter dated April 21, 2006.

2.0 PROPOSED CHANGE

The following proposed changes address applicable RAI responses as indicated:

LCO 3.4.17. CONDITION B is editorially revised from "Required Action and associated Completion Time Condition A not met" to "Required Action and associated Completion Time of Condition A not met" to address NRC request for additional information (RAI) question number 2.

Section 5.5.2.11 Steam Generator (SG) Program paragraph 5.5.2.11.c is rewritten to address RAI question numbers 4 and 5.

Section 5.5.2.11 Steam Generator (SG) Program paragraph 5.5.2.1 1.d is revised to add "d.4," a reference to an added paragraph. Subsequently, paragraph 5.5.2.11.d.4 is added to Section 5.5.2.11.d. These two revisions address RAI question number 3.

Section 5.5.2.11 Steam Generator (SG) Program paragraph 5.5.2.11.d.2 is revised to delete "and sleeves" to address RAI question number 6.

Section 5.5.2.11 Steam Generator (SG) Program paragraph 5.5.2.11.f.1 first sentence is revised to add "with heat treatment" and first sentence of second paragraph is deleted to address RAI question number 7.

Section 5.5.2.11 Steam Generator (SG) Program paragraph 5.5.2.11.f.1 second paragraph "full" is replaced with "entire" to enhance consistency with the SG tube definition discussed in RAI question number 6.

3.0 REGULATORY SAFETY ANALYSIS The No Significant Hazards Consideration and Environmental Evaluation, provided with PCN-564, both remain bounding.

Attachment A (Original PCN 564 [Attachment E] Pages)

SONGS Unit 2

TABLE OF CONTENTS 3.3 INSTRUMENTATION (continued) 3.3.5 Engineered Safety Features Actuation System (ESFAS)

Instrumentation 3.3-22 3.3.6 Engineered Safety Features Actuation System (ESFAS) 3 Logic and Manual Trip.......

.. 3.3-27 3.3.7 Diesel Generator (DG) -Undervoltage Start.

.. 3.3-32 3.3.8 Containment Purge Isolation Signal (CPIS)........

3.3-35 3.3.9 Control Room Isolation Signal (CRIS) 3.3-39 3.3.10 Fuel Handling Isolation Signal (FHIS) 3.3-42 3.3.11 Post Accident Monitoring Instrumentation (PAMI).

3.3-44 3.3.12 Remote Shutdown System.

3.3-48 3.3.13 Source Range Monitoring Channels 3.3-51 3.4 REACTOR COOLANT SYSTEM (RCS).........

3.4-1 3.4.1 RCS DNB Pressure, Temperature, and Flow Limits........

3.4-1 3.4.2 RCS Minimum Temperature'for'Criticaiity" "........3.4-4 3.4.3 RCS Pressure and Temperature (P/T) Limits........

3.4-5 3.4.3.1 Pressurizer Heatup/Cooldown Limits.............

3.4-13 3.4.4 RCS Loops-MODES l and 2....................

3.4-15 3.4.5 RCS Loops-MODE 3......

3.4-16 3.4.6 RCS Loops-MODE 4......

3.4-18 3.4.7 RCS Loops-MODE 5, Loops Filled......

3.4-21 3.4.8 RCS Loops -MODE 5, Loops Not Filled...........

3.4-24 3.4.9 Pressurizer 3.4-26 3.4.10 Pressurizer Safety Valves.

3.4-28 3.4.11 Not Used 3.4.12.1 Low Temperature Overpressure Protection (LTOP)

System, RCS Temperature < 256 0 F 3.4-30 3.4.12.2 Low Temperature Overpressure Protection (LTOP)

System, RCS Temperature > 256°F...........

3.4-35 3.4.13 RCS Operational LEAKAGE...............

3.4-37 3.4.14 RCS Pressure Isolation Valve (PIV)

Leakage.

3.4-39 3.4.15 RCS Leakage Detection Instrumentation.........

3.4-44 3.4.16 RCS Specific Activity....................

3.4-47 3.4.17 RCS Steam Generator (SG)

Tube Integrity..........

3.4-51 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS)

... 3.5-1 3.5.1 Safety Injection Tanks (SITs)..............

3.5-1 3.5.2 ECCS-Operating........................

3.5-4 3.5.3 ECCS -Shutdown 3.5-8 3.5.4 Refueling Water Storage Tank (RWST) 3.5-9 3.5.5 Trisodium Phosphate (TSP)......

3.5-11 (continued)

SAN ONOFRE--Unit 2 ii i Amendment No.

TABLE OF CONTENTS B 3.3 B 3.3.7 B 3.3.8 B 3.3.9 B 3.3.10 B 3.3.11 B 3.3.12 B 3.3.13 B 3.4 B 3.4.1 B 3.4.2 B 3.4.3 B 3.4.4 B 3.4.5 B 3.4.6 B 3.4.7 B 3.4.8 B 3.4.9 B 3.4.10 B 3.4.11 B 3.4.12.1 B 3.4.12.2 B 3.4.13 B 3.4.14 B 3.4.15 B 3.4.16 B 3.4.17 B 3.5 B 3.5.1 B 3.5.2 B 3.5.3 B 3.5.4 B 3.5.5 B 3.6 B 3.6.1 B 3.6.2 B 3.6.3 B 3.6.4 B 3.6.5 B 3.6.6.1 B 3.6.6.2 B 3.6.7 B 3.6.8 INSTRUMENTATION (continued)

Diesel Generator Undervoltage Start Containment Purge Isolation Signal (CPIS)

Control Room Isolation Signal (CRIS)........

Fuel Handling Isolation Signal (FHIS)

Post Accident Monitoring Instrumentation iPAMi)

Remote Shutdown System..................

Source Range Monitoring Channels...........

REACTOR COOLANT SYSTEM (RCS)

RCS DNB (Pressure, Temperature, and Flow) Limits RCS Minimum Temperature for Criticality RCS Pressure and Temperature (P/T) Limits RCS Loops-MODES 1 and 2................

RCS Loops-MODE 3 RCS Loops-MODE 4 RCS Loops-MODE 5, Loops Filled RCS Loops-MODE 5, Loops Not Filled Pressurizer Pressurizer Safety Valves.

Not Used Low Temperature Overpressure Protection (LTOP)

System, RCS Temperature

256 0 F Low Temperature Overpressure Protection (LTOP)

System, RCS Temperature > 256 0 F..........

RCS Operational LEAKAGE RCS Pressure Isolation Valve (PIV)

Leakage RCS Leakage Detection Instrumentation RCS Specific Activity RCS Steam Generator (SG)

Tube Integrity EMERGENCY CORE COOLING SYSTEMS (ECCS)

Safety Injection Tanks (SITs)

ECCS -Operating ECCS -Shutdown Refueling Water Storage Tank (RWST)

Trisodium Phosphate (TSP)

B 3.3-126 B 3.3-135 B 3.3-145 B 3.3-152 B 3.3-159 B 3.3-176 B 3.3-181 B 3.4-1 B 3.4-1 B 3.4-7 B 3.4-9 B 3.4-23 B 3.4-27 B 3.4-31 B 3.4-36 B 3.4-42 B 3.4-46 B 3.4-51 B 3.4-55 B 3.4-65 B 3.4-70 B 3.4-76 B 3.4-82 B 3.4-88 B 3.4-93 B 3.5-1 B 3.5-1 B 3.5-11 B 3.5-21 B 3.5-24 B 3.5-30 B 3.6-1 B 3.6-1 B 3.6-5 B 3.6-13 B 3.6-27 B 3.6-30 B 3.6-33 B 3.6-43 B 3.6-48 B 3.6-53 CONTAINMENT SYSTEMS Containment Containment Air Locks Containment Isolation Valves Containment Pressure...........

Containment Air Temperature Containment Spray and Cooling System Containment Cooling System.....

Hydrogen Recombiners...........

Containment Dome Air Circulators..

(continued)

SAN ONOFRE--Unit 2 vii Amendment No.

Definitions 1.1 1.1 Definitions ENGINEERED SAFETY FEATURE (ESF)

RESPONSE

TIME (Continued) measurement, response time may be verified for selected components provided that the components and methodology for verification have been previously reviewed and approved by the NRC.

LEAKAGE LEAKAGE shall be:

a.

Identified LEAKAGE

1. LEAKAGE, such as that from pump seals or valve packing (except reactor coolant pump (RCP) leakoff), that is captured and conducted to collection systems or a sump or collecting tank;

2.

LEAKAGE into the containment atmosphere from sources that are both specifically located and known either not to interfere with the operation of leakage detection systems or not to be pressure boundary LEAKAGE; or

3. Reactor Coolant System (RCS) through a steam generator to System (primary to secondary LEAKAGE the Secondary LEAKAGE).

b.

Unidentified LEAKAGE All LEAKAGE that is not identified LEAKAGE.

c.

Pressure Boundary LEAKAGE MODE LEAKAGE (except primary to secondary LEAKAGE) through a nonisolable fault in an RCS component body, pipe wall, or vessel wall.

A MODE shall correspond to any one inclusive combination of core reactivity condition, power level, average reactor coolant temperature, and reactor vessel head closure bolt tensioning specified in Table 1.1-1 with fuel in the reactor vessel.

(continued)

SAN ONOFRE--UNIT 2 1.1-4 Amendment No.

RCS Operational LEAKAGE 3.4.13 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.13 RCS Operational LEAKAGE LCO 3.4.13 RCS operational LEAKAGE shall be limited to:

a.

No pressure boundary LEAKAGE;

b.

I gpm unidentified LEAKAGE;

c.

10 gpm identified LEAKAGE; and

d.

150 gallons per day primary to secondary LEAKAGE through any one Steam Generator (SG).

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

RCS Operational A.1 Reduce LEAKAGE to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months LEAKAGE not within within limits.

limits for reasons other than pressure boundary LEAKAGE or primary to secondary LEAKAGE.

B.

Required Action and B.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A AND not met.

B.2 Be in MODE 5.

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR Pressure boundary LEAKAGE exists.

OR Primary to secondary LEAKAGE not within limit.

SAN ONOFRE--UNIT 2 3.4-37 Amendment No.

RCS Operational LEAKAGE 3.4.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY 4

SR 3.4.13.1 ------------------ NOTES---------------

1.

Not required to be performed in MODE 3 or 4 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months of steady state operation.

2.

Not applicable to primary to secondary LEAKAGE.

Perform RCS water inventory balance.

NOTE ------

Only required to be performed during steady state operation.

If a transient evolution is occurring 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months from the last water inventory balance, then a water inventory balance shall be performed within 120 hours0.00139 days 0.0333 hours 1.984127e-4 weeks 4.566e-5 months of the last water inventory balance 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months

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

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after establishment of steady state operation.

SR 3.4.13.2 Verify primary to secondary LEAKAGE is 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months

< 150 gallons per day through any one SG.

SAN ONOFRE--UNIT 2 3.4-38 Amendment No.

SG Tube Integrity 3.4.17 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.17 Steam Generator (SG)

Tube Integrity SG tube integrity shall be maintained.

LCO 3.4.17 AND All SG tubes satisfying the tube repair criteria shall be plugged or repaired in accordance with the Steam Generator Program.

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTIONS

NOTE Separate Condition entry is allowed for each SG tube.

CONDITION REQUIRED ACTION COMPLETION TIME A.

One or more SG tubes A.1 Verify tube integrity 7 days satisfying the tube of the affected repair criteria and tube(s) is maintained not plugged or until the next repaired in accordance refueling outage or with the Steam SG tube inspection.

Generator Program.

AND A.2 Plug or repair the Prior to affected tube(s) in entering MODE 4 accordance with the following the Steam Generator next refueling Program.

outage or SG tube inspection B.

Required Action and B.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time Condition A not AND met.

B.2 Be in MODE 5.

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR SG tube integrity not maintained.

SAN ONOFRE--UNIT 2 3.4-51 Amendment No.

SG Tube Integrity 3.4.17 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.17.1 Verify SG tube integrity in accordance with In accordance the Steam Generator Program.

with the Steam Generator Program SR 3.4.17.2 Verify that each inspected SG tube that Prior to satisfies the tube repair criteria is entering MODE 4 plugged or repaired in accordance with the following a SG Steam Generator Program.

tube inspection I

SAN ONOFRE--UNIT 2 3.4-52 Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.8 Primary Coolant Sources Outside Containment Program (continued) system (post-accident sampling return piping only until such time as a modification eliminates the post-accident piping as a potential leakage path).

The program shall include the following:

a.

Preventive maintenance and periodic visual inspection requirements; and

b.

Integrated leak test requirements for each system at refueling cycle intervals or less.

5.5.2.9 Pre-Stressed Concrete Containment Tendon Surveillance Program This program provides controls for monitoring any tendon degradation in pre-stressed concrete containment, including effectiveness of its corrosion protection medium, to ensure containment structural integrity.

Program itself is relocated to the LCS.

5.5.2.10 Inservice Inspection and Testing Program This program provides controls for inservice inspection of ASME Code Class 1, 2, and 3 components and Code Class CC and MC components including applicable supports.

The program provides controls for inservice testing of ASME Code Class 1, 2, and 3 components.

The program itself is located in the LCS.

5.5.2.11 Steam Generator (SG)

Program A Steam Generator Program shall be established and implemented to ensure that SG tube integrity is maintained.

In addition, the Steam Generator Program shall include the following provisions:

a.

Provisions for condition monitoring assessments.

Condition monitoring assessment means an evaluation of the "as found" condition of the tubing with respect to the performance criteria for structural integrity and accident induced leakage.

The "as found" condition refers to the condition of the tubing during an SG inspection outage, as determined from the inservice inspection results or by other means, prior to the plugging or repair of tubes.

Condition monitoring assessments shall be conducted during each outage during which the SG tubes are inspected, plugged, or repaired to confirm that the performance criteria are being met.

(continued)

SAN ONOFRE--UNIT 2 5.0-13 Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG)

Program (continued)

b.

Performance criteria for SG tube integrity.

SG tube integrity shall be maintained by meeting the performance criteria for tube structural integrity, accident induced leakage, and operational LEAKAGE.

1.

Structural integrity performance criterion: All in-service steam generator tubes shall retain structural integrity over the full range of normal operating conditions (including startup, operation in the power range, hot standby, and cool down and all anticipated transients included in the design specification) and design basis accidents.

This includes retaining a safety factor of 3.0 against burst under normal steady state full power operation primary-to-secondary pressure differential and a safety factor of 1.4 against burst applied to the design basis accident primary-to-secondary pressure differentials.

Apart from the above requirements, additional loading conditions associated with the design basis accidents, or combination of accidents in accordance with the design and licensing basis, shall also be evaluated to determine if the associated loads contribute significantly to burst or collapse.

In the assessment of tube integrity, those loads that do significantly affect burst or collapse shall be determined and assessed in combination with the loads due to pressure with a safety factor of 1.2 on the combined primary loads and 1.0 on axial secondary loads.

2.

Accident induced leakage performance criterion: The primary to secondary accident induced leakage rate for any design basis accident, other than a SG tube rupture, shall not exceed the leakage rate assumed in the accident analysis in terms of total leakage rate for all SGs and leakage rate for an individual SG.

Leakage is not to exceed 0.5 gpm per SG and I gpm through both SGs.

3.

The operational LEAKAGE performance criterion is specified in LCO 3.4.13, "RCS Operational LEAKAGE."

(continued)

SAN ONOFRE--UNIT 2 5.0-14 Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG)

Program (continued)

c.

Provisions for SG tube repair criteria.

Tubes found by inservice inspection to contain flaws with a depth equal to or exceeding 44% of the nominal tube wall thickness shall be plugged or repaired.

Sleeves shall be removed from service upon detection of service-induced degradation of the sleeve material or any portion of the sleeve-to-tube weld.

d.

Provisions for SG tube inspections.

Periodic SG tube inspections shall be performed.

The number and portions of the tubes inspected and methods of inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable tube repair criteria.

The tube-to-tubesheet weld is not part of the tube.

In addition to meeting the requirements of d.1, d.2, and d.3 below, the inspection scope, inspection methods, and inspection intervals shall be such as to ensure that SG tube integrity is maintained until the next SG inspection.

An assessment of degradation shall be performed to determine the type and location of flaws to which the tubes may be susceptible and, based on this assessment, to determine which inspection methods need to be employed and at what locations.

1.

Inspect 100% of the tubes in each SG during the first refueling outage following SG replacement.

2.

Inspect 100% of the tubes and sleeves at sequential periods of 60 effective full power months.

The first sequential period shall be considered to begin after the first inservice inspection of the SGs.

No SG shall operate for more than 24 effective full power months or one refueling outage (whichever is less) without being inspected.

(continued)

SAN ONOFRE--UNIT 2 5.0-15 Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG)

Program (continued)

3.

If crack indications are found in any SG tube, then the next inspection for each SG for the degradation mechanism that caused the crack indication shall not exceed 24 effective full power months or one refueling outage (whichever is less).

If definitive information, such as from examination of a pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a crack-like indication is not associated with a crack(s), then the indication need not be treated as a crack.

e.

Provisions for monitoring operational primary to secondary LEAKAGE.

f.

Provisions for SG tube repair methods.

Steam generator tube repair methods shall provide the means to re-establish the RCS pressure boundary integrity of SG tubes without removing the tube from service.

For the purposes of these Specifications, tube plugging is not a repair.

All acceptable tube repair methods are listed below.

1.

TIG welded sleeving as described in ABB/CE Topical Report, CEN-630-P, Rev. 2, is currently approved by the NRC.

Tube repair includes the installation by welding of the sleeves, heat treatment in accordance with CEN-630-P, Rev. 2, to remove the stresses that are introduced by the sleeve installation, acceptance testing of the sleeve, and nondestructive examination for future comparison.

Tube repair can be performed on certain tubes that have been previously plugged as a corrective or preventive measure.

A tube inspection of the full length of the tube shall be performed on a previously plugged tube prior to returning the tube to service.

(continued)

SAN ONOFRE--UNIT 2 5.0-16 Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.12 Ventilation Filter Testing Program (VFTP)

This Program establishes the required testing of the Engineered Safety Feature filter ventilation systems, "Control Room Emergency Air Cleanup System" and "Fuel Handling Building Post-accident Cleanup Filter System."

The frequency of testing shall be in accordance with Regulatory Guide 1.52, Revision 2.

As a minimum the VFTP program shall include the following:

a.

Inplace testing of the high efficiency particulate air (HEPA) filters to demonstrate acceptable penetration and system bypass when tested at the appropriate system flowrate in accordance with Regulatory Guide 1.52, Revision 2, and ANSI N510-1975 (see Note 1); and

b.

Inplace testing of the charcoal adsorber to demonstrate acceptable penetration and system bypass when tested at the appropriate system flowrate in accordance with Regulatory Guide 1.52, Revision 2, and ANSI N510-1975 (see Note 1); and

c.

Laboratory testing of charcoal adsorber samples obtained in accordance with Regulatory Guide 1.52, Revision 2 and tested per the methodology of ASTM D3803-1989 at 300C and 70%

relative humidity to show acceptable methyl iodide penetration; and

d.

Testing to demonstrate the pressure drop across the combined HEPA filters, the prefilters, and the charcoal adsorbers, when tested at the appropriate system flowrate.

Note 1:

Sample and injection points shall be qualified per ANSI N510-1975 unless manifolds have been qualified per ASME N510-1989.

HEPA testing will be conducted with DOP aerosol or suitable alternate.

(continued)

SAN ONOFRE--UNIT 2 5.0-17 Amendment No.

Reporting Requirements 5.7 5.7 Reporting Requirements (continued) 5.7.2 Special Reports Special Reports may be required covering inspection, test, and maintenance activities.

These special reports are determined on an individual basis for each unit and their preparation and submittal are designated in the Technical Specifications.

Special Reports shall be submitted to the U. S. Nuclear Regulatory Commission, Attention: Document Control Desk, Washington, D. C.

20555, with a copy to the Regional Administrator of the Regional Office of the NRC, in accordance with 10 CFR 50.4 within the time period specified for each report.

The following Special Reports shall be submitted:

a.

When a pre-planned alternate method of monitoring post-accident instrumentation functions is required by Condition B or Condition G of LCO 3.3.11, a report shall be submitted within 30 days from the time the action is required.

The report shall outline the action taken, the cause of the inoperability, and the plans and schedule for restoring the instrumentation channels of the function to OPERABLE status.

b.

Any abnormal degradation of the containment structure detected during the tests required by the Pre-Stressed Concrete Containment Tendon Surveillance Program shall be reported to the NRC within 30 days.

The report shall include a description of the tendon condition, the condition of the concrete (especially at tendon anchorages), the inspection procedures, the tolerances on cracking, and the corrective action taken.

c.

A report shall be submitted within 180 days after the initial entry into MODE 4 following completion of an inspection performed in accordance with the Specification 5.5.2.11, Steam Generator (SG)

Program.

The report shall include:

(continued)

SAN ONOFRE--UNIT 2 5.0-30 Amendment No.

Reporting Requirements 5.7 5.7 Reporting Requirements (continued) 5.7.2 Special Reports (continued)

1.

The scope of inspections performed on each SG,

2.

Active degradation mechanisms found,

3.

Nondestructive examination techniques utilized for each degradation mechanism,

4.

Location, orientation (if linear), and measured sizes (if available) of service induced indications,

5.

Number of tubes plugged or repaired during the inspection outage for each active degradation mechanism,

6.

Total number and percentage of tubes plugged or repaired to

date,

7.

The results of condition monitoring, including the results of tube pulls and in-situ testing,

8.

The effective plugging percentage for all plugging and tube repairs in each SG, and

9.

Repair method utilized and the number of tubes repaired by each repair method.

SAN ONOFRE--UNIT 2 5.0-31 Amendment No.

Attachment B (Original PCN 564 [Attachment F] Pages)

SONGS Unit 3

TABLE OF CONTENTS 3.3 INSTRUMENTATION (continued) 3.3.5 Engineered Safety Features Actuation System (ESFAS)

Instrumentation............

3.3-22 3.3.6 Engineered Safety Features Actuation System (ESFAS)

Logic and Manual Trip....

3.3-27 3.3.7 Diesel Generator (DG) -Undervoltage Start 3.3-32 3.3.8 Containment Purge Isolation Signal (CPIS)........

3.3-35 3.3.9 Control Room Isolation Signal (CRIS) 3.3-39 3.3.10 Fuel Handling Isolation Signal (FHIS) 3.3-42 3.3.11 Post Accident Monitoring Instrumentation iPAMi).

3.3-44 3.3.12 Remote Shutdown System......................

3.3-48 3.3.13 Source Range Monitoring Channels 3.3-51 3.4 REACTOR COOLANT SYSTEM (RCS).........

3.4-1 3.4.1 RCS DNB Pressure, Temperature, and Flow Limits..................

3.4-1 3.4.2 RCS Minimum Temperature'for'Criticality"..

3.4-4 3.4.3 RCS Pressure and Temperature (P/T) Limits........

3.4-5 3.4.3.1 Pressurizer Heatup/Cooldown Limits.............

3.4-13 3.4.4 RCS Loops -MODES 1 and 2....................

3.4-15 3.4.5 RCS Loops -MODE 3........

3.4-16 3.4.6 RCS Loops -MODE 4..............

3.4-18 3.4.7 RCS Loops-MODE 5, Loops Filled.....

3.4-21 3.4.8 RCS Loops-MODE 5, Loops Not Filled............

3.4-24 3.4.9 Pressurizer..

3.4-26 3.4.10 Pressurizer Safety* Valves..3.4-28 3.4.11 Not Used 3.4.12.1 Low Temperature Overpressure Protection (LTOP)

System, RCS Temperature

246°F 3.4-30 3.4.12.2 Low Temperature Overpressure Protection (LTOP)

System, RCS Temperature > 246 0 F 3.4-35 3.4.13 RCS Operational LEAKAGE 3.4-37 3.4.14 RCS Pressure Isolation Valve (PIV)

Leakage.....

3.4-39 3.4.15 RCS Leakage Detection Instrumentation...........

3.4-44 3.4.16 RCS Specific Activity.........

3.4-47 3.4.17 RCS Steam Generator (SG)

Tube Integrity..........

3.4-51 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS)..............

3.5-1 3.5.1 Safety Injection Tanks (SITs).....

3.5-1 3.5.2 ECCS-Operating.........

3.5-4 3.5.3 ECCS-Shutdown........

3.5-8 3.5.4 Refueling Water Storage Tank (RWST) 3.5-9 3.5.5 Trisodium Phosphate (TSP)......

3.5-11 (continued)

SAN ONOFRE--Unit 3 iii Amendment No.

TABLE OF CONTENTS B 3.3 B 3.3.7 B 3.3.8 B 3.3.9 B 3.3.10 B 3.3.11 B 3.3.12 B 3.3.13 B 3.4 B 3.4.1 B 3.4.2 B 3.4.3 B 3.4.4 B 3.4.5 B 3.4.6 B 3.4.7 B 3.4.8 B 3.4.9 B 3.4.10 B 3.4.11 B 3.4.12.1 B 3.4.12.2 B 3.4.13 B 3.4.14 B 3.4.15 B 3.4.16 B 3.4.17 B 3.5 B 3.5.1 B 3.5.2 B 3.5.3 B 3.5.4 B 3.5.5 B 3.6 B 3.6.1 B 3.6.2 B 3.6.3 B 3.6.4 B 3.6.5 B 3.6.6.1 B 3.6.6.2 B 3.6.7 B 3.6.8 INSTRUMENTATION (continued)

Diesel Generator Undervoltage Start Containment Purge Isolation Signal (CPIS)

Control Room Isolation Signal (CRIS)........

Fuel Handling Isolation Signal (FHIS)

Post Accident Monitoring Instrumentation (PAMI)

Remote Shutdown System..............

Source Range Monitoring Channels........

REACTOR COOLANT SYSTEM (RCS)

RCS DNB (Pressure, Temperature, and Flow) Limits RCS Minimum Temperature for Criticality RCS Pressure and Temperature (P/T) Limits RCS Loops-MODES 1 and 2................

RCS Loops-MODE 3 RCS Loops-MODE 4 RCS Loops-MODE 5, Loops Filled RCS Loops-MODE 5, Loops Not Filled Pressurizer Pressurizer Safety Valves Not Used Low Temperature Overpressure Protection (LTOP)

System, RCS Temperature

246 0 F Low Temperature Overpressure Protection (LTOP)

System, RCS Temperature > 246 0 F..........

RCS Operational LEAKAGE RCS Pressure Isolation Valve (PIV)

Leakage RCS Leakage Detection Instrumentation RCS Specific Activity RCS Steam Generator (SG)

Tube Integrity EMERGENCY CORE COOLING SYSTEMS (ECCS)

Safety Injection Tanks (SITs)

ECCS -Operating ECCS -Shutdown......................

Refueling Water Storage Tank (RWST)

Trisodium Phosphate (TSP)

CONTAINMENT SYSTEMS Containment Containment Air Locks Containment Isolation Valves....

Containment Pressure...................

Containment Air Temperature Containment Spray and Cooling System......

Containment Cooling System...............

Hydrogen Recombiners...................

Containment Dome Air Circulators...........

SB 3.3-126

" B 3.3-135 B 3.3-145 B 3.3-152 B 3.3-159 B 3.3-176 B 3.3-181 B 3.4-1 B 3.4-1 B 3.4-7 B 3.4-9 B 3.4-23 B 3.4-27 B 3.4-31 B 3.4-36 B 3.4-42 B 3.4-46 B 3.4-51 B 3.4-55 B 3.4-65 B 3.4-70 B 3.4-76 B 3.4-82 B 3.4-88 B 3.4-93 B 3.5-1 B 3.5-1 B 3.5-11 B 3.5-21 B 3.5-24 B 3.5-30 B 3.6-1 B 3.6-1 B 3.6-5 B 3.6-13 B 3.6-27 B 3.6-30 B 3.6-33 B 3.6-43 B 3.6-48 SB 3.6-53 (continued)

I SAN ONOFRE--Unit 3 vii Amendment No.

Definitions 1.1 1.1 Definitions ENGINEERED SAFETY measurement, response time may be verified for FEATURE (ESF)

RESPONSE

selected components provided that the components TIME (Continued) and methodology for verification have been previously reviewed and approved by the NRC.

LEAKAGE LEAKAGE shall be:

a.

Identified LEAKAGE

1.

LEAKAGE, such as that from pump seals or valve packing (except reactor coolant pump (RCP) leakoff), that is captured and conducted to collection systems or a sump or collecting tank;

2.

LEAKAGE into the containment atmosphere from sources that are both specifically located and known either not to interfere with the operation of leakage detection systems or not to be pressure boundary LEAKAGE; or

3. Reactor Coolant System (RCS)

LEAKAGE through a steam generator to the Secondary System (primary to secondary LEAKAGE).

b.

Unidentified LEAKAGE All LEAKAGE that is not identified LEAKAGE.

c.

Pressure Boundary LEAKAGE LEAKAGE (except primary to secondary LEAKAGE) through a nonisolable fault in an RCS component body, pipe wall, or vessel wall.

MODE A MODE shall correspond to any one inclusive combination of core reactivity condition, power level, average reactor coolant temperature, and reactor vessel head closure bolt tensioning specified in Table 1.1-1 with fuel in the reactor vessel.

(continued)

SAN ONOFRE--UNIT 3 1.1-4 Amendment No.

RCS Operational LEAKAGE 3.4.13 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.13 RCS Operational LEAKAGE LCO 3.4.13 RCS operational LEAKAGE shall be limited to:

a.

No pressure boundary LEAKAGE;

b.

I gpm unidentified LEAKAGE;

c.

10 gpm identified LEAKAGE; and

d.

150 gallons per day primary to secondary LEAKAGE through any one Steam Generator (SG).

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

RCS Operational A.1 Reduce LEAKAGE to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months LEAKAGE not within within limits.

limits for reasons other than pressure boundary LEAKAGE or primary to secondary LEAKAGE.

B. Required Action and B.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A AND not met.

B.2 Be in MODE 5.

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR Pressure boundary LEAKAGE exists.

OR Primary to secondary LEAKAGE not within limit.

SAN ONOFRE--UNIT 3 3.4-37 Amendment No.

RCS Operational LEAKAGE 3.4.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY 9

SR 3.4.13.1 ----------------- NOTES----------------

1. Not required to be performed in MODE 3 or 4 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months of steady state operation.

2.

Not applicable to primary to secondary LEAKAGE.

Perform RCS water inventory balance.

NOTE ------

Only required to be performed during steady state operation.

If a transient evolution is occurring 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months from the last water inventory balance, then a water inventory balance shall be performed within 120 hours0.00139 days 0.0333 hours 1.984127e-4 weeks 4.566e-5 months of the last water inventory balance I

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months

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

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after establishment of steady state operation.

SR 3.4.13.2 Verify primary to secondary LEAKAGE is 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months

< 150 gallons per day through any one SG.

SAN ONOFRE--UNIT 3 3.4-38 Amendment No.

SG Tube Integrity 3.4.17 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.17 Steam Generator (SG)

Tube Integrity SG tube integrity shall be maintained.

LCO 3.4.17 AND All SG tubes satisfying the tube repair criteria shall be plugged or repaired in accordance with the Steam Generator Program.

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTIONS ACTIONS--------------NOTE -----------------------------------

Separate Condition entry is allowed for each SG tube.

CONDITION REQUIRED ACTION COMPLETION TIME A.

One or more SG tubes A.1 Verify tube integrity 7 days satisfying the tube of the affected repair criteria and tube(s) is maintained not plugged or until the next repaired in accordance refueling outage or with the Steam SG tube inspection.

Generator Program.

AND A.2 Plug or repair the Prior to affected tube(s) in entering MODE 4 accordance with the following the Steam Generator next refueling Program.

outage or SG tube inspection B.

Required Action and B.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time Condition A not AND met.

B.2 Be in MODE 5.

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR SG tube integrity not maintained.

I SAN ONOFRE--UNIT 3 3.4-51 Amendment No.

I

SG Tube Integrity 3.4.17 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.17.1 Verify SG tube integrity in accordance with In accordance the Steam Generator Program.

with the Steam Generator Program SR 3.4.17.2 Verify that each inspected SG tube that Prior to satisfies the tube repair criteria is entering MODE 4 plugged or repaired in accordance with the following a SG Steam Generator Program.

tube inspection I

SAN ONOFRE--UNIT 3 3.4-52 Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.8 Primary Coolant Sources Outside Containment Program (continued) system (post-accident sampling return piping only until such time as a modification eliminates the post-accident piping as a potential leakage path).

The program shall include the following:

a.

Preventive maintenance and periodic visual inspection requirements; and

b.

Integrated leak test requirements for each system at refueling cycle intervals or less.

5.5.2.9 Pre-Stressed Concrete Containment Tendon Surveillance Program This program provides controls for monitoring any tendon degradation in pre-stressed concrete containment, including effectiveness of its corrosion protection medium, to ensure containment structural integrity.

Program itself is relocated to the LCS.

5.5.2.10 Inservice Inspection and Testing Program This program provides controls for inservice inspection of ASME Code Class 1, 2, and 3 components and Code Class CC and MC components including applicable supports.

The program provides controls for inservice testing of ASME Code Class 1, 2, and 3 components.

Program itself is located in the LCS.

5.5.2.11 Steam Generator (SG)

Program A Steam Generator Program shall be established and implemented to ensure that SG tube integrity is maintained.

In addition, the Steam Generator Program shall include the following provisions:

a.

Provisions for condition monitoring assessments.

Condition monitoring assessment means an evaluation of the "as found" condition of the tubing with respect to the performance criteria for structural integrity and accident induced leakage.

The "as found" condition refers to the condition of the tubing during an SG inspection outage, as determined from the inservice inspection results or by other means, prior to the plugging or repair of tubes.

Condition monitoring assessments shall be conducted during each outage during which the SG tubes are inspected, plugged, or repaired to confirm that the performance criteria are being met.

(continued)

SAN ONOFRE--UNIT 3 5.0-13 Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG)

Program (continued)

b.

Performance criteria for SG tube integrity.

SG tube integrity shall be maintained by meeting the performance criteria for tube structural integrity, accident induced leakage, and operational LEAKAGE.

1.

Structural integrity performance criterion: All in-service steam generator tubes shall retain structural integrity over the full range of normal operating conditions (including startup, operation in the power range, hot standby, and cool down and all anticipated transients included in the design specification) and design basis accidents.

This includes retaining a safety factor of 3.0 against burst under normal steady state full power operation primary-to-secondary pressure differential and a safety factor of 1.4 against burst applied to the design basis accident primary-to-secondary pressure differentials.

Apart from the above requirements, additional loading conditions associated with the design basis accidents, or combination of accidents in accordance with the design and licensing basis, shall also be evaluated to determine if the associated loads contribute significantly to burst or collapse.

In the assessment of tube integrity, those loads that do significantly affect burst or collapse shall be determined and assessed in combination with the loads due to pressure with a safety factor of 1.2 on the combined primary loads and 1.0 on axial secondary loads.

2.

Accident induced leakage performance criterion: The primary to secondary accident induced leakage rate for any design basis accident, other than a SG tube rupture, shall not exceed the leakage rate assumed in the accident analysis in terms of total leakage rate for all SGs and leakage rate for an individual SG.

Leakage is not to exceed 0.5 gpm per SG and I gpm through both SGs.

3.

The operational LEAKAGE performance criterion is specified in LCO 3.4.13, "RCS Operational LEAKAGE."

(continued)

SAN ONOFRE--UNIT 3 5.0-14 Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG)

Program (continued)

c.

Provisions for SG tube repair criteria.

Tubes found by inservice inspection to contain flaws with a depth equal to or exceeding 44% of the nominal tube wall thickness shall be plugged or repaired.

Sleeves shall be removed from service upon detection of service-induced degradation of the sleeve material or any portion of the sleeve-to-tube weld.

d.

Provisions for SG tube inspections.

Periodic SG tube inspections shall be performed.

The number and portions of the tubes inspected and methods of inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable tube repair criteria.

The tube-to-tubesheet weld is not part of the tube.

In addition to meeting the requirements of d.1, d.2, and d.3 below, the inspection scope, inspection methods, and inspection intervals shall be such as to ensure that SG tube integrity is maintained until the next SG inspection.

An assessment of degradation shall be performed to determine the type and location of flaws to which the tubes may be susceptible and, based on this assessment, to determine which inspection methods need to be employed and at what locations.

1.

Inspect 100% of the tubes in each SG during the first refueling outage following SG replacement.

2.

Inspect 100% of the tubes and sleeves at sequential periods of 60 effective full power months.

The first sequential period shall be considered to begin after the first inservice inspection of the SGs.

No SG shall operate for more than 24 effective full power months or one refueling outage (whichever is less) without being inspected.

(continued)

SAN ONOFRE--UNIT 3 5.0-15 Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG)

Program (continued)

3.

If crack indications are found in any SG tube, then the next inspection for each SG for the degradation mechanism that caused the crack indication shall not exceed 24 effective full power months or one refueling outage (whichever is less).

If definitive information, such as from examination of a pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a crack-like indication is not associated with a crack(s), then the indication need not be treated as a crack.

e.

Provisions for monitoring operational primary to secondary LEAKAGE.

f.

Provisions for SG tube repair methods.

Steam generator tube repair methods shall provide the means to re-establish the RCS pressure boundary integrity of SG tubes without removing the tube from service.

For the purposes of these Specifications, tube plugging is not a repair.

All acceptable tube repair methods are listed below.

1.

TIG welded sleeving as described in ABB/CE Topical Report, CEN-630-P, Rev. 2, is currently approved by the NRC.

Tube repair includes the installation by welding of the sleeves, heat treatment in accordance with CEN-630-P, Rev. 2, to remove the stresses that are introduced by the sleeve installation, acceptance testing of the sleeve, and nondestructive examination for future comparison.

Tube repair can be performed on certain tubes that have been previously plugged as a corrective or preventive measure.

A tube inspection of the full length of the tube shall be performed on a previously plugged tube prior to returning the tube to service.

(continued)

SAN ONOFRE--UNIT 3 5.0-16 Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.12 Ventilation Filter Testing Program (VFTP)

This Program establishes the required testing of the Engineered Safety Feature filter ventilation systems, "Control Room Emergency Air Cleanup System" and "Fuel Handling Building Post-accident Cleanup Filter System."

The frequency of testing shall be in accordance with Regulatory Guide 1.52, Revision 2.

As a minimum the VFTP program shall include the following:

a.

Inplace testing of the high efficiency particulate air (HEPA) filters to demonstrate acceptable penetration and system bypass when tested at the appropriate system flowrate in accordance with Regulatory Guide 1.52, Revision 2, and ANSI N510-1975 (see Note 1); and

b.

Inplace testing of the charcoal adsorber to demonstrate acceptable penetration and system bypass when tested at the appropriate system flowrate in accordance with Regulatory Guide 1.52, Revision 2, and ANSI N510-1975 (see Note 1); and

c.

Laboratory testing of charcoal adsorber samples obtained in accordance with Regulatory Guide 1.52, Revision 2 and tested per the methodology of ASTM D3803-1989 at 30'C and 70%

relative humidity to show acceptable methyl iodide penetration; and

d.

Testing to demonstrate the pressure drop across the combined HEPA filters, the prefilters, and the charcoal adsorbers, when tested at the appropriate system flowrate.

Note 1:

Sample and injection points shall be qualified per ANSI N510-1975 unless manifolds have been qualified per ASME N510-1989.

HEPA testing will be conducted with DOP aerosol or suitable alternate.

(continued)

SAN ONOFRE--UNIT 3 5.0-17 Amendment No.

Reporting Requirements 5.7 5.7 Reporting Requirements (continued) 5.7.2 Special Reports Special Reports may be required covering inspection, test, and maintenance activities.

These special reports are determined on an individual basis for each unit and their preparation and submittal are designated in the Technical Specifications.

Special Reports shall be submitted to the U. S. Nuclear Regulatory Commission, Attention: Document Control Desk, Washington, D. C.

20555, with a copy to the Regional Administrator of the Regional Office of the NRC, in accordance with 10 CFR 50.4 within the time period specified for each report.

The following Special Reports shall be submitted:

a.

When a pre-planned alternate method of monitoring post-accident instrumentation functions is required by Condition B or Condition G of LCO 3.3.11, a report shall be submitted within 30 days from the time the action is required.

The report shall outline the action taken, the cause of the inoperability, and the plans and schedule for restoring the instrumentation channels of the function to OPERABLE status.

b.

Any abnormal degradation of the containment structure detected during the tests required by the Pre-Stressed Concrete Containment Tendon Surveillance Program shall be reported to the NRC within 30 days.

The report shall include a description of the tendon condition, the condition of the concrete (especially at tendon anchorages), the inspection procedures, the tolerances on cracking, and the corrective action taken.

c.

A report shall be submitted within 180 days after the initial entry into MODE 4 following completion of an inspection performed in accordance with the Specification 5.5.2.11, Steam Generator (SG)

Program.

The report shall include:

(continued)

SAN ONOFRE--UNIT 3 5.0-30 Amendment No.

Reporting Requirements 5.7 5.7 Reporting Requirements (continued) 5.7.2 Special Reports (continued)

1.

The scope of inspections performed on each SG,

2.

Active degradation mechanisms found,

3.

Nondestructive examination techniques utilized for each degradation mechanism,

4.

Location, orientation (if linear), and measured sizes (if available) of service induced indications,

5.

Number of tubes plugged or repaired during the inspection outage for each active degradation mechanism,

6.

Total number and percentage of tubes plugged or repaired to

date,

7.

The results of condition monitoring, including the results of tube pulls and in-situ testing,

8.

The effective plugging percentage for all plugging and tube repairs in each SG, and

9.

Repair method utilized and the number of tubes repaired by each repair method.

SAN ONOFRE--UNIT 3 5.0-31 Amendment No.

Attachment C (Proposed Pages)

(Redline and Strikeout)

SONGS Unit 2

SG Tube Intparitv 3.4.17 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.17 Steam Generator (SG)

Tube Integrity SG tube integrity shall be maintained.

LCO 3.4.17 AND All SG tubes satisfyinq the tube repair criteria shall be pluqqed or repaired in accordance with the Steam Generator Program.

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTIONS

NOTE Seoarate Condition entrv is allowed for each SG tube.

CONDITION REQUIRED ACTION COMPLETION TIME A.

One or more SG tubes A.1 Verify tube integrity 7 days satisfvinq the tube of the affected repair criteria and tube(s) is maintained not pluqqed or until the next repaired in accordance refuelinq outaqe or with the Steam SG tube inspection.

Generator Program.

AND A.2 Pluq or repair the Prior to affected tube(s) in enterinq MODE 4 accordance with the followinq the Steam Generator next refueling Program.

outaqe or SG tube inspection B.

Required Action and B.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months assoclated Completion Timeo Condition A AND not met.

B.2 Be in MODE 5.

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR SG tube integrity not maintained.

I SAN ONOFRE--UNIT 2 3.4-51 Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG)

Tube Surveillanca Program (continued) assessed in combination with the loads due to pressure with a safety factor of 1.2 on the combined primary loads and 1.0 on axial secondary loads.

2.

Accident induced leakaqe performance criterion: The primary to secondary accident induced leakaqe rate for any desiqn basis accident, other than a SG tube rupture, shall not exceed the leakaqe rate assumed in the accident analysis in terms of total leakaqe rate for all SGs and leakaqe rate for an individual SG.

Leakaqe is not to exceed 0.5 gpm per SG and 1 gpm through both SGs.

3.

The operational LEAKAGE performance criterion is specified in LCO 3.4.13, "RCS Operational LEAKAGE."

C.

(ProvisGi n fer 99 tuabe repair eriteria. Tubes feun 'by linsarvicfe inspeetion to eentain flaws with a depth eaual to or exceedinq 40%of the nominal tube wall thiekness shall be plugged or repaired.

Provisions for SG tube repair criteria.

The non-sleeved reqion of a tube found by inservice inspection to contain flaws with a depth equal to or exceedinq 44% of the nominal tube wall thickness shall be pluqqed or repaired except if the flaws are permitted to remain in service throuqh application of an alternate tube repair criteria discussed below.

-Sleeves shall be ramoeved from

.,ri.

uon deteetion of sariceinduced deqradatien of the sleeve material or any VV1LIJI klu

.J1 6I.II...

vv~L~#IAUu.

Tubes shall be pluqqed if the sleeved reqion of a tube is found by inservice inspection to contain flaws in the (a) sleeve or (b) pressure boundary portion of the oriqinal tube wall in the sleeve tube assembly (i.e., the sleeve-to-tube (continued)

SAN ONOFRE--UNIT 2 5.0-14a Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued)

d.

Provisions for SG tube inspections.

Periodic SG tube inspections shall be performed.

The number and portions of the tubes inspected and methods of inspection shall be performed with the objective of detectinq flaws of any type (e.q., volumetric flaws, axial and circumferential cracks) that may be present alonq the lenqth of the tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable tube repair criteria.

The tube-to-tubesheet weld is not part of the tube.

In additip meetinq the requirements of d.1, d.2, d.3, and d.[3 Obelow, the inspection scope, inspection methods, and inspection intervals shall be such as (continued)

I SAN ONOFRE--UNIT 2 5.0-14b Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG)

Tube Surveillance Program (continued) to ensure that SG tube intearitv is maintained until the next SG inspection.

An assessment of dearadation shall be nerformed to determine the tvne and location of flaws to which the tubes mav be susceptible and. based on this assessment. to determine which inspection methods need to be employed and at what locations.

1.

Inspect 100% of the tubes in each SG during the first refueling outage following SG replacement.

2.

Insoect 100% of the tubes &)at seauential oeriods of 60 effective ful Dower months.

The first seauential period shall be considered to beain after the first inservice insoection of the SGs.

No SG shall onerate for more than 24 effective full Dower months or one refueling outage (whichever is less) without'being inspected.

3.

If crack indications are found in anv SG tube,."then the next insoection for each SG for the dearadation mechanism that caused the crack indication shall not exceed 24 effective full Dower months or one refuelina outaae (whichever is less).

If definitive information, such as from examination of a nulled tube. diaanostic non-destructive testino. or enoineerino evaluation indicates that a crack-like indication is not associated with a crack(s), then the indication need not be treated as a crack.

4.

All sleeves shall be inspected with eddv current orior to initial oneration.

This includes oressure retainina nortions of the narent tube in contact with the sleeve, the sleeve-to-tube weld and the pressure retainingt portion of the sleeve.

e.

Provisions for monitoring operational primary to secondary LEAKAGE.

f.

Provisions for SG tube renair methods.

Steam aenerator tube repair methods shall provide the means to re-establish the RCS pressure boundarv intearitv of SG tubes without removina the tube from service.

For the ourooses of these Soecifications, tube oluaaino is not a repair.

All acceptable tube repair methods are listed below.

(continued)

SAN ONOFRE--UNIT 2 5.0-15a Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG)

Tube Survill,,..

Program (continued)

1.

TIG welded sleevinq with heat reatment, as described in ABB/CE Topical Report, CEN-630-P, Rev.

2, is currently approved by the NRC.

Tube reoair ineludcs the installation by weldinq of the sleeves, heat treatment in leIerdanee with GEN 630 GlP Rev. 2. te refneve the stresses that are intredueed-by the sleeve ir.3tallatin, aeeeptanee testinq of the ube repair can be performed on certain tubes that have been previously pluqqed as a corrective or preventive measure.

A tube inspection of the +u++

rlenqth of the tube shall be performed on a previously plugged tube prior to returning the tube to service.

(continued)

SAN ONOFRE--UNIT 2 5.0-16a Amendment No.

Attachment D (Proposed Pages)

(Redline and Strikeout)

SONGS Unit 3

SG Tube Intprritv 3.4.17 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.17 Steam Generator (SG)

Tube Integrity SG tube integrity shall be maintained.

LCO 3.4.17 AND All SG tubes satisfyinq the tube repair criteria shall be pluqqed or repaired in accordance with the Steam Generator Program.

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTIONS

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

Seoarate Condition entry is allowed for each SG tube.

CONDITION REQUIRED ACTION COMPLETIONI TIME A.

One or more SG tubes A.1 Verify tube integrity 7 days satisfyinq the tube of the affected repair criteria and tube(s) is maintained not pluqqed or until the next repaired in accordance refuelinq outaqe or with the Steam SG tube inspection.

Generator Program.

AND A.2 Pluq or repair the Prior to affected tube(s) in enterinq MODE 4 accordance with the followinq the Steam Generator next refueling Program.

outaqe or SG tube inspection B.

Reauired Action and B.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associ'ted Completion Time( ofCondition A AND not met.

B.2 Be in MODE 5.

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR SG tube integrity not maintained.

I SAN ONOFRE--UNIT 3 3.4-51 Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG)

Tube Survill,,..

Program (continued) assessed in combination with the loads due to pressure with a safety factor of 1.2 on the combined primary loads and 1.0 on axial secondary loads.

2.

Accident induced leakaae performance criterion: The orimarv to secondarv accident induced leakaae rate for any desian basis accident. other than a SG tube ruDture. shall not exceed the leakaae rate assumed in the accident analvsis in terms of total leakaae rate for all SGs and leakaae rate for an individual SG.

Leakaae is not to exceed 0.5 gpm per SG and 1 gpm through both SGs.

3.

The operational LEAKAGE oerformance criterion is specified in LCO 3.4.13, "RCS Operational LEAKAGE.."

C.

Provisions for SG tube re.air

,riteri,.

Tubes found by plugg*ed or repare;rd.

Provisions for SG tube repair criteria.

The non-sleeved reaion of a tube found bv inservice insoection to contain flaws with a deDth eaual to or exceedina 44% of the nominal tube wall thickness shall be Dluaaed or reDaired exceDt if the flaws are Dermitted to remain in service throuah aoDlication of an alternate tube repair criteria discussed below.

Sleeves shall be removed fr....ric u~en detection of scrvie induced dearadatien of the sleeve material or any portion of the sleeve to tube weld.

Tubes shall be oluaaed if the sleeved reaion of a tube is found bv inservice inspection to contain flaws in the (a) sleeve or Wb) pressure boundary Dortion of the oriainal tube wall in the sleeve tube assembly (i.e., the sleeve-to-tube joint).

(continued)

SAN ONOFRE--UNIT 3 5.0-14a Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued)

d.

Provisions for SG tube insoections.

Periodic SG tube insDections shall be performed.

The number and Dortions of the tubes inspected and methods of insoection shall be performed with the obiective of detectina flaws of any tvDe (e.a.. volumetric flaws. axial and circumferential cracks) that may be oresent alona the lenath of the tube. from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet. and that may satisfy the aDplicable tube repair criteria.

The tube-to-tubesheet weld is not Dart of the tube.

In additij&_t&;

meetina the reauirements of d.1. d.2. d.3. and d.3 elow. the inspection SCODe. inspection methods, and inspe-ion intervals shall be such as I

(continued)

SAN ONOFRE--UNIT 3 5.0-14b Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG)

Tube Sureillane, Program (continued) to ensure that SG tuhe inteoritv is maintained until the next SG insnection.

An assessment of deuradation shall he nerfnrmed to determine the tvne and lOcation nf flaws to which the tihes mav he susrcentihle and. hased on this assessment. to determine which inspection methods need to be employed and at what locations.

1.

Tnsnect 100I.

nf the tuhes in each SG during the first refueling outage following SG replacement.

2.

Tnsnecrt Ilflt3 of the theY at senuential neriods of 60 effective full nower months.

The first senuential nerind shall he rnnsidered to heain after the first inservire insnection of the SYs.

No SG shall nnerate for more than 24 effective full nower months nr nne refueling outage (whichever is less) without being inspected.

3.

Tf crack indirations are found in anv SG tuheP.. then the next insnectinn for each SG for the dearadation merhanism that raused the crack indication shall not exreed 74 effertive full nower months or one refuelina notaae (whirhever is less).

Tf definitive information, such as from examination of a nilled tuhe. diaonnstic nnn-destrurtive testinO.

or enaineerina evaluation indicates that a crack-like indication is not assoriated with a rrark(s), then the indication need not be treated as a crack.

4.

All sleeves shall he insnected with eddy *urrent nrior to initial oneration.

This includes nressure retainino nnrtinns of the narent tuihe in rnntart with the sleeve, the sleeve-to-tuhe weld and the pressure retaining portion of the sleeve.

e.

Provisinns for monitoring operational primary to secondary LEAKAGE.

f.

Provisions for SG tuNhe renair methods.

Steam oeneratnr tuMe renair methnds shall nrovide the means to re-estahlish the RCS nress~ure houndarv inteoritv of SG tuhes without remnvina the tMeY from service.

For the nurnnses of these Snprifiratinns, tuhe nluooino is not a repair.

All acceptable tube repair methods are listed below.

(continued)

SAN ONOFRE--UNIT 3 5.0-15a Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG)

Tube Survillan,,

Program (continued)

1.

TIG welded sleevin h eattreatment as described in ABB/CE ToDical Re tE N6 3O-P, Rev. 2, is currently approved by the NRC.

Tube rebair ineludes the installation byv weldina Of tkhl sleeves. heat treatment in aeeordanee with GEN 630.

\\ ~ ~ ~

~

L.*,,

o,...,,....

Rev. 2. to remove the stresses that are intreadueed by

/the sleeve installation. aeeeotanee testine of thep

,Tube"eDair can be Derformed on certain tubes that have been Dreviously Dluaaed as a corrective or entive measure.

A tube inspection of the +tt4 eirelenoth of the tube shall be Derformed on a Dreviously plugged tube prior to returning the tube to service.

(continued)

SAN ONOFRE--UNIT 3 5.0-16a Amendment No.

Attachment E (PCN 564 Supplement 1 Proposed Pages)

SONGS Unit 2 (To Replace PCN-564 Pages)

SG Tube Integrity 3.4.17 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.17 LCO 3.4.17 Steam Generator (SG)

Tube Integrity SG tube integrity shall be maintained.

AND All SG tubes satisfying the tube repair criteria shall be plugged or repaired in accordance with the Steam Generator Program.

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTIONS

NOTE Separate Condition entry is allowed for each SG tube.

CONDITION REQUIRED ACTION COMPLETION TIME A.

One or more SG tubes A.1 Verify tube integrity 7 days satisfying the tube of the affected repair criteria and tube(s) is maintained not plugged or until the next repaired in accordance refueling outage or with the Steam SG tube inspection.

Generator Program.

AND A.2 Plug or repair the Prior to affected tube(s) in entering MODE 4 accordance with the following the Steam Generator next refueling Program.

outage or SG tube inspection B.

Required Action and B.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A AND not met.

B.2 Be in MODE 5.

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR SG tube integrity not maintained.

SAN ONOFRE--UNIT 2 3.4-51 Amendment No.

I

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG)

Program (continued)

c.

Provisions for SG tube repair criteria.

The non-sleeved region of a tube found by inservice inspection to contain flaws with a depth equal to or exceeding 44% of the nominal tube wall thickness shall be plugged or repaired except if the flaws are permitted to remain in service through application of an alternate tube repair criteria discussed below.

Tubes shall be plugged if the sleeved region of a tube is found by inservice inspection to contain flaws in the (a) sleeve or (b) pressure boundary portion of the original tube wall in the sleeve tube assembly (i.e., the sleeve-to-tube joint).

d.

Provisions for SG tube inspections.

Periodic SG tube inspections shall be performed.

The number and portions of the tubes inspected and methods of inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable tube repair criteria.

The tube-to-tubesheet weld is not part of the tube.

In addition to meeting the requirements of d.1, d.2, d.3, and d.4 below, the inspection scope, inspection methods, and inspection intervals shall be such as to ensure that SG tube integrity is maintained until the next SG inspection.

An assessment of degradation shall be performed to determine the type and location of flaws to which the tubes may be susceptible and, based on this assessment, to determine which inspection methods need to be employed and at what locations.

1.

Inspect 100% of the tubes in each SG during the first refueling outage following SG replacement.

2.

Inspect 100% of the tubes at sequential periods of 60 effective full power months.

The first sequential period shall be considered to begin after the first inservice inspection of the SGs.

No SG shall operate for more than 24 effective full power months or one refueling outage (whichever is less) without being inspected.

(continued)

SAN ONOFRE--UNIT 2 5.0-15 Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG)

Program (continued)

3.

If crack indications are found in any SG tube, then the next inspection for each SG for the degradation mechanism that caused the crack indication shall not exceed 24 effective full power months or one refueling outage (whichever is less).

If definitive information, such as from examination of a pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a crack-like indication is not associated with a crack(s), then the indication need not be treated as a crack.

4.

All sleeves shall be inspected with eddy current prior to initial operation.

This includes pressure retaining portions of the parent tube in contact with the sleeve, the sleeve-to-tube weld and the pressure retaining portion of the sleeve.

e.

Provisions for monitoring operational primary to secondary LEAKAGE.

f.

Provisions for SG tube repair methods.

Steam generator tube repair methods shall provide the means to re-establish the RCS pressure boundary integrity of SG tubes without removing the tube from service.

For the purposes of these Specifications, tube plugging is not a repair.

All acceptable tube repair methods are listed below.

1.

TIG welded sleeving with heat treatment, as described in ABB/CE Topical Report, CEN-630-P, Rev. 2, is currently approved by the NRC.

Tube repair can be performed on certain tubes that have been previously plugged as a corrective or preventive measure.

A tube inspection of the entire length of the tube shall be performed on a previously plugged tube prior to returning the tube to service.

(continued)

SAN ONOFRE--UNIT 2 5.0-16 Amendment No.

Attachment F (PCN 564 Supplement 1 Proposed Pages)

SONGS Unit 3 (To Replace PCN-564 Pages)

SG Tube Integrity 3.4.17 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.17 Steam Generator (SG)

Tube Integrity SG tube integrity shall be maintained.

LCO 3.4.17 AND All SG tubes satisfying the tube repair criteria shall be plugged or repaired in accordance with the Steam Generator Program.

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTIONS ACTIONS

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

Separate Condition entry is allowed for each SG tube.

CONDITION REQUIRED ACTION COMPLETION TIME A.

One or more SG tubes A.1 Verify tube integrity 7 days satisfying the tube of the affected repair criteria and tube(s) is maintained not plugged or until the next repaired in accordance refueling outage or with the Steam SG tube inspection.

Generator Program.

AND A.2 Plug or repair the Prior to affected tube(s) in entering MODE 4 accordance with the following the Steam Generator next refueling Program.

outage or SG tube inspection B.

Required Action and B.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A AND not met.

B.2 Be in MODE 5.

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR SG tube integrity not maintained.

SAN ONOFRE--UNIT 3 3.4-51 Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG)

Program (continued)

c.

Provisions for SG tube repair criteria.

The non-sleeved region of a tube found by inservice inspection to contain flaws with a depth equal to or exceeding 44% of the nominal tube wall thickness shall be plugged or repaired except if the flaws are permitted to remain in service through application of an alternate tube repair criteria discussed below.

Tubes shall be plugged if the sleeved region of a tube is found by inservice inspection to contain flaws in the (a) sleeve or (b) pressure boundary portion of the original tube wall in the sleeve tube assembly (i.e., the sleeve-to-tube joint).

d.

Provisions for SG tube inspections.

Periodic SG tube inspections shall be performed.

The number and portions of the tubes inspected and methods of inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable tube repair criteria.

The tube-to-tubesheet weld is not part of the tube.

In addition to meeting the requirements of d.1, d.2, d.3, and d.4 below, the inspection scope, inspection methods, and inspection intervals shall be such as to ensure that SG tube integrity is maintained until the next SG inspection.

An assessment of degradation shall be performed to determine the type and location of flaws to which the tubes may be susceptible and, based on this assessment, to determine which inspection methods need to be employed and at what locations.

1.

Inspect 100% of the tubes in each SG during the first refueling outage following SG replacement.

2.

Inspect 100% of the tubes at sequential periods of 60 effective full power months.

The first sequential period shall be considered to begin after the first inservice inspection of the SGs.

No SG shall operate for more than 24 effective full power months or one refueling outage (whichever is less) without being inspected.

(continued)

SAN ONOFRE--UNIT 3 5.0-15 Amendment No.

Procedures, Programs, and Manuals 5.5 5.5 Procedures, Programs, and Manuals (continued) 5.5.2.11 Steam Generator (SG)

Program (continued)

3.

If crack indications are found in any SG tube, then the next inspection for each SG for the degradation mechanism that caused the crack indication shall not exceed 24 effective full power months or one refueling outage (whichever is less).

If definitive information, such as from examination of a pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a crack-like indication is not associated with a crack(s), then the indication need not be treated as a crack.

4.

All sleeves shall be inspected with eddy current prior to initial operation.

This includes pressure retaining portions of the parent tube in contact with the sleeve, the sleeve-to-tube weld and the pressure retaining portion of the sleeve.

e.

Provisions for monitoring operational primary to secondary LEAKAGE.

f.

Provisions for SG tube repair methods.

Steam generator tube repair methods shall provide the means to re-establish the RCS pressure boundary integrity of SG tubes without removing the tube from service.

For the purposes of these Specifications, tube plugging is not a repair.

All acceptable tube repair methods are listed below.

1.

TIG welded sleeving with heat treatment, as described in ABB/CE Topical Report, CEN-630-P, Rev. 2, is currently approved by the NRC.

Tube repair can be performed on certain tubes that have been previously plugged as a corrective or preventive measure.

A tube inspection of the entire length of the tube shall be performed on a previously plugged tube prior to returning the tube to service.

(continued)

SAN ONOFRE--UNIT 3 5.0-16 Amendment No.

Response to NRC Request for Additional Information (RAI) (Reference 2)

RESPONSES TO NRC REQUEST FOR ADDITIONAL INFORMATION ON PROPOSED TECHNICAL SPECIFICATION IMPROVEMENT REGARDING STEAM GENERATOR TUBE INTEGRITY BASED ON TECHNICAL SPECIFICATION TASK FORCE (TSTF)-449 "STEAM GENERATOR TUBE INTEGRITY" SOUTHERN CALIFORNIA EDISON SAN ONOFRE NUCLEAR GENERATING STATION, UNITS 2 AND 3 DOCKET NOS. 50-361 AND 50-362 By letter dated November 30, 2005 (Agencywide Documents Access and Management System (ADAMS) Accession No. ML053390294), Southern California Edison (SCE, the licensee), submitted a request to amend the technical specifications (TS) for the San Onofre Nuclear Generating Station, Units 2 and 3 (SONGS 2 and 3). The proposed change is based on Standard Technical Specification Change Traveler TSTF-449, "Steam Generator Tube Integrity," Revision 4 (ADAMS Accession No. ML051090200), approved by the Nuclear Regulatory Commission (NRC).

Variations from TSTF-449 are listed In Section 2.1 of Enclosure 3 to the November 30,2005, application.

The NRC staff has reviewed the application consistent with the model safety evaluation published in the Federal Register March 2, 2005 (70 FR 10298), and determined the need to request additional information (RAI) to complete Its review.

1. By letter dated November 3, 2005 (ADAMS Accession No. ML053110284), the licensee submitted a request to change its TS to define the extent of the required tube Inspections and repair criteria within the tubesheet regions. This amendment Is currently under review by the staff. The changes proposed in this amendment are not Included in the current proposal to incorporate TSTF-449.

Therefore, the staff requests the licensee to clarify whether It Intends to have TSTF-449 approved prior to the November 3, 2005 request. If so, the November 3, 2005, request will need to be modified to reflect the adoption of TSTF-449. If not, the staff requests the licensee to discuss its plans to modify the current proposal to reflect the November 3, 2005 request.

SCE Response: Although the two submittals both relate to the steam generator TS, they are associated with different technical aspects of the TS. The NRC reviews of the two submittals are not necessarily connected and as such either change can be the first to be approved by the NRC independent of the other change. Once one of the changes is approved by the NRC, SCE will prepare and provide any appropriate TS replacement pages required to conform the other change with the approved change.

The following RAIs are based on the proposed TS changes found in Attachments C and D of the November 30, 2005, application.

2.

Page 3.4-51, TS 3.4.17, "Steam Generator (SG) Tube Integrity," has a typographical error. Condition B should read, "Required Action and associated Completion Time of Condition A not met."

SCE Response: Supplement 1 to Proposed Change NPF-10/15-564 adds the word "of" to provide consistency with TSTF-449.

3.

On Page 5.0-14, TS 5.5.2.11.b.3 describes the inspection of sleeves prior to Initial operation and is proposed for deletion. The staff requests the licensee to discuss the basis for not including this requirement in its proposal or to modify Its proposal to include the inspection of sleeves prior to Initial operation.

SCE Response: Supplement 1 to Proposed Change NPF-10/15-564 provides the modification on page 5.0-16.

4.

On Page 5.0-14a, TS 5.5.2.11.c describes the provisions for SG tube repair criteria and the removal of sleeves from service upon detection of service-induced degradation. Since the definition of an SG tube includes any repairs to the tube, the provisions in this TS may be misinterpreted. Therefore, the staff requests the licensee to discuss its plans to more clearly define the repair criteria in this TS.

An example of this modification is as follows:

c. Provisions for SG tube repair criteria. The non-sleeved region of a tube found by Inservice inspection to contain flaws with a depth equal to or exceeding 44 percent of the nominal tube wall thickness shall be plugged or repaired except If the flaws are permitted to remain In service through application of an alternate tube repair criteria discussed below.

Tubes shall be plugged If the sleeved region of a tube Is found by Inservice Inspection to contain flaws In the (a) sleeve or (b) pressure boundary portion of the original tube wall In the sleeve tube assembly (i.e., the sleeve-to-tube joint).

SCE Response: Supplement 1 to Proposed Change NPF-1 0/15-564 incorporates the NRC staff's example modification.

5.

On Page 5.0-14a, TS 5.5.2.11.c describes the removal of sleeves from service upon detection of service-induced degradation of the sleeve material or any portion of the sleeve-to-tube weld. The staff notes that sleeves may be Installed through the use of an expansion (lower) joint (i.e., without a weld) In the tubesheet. Therefore, the staff requests the licensee to discuss why it Is not necessary to have a repair criteria for a non-welded joint or to modify its proposal to address a non-welded joint.

SCE Response: The SCE Response to RAI 4 addresses a non-welded joint.

6.

On Page 5.0-15a, TS 5.5.2.11.d.2 states, "Inspect 100% of the tubes and sleeves at sequential periods of 60 effective full power months..." The staff notes that on page B 3.4-95, the SG tube Is defined as "...the entire length of the tube, Including the tube wall and any repairs made to It, between the tube-to-tubesheet weld at the tube Inlet and the tube-to-tubesheet weld at the tube outlet. The tube-to-tubesheet weld Is not considered part of the tube." Since a sleeved tube Is within the definition of an SG tube, the phrase "tubes and sleeves" Is redundant and may lead to an unnecessary distinction. Therefore, the staff requests the licensee to delete the phrase "and sleeves" from the aforementioned reference.

SCE Response: Supplement 1 to Proposed Change NPF-10/15-564 provides the requested deletion of the phrase "and sleeves".

7.

On Page 5.0-16a, TS 5.5.2.11.f.1 describes the acceptable tube repair methods for SONGS 2 and 3. Presumably the heat treatment, acceptance testing, and non-destructive examination of the sleeves Is discussed In the referenced topical report. If this Is the case, the staff requests the licensee to discuss its plans to delete the second paragraph detailing this Information related to the NRC approved tungsten Inert gas welded sleeving method.

SCE Response: Heat treatment is an option in the referenced topical report.

Heat treatment is a requirement in the existing TS. This is the reason that heat treatment is not deleted from the TS.

Supplement 1 to Proposed Change NPF-1 0/15-564 provides the requested deletion of unnecessary material in the second paragraph.

Supplement 1 also provides a consistency update in the second paragraph. The word "full" is replaced with "entire". This enhances consistency with the SG tube definition discussed in RAI 6.

The following RAI is based on the proposed TS changes found in Attachment G of the application (i.e., the redline and strikeout proposed TS Bases Pages to the application stated to be typical for both Units 2 and 3).

8.

On page B 3.4-71, the second to the last paragraph under, "Applicable Safety Analyses," states, "...The dose consequences resulting from the SLB [steam line break] accident are within the limits defined in 10 CFR 100." The corresponding sentence on page B 3.4.13-2 of TSTF-449, Revision 4, states, "...The dose consequences resulting from the SLB accident are well within the limits defined In 10 CFR 50 or the staff approved licensing basis (i.e.,

a small fraction of these limits)." The staff notes that on Page B 3.4-94, under, "Applicable Safety Analyses," the last sentence continues to Page B 3.4-95 and states, "...10 CFR 100 (Ref. 3) or the NRC approved licensing basis (e.g., a small fraction of these limits)."

The staff requests the licensee to discuss the discrepancy between its proposal and the TSTF or to modify its proposal consistent with the TSTF.

SCE Response: Proposed Change NPF-10/15-564 included discussion of this page B 3.4-71 variation from TSTF-449, Revision 4 as follows:

Page 3, Section 2.1 Variations from the CLIIP, sixth bullet: 'The TS Bases changes for TS B 3.4.13 provide more detail than TSTF-449 Revision 4 on the dose consequence limits reference for Steam Line Break Accident dose consequences. This is appropriate because this provides more specificity."

The variation between Proposed Change NPF-1 0/15-564 and TSTF-449 Revision 4 is due to the use of the actual (staff approved) SONGS Units 2 and 3 licensing basis in the submittal, as allowed by the TSTF.

Per the SONGS Units 2 and 3 Updated Final Safety Analysis Report (UFSAR),

the dose consequences resulting from the SLB accident are within the limits defined in 10 CFR 100:

The SONGS Units 2 and 3 pre-trip steam line break with fuel failure dose consequence limits are documented in UFSAR Table 15.10.1.3.1.1-3.

The radiological acceptance criterion for a SLB with fuel failure is to be within the 10 CFR 100 guideline values.

The SONGS Units 2 and 3 post-trip return-to-power steam line break with pre-accident iodine spiking dose consequence limits are documented in UFSAR Table 15.10.1.3.1.2-3. The radiological acceptance criterion for a SLB with pre-accident iodine spiking is to be within the 10 CFR 100 guideline values.

The SONGS Units 2 and 3 post-trip return-to-power steam line break with accident initiated iodine spiking dose consequence limits are documented in UFSAR Table 15.10.1.3.1.2-3. The radiological acceptance criterion for a SLB with accident initiated iodine spiking is to be within a small fraction (i.e., 10 percent) of the 10 CFR 100 guideline values.

The reference to 10 CFR 100 requirements in Proposed Change NPF-10/15-564 page B 3.4-71 is consistent with the wording used in Proposed Change NPF-10/15-564 pages B 3.4-94 and B 3.4-95.

v t e Letter Sequence Supplement
TAC:MC9236, Steam Generator Tube Integrity (Approved, Closed) TAC:MC9237, Steam Generator Tube Integrity (Approved, Closed)
Initiation Request, Request Acceptance... Supplement Administration Questions 21 April 2006 Answers Results Approval, Approval Other:
MONTHYEAR2006-04-21 [Table View]

ML061530259

Text

Subject:

References:

Subject:

Subject:

Dear Sir or Madam:

1.0 INTRODUCTION

2.0 PROPOSED CHANGE

RESPONSE

RESPONSE

Navigation menu

Search