Text

Annual Update to the DCPP License Renewal Application and License Renewal Application Amendment Number 45
	ML12009A070
Person / Time
Site:	Diablo Canyon
Issue date:	12/21/2011
From:	Becker J; Pacific Gas & Electric Co
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	DCL-11-136
	Download: ML12009A070 (103)
	v • d • e

{{#Wiki_filter:Pacific Gas and Electric Company` James R.Becker Diablo Canyon Power Plant Site Vice President Mail Code 104/6 P. 0. Box 56 Avila Beach, CA 93424 December 21, 2011 805.545.3462 Internal: 691.3462 PG&E Letter DCL-1 1-136 Fax: 805.545.6445 U.S. Nuclear Regulatory Commission 10 CFR 54.21(b) ATTN: Document Control Desk Washington, DC 20555-0001 Docket No. 50-275, OL-DPR-80 Docket No. 50-323, OL-DPR-82 Diablo Canyon Units 1 and 2 10 CFR 54.21 (b) Annual Update to the DCPP License Renewal Application and License Renewal Application Amendment Number 45

Dear Commissioners and Staff:

By letter dated November 23, 2009, Pacific Gas and Electric Company (PG&E) submitted an application to the U.S. Nuclear Regulatory Commission (NRC) for the renewal of Facility Operating Licenses DPR-80 and DPR-82, for Diablo Canyon Power Plant (DCPP) Units 1 and 2, respectively. The application included the license renewal application (LRA), and Applicant's Environmental Report - Operating License Renewal Stage. As required by 10 CFR 54.21(b), each year following submittal of the LRA, an amendment to the LRA must be submitted that identifies any change to the current licensing basis (CLB) that materially affects the contents of the LRA, including the Final Safety Analysis Report (FSAR) supplement. Enclosure 1 identifies DCPP LRA changes that are being made to reflect CLB that materially affect the LRA. Enclosure 2 contains the affected LRA pages with changes shown as electronic mark-ups (deletions crossed out and insertions italicized). The LRA update covers the period from October 1, 2010, through September 30, 2011. As a reviewer aid, all pages of the Appendix B aging management program section are provided, including unchanged pages, when there is a change on any of the pages in that section. Changes to existing commitments are contained in the changes to LRA Table A4-1 in Enclosure 2. If you have any questions regarding this response, please contact Mr. Terence L. Grebel, License Renewal Project Manager, at (805) 545-4160. A member of the STARS (Strategic Teaming and Resource Sharing) ALliance Catlaway

Comanche Peak
DiabLo Canyon
Pato Verde
San Onofre
South Texas Project
Wolf Creek

PG&E Letter DCL-11-136 December 21, 2011 Document Page 2 Control Desk I declare under penalty of perjury that the foregoing is true and correct. Executed on December 21, 2011. Sincerel , James R. Becker Site Vice President jwh/50412026 Enclosures cc: Diablo Distribution cc/enc: Elmo E. Collins, NRC Region IV Regional Administrator Nathanial B. Ferrer, NRC Project Manager, License Renewal Michael S. Peck, NRC Senior Resident Inspector Alan B. Wang, NRC Licensing Project Manager A member of the STARS (Strategic Teaming and Resource Sharing) Atliance Cattaway

Comanche Peak
Diabto Canyon
Palo Verde
San Onofre
South Texas Project
Wolf Creek

PG&E Letter DCL-1 1-136 Page 1 of 2 DCPP License Renewal Application (LRA) Changes Reflected in the Annual LRA Update Amendment 45 Affected LRA Section Reason for Change Table 3.3.2-8 Completed. PG&E replaced the carbon steel with stainless steel Table A4-1, #23 clad Centrifugal Charging Pump (CCP) 2-2 pump casings in the Section 3.3.2.2.14 chemical and volume control system with a completely stainless steel pump casing. Table A4-1, #71 Completed. The intake structure has been returned to (a)(2) status. Section Al. 15 Updated to reflect the revised date for withdrawal of Unit 1 Section B2.1.15 Capsule B as approved in NRC letter dated October 29, 2010 (ML103010159). Table 3.3.2-7 Updated to remove External Surfaces Monitoring Program for regulators and solenoid valves containing copper alloy (> 15% Zinc). (Reference PG&E Letter DCL-1 0-130, dated October 12, 2010) Table A4-1, #31 Completed. The Unit 2 gap repair work has been completed. Table A4-1, #35 Completed. The procedure acceptance criteria to specifically preclude repositioning a tube more than once without capping or replacing has been revised. This precludes repositioning a tube having chrome plated surfaces from the chrome being moved out of the areas of known wear. Table A4-1, #62 Completed. The Unit 2 diesel generator starting air and turbocharger air compressors have been upgraded. Section 4.2.1 Pressurized Thermal Shock analyses results are updated to Table 4.2-1 reflect WCAP-1 7315-NP and WCAP-1 7299-NP. Table 4.2-2 LRA Table A4-1, Item 24 is deleted. Table 4.2-3 Section 4.2.2 Table 4.2-4 Table 4.2-5 Section 4.2.3 Table 4.2-6 Table 4.2-7 Section 4.9 Section A3.1.2 Table A4-1, #24 Section 3.2.2.1.1 Updated to reflect the re-evaluation of cast iron and gray cast iron Table 3.2.2-1 components based on lessons learned from a license renewal Table 3.2.2-4 inspection at a different nuclear power plant. Also, added Section 3.3.2.1.3 applicable aging management programs for components for Section 3.3.2.1.4 which there are multiple aging effects. Section 3.3.2.1.5 Section 3.3.2.1.7 Section 3.3.2.1.8 Section 3.3.2.1.11 Section 3.3.2.1.12 Section 3.3.2.1.13

PG&E Letter DCL-1 1-136 Page 2 of 2 Affected LRA Section Reason for Change Section 3.3.2.1.14 Section 3.3.2.1.16 Section 3.3.2.1.17 Section 3.3.2.1.18 Section 3.3.2.1.19 Table 3.3.2-3 Table 3.3.2-4 Table 3.3.2-5 Table 3.3.2-7 Table 3.3.2-8 Table 3.3.2-11 Table 3.3.2-12 Table 3.3.2-13 Table 3.3.2-14 Table 3.3.2-16 Table 3.3.2-17 Table 3.3.2-18 Table 3.3.2-19 Section 3.4.2.1.1 Section 3.4.2.1.2 Section 3.4.2.1.4 Table 3.4.2-1 Table 3.4.2-2 Table 3.4.2-4 Table 2.3.1-2 Updated to reflect plant modifications (review of equipment Table 2.3.2-3 changes). Table 2.3.3-4 Table 2.3.3-7 Table 2.4-1 Table 3.1.2-2 Section 3.2.2.1.3 Table 3.2.2-3 Table 3.3.2-4 Table 3.3.2-7 Table 3.5.2-1 Table 3.3.2-4 Updated to reflect abandonment of equipment associated with Table 3.3.2-5 the boric acid evaporator subsystem. Table 3.3.2-8 Table 3.3.2-17 Table 3.3.2-18 Table 3.4.2-2

PG&E Letter DCL-11-136 Page 1 of 98 LRA Amendment 45 Affected LRA Sections, Tables, and Figures Table 2.3.1-2 Table 2.3.2-3 Table 2.3.3-4 Table 2.3.3-7 Table 2.4-1 Table 3.1.2-2 Section 3.2.2.1.1 Section 3.2.2.1.3 Table 3.2.2-1 Table 3.2.2-3 Table 3.2.2-4 Section 3.3.2.1.3 Section 3.3.2.1.4 Section 3.3.2.1.5 Section 3.3.2.1.7 Section 3.3.2.1.8 Section 3.3.2.1.11 Section 3.3.2.1.12 Section 3.3.2.1.13 Section 3.3.2.1.14 Section 3.3.2.1.16 Section 3.3.2.1.17 Section 3.3.2.1.18 Section 3.3.2.1.19 Section 3.3.2.2.14 Table 3.3.2-3 Table 3.3.2-4 Table 3.3.2-5 Table 3.3.2-7 Table 3.3.2-8 Table 3.3.2-11 Table 3.3.2-12 Table 3.3.2-13 Table 3.3.2-14 Table 3.3.2-16 Table 3.3.2-17 Table 3.3.2-18 Table 3.3.2-19 Section 3.4.2.1.1 Section 3.4.2.1.2 Section 3.4.2.1.4 Table 3.4.2-1 Table 3.4.2-2

PG&E Letter DCL-11-136 Page 2 of 98 LRA Amendment 45 Affected LRA Sections, Tables, and Figures Table 3.4.2-4 Table 3.5.2-1 Section 4.2.1 Table 4.2-1 Table 4.2-2 Table 4.2-3 Section 4.2.2 Table 4.2-4 Table 4.2-5 Section 4.2.3 Table 4.2-6 Table 4.2-7 Section 4.9 Section A.l15 Section A3.1.2 Table A4-1, #23, 24, 31, 35, 62, 71 Section B2.1.15 Section 2.3 PG&E Letter DCL-1 1-136 SCOPING AND SCREENING RESULTS: MECHANICAL SYSTEMS Page 3 of 98 Table 2.3.1-2 Reactor Coolant System Component Type Intended Function Filter Leakage Boundary (spatial) Structural Integrity (attached) Section 2.3 PG&E Letter DCL-1 1-136 SCOPING AND SCREENING RESULTS: MECHANICAL SYSTEMS Page 4 of 98 Table 2.3.2-3 Residual Heat Removal System Component Type Intended Function Indicator Leakage Boundary (spatial) StructuralIntegrity (attached) Section 2.3 PG&E Letter DCL-11-136 SCOPING AND SCREENING RESULTS: Page 5 of 98 MECHANICAL SYSTEMS Table 2.3.3-4 Component Cooling Water System Component Type Intended Function Tubing Leakage Boundary (spatial) Pressure Boundary StructuralIntegrity (attached)

Enclosure 2 Section 2.3 PG&E Letter DCL-1 1-136 SCOPING AND SCREENING RESULTS: Page 6 of 98 MECHANICAL SYSTEMS Table 2.3.3-7 CompressedAir System Component Type Intended Function Pressure Boundary I Orifice Throttle Section 2.4 PG&E Letter DCL-11-136 SCOPING AND SCREENING RESULTS: STRUCTURES Page 7 of 98 Table 2.4-1 ContainmentBuildina Component Type Intended Function Hatch Shelter, Protection _StructuralSupport Structural Steel Missile Barrier Section 3.1 PG&E Letter DCL-11-136 AGING MANAGEMENT OF REACTOR VESSEL, Page 8 of 98 INTERNALS, AND REACTOR COOLANT SYSTEM Table 3.1.2-2 Reactor Vessel, Internals, and Reactor Coolant System - Summary of Aging Management Evaluation - Reactor Coolant System Component Intended Material Environment Aging Effect Aging Management NUREG- Table 1 Item Notes Type Function Requiring Program 1801 Vol. Management 2 Item Filter LBS, SIA Stainless Demineralized Loss of material Water Chemistry V. C-4 3.2.1.03 C Steel Water (Int) (B2.1.2) and One-Time Inspection (B2.1.16) Filter LBS, SIA Stainless PlantIndoor Air None None IV.E-2 3.1 . 1.86 A Steel (Ext) I I I I _II Section 3.2 PG&E Letter DCL-11-136 AGING MANAGEMENT OF ENGINEERED Page 9 of 98 SAFETY FEATURES 3.2.2.1.1 Safety Injection System Materials The materials of construction for the safety injection system component types are:

        "   Cast IronR
          " Cast Iron (Gray Cast Iron)

Section 3.2 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF ENGINEERED SAFETY FEATURES Page 10 of 98 3.2.2.1.3 Residual Heat Removal System Materials The materials of construction for the residual heat removal system component types are: 0 Glass Section 3.2 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF ENGINEERED SAFETY FEATURES Page 11 of 98 Table 3.2.2-1 En*---Enineered Safety Features - Summarv of AaQina Manaaement Evaluation - Safetv Iniection System

                       '   ---   --

S --- -- -----------------------------------

                                                          -                                  --- - ........ .......... -                    .

Component Intended Material Environment Aging Effect Aging Management Program NUREG- Table 1 Notes Type Function Requiring 1801 Vol. Item Management 2 Item Filter PB Cast Iron Lubricating Oil Loss of material Lubricating Oil Analysis (B2.1.23) V.D1-28 3.2.1.16 B (Gray Cast (Int) and One-Time Inspection Iron) (B2.1.16) Filter PB Cast Iron Plant IndoorAir Loss of material External Surfaces Monitoring V.E-7 3.2.1.31 B (Gray Cast (Ext) Program (B2.1.20) Iron) Section 3.2 PG&E Letter DCL-11-136 AGING MANAGEMENT OF ENGINEERED SAFETY FEATURES Page 12 of 98 Table 3.2.2-3 Engineered Safety Features- Summary of Aging ManagementEvaluation - Residual Heat Removal System Component Intended Material Environment Aging Effect Aging Management NUREG- Table I Item Notes Type Function Requiring Program 1801 Vol. Management 2 Item Indicator LBS, SIA Glass BoratedWater None None None None H, 5 Leakage (Ext) Indicator LBS, SIA Glass Treated Borated None None V.F-9 3.2.1.52 A Water (Int) Indicator LBS, SIA Stainless Borated Water None None V. F- 13 3.2. 1.57 A Steel Leakage (Ext) Indicator LBS, SIA Stainless Treated Borated Loss of material Water Chemistry V.D1-30 3,2.1.49 E, 3 Steel Water (Int) (B2. 1.2) and One-Time I__IIInspection (B2.1.16) Indicator LBS, SIA Stainless Treated Borated Cracking Water Chemistry V.D1-31 3.2.1.48 E, 3 Steel Water (Int) (B2.1.2) and One-Time Inspection (B2.1.16) Notes for Table 3.2.2-3: Plant Specific Notes: 5 There are no aging effects associatedwith glass with borated water leakage. This non-NUREG-1801 Revision I line is based upon NUREG-1801 Revision 2 line VlI.J.AP-96. Section 3.2 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF ENGINEERED SAFETY FEATURES Page 13 of 98 T~hlI. .' 2 2-4

Fnnin,~~md P.~.f~tv ~ - .g,,mm~ri, nf Aninc, M~n~n~m~nt gi,~Iu~finn rnnt~ainm~cint I-41/Afl CZietc~m

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Component Intended Material Environment Aging Effect Aging Management Program NUREG- Table 1 Notes Type Function Requiring 1801 Vol. Item Management 2 Item Heat HT, PB Cast Iron Secondary Loss of material Water Chemistry (B2.1.2) and VIII.F-28 3.4.1.03 A Exchanger (Gray Cast Water (Int) One-Time Inspection (B2.1.16) (Containment Iron) Purge) Tubing LBS, PB, Stainless Closed Cycle Loss of material Closed-Cycle Cooling Water VII.C2-10 3.3.1.50 B SIA Steel Cooling Water System (B2.1.10) I (Int) Tubing LBS, PB, Stainless Plant Indoor None None VII.J-15 3.3.1.94 A SIA Steel Air (Ext) Valve PB Cast Iron Ventilation Loss of material Inspection of Internal Surfaces in VII.F3-3 3.3.1.72 D, 9 (Gray Cast Atmosphere Miscellaneous Piping and Ducting I Iron) I(Int) Components (B2.1.22) Plant Specific Notes: 9 The operatingtemperaturefor these components is above dew point. Condensationcan occurbut rarely. Components surfaces are normally dry. Section 3.3 PG&E Letter DCL-11-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 14 of 98 3.3.2.1.3 Saltwater and Chlorination System Materials The materials of construction for the saltwater and chlorination system component types are:

        '   Cast Iron Cast Iron (Gray Cast Iron)

Section 3.3 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF AUXILIARY Page 15 of 98 SYSTEMS 3.3.2.1.4 Component Cooling Water System Materials The materials of construction for the component cooling water system component types are: 0 Cast Iron Section 3.3 PG&E Letter DCL-11-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 16 of 98 3.3.2.1.5 Makeup Water System Materials The materials of construction for the makeup water system component types are: 0 Gast kron Section 3.3 PG&E Letter DCL-11-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 17 of 98 3.3.2.1.7 Compressed Air System Materials The materials of construction for the compressed air system component types are:

        '    Cast Iron Cast Iron (Gray Cast Iron)

Section 3.3 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF AUXILIARY Page 18 of 98 SYSTEMS 3.3.2.1.8 Chemical and Volume Control System Materials The materials of construction for the chemical and volume control system component types a re: Cast Iron (Gray Cast Iron) Section 3.3 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 19 of 98 3.3.2.1.11 Auxiliary Building HVAC System Materials The materials of construction for the auxiliary building HVAC system component types are:

Gast Iron
Cast Iron (Gray Cast Iron)

Section 3.3 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 20 of 98 3.3.2.1.12 Fire Protection System Materials The materials of construction for the fire protection system component types are: 0 Cast !FRo Section 3.3 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 21 of 98 3.3.2.1.13 Diesel Generator Fuel Oil System Materials The materials of construction for the diesel generator fuel oil system component types are:

        -   Cast Iron
        "   Ductile Iron Section 3.3 PG&E Letter DCL-1 1-136                                AGING MANAGEMENT OF AUXILIARY Page 22 of 98                                                                 SYSTEMS 3.3.2.1.14    Diesel Generator System Materials The materials of construction for the diesel generator system component types are:

Cast Iron C

Cast Iron (Gray Cast Iron)

Aging Management Programs The following aging management programs manage the aging effects for the diesel generator system component types:

Selective Leaching of Materials (B2.1.17)

Section 3.3 PG&E Letter DCL-11-136 AGING MANAGEMENT OF AUXILIARY Page 23 of 98 SYSTEMS 3.3.2.1.16 Gaseous Radwaste System Materials The materials of construction for the gaseous radwaste system component types are: rCast Iron

       . Cast Iron (Gray Cast Iron)

Section 3.3 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 24 of 98 3.3.2.1.17 Liquid Radwaste System Materials The materials of construction for the liquid radwaste system component types are:

       "    Cast IronR

Cast Iron (Gray Cast Iron)

Section 3.3 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 25 of 98 3.3.2.1.18 Miscellaneous Systems In-Scope ONLY based on Criterion 10 CFR 54.4(a)(2) ° Materials The materials of construction for the miscellaneous systems in scope ONLY based on Criterion 10 CFR 54.4(a)(2) component types are: 0 Cast !Fon Section 3.3 PG&E Letter DCL-11-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 26 of 98 3.3.2.1.19 Oily Water and Turbine Sump System Materials The materials of construction for the oily water and turbine sump system component types are:

          *CasRt   Iron.

Cast Iron (Gray Cast Iron)

Aging Management Programs The following aging management programs manage the aging effects for the oily water and turbine sump system component types: 0 Selective Leaching of Materials (B2. 1.17) Section 3.3 PG&E Letter DCL-11-136 AGING MANAGEMENT OF AUXILIARY Page 27 of 98 SYSTEMS 3.3.2.2.14 Loss of Material due to Cladding Breach The Water Chemistry program (B2.1.2) and the One-Time Inspection program (B2.1.16) manage loss of material due to cladding breach for steel clad with stainless steel pump casings exposed to treated borated water. The one-time inspection includes each of the affected components and will address the full internal cladding surface exposed to treated borated water. NRC Information Notice 80-38 and Information Notice 94-63 address loss of material due to cladding breach for CVCS pumps fabricated of steel with stainless steel cladding. DCPP identifies pumps CCP 1-1 and CCP 2-2 as fabricated of steel with stainless steel cladding. NRC Information Notice 80-38 advises that the condition presents a "potential source of degradation over long term operations" and recommends a "non-destructive examination of this pump type." Information Notice 94-63 provides additional information about the condition described based on the analysis of industry operating experience and concludes that "corrosion of the base metal due to cladding cracks is usually relatively easy to identify through visual inspection". The One-Time Inspection program (B2.1.16) provides a non-destructive visual examination consistent with the guidance of Information Notice 80-38 and 94-63. Prior to the period of extended operation, DGPP Will replace the current carbon steel wih stainlerss rMtoel c-lad-COrP 2 2 PUMP casings with a comspletely M.st ainless stee te!r pump

..... g 7During the Unit I and Unit 2 sixteenth refueling outages, PG&E replaced the CCP 1-l and CCP 2-2 carbon steel pump casings with completely stainless steel casings, respectively.

Section 3.3 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 28 of 98 Table 3.3.2-3 Auxiliary Systems - Summary of Aging ManagementEvaluation - Saltwater and ChlorinationSystem Component Intended Material Environment Aging Effect Aging Management NUREG- Table 1 Item Notes Type Function Requiring Program 1801 Vol. Management 2 Item Piping LBS Cast Iron Plant Indoor Air Loss of material External Surfaces VII.I-8 3.3.1.58 B (Gray Cast (Ext) Monitoring Program Iron) (82.1.20) Piping LBS Cast Iron Raw Water (Int) Loss of material Open-Cycle Cooling VII.C1-19 3.3.1.76 A (Gray Cast Water System (B12.1.9) Iron) Piping LBS Cast Iron Raw Water (Int) Loss of material Selective Leaching of VII. Cl-11 3.3.1.85 A (Gray Cast Materials (B2. 1.17) Iron) Pump LBS Cast Iron Demineralized Loss of matenal Selective Leaching of VII. G- 16 3.3. 1.85 A (Gray Cast Water (Int) Materials (B2. 1.17) Iron) Pump LBS Cast Iron Demineralized Loss of material Water Chemistry VIII.B1-11 3.4.1.04 A (Gray Cast Water (Int) (B2.1.2) and One-Time Iron) Inspection (B2.1.16) Pump LBS Cast Iron Plant Indoor Air Loss of material External Surfaces VII.I-8 3.3.1.58 B (Gray Cast (Ext) Monitoring Program Iron) (82.1.20) Strainer LBS Cast Iron Plant Indoor Air Loss of material External Surfaces VII.I-8 3.3.1.58 B (Gray Cast (Ext) Monitoring Program Iron) (B2.1.20) Strainer LBS Cast Iron Raw Water (Int) Loss of material Open-Cycle Cooling VII.C1-19 3.3.1.76 A (Gray Cast Water System (B2.1.9) Iron) Strainer LBS Cast Iron Raw Water (Int) Loss of materal Selective Leaching of VII. Cl-11 3.3. 1.85 A (Gray Cast Materials (B2.1,17) Iron) Valve PB Cast Iron Atmosphere/ Loss of material External Surfaces VII.I-9 3.3.1.58 B (Gray Cast Weather (Ext) Monitoring Program Iron) (82.1.20) Section 3.3 PG&E Letter DCL-11-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 29 of 98 Table 3.3.2-3 Auxiliary Systems - Summary of Aging Management Evaluation- Saltwaterand ChlorinationSystem Component Intended Material Environment Aging Effect Aging Management NUREG- Table I Item Notes Type Function Requiring Program 1801 Vol. Management 2 Item Valve LBS Cast Iron Demineralized Loss of material Selective Leaching of VII.G-16 3.3. 1.85 A (Gray Cast Water (Int) Materials (B2. 1.17) Iron) Valve LBS Cast Iron Demineralized Loss of material Water Chemistry VIII.B1-11 3.4.1.04 A (Gray Cast Water (Int) (B2.1.2) and One-Time Iron) Inspection (B2.1.16) Valve LBS Cast Iron Plant Indoor Air Loss of material External Surfaces VII.I-8 3.3.1.58 B (Gray Cast (Ext) Monitoring Program Iron) (B2.1.20) Valve LBS, PB Cast Iron Raw Water (Int) Loss of material Open-Cycle Cooling VII.C1-19 3.3.1.76 A (Gray Cast Water System (B2.1.9) Iron) Valve LBS, PB Cast Iron Raw Water (Int) Loss of material Selective Leaching of VI1.CI-11 3.3.1.85 A (Gray Cast Materials (B2. 1.17) Iron) Valve PB CopperAlloy Raw Water (Int) Loss of material Open-Cycle Cooling V11. C1-9 3.3.1.81 A (Aluminum > Water System (B2. 1 9) 8%)

Enclosure 2 Section 3.3 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 30 of 98 Table 3.3.2-4 Auxiliary Systems - Summary of Aging Management Evaluation - Component Cooling Water System Component Intended Material Environment Aging Effect Aging Management NUREG- Table 1 Item Notes Type Function Requiring Program 1801 Vol. Management 2 Item Piping PB Carbon Steel Atmosphere/ Loss of material Inspection of Internal VII..9 3.3.1.58 E, 4 Weather (Int) Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22) Piping PB Carbon Steel Closed Cycle Loss of material Inspection of Internal VI1.C2-14 3.3.1.47 E, 5 Cooling Water (Int) Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22) Regulates P-B Gae6t-ler,, a2 Ga,

                                               *-(4            NVOe             Ne                               3.3.-_-_-_-_-_-_-

A RegulateFs PB Cast 'rFO Plant indoor Air Lo66 of matera E)enal Sufae VI-8 B (EA)Monitoring Program Regu4ateGs PB Cast-On Atmgepe Lo66 of Materiaa Etrna Surfacvies- 9 3.3. :158 B WeatheF (E*4) Monitoring Program Valve PB Carbon Steel Closed Cycle Loss of material Inspection of Internal VII C2-14 3.3.1.47 E, 5 Cooling Water (Int) Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22) Valve PB Stainless Closed Cycle Loss of material Inspection of Internal VII C2-10 3.3.1.50 E, 5 Steel Cooling Water (Int) Surfaces in MiscellaneousPiping and Ducting Components (B2.1.22) I Notes for Table 3.3.2-4: Plant Specific Notes: I 4 Closed Cooling Water piping with internalenvironment of atmosphere/weather. Section 3.3 PG&E Letter DCL-11-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 31 of 98 5 Components are associatedwith the boric acid evaporatorsubsystem which is abandoned-in-place. Thus, aging of the components will be managed by the Inspection of InternalSurfaces in MiscellaneousPiping and Ducting Components aging managementprogram. Section 3.3 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 32 of 98 Table 3.3.2-5 Auxiliary Systems - Summary of Aging Management Evaluation - Makeup Water System Component Intended Material Environment Aging Effect Aging Management NUREG- Table I Item Notes Type Function Requiring Program 1801 Vol. Management 2 Item Piping LBS Stainless Demineralized Loss of material Inspection of Internal VIII.E-29 3.4.1.16 E, 6 Steel Water (Int) Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22) Pump PB Cast Iron Demineralized Loss of material Water Chemistry VIII. E-34 3.4.1.04 A (Gray Cast Water (Int) (B2.1.2) and One- Time Iron) Inspection (B2.1.16) Valve PB Cast Iron Atmosphere/ Loss of material External Surfaces VII.I-9 3.3.1.58 B (Gray Cast Weather (Ext) Monitoring Program Iron) (B2.1.20) Valve PB Cast Iron Buried (Ext) Loss of material Selective Leaching of VII. G- 15 3.3. 1 85 A (Gray Cast Materials(B2.1.17) Iron) Valve PB Cast Iron Buried (Ext) Loss of Material Buried Piping and Tanks VII.G-25 3.3.1.19 B (Gray Cast Inspection (B2.1.18) Iron) Valve LBS, PB Cast Iron Demineralized Loss of material Water Chemistry VIII.E-34 3.4.1.04 A (Gray Cast Water (Int) (B2.1.2) and One-Time Iron) Inspection (B2.1.16) Valve L-Bs Gast-lre Plant Indoor Air Lns ,of material drnal Sfa Extm) VI-r-- 3.3. B (k., Monitoring Program Valve L43S Gast !en+ P-otable W~ater (Int' Less of matorFal Inspecation of Internal Na~e Nene G Su~faGes4iR Miscellaneous Piping Vav g G~4Feý Raw VWateF (4pt) Loss of materia Fire Water System V47G-24 34.4-"B B8 I - . . )/g_ Section 3.3 PG&E Letter DCL-11-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 33 of 98 Table 3.3.2-5 Auxiliary Systems - Summary of Aging Management Evaluation - Makeup Water System Component Intended Material Environment Aging Effect Aging Management NUREG- Table 1 Item Notes Type Function Requiring Program 1801 Vol. Management 2 Item Valve LBS Cast Iron Potable Water (Int) Loss of material Inspection of Internal None None G (Gray Cast Surfaces in Iron) Miscellaneous Piping and Ducting Components (B2.1.22) Valve LBS Cast Iron Potable Water (Int) Loss of material Selective Leaching of None None G (Gray Cast Materials (82.1.17) Iron) Valve LBS Stainless Demineralized Loss of material Inspection of Internal VIII.E-29 3.4.1.16 E, 6 Steel Water (Int) Surfaces in MiscellaneousPiping and Ducting Components (B2.1.22) I Notes for Table 3.3.2-5: Plant Specific Notes: 6 Components are associatedwith the boric acid evaporatorsubsystem which is abandoned-in-place. Thus, aging of the components will be managed by the Inspection of InternalSurfaces in Miscellaneous Pipingand Ducting Components aging management program. Section 3.3 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 34 of 98 Table 3.3.2-7 Auxiliary Systems - Summary of Aging Management Evaluation- CompressedAir System Component Intended Material Environment Aging Effect Aging Management NUREG- Table 1 Item Notes Type Function Requiring Program 1801 Vol. Management 2 Item Filter FIL, PB Stainless Atmosphere! Loss of material External Surfaces None None G Steel Weather (Ext) MonitoringProgram (B2.1.20) Filter FIL, PB Stainless Dry Gas (Int) None None VII.J- 19 3.3.1.97 A Steel Orifice PB, TH Stainless PlantIndoor Air None None VII.J- 15 3.3.1.94 A Steel (Ext) Orifice PB, TH Stainless Plant IndoorAir Loss of material Inspection of Internal VII.D-4 3.3.1.54 E, 3 Steel (Int) Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22) Regulators PB Cast Iron Plant Indoor Air Loss of material External Surfaces VII.D-3 3.3.1.57 B (Gray Cast (Ext) Monitoring Program Iron) (B2.1.20) Regulators PB Cast Iron Plant Indoor Air Loss of material Inspection of Internal VII.D-2 3.3.1.53 E, 3 (Gray Cast (Int) Surfaces in Iron) Miscellaneous Piping and Ducting Components (B2.1.22) Regulators PB Cast Iron Plant IndoorAir Loss of material Selective Leaching of None None G, 4 (Gray Cast (Int) Materials (B2.1.17) Iron) RegulatEws P-9 Goppef-Alloy1.- AfitspheFe/- Loss of m~aterial External Surface6 None None (> 15% ZincG WeatheF (Ed) Monitoring Progr.am Regulators PB Copper Alloy PlantIndoor Air Loss of material Inspection of Internal VII. G-9 3.3.1.28 E, 3 (> 15% Zinc) (Int) Surfaces in MiscellaneousPiping and Ducting Components (B2. 1.22) Section 3.3 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 35 of 98 Table 3.3.2-7 Auxiliary Systems - Summary of Aging Management Evaluation- Compressed Air System Component Intended Material Environment Aging Effect Aging Management NUREG- Table 1 Item Notes Type Function Requiring Program 1801 Vol. Management 2 Item Solenoid Valve P-9 GOP~eF Alkoy- AtnGmeeIWe/ Loss of mnaterilo~ ral Su~faces None NoneG (> 1%-~ WeVVatheF (EA4) Mon40itrng Programn Solenoid Valve PB CopperAlloy Plant IndoorAir Loss of material Inspection of Internal VII. G-9 3.3.1.28 E, 3 (> 15% Zinc) (Int) Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22) Notes for Table 3.3.2-7: Plant Specific Notes: 4 Gray Cast Iron SSCs with surfaces exposed to Ventilation Atmosphere (Internal)or Plant IndoorAir (Internal)are subject to wetting due to condensationand thus are subject to loss of material due to selective leaching. Section 3.3 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 36 of 98 Table 3.3.2-8 Auxiliary Systems - Summary of Aging Management Evaluation- Chemical and Volume Control System Component Intended Material Environment Aging Effect Aging Management Program NUREG- Table I Notes Type Function Requiring 1801 Vol. Item Management 2 Item Demineralizer LBS Stainless Demineralized Loss of material Inspection of Internal Surfaces VIII.E-29 3.4.1.16 AE, 9 Steel Water (Int) in Miscellaneous Piping and Ducting Components (B2.I. 22)W-ater GenspL (82.1.2) and One Time Inspection (/3B424.16 Evaporator LBS Stainless Treated Borated Loss of material Inspection of Intemal Surfaces VII.E1-17 3.3.1.91 E, 59 Steel Water (Int) in MiscellaneousPiping and Ducting Components (B2. 1.22Watee r he e'- (132.1.2) and One Time ___________Insmpectioni(82.1.16) r.ap..atGF L-BS Stainless- Teated Bo*r*od G-rGkg WWter Chemistr, (1.2 And VWI

                                                                                                               \Il=4    20 3.3.19      -

Filter LBS Stainless Treated Borated Loss of material Inspection of Intemal Surfaces V/I.E1-17 3.3.1.91 E, 9 Steel Water (Int) in MiscellaneousPiping and Ducting Components (B2.1.22) Flow Element LBS, SIA Stainless Treated Borated Loss of material Inspection of InternalSurfaces VII.E1-17 3.3.1.91 E, 9 Steel Water (Int) in MiscellaneousPiping and Ducting Components (B2.1.22) Heat LBS, SIA, Carbon Closed Cycle Loss of material Inspection of Intemal Surfaces VII.E1-6 3.3.1.48 E, 9B Exchanger SS Steel Cooling Water in Miscellaneous Piping and (Boric Acid (Int) Ducting Components Evaporator/ (B2. 1.22)Clesed Cycle Cooling Condenser) ^aIo+e Syste(1),,, _ __\ Heat LBS, SS Carbon Secondary Loss of material Inspection of InternalSurfaces VIII.E-34 3.4.1.04 E, 9 Exchanger Steel Water (Int) in Miscellaneous Piping and (Boric Acid Ducting Components (B2. 1.22) Evaporator! Condenser)

Enclosure 2 Section 3.3 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 37 of 98 Table 3.3.2-8 Auxiliary Systems - Summary of Aging Management Evaluation- Chemical and Volume Control System Component Intended Material Environment Aging Effect Aging Management Program NUREG- Table 1 Notes Type Function Requiring 1801 Vol. Item Management 2 Item Heat- Las,-SS Ga*bGR Steam-(10) Loseof mraterial*,AlateAF Chmisty (2.1 .2) and V111.13, 4.14 E,5-Steel One Time Inspection (B2.1.1*6 (0FwGr Acid-Evapowator-Heat LBS, SS Stainless Closed Cycle Loss of material Inspection of Intemal Surfaces VII.C2-10 3.3.1.50 E, 9D Exchanger Steel Cooling Water in Miscellaneous Piping and (Boric Acid (Int) Ducting Components Evaporator/ (B2.1.22)CGloed Cycle Cooling Condenser) Water System,, .1.10) Heat LBS, SS Stainless Secondary Loss of material Inspection of Internal Surfaces VIII.E-29 3.4.1.16 E, 9C Exchanger Steel Water (Ext) in Miscellaneous Piping and (Boric Acid Ducting Components Evaporator/ (B2.1.22)0Wate-r eetry-Condenser) (92.1.2) and Ge* Time nspcion (B2.1.16)

                                                                         .....

Heat- LBS-SS Stainless- Serenday GaGl,*,*,., Water Chemisty (B2.1.2) and V!.W=- 3.44-4 G Eha~ge-- Steel WateF--(EA One Ti*e InspGction (92.1.16) (139kAGi4 Evapo-ator Heat LBS, SS Stainless Closed Cycle Loss of material Inspection of Internal Surfaces VI1.C2-10 3.3.1.50 E, 9D Exchanger Steel Cooling Water in Miscellaneous Piping and (Boric Acid (Ext) Ducting Components Distillate) (B2.1.22)Closed Cycle Cooling Heat LBS, SIA, Stainless Closed Cycle Loss of material Inspection of InternalSurfaces VI1.C2-10 3.3.1.50 E, 9D Exchanger SS Steel Cooling Water in Miscellaneous Piping and (Boric Acid (Int) Ducting Components Distillate) (B2.1.22)CGlsod Cycle Cooling __-__ater Sytem4(*2.*110)

Enclosure 2 Section 3.3 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 38 of 98 Table 3.3.2-8 Auxiliary Systems - Summary of Aging Management Evaluation - Chemical and Volume Control System Component Intended Material Environment Aging Effect Aging Management Program NUREG- Table 1 Notes Type Function Requiring 1801 Vol. Item Management 2 Item Heat LBS, SS Stainless Demineralized Loss of material Inspection of Internal Surfaces VIII.E-29 3.4.1.16 E, 9G Exchanger Steel Water (Int) in Miscellaneous Piping and (Boric Acid Ducting Components Distillate) (82.1.22)-Water Gher4stfý- (924.1.2), and One Time Heat LBS Stainless Secondary Loss of material Inspection of Internal Surfaces VIII.E-29 3.4.1.16 E, 9 Exchanger Steel Water (Int) in Miscellaneous Piping and (Boric Acid Ducting Components (B2. 1.22) Evaporator) Heat- LBS Stanless- Steam-{k(-t) Water Chemistry (82.1,2) and- ."ý3. V.11431 2 E 5 E-xGhaRger- Steel One Time Inspection (82.1.16) (69FOGAGi4 Heat- L4B Staimless- Steamt(4nBt Los of material Waiter Chemistry (132.1.2) and V*b,*B.3 34.4.1 E.3 ExGhafiger-- Steel One Time Inspection (132.1.46) (13FG GAGid-Heat LBS9 2-tai ess,- TrFeated BerFate G~aGkinq 'ater Chemistry (62.1.2) ad VlkE445 3-3-1-O8 E1-EXGhanger- Steel W~ateF (EA) Qnz TimeA Inspection (1324.W.6 {(BeiG -AGi Heat LBS Stainless Treated Borated Loss of material Inspection of Internal Surfaces VII.El-17 3.3.1.91 E,,69 Exchanger Steel Water (Ext) in Miscellaneous Piping and (Boric Acid Ducting Components Evaporator) (B2.1.22)Water-Chlemietpy-(B..2ndOe Time Heat- LBS-SIA- Stainleess Treated Batd CGking Water Chemit ,A,. a VI.E 5 3.3.0* EGhaeref- &S Steel VWat(I4 OnAe TimEI ion (182.1.16) (BeP~i-Aeid-Section 3.3 PG&E Letter DCL-11-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 39 of 98 Table 3.3.2-8 Auxiliary Systems - Summary of Aging Management Evaluation - Chemical and Volume Control System Component Intended Material Environment Aging Effect Aging Management Program NUREG- Table 1 Notes Type Function Requiring 1801 Vol. Item Management 2 Item Heat LBS, SIA, Stainless Treated Borated Loss of material Inspection of Internal Surfaces VII.El-17 33.1.91 E, 59 Exchanger SS Steel Water (Int) in Miscellaneous Pipingand (Boric Acid Ducting Components Evaporator) (B2.1.22)WateF Ghemistpy-(B2.1.2) and One Time n..p..tion (-2.1 .16) Heat LBS Stainless Secondary Loss of material Inspection of InternalSurfaces VIII.E-29 3.4.1.16 E, 9G Exchanger Steel Water (Ext) in Miscellaneous Pipingand (Boric Acid Ducting Components Feed) (B2.1.22)Water Ghemtpy-(132.1.2) and One Time inspection (B32.1 .6) ___ Heat- L-- Stainleess SeGOsday ar-,ki.rng Watcr-Chemistry, (2.1.2) and- V4lO .4.4-.4 G EXehanger- Steel Water-(E-d* One Time Inspection A(,-B2.1,16) F-ee Heat LBS Stainless Secondary Loss of matenal Inspection of InternalSurfaces VIII.E-29 3.4.1.16 E, 9 Exchanger Steel Water (Int) in Miscellaneous Pipingand (Boric Acid Ducting Components (B2. 1.22) Feed) Neat- L-BS Stainless- Steam-(It) G.a.k.,. Water Chemistry (92.1.2) and VIk13, 2 3.44.39 Steel One Time Inspection (B2.1.!6) F-ee Neat- L-88 Stainle6s Steam-(R Lo*ss of material Water Chemistry (B2. 1.2) and VI.131-3 4.1.- F.~agsteel One Time Inspection (132.1416) Feed) Neat- 1B8 Stainless- Treated Be*ated GraGking WateFG hemistry (132.1.2) and VWE513.1.08 E Ehanger- Steel WateF (I t) One Time Inspection (B2.1416) (-ee AG4

Enclosure 2 Section 3.3 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 40 of 98 Table 3.3.2-8 Auxiliary Systems - Summary of Aging Management Evaluation - Chemical and Volume Control System Component Intended Material Environment Aging Effect Aging Management Program NUREG- Table 1 Notes Type Function Requiring 1801 Vol. Item Management 2 Item Heat LBS Stainless Treated Borated Loss of material Inspection of Internal Surfaces VII.El-17 3.3.1.91 E, 59 Exchanger Steel Water (Int) in Miscellaneous Piping and (Boric Acid Ducting Components Feed) (B2. 1.22)W1at A-Gfhp.ietfV-(92.1.2) and One Time Heat LBS, SIA, Carbon Closed Cycle Loss of material Inspection of Internal Surfaces VII.E1-6 3.3.1.48 E, 98 Exchanger SS Steel Cooling Water in Miscellaneous Piping and (Boric Acid (Int) Ducting Components Vent) (B2. 1.22)CGosed Cycle Ceeling W..ater Sytem (B2..1.1

                                                                                         ....

Heat LBS, SS Carbon Demineralized Loss of material Inspection of InternalSurfaces VIII.E-37 3.4.1.03 E, 9A Exchanger Steel Water (Int) in Miscellaneous Piping and (Boric Acid Ducting Components Vent) (B2.1.22)WateF-GemieFy-(832.1.2) and One Time __________ ncpetion (821.16) 4 Heat LBS, SS Stainless Closed Cycle Loss of material Inspection of Internal Surfaces VI1.C2-10 3.3.1.50 E, 9D Exchanger Steel Cooling Water in Miscellaneous Piping and (Boric Acid (Int) Ducting Components Vent) (B2. 1. ),G2,*Ced Cycle Cooling Water S-yrtem(2.1) Heat LBS, SS Stainless Secondary Loss of material Inspection of Internal Surfaces VIII.E-29 3.4.1.16 E, 9G Exchanger Steel Water (Ext) in Miscellaneous Piping and (Boric Acid Ducting Components Vent) (B2. 1.22)0Water Chewstp (62.1.2) and One Time __________ Inpcin I (812.1.1 6) Heat- LBS S& Stainless- SeGendaFy- G~aeliR9 Wate Cei It1y (32.1.2) and VIWI.E30 3.444.4 G Steel Water-(EA) One Time !nspectiGn (B2.1.16) (BerOGAGi Section 3.3 PG&E Letter DCL-11-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 41 of 98 Table 3.3.2-8 Auxiliary Systems - Summary of Aging Management Evaluation - Chemical and Volume Control System Component Intended Material Environment Aging Effect Aging Management Program NUREG- Table I Notes Type Function Requiring 1801 Vol. Item Management 2 Item Piping LBS, SIA Stainless Demineralized Loss of material Inspection of Internal Surfaces VIII.E-29 3.4.1.16 E, 9 Steel Water (Int) in Miscellaneous Piping and Ducting Components (B2.1.22) Piping LBS, SIA Stainless Sodium Loss of material Inspection of Internal Surfaces None None G, 9 Steel Hydroxide (Int) in MiscellaneousPiping and Ducting Components (82.1.22) Piping LBS, PB, Stainless Treated Borated Loss of material Inspection of Intemal Surfaces VII.El-17 3.3.1.91 E, 9 SIA Steel Water (Int) in MiscellaneousPiping and Ducting Components (B2.1.22) Pump LBS, RB*- Carbon Borated Water Loss of material Boric Acid Corrosion (B2.1.4) VII.El-1 3.3.1.89 A SIA Steel with Leakage (Ext) Stainless Steel Cladding Pump LBS Carbon Demineralized Loss of material Inspection of Internal Surfaces VIII.E-29 3.4.1.16 E, 9A Steel with Water (Int) in MiscellaneousPiping and Stainless Ducting Components Steel (B2.1.22)WateF Chem'tiy-Cladding (132.1.2) and One Time hIQn (B21 .16) I_________-np PupB P-14 Garbon Treated Borated faGkir Water Chemistry (B2.1.2) and VI-17 3.3.1.Q9 E Steel with- WateF (It) One-Time Inspection (B2.1..16) StRA'PeeF Steel-Pump LBS, RB-- Carbon Treated Borated Loss of material Water Chemistry (132.1.2) and VII.E1-17 3.3.1.91 E, 5 SIA Steel with Water (Int) One-Time Inspection (132.1.16) Stainless Steel Cladding Section 3.3 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 42 of 98 Table 3.3.2-8 Auxiliary Systems - Summary of Aging Management Evaluation- Chemical and Volume Control System Component Intended Material Environment Aging Effect Aging Management Program NUREG- Table 1 Notes Type Function Requiring 1801 Vol. Item Management 2 Item pUMP P9 GaFbon Treated Berated *-esrs fWmaterial ater Chemistry (82.1.2* and V11...4-.2 3I.31.36 E-Steel-with- WateF-(,I4t One Time Inspection (12.1.16) stainese-Steel-Pump LBS Stainless Treated Borated Loss of material Inspection of Internal Surfaces VIlE1-17 3.3.1.91 E, 9 Steel Water (Int) in Miscellaneous Piping and Ducting Components (B2.1.22) Sight Gauge LBS, SIA Stainless Treated Borated Loss of material Inspection of Internal Surfaces VII. El-17 3.3.1.91 E, 9 Steel Water (Int) in MiscellaneousPiping and Ducting Components (B2. 1.22) Tank LBS Stainless Secondary Loss of material Inspection of Internal Surfaces VIII.E-29 3.4.1.16 E, 9 Steel Water (Int) in MiscellaneousPiping and Ducting Components (B2.1.22) Tak L4B S-tainiees- Steam-(nt-) Granl4 Water Chcmistry (12.1.2) and-

                                                                            )                                     V11..91 2 3.4..-.3       E-,5 Steel                                              One    Ti.,   I         InDEtien 4 4(2 \

T~*LBS Trap LBS Trap LBS Valve LBS Iron) I_ Section 3.3 Valve LBS Iron) Valve Valve Valve Valve Vessel LBS ___ ___ ___ ___ _____ ___ _ ___ Notes for Table 3.3.2-8: Plant Specific Notes: Section 3.3 9 Components Section 3.3 Iron) Damper PB Damper PB Iron) (Int) Pump LBS (Int) Pump LBS Pump LBS Iron) (Int) Pump LBS Iron) Pump LBS Iron) (Int) Valve LBS (> 15% Zinc) Cooling Water (Int) Valve LBS (> 15% Zinc) Water (Int) Sainies6- Steam-(l!nt) Loss of mnaterial Water Chemnistry (132.1.2) and- Vl44.B1 3 3.4..37 E Tank LBS Stainless Treated Borated Loss of material Inspection of Internal Surfaces VII.E1-17 3.3.1.91 E, &9 Steel Cast Water (Int) in Miscellaneous Piping and Austenitic Ducting Components (B2. 1.22)AWetear-Ghenis~tfy-(82.1.2) and One Time rIrnspection (82.1.6) ____ Carbon Secondary Loss of material Inspection of InternalSurfaces VIII.E-34 3.4. 1.04 E, 9 Steel Water (Int) in Miscellaneous Pipingand Ducting Components (B2. 1.22) GaFIbeG Steam I.nt) Loss- of mnaterial Watepr Chemistry (132.1.2) and4 V1119184 3.4.37 E~ Stee.1 Qn Tm In (62n' -r) Cast Iron Plant Indoor Air Loss of material External Surfaces Monitoring VII.1-8 3.3.1.58 B (Gray Cast (Ext) Program (82.1.20) IIII_ __ PG&E Letter DCL-11-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 43 of 98 Table 3.3.2-8 Auxiliary >ystems - Summary of Aging Management Evaluation- Chemical and Volume Control System Component Intended Material Environment Aging Effect Aging Management Program NUREG- Table I Notes Type Function Requiring 1801 Vol. Item Management 2 Item Valve LBS Cast Iron Ventilation Loss of material Inspection of Internal Surfaces V.A-19 3.2.1.32 B (Gray Cast Atmosphere (Int) in Miscellaneous Piping and Iron) Ducting Components (B2.1.22) Cast Iron Ventilation Loss of material Selective Leaching of Materials None None G, 8 (Gray Cast Atmosphere (Int) (82.1.17) LBS, PB, Stainless Demineralized Loss of material Inspection of Internal Surfaces VIII.E-29 3.4. 1.16 E, 9 SIA Steel Water (Int) in Miscellaneous Pipingand Ducting Components (B2.1.22) LBS, SIA Stainless Sodium Loss of material Inspection of Internal Surfaces None None G, 9 Steel Hydroxide (Int) in Miscellaneous Piping and Ducting Components (B2.1.22) LBS, PB, Stainless Treated Borated Loss of material Inspection of Internal Surfaces VIlE.1-17 3.3.1.91 E, 9 SIA Steel Water (Int) in Miscellaneous Piping and Ducting Components (B2.1.22) LBS, SIA Stainless Treated Borated Loss of material Inspection of Internal Surfaces VIlE1-17 3.3.1.91 E, 9 Steel Cast Water (Int) in Miscellaneous Piping and Austenitic Ducting Components (82.1.22) Stainless Treated Borated Loss of material Inspection of Intemal Surfaces VIILE1-17 3.3.1.91 E, 69 Steel Water (Int) in MiscellaneousPiping and Ducting Components (B2.1.22)Water Chemistry (B2.1.2) and One-Time Inspection (B2.1.16)WateF-Chemistry (132.1.2) and Ono- ___ ___ __ ___ ___ _ imoe !nSPectiOn B .. 6 _ _ _ _ _ _ _ _ _ _ _ _ PG&E Letter DCL-11-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 44 of 98 8 Gray Cast Iron SSCs with surfaces exposed to Ventilation Atmosphere (Internal)or Plant Indoor Air (Internal)are subject to wetting due to condensation and thus are subject to loss of material due to selective leaching. are associatedwith the boric acid evaporatorsubsystem which is abandoned-in-place. Thus, aging of the components will be managed by the Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components aging management program. PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 45 of 98 Table 3.3.2-11 Auxiliary Systems - Summary of Aging Management Evaluation - Auxiliary Building HVAC System Component Intended Material Environment Aging Effect Aging Management NUREG- Table 1 Notes Type Function Requiring Program 1801 Vol. Item Management 2 Item Damper PB Cast Iron Plant Indoor Loss of material External Surfaces Monitoring VII.F2-2 3.3.1.56 B (Gray Cast Air (Ext) Program (B2.1.20) Cast Iron Ventilation Loss of material Inspection of Internal VII.F2-3 3.3.1.72 B (Gray Cast Atmosphere Surfaces in Miscellaneous Iron) (Int) Piping and Ducting Components (B2.1.22) Cast Iron Ventilation Loss of material Selective Leaching of None None G, 5 (Gray Cast Atmosphere Materials(B2.1.17) Carbon Steel Closed Cycle Loss of material Closed-Cycle Cooling Water VII.F2-18 3.3.1.47 B Cooling Water System (B2. 1.10) Carbon Steel Plant Indoor Loss of material External Surfaces Monitoring VII. I-8 3.3. 1.58 B Air (Ext) Program(B2.1.20) Cast Iron Closed Cycle Loss of material Closed-Cycle Cooling Water VII.F2-18 3.3.1.47 B (Gray Cast Cooling Water System (B2. 1.10) Cast Iron Plant Indoor Loss of material External Surfaces Monitoring VII.I-8 3.3.1.58 B (Gray Cast Air (Ext) Program (B2.1.20) Cast Iron Closed Cycle Loss of material Selective Leaching of VII. C2-8 3.3. 1.85 A (Gray Cast Cooling Water Materials (B2. 1.17) CopperAlloy Closed Cycle Loss of material Closed-Cycle Cooling Water VII.F2-13 3.3.1.51 B System (B2. 1.10) CopperAlloy Demineralized Loss of material Water Chemistry (B2. 1.2) VIII.A-5 3.4.1.15 A and One-Time Inspection (B2.1.16)

Enclosure 2 Section 3.3 PG&E Letter DCL-11-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 46 of 98 Table 3.3.2-11 Auxiliary Systems - Summary of Aging Management Evaluation - Auxiliary Building HVAC System Component Intended Material Environment Aging Effect Aging Management NUREG- Table I Notes Type Function Requiring Program 1801 Vol. Item Management 2 Item Valve LBS CopperAlloy Potable Water Loss of material Inspection of Internal None None G (> 15% Zinc) (Int) Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22) Notes for Table 3.3.2-11: Plant Specific Notes: I 5 Gray Cast Iron SSCs with surfaces exposed to Ventilation Atmosphere (Internal)or Plant IndoorAir (Internal)are subject to wetting due to condensation and thus are subject to loss of material due to selective leaching. Section 3.3 PG&E Letter DCL-11-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 47 of 98 Table 3.3.2-12 Auxiliary Systems - Summary of Aging Management Evaluation - Fire Protection System Component Intended Material Environment Aging Effect Aging Management Program NUREG- Table 1 Notes Type Function Requiring 1801 Vol. Item Management 2 Item Hydrant PB Gasbt.Frn Buried (Ext) Loss of material Buried Piping and Tanks VII.G-25 3.3.1.19 B Carbon Steel Inspection (B2.1.18) Hydrant PB Cast-rGn Raw Water (Int) Loss of material Fire Water System (B2.1.13) VII.G-24 3.3.1.68 B Carbon Steel Piping PB Cast Iron Buried (Ext) Loss of material Selective Leaching of VII. G-15 3.3.1.85 A (Gray Cast Materials(B2.1.17) Iron) Piping PB Cast Iron Buried (Ext) Loss of material Buried Piping and Tanks VII.G-25 3.3.1.19 B (Gray Cast Inspection (B2.1.18) Iron) Piping PB Cast Iron Raw Water (Int) Loss of material Selective Leaching of VII. G-14 3.3.1.85 A (Gray Cast Materials(B2.1.17) Iron) Piping PB Cast Iron Raw Water (Int) Loss of material Fire Water System (B2.1.13) VII.G-24 3.3.1.68 B (Gray Cast Iron) Pump PB, SS Cast Iron Plant Indoor Air Loss of material External Surfaces Monitoring VII.1-8 3.3.1.58 B (Gray Cast (Ext) Program (B2.1.20) Iron) Pump PB, SS Cast Iron Raw Water (Int) Loss of material Selective Leaching of VII. G-14 3.3.1.85 A (Gray Cast Materials (B2.1.17) Iron) Pump PB, SS Cast Iron Raw Water (Int) Loss of material Fire Water System (B2.1.13) VII.G-24 3.3.1.68 B (Gray Cast Iron) Straine PB Cast trn Plnt IndoorAir- Less of Mat ernal Surfaces Monitoring V11-.-8 3-3--.58 B St-a*e+ P19B CGa ,t-,,,, Raw-WateF-IR Loess of Mate alFe Water Sytem, (B2.113) V11G-24 3-1-6 B Valve PB9 C;stI At!oenep /-n Losseofmato External Surfaces Monitoring V11-.9 23-4 ___________Weatherf-ý Program (62.1.20) Section 3.3 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 48 of 98 Table 3.3.2-12 Auxiliary Systems - Summary of Aging ManagementEvaluation - Fire Protection System Component Intended Material Environment Aging Effect Aging Management Program NUREG- Table 1 Notes Type Function Requiring 1801 Vol. Item Management 2 Item Valve P9 Gaet 'FO B~ied(E~d) LOSS Of mAaterial 3Urfied Piping and Tanks V1 G :25 3.4.49 a nsperti*n (B21 2,18) Valve 124B C;-t Itn PlAnt Indoor Ar Loss of matr 'nspection of internal S'urfaces VJ G-2, B34.71 (14#,n M.scc uneo'us Piping and Durting Components Valve P-B Ga6t ken Raw-WateF-(IP Lo6ss ef materia Fire Water System (B2.1.13) VWG 24 331.6 a Valve PB9 Cast-!Fen Dy Ga&-{(I4t Ne.R Ne.~e Vlk-2~3 3.3.1.7~ A Valve PB Cast Iron Plant IndoorAir Loss of material Inspection of InternalSurfaces VII. G-23 3.3.1.71 B (Gray Cast (Int) in MiscellaneousPiping and Iron) Ducting Components (B2.1.22) Valve PB Cast Iron Plant IndoorAir Loss of material Selective Leaching of None None G, 4 (Gray Cast (Int) Materials (B2.1.17) Iron) Notes for Table 3.3.2-12: Plant Speciflc Notes: 4 Gray Cast Iron SSCs with surfaces exposed to Ventilation Atmosphere (Internal)or Plant IndoorAir (Internal)are subject to wetting due to condensationand thus are subject to loss of materialdue to selective leaching. Section 3.3 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 49 of 98 I aDle ,.J. 3- 7,1 AUXllar -ysrems - ,ummary OT i*-glng managemenrtvaiuarion- ulesei ueneraror -uel (iIl >ysrem Component Intended Material Environment Aging Effect Aging Management NUREG- Table I Notes Type Function Requiring Program 1801 Vol. Item Management 2 Item Pump PB Gast- Fuel Oil (Int) Loss of material Fuel Oil Chemistry (B2.1.14) VII.H1-10 3.3.1.20 B GeaDuctile and One-Time Inspection Iron (B2.1.16) Pump PB Cast- Plant Indoor Loss of material External Surfaces Monitoring VII.1-8 3.3.1.58 B k-GeDuctile Air (Ext) Program (B2.1.20) Iron Valve PB cast r!O FUeI-Gil-(E)) Loss o-f Matei Fuel, Oil Chem*.istF (132.1.14). V14*1..

                                                                                                             -. 0 3.1.20      B
                                                                         *and- One Tirnc Inspepion Valve              P-B       Cas4t Iron   FUGl      Int) L0o6 Of materl   FuRlOil ChemiQtr4 (B2.1.11) V4.H! 10 3.3.20          B and One Time Inspection Section 3.3 PG&E Letter DCL-1 1-136                                                                 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 50 of 98 Table 3.3.2-14    Auxiliary Systems - Summary of Aging ManagementEvaluation - Diesel GeneratorSystem Component    Intended     Material     Environment        Aging Effect     Aging Management        NUREG- Table 1 Item    Notes Type      Function                                      Requiring              Program          1801 Vol.

Management 2 Item Compressor SIA Cast Iron Plant Indoor Air Loss of material External Surfaces VII.I-8 3.3.1.58 B (Gray Cast (Ext) Monitoring Program Iron) (B2.11.20) Compressor SIA Cast Iron Plant Indoor Air Loss of material Inspection of Internal VIII.G-34 3.4.1.30 D (Gray Cast (Int) Surfaces in Iron) Miscellaneous Piping and Ducting Components (B2.1.22) Compressor SIA Cast Iron Plant Indoor Air Loss of material Selective Leaching of None None G, 3 (Gray Cast (Int) Materials(B2.1.17) Iron) Pump PB Cast Iron Closed Cycle Loss of material Selective Leaching of VII. C2-8 3.3.1.85 A (Gray Cast Cooling Water (Int) Materials(B2.1.17) Iron) Pump PB Cast Iron Closed Cycle Loss of material Closed-Cycle Cooling VII.H2-23 3.3.1.47 B (Gray Cast Cooling Water (Int) Water System (B2. 1.10) Iron) Pump LBS, PB, Cast Iron Fuel Oil (Int) Loss of material Fuel Oil Chemistry VII.H2-24 3.3.1.20 B SIA (Gray Cast (B2.1.14) and One-Time Iron) Inspection (B2.1.16) Pump LBS, PB Cast Iron Lubricating Oil Loss of material Lubricating Oil Analysis VII.H2-20 3.3.1.14 B (Gray Cast (Int) (B2.1.23) and One-Time Iron) Inspection (B2.1.16) Pump LBS, PB, Cast Iron Plant Indoor Air Loss of material External Surfaces VII.I-8 3.3.1.58 B SIA (Gray Cast (Ext) Monitoring Program Iron) (B2.1.20) Sight Gauge PB Carbon Steel Fuel Oil (Int) Loss of material Fuel Oil Chemistry VII.1H2-24 3.3.1.20 B (B2. 1.14) and One-Time Inspection (B2.1.16) Sight Gauge PB Carbon Steel Plant IndoorAir Loss of material External Surfaces VII. 1-8 3.3.1.58 B (Ext) Monitoring Program (B2.1.20) Section 3.3 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 51 of 98 Table 3.3.2-14 Auxiliary Systems - Summary of Aging Management Evaluation - Diesel GeneratorSystem Component Intended Material Environment Aging Effect Aging Management NUREG- Table I Item Notes Type Function Requiring Program 1801 Vol. Management 2 Item Sight Gauge PB Cast Iron Fuel Oil (Int) Loss of material Fuel Oil Chemistry VII.H2-24 33.1.20 B (Gray Cast (B2.1.14) and One-Time Iron) Inspection (B2.1.16) Sight Gauge PB Cast Iron Plant Indoor Air Loss of material External Surfaces VII.I-8 3.3.1.58 B (Gray Cast (Ext) Monitoring Program Iron) (B2.1.20) Valve PB Cast Iron Closed Cycle Loss of material Selective Leaching of VII. C2-8 3.3.1.85 A (Gray Cast Cooling Water (Int) Materials(B2.1.17) Iron) Valve PB Cast Iron Closed Cycle Loss of material Closed-Cycle Cooling VII.H2-23 3.3.1.47 B (Gray Cast Cooling Water (Int) Water System (B2.! .10) Iron) Valve PB9 Cast-'FOR Fuel-Oil-(IPA) L-eocs of material Fuel Oil Chemictry VIWH2-224 3.3.1.20 B (B2.1.141) and One Time Valve PB Cast Iron Lubricating Oil Loss of material Lubricating Oil Analysis VII.H2-20 3.3.1.14 B (Gray Cast (Int) (B2.1.23) and One-Time Iron) Inspection (B2.1.16) Valve PB Cast Iron Plant Indoor Air Loss of material External Surfaces VII.I-8 3.3.1.58 B (Gray Cast (Ext) Monitoring Program Iron) (B2.1.20) Valve PB Cast Iron Plant Indoor Air Loss of material Inspection of Internal VII.H2-21 3.3.1.71 B (Gray Cast (Int) Surfaces in Iron) Miscellaneous Piping and Ducting Components (B2.1.22) Valve PB Cast Iron Plant IndoorAir Loss of material Selective Leaching of None None G, 3 (Gray Cast (Int) Materials(B2. 1.17) Ilron) Section 3.3 PG&E Letter DCL-11-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 52 of 98 Notes for Table 3.3.2-14: Plant Specific Notes: 3 Gray Cast Iron SSCs with surfaces exposed to Ventilation Atmosphere (Internal)or Plant IndoorAir (Internal)are subject to wetting due to condensationand thus are subject to loss of materialdue to selective leaching. Section 3.3 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 53 of 98 Table 3.3.2-16 Auxiliary Systems - Summary of Aging Management Evaluation- Gaseous Radwaste System Component Intended Material Environment Aging Effect Aging Management NUREG- Table 1 Item Notes Type Function Requiring Program 1801 Vol. Management 2 Item Compressor LBS, SS Cast Iron Plant Indoor Air Loss of material External Surfaces VII.1-8 3.3.1.58 B (Gray Cast (Ext) Monitoring Program Iron) (92.11.20) Compressor LBS, SS Cast Iron Plant Indoor Air Loss of material Inspection of Internal VII.G-23 3.3.1.71 B (Gray Cast (Int) Surfaces in Iron) Miscellaneous Piping and Ducting Components (B2.11.22) Compressor LBS, SS Cast Iron PlantIndoor Air Loss of material Selective Leaching of None None G, 6 (Gray Cast (Int) Materials(B2.1.17) Iron) Compressor LBS, SS Cast Iron Raw Water (Int) Loss of material Selective Leaching of VII. Cl-11 3.3.1.85 A (Gray Cast Materials(B2.1.17) Iron) Compressor LBS, SS Cast Iron Raw Water (Int) Loss of material Inspection of Internal VII.C1-19 3.3.1.76 E, 3 (Gray Cast Surfaces in Iron) Miscellaneous Piping and Ducting Components (B2.11.22) Valve LBS CopperAlloy Plant Indoor Air Loss of material Inspection of Internal VII. G-9 3.3.1.28 E, 5 (> 15% Zinc) (Int) Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22) Valve LBS, SS CopperAlloy Raw Water (Int) Loss of material Inspection of Internal VI1.C1-9 3.3.1.81 E, 3 (> 15% Zinc) Surfaces in Miscellaneous Piping and Ducting Components (B2. 1.22) Section 3.3 PG&E Letter DCL-11-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 54 of 98 Notes for Table 3.3.2-16: Plant Specific Notes: 5 NUREG-1801, Section XI. M24, CompressedAir Monitoring applies to monitoring of the piping and components associatedwith the air compressors and dryers. Air compressorand dryerpiping and components are not in scope for DCPP. In scope piping and components are associatedwith containmentpenetrationsand air/nitrogengas piping and components for backup operationof valves. Therefore NUREG-1801, Section XI.M24 is not considered applicableto DCPPand different aging managementprogramsare specified for the in scope piping and components. 6 Gray Cast Iron SSCs with surfaces exposed to Ventilation Atmosphere (Internal)or Plant Indoor Air (Internal)are subject to wetting due to condensation and thus are subject to loss of materialdue to selective leaching. Section 3.3 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 55 of 98 Table 3.3.2-17 Auxiliary Systems - Summary of Aging Management Evaluation- Liquid Radwaste System Component Intended Material Environment Aging Effect Aging Management NUREG- Table 1 Item Notes Type Function Requiring Program 1801 Vol. Management 2 Item Piping LBS Carbon Steel Raw Water (Int) Loss of material Inspection of Internal VII.C1-19 3.3.1.76 E, 8 Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22) Piping LBS Stainless Raw Water (Int) Loss of material Inspection of Internal VII.C1-15 3.3.1.79 E, 8 Steel Surfaces in Miscellaneous Piping and Ducting Components (B2. 1.22) Sample Cooler LBS, SIA Copper Alloy Raw Water (Int) Loss of material Inspection of Internal VII CI-9 3.3 1.81 E, 3 (> 15% Zinc) Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22) Strainer LBS Cast Iron Plant Indoor Air Loss of material External Surfaces VII.I-8 3.3.1.58 B (Gray Cast (Ext) Monitoring Program Iron) (82.1.20) Strainer LBS Cast Iron Raw Water (Int) Loss of material Selective Leaching of VII. Cl-11 3.3.1.85 A (Gray Cast Materials (B2. 1.17) Iron) Strainer LBS Cast Iron Raw Water (Int) Loss of material Inspection of Internal VII.C1-19 3.3.1.76 E, 2 (Gray Cast Surfaces in Iron) Miscellaneous Piping and Ducting Components (12.1.22) Trap LBS Cast Iron Plant Indoor Air Loss of material External Surfaces VII.I-8 3.3.1.58 B (Gray Cast (Ext) Monitoring Program Iron) (B2.1.20) Trap LBS Cast Iron Raw Water (Int) Loss of material Selective Leaching of VII.Cl-11 3.3. 1.85 A (Gray Cast Materials(B2.1.17) Iron) Section 3.3 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 56 of 98 Table 3.3.2-17 Auxiliary Systems - Summary of Aging Management Evaluation - Liquid Radwaste System Component Intended Material Environment Aging Effect Aging Management NUREG- Table 1 Item Notes Type Function Requiring Program 1801 Vol. Management 2 Item Trap LBS Cast Iron Raw Water (Int) Loss of material Inspection of Internal VII.C1-19 3.3.1.76 E, 2 (Gray Cast Surfaces in Iron) Miscellaneous Piping and Ducting Components (B2.11.22) Valve LBS, PB, Cast Iron Plant Indoor Air Loss of material External Surfaces VII.I-8 3.3.1.58 B SIA (Gray Cast (Ext) Monitoring Program Iron) (B2.1.20) Valve LBS, SIA Cast Iron Raw Water (Int) Loss of materal Selective Leaching of VII. C1-11 3.3.1.85 A (Gray Cast Materials(B2.1.17) Iron) Valve LBS, PB, Cast Iron Raw Water (Int) Loss of material Inspection of Internal VII.C1-19 3.3.1.76 E, 2 SIA (Gray Cast Surfaces in Iron) Miscellaneous Piping and Ducting Components (B2.1.22) Valve LBS Copper Alloy Demineralized Loss of material Water Chemistry VIII. F-15 3.4.1.15 A (> 15% Zinc) Water (Int) (B2.1.2) and One-Time Inspection (B2.1.16) Valve LBS Stainless Raw Water (Int) Loss of material Inspection of Internal VII. C1-15 3.3. 1.79 E, 8 Steel Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22) I Notes for Table 3.3.2-17: Plant Specific Notes: 8 Components are associatedwith the boric acid evaporatorsubsystem which is abandoned-in-place. Thus, aging of the components will be managed by the Inspection of InternalSurfaces in MiscellaneousPiping and Ducting Components aging managementprogram. Section 3.3 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 57 of 98 Table 3.3.2-18 Auxiliary Systems - Summary of Aging Management Evaluation- Miscellaneous Systems in scope ONLY for Criterion 10 CFR 54.4(a)(2) Component Intended Material Environment Aging Effect Aging Management NUREG- Table 1 Item Notes Type Function Requiring Program 1801 Vol. Management 2 Item Piping LBS Carbon Steel Secondary Water Loss of material Inspection of Internal VIII. C-7 3.4. 1.04 E, 7 (Int) Surfaces in MiscellaneousPiping and Ducting Components (B2. 1.22) Piping LBS Cast Iron Plant Indoor Air Loss of material External Surfaces VII.I-8 3.3.1.58 B (Gray Cast (Ext) Monitoring Program Iron) (B2.11.20) Piping LBS Cast Iron Plant Indoor Air Loss of material Inspection of Internal VII.G-23 3.3.1.71 B (Gray Cast (Int) Surfaces in Iron) Miscellaneous Piping and Ducting Components (B2.1.22) Piping LBS Cast Iron Plant Indoor Air Loss of material Selective Leaching of None None G, 6 (Gray Cast (Int) Materials(B2.1.17) Iron) Piping LBS Cast Iron Raw Water (Int) Loss of material Selective Leaching of VII.C1-11 3.3.1.85 A (Gray Cast Materials(B2.1.17) Iron) Piping LBS Cast Iron Raw Water (Int) Loss of material Inspection of Internal VI1.C1-19 3.3.1.76 E, 5 (Gray Cast Surfaces in Iron) Miscellaneous Piping and Ducting IComponents (B2.1.22) Section 3.3 PG&E Letter DCL-11-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 58 of 98 Table 3.3.2-18 Auxiliary Systems - Summary of Aging Management Evaluation- Miscellaneous Systems in scope ONLY for Criterion 10 CFR 54.4(a)(2) Component Intended Material Environment Aging Effect Aging Management NUREG- Table 1 Item Notes Type Function Requiring Program 1801 Vol. Management 2 Item Piping LBS Stainless Treated Borated Loss of material Inspection of Internal VILE1-17 3.3.1.91 E, 47 Steel Water (Int) Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22)Wate-Chemistry (92.1.2) and One Time InSPetionr PR9LiS StP4ee Trceated BorFated G~aeking WateFCemnistry VlLE 1-2-0 134,90 E,-4 Stee4 Wateriont) (12.1.2) and One Time _.n.p.ction (B2.1.16) PVPLas Gast-lken GlosedeGyGde-r....,:. A+.. i^- I,*/.,*\ Loas s of ma teri;al Glesod Cycle Cooling

                                                                                          *^AI4,r e,**, /0' 1 10)\

VWC.2-44 3.3.1.7 9 PUM Ca1st-ken Plant Indoor Air Loss of materil ExteRl SrfRAce VIW4 3.4i598 B Monitoring Program (B\...... __ _ _ _ Strainer LBS Cast Iron Closed Cycle Loss of material Selective Leaching of VII. C2-8 3.3. 1 85 A (Gray Cast Cooling Water (Int) Materials (B2. 1.17) Iron) Strainer LBS Cast Iron Closed Cycle Loss of material Closed-Cycle Cooling VII.C2-14 3.3.1.47 B (Gray Cast Cooling Water (Int) Water System (B2.1 .10) Iron) Strainer LBS Cast Iron Plant Indoor Air Loss of material External Surfaces VII.I-8 3.3.1.58 B (Gray Cast (Ext) Monitoring Program Iron) (B2.1.20) Valve Cast

                          ,       oeR    GIed' G*'le-               Loss of material      OlGoso6d Cycle C9ooing    VIIIG2 44    3.347           B
                                                       ~

I~~~~ ~ Geln Wae4#4 Sytexý *1te Valve LBS Gast eFeR Pat Indoo Air of material Eternal SurfacFs VWIP 3.-.-fl B kEA) Monitorn*g Program ___ __ __ _ ___ _ __ __ __ _ _ __ __ ___ __ __ ___ _ k& 24,20) _ _ __- __ ___ __ _ Section 3.3 PG&E Letter DCL-11-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 59 of 98 Table 3.3.2-18 Auxiliary Systems - Summary of Aging Management Evaluation- Miscellaneous Systems in scope ONLY for Criterion 10 CFR 54.4(a)(2) Component Intended Material Environment Aging Effect Aging Management NUREG- Table I Item Notes Type Function Requiring Program 1801 Vol. Management 2 Item Valve LBS Stainless Secondary Water Loss of material Inspection of Internal VIII.D1-4 3.4. 1.16 E, 7 Steel (Int) Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22) Valve LBS Stainless Treated Borated Loss of material Inspection of Internal VII.E1-17 3.3.1.91 E, 47 Steel Water (Int) Surfaces in Miscellaneous Piping and Ducting Components (B2.1. 22)ater-CheFmistry (62.1.2) and Gno Time Inspection Valve LB.S Stai$ ess- rated RBrted- G4aGk4Rg Water-GlCh V.E4-20 .. 1.90 E--4 Steel Water {l, (132.1.2) ad GRe Time __________________ __________________________________ Inspection (B324-4.6) Notes for Table 3.3.2-18: Plant Specific Notes: 6 Gray Cast Iron SSCs with surfaces exposed to Ventilation Atmosphere (Internal)or Plant Indoor Air (Internal)are subject to wetting due to condensationand thus are subject to loss of material due to selective leaching. 7 Components are associatedwith the boric acid evaporatorsubsystem which is abandoned-in-place. Thus, aging of the components will be managedby the Inspection of Internal Surfaces in Miscellaneous Pipingand Ducting Components aging managementprogram.

Enclosure 2 Section 3.3 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 60 of 98 Table 3.3.2-19 Auxiliary Systems - Summary of Aging Management Evaluation- Oily Water and Turbine Sump System Component Intended Material Environment Aging Effect Aging Management NUREG- Table 1 Item Notes Type Function Requiring Program 1801 Vol. Management 2 Item Piping PB Cast Iron Encased in None None VII.J-21 3.3.1.96 A (Gray Cast Concrete (Ext) Iron) Piping LBS Cast Iron Plant Indoor Air Loss of material External Surfaces VII.I-8 3.3.1.58 B (GrayCast (Ext) Monitoring Program Iron) (B2.1.20) Piping LBS, PB Cast Iron Plant Indoor Air Loss of material Inspection of Internal VII.G-23 3.3.1.71 B (Gray Cast (Int) Surfaces in Iron) Miscellaneous Piping and Ducting Components (B2.1.22) Piping LBS, PB Cast Iron Plant IndoorAir Loss of material Selective Leaching of None None G, 3 (Gray Cast (Int) Materials (B2. 1.17) Iron) Piping LBS, PB Cast Iron Raw Water (Int) Loss of material Selective Leaching of VII.C1-11 3.3.1.85 A (Gray Cast Materials(B2.1.17) Iron) Piping LBS, PB Cast Iron Raw Water (Int) Loss of material Inspection of Internal VII.C1-19 3.3.1.76 E, 2 (Gray Cast Surfaces in Iron) Miscellaneous Piping and Ducting Components (B2.11.22) Pump LBS Cast Iron Plant Indoor Air Loss of material External Surfaces VII.I-8 3.3.1.58 B (Gray Cast (Ext) Monitoring Program Iron) (B2.1.20) Pump LBS Cast Iron Raw Water (Int) Loss of material Selective Leaching of VII. Cl-11 3.3. 1.85 A (Gray Cast Materials (B2. 1.17) Iron) Section 3.3 PG&E Letter DCL-11-136 AGING MANAGEMENT OF AUXILIARY SYSTEMS Page 61 of 98 Table 3.3.2-19 Auxiliary Systems - Summary of Aging Management Evaluation- Oily Water and Turbine Sump System Component Intended Material Environment Aging Effect Aging Management NUREG- Table I Item Notes Type Function Requiring Program 1801 Vol. Management 2 Item Pump LBS Cast Iron Raw Water (Int) Loss of material Inspection of Internal VII.C1-19 3.3.1.76 E, 2 (Gray Cast Surfaces in Iron) Miscellaneous Piping and Ducting Components (12.1.22) 1 Notes for Table 3.3.2-19: Plant Specific Notes: 3 Gray Cast Iron SSCs with surfaces exposed to Ventilation Atmosphere (Internal)or Plant IndoorAir (Internal)are subject to wetting due to condensationand thus are subject to loss of material due to selective leaching. Section 3.4 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF STEAM AND Page 62 of 98 POWER CONVERSION SYSTEM 3.4.2.1.1 Turbine Steam Supply System Materials The materials of construction for the turbine steam supply system component types are:

          *Cast   Iron

Cast Iron (Gray Cast Iron)

Aging Management Programs The following aging management programs manage the aging effects for the turbine steam supply system component types:

Selective Leaching of Materials (B2.1.17)

Section 3.4 PG&E Letter DCL-11-136 AGING MANAGEMENT OF STEAM AND POWER CONVERSION SYSTEM Page 63 of 98 3.4.2.1.2 Auxiliary Steam System Materials The materials of construction for the auxiliary steam system component types are:

        -   Cact Iron Section 3.4 PG&E Letter DCL-1 1-136                               AGING MANAGEMENT OF STEAM AND POWER CONVERSION SYSTEM Page 64 of 98 3.4.2.1.4     Condensate System Materials The materials of construction for the condensate system component types are:

Cas t Iron
Cast Iron (Gray Cast Iron)

Aging Management Programs The following aging management programs manage the aging effects for the condensate system component types:

Selective Leaching of Materials (B2. 1.17)

Section 3.4 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF STEAM AND Page 65 of 98 POWER CONVERSION SYSTEM Table 3.4.2-1 Steam and Power Conversion System - Summary of Aging Management Evaluation- Turbine Steam Suppl, System Component Intended Material Environment Aging Effect Aging Management NUREG- Table 1 Item Notes Type Function Requiring Program 1801 Vol. Management 2 Item Valve LBS Cast Iron Plant Indoor Air Loss of material External Surfaces VIII.H-7 3.4.1.28 B (GrayCast (Ext) Monitoring Program Iron) (B2.1.20) Valve LBS Cast Iron Secondary Water Loss of material Selective Leaching of VIII.A-8 3.4.1.36 A (Gray Cast (Int) Materials(B2.1.17) Iron) Valve LBS Cast Iron Secondary Water Loss of material Water Chemistry VIII.D1-8 3.4.1.04 A (Gray Cast (Int) (B2.1.2) and One-Time Iron) Inspection (B2.1.16) Section 3.4 PG&E Letter DCL-11-136 AGING MANAGEMENT OF STEAM AND Page 66 of 98 POWER CONVERSION SYSTEM Table 3.4.2-2 Steam and Power Conversion System - Summary of Aging Management Evaluation - Auxiliary Steam System Component Intended Material Environment Aging Effect Aging Management NUREG- Table 1 Item Notes Type Function Requiring Program 1801 Vol. Management 2 Item Heat LBS, SIA, Carbon Steel Closed Cycle Loss of material Inspection of Internal VIII.G-5 3.4.1.24 BE, 8 Exchanger SS Cooling Water (Int) Surfaces in (Aux Steam Miscellaneous Piping Drain Rec Vent and Ducting Cond) Components (B2.1.22)CGesed-Cy*e Cooling Water System Heat LBS, SIA, Carbon Steel Secondary Water Loss of material Inspection of Internal VIII.B 1-11 3.4.1.04 E, 8 Exchanger SS (Int) Surfaces in (Aux Steam Miscellaneous Piping Drain Rec Vent and Ducting Cond) Components (B2. 1.22) Heati LBS.SLA- GarIbon Steel Steaondat) Loss of material Inspection of Intemal VIII.B1-1 3.4.1.47 E-,8 Ss Int)er- Surfaces in Miscellaneous Piping Drain Rec Vent and Ducfing (32,44a)Water-Ghemicstry (132.1.2) and Ono Time InsPection CGI1 om~ponents(2..2) Piping LBS Carbon Steel Secondary Water Loss of material Inspection of Internal VIII. BI-11 3.4.1.04 E, 8 (Int) Surfaces in Miscellaneous Piping and Ducting, __________ __ ____ ______ __ ____ ____ ___ ___________ Components (B2. 1.22) _ _ _ __ _____ _____ Section 3.4 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF STEAM AND Page 66 of 98 POWER CONVERSION SYSTEM Table 3.4.2-2 Steam and Power Conversion System - Summary of Aging Management Evaluation- Auxiliary Steam System Component Intended Material Environment Aging Effect Aging Management NUREG- Table 1 Item Notes Type Function Requiring Program 1801 Vol. Management 2 Item Heat LBS, SIA, Carbon Steel Closed Cycle Loss of material Inspection of Internal VIII.G-5 3.4.1.24 BE, 8 Exchanger SS Cooling Water (Int) Surfaces in (Aux Steam Miscellaneous Piping Drain Rec Vent and Ducting Cond) Components (B2.1.22)GIosed Heat LBS, SIA, Carbon Steel Secondary Water Loss of material Inspection of Internal VIII.B1-11 3.4.1.04 E, 8 Exchanger SS (Int) Surfaces in (Aux Steam Miscellaneous Piping Drain Rec Vent and Ducting Cond) Components (B2. 1.22) Heatn LBS13 Carb Steel Steam(ondrt e Loss of material Inspection of Internmal V.ILB13 1 3.4.1.37 E, 8 nha)e- Surfaes in (Auteasclanous Piping rFain Rcc Vent and Ducting oemponents Ghomistr; (62.1.2) and One Time !neopectiOn Piping LBS Carbon Steel Secondary Water Loss of material Inspection of Internal VIII. B 1-11 3.4.1.04 E, 8 (Int) Surfaces in Miscellaneous Piping and Ducting ____ ____ __ _ ____ ______ __ _ ____ ___ ___ ___________ Components (B2. 1.22) _ _ _ __ _____ _____ Section 3.4 PG&E Letter DCL-11-136 AGING MANAGEMENT OF STEAM AND Page 67 of 98 POWER CONVERSION SYSTEM Table 3.4.2-2 Steam and Power Conversion System - Summary of Aging Management Evaluation- Auxiliary Steam System Component Intended Material Environment Aging Effect Aging Management NUREG- Table 1 Item Notes Type Function Requiring Program 1801 Vol. Management 2 Item Piping LBS Stainless Secondary Water Loss of material Inspection of Internal VIII.B 1-4 3.4.1.16 E, 8 Steel (Int) Surfaces in MiscellaneousPiping and Ducting Components (B2.1.22) Pump LBS Cast Iron Plant Indoor Air Loss of material External Surfaces VIII.H-7 3.4.1.28 B (Gray Cast (Ext) Monitoring Program Iron) (B2.1.20) Pump LBS Cast Iron Raw Water (Int) Loss of material Selective Leaching of VIII. G-24 3.4.1.36 A (Gray Cast Materials (B2.1.17) Iron) Pump LBS Cast Iron Raw Water (Int) Loss of material Inspection of Internal VIII.G-36 3.4.1.08 E (Gray Cast Surfaces in Iron) Miscellaneous Piping and Ducting Components (B2.1.22) Strainer LBS Cast Iron Plant Indoor Air Loss of material External Surfaces VIII.H-7 3.4.1.28 B (Gray Cast (Ext) Monitoring Program Iron) (B2.1.20) Strainer LBS Cast Iron Steam (Int) Loss of material Water Chemistry VIII.B1-8 3.4.1.37 E, 6 (Gray Cast (B2.1.2) and One-Time Iron) Inspection (B2.1.16) Strainer LBS Cast Iron Steam (Int) Wall thinning Flow-Accelerated VIII.B1-9 3.4.1.29 B (Gray Cast Corrosion (B2.1.6) _____________ ~ Iron)________ Strainer LBS Carbon Steel Secondary Water Loss of material Inspection of Internal VIII.B1-11 3.4.1.04 E, 8 (Int) Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22) I Section 3.4 PG&E Letter DCL-11-136 AGING MANAGEMENT OF STEAM AND Page 68 of 98 POWER CONVERSION SYSTEM Table 3.4.2-2 Steam and Power Conversion System - Summary of Aging Management Evaluation- Auxiliary Steam System Component Intended Material Environment Aging Effect Aging Management NUREG- Table I Item Notes Type Function Requiring Program 1801 Vol. Management 2 Item Strainer LBS Carbon Steel Secondary Water Loss of material Inspection of Internal VIII.B 1-11 3.4.1.04 E, 8 (Int) Surfaces in Miscellaneous Piping and Ducting Components (B2. 1.22) Tank LBS Carbon Steel Secondary Water Loss of material Inspection of Internal VIII, G-41 3.4.1.06 E, 8 (Int) Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22) Trap LBS Carbon Steel Steam (Int) Loss of material Inspection of Internal VIII.B 1-8 3.4.1.37 E, 8 Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22) Valve LBS Carbon Steel Secondary Water Loss of material Inspection of Internal VIII. B 1-11 3.4.1.04 E, 8 (Int) Surfaces in Miscellaneous Piping and Ducting Components (B2.1.22) Valve Ga64,4rem Plant IndCoo Air Lose of Materi Et4ornal ,,urAr, VIII.,N7 34.1.28 a kE-xoMonitoring Program VaI~e LBaSs4-l ~ Raw Wate f-( 4~~ Lose of at eri al

ep e t o f I t r al VI. - 6 3 40 S"Gem..... (92.1.22)

Valve LBS Cast Iron Plant Indoor Air Loss of material External Surfaces VIII.H- 3.4. 1.28Nen BG (Gray Cast (Ext) Monitoring Program 7Nene e Iron) (B2.1.20) Section 3.4 PG&E Letter DCL-11-136 AGING MANAGEMENT OF STEAM AND Page 69 of 98 POWER CONVERSION SYSTEM Table 3.4.2-2 Steam and Power Conversion System - Summary of Aging Management Evaluation - Auxiliary Steam System Component Intended Material Environment Aging Effect Aging Management NUREG- Table 1 Item Notes Type Function Requiring Program 1801 Vol. Management 2 Item Valve LBS Cast Iron Raw Water (Int) Loss of material Selective Leaching of VIII. G-24 3.4. 1.36 A (Gray Cast Materials (B2. 1.17) Iron) Valve LBS Cast Iron Raw Water (Int) Loss of material Inspection of Internal VIII. G-36 3.4. 1.08 E (GrayCast Surfaces in Iron) MiscellaneousPiping and Ducting Components (B2.1.22) Valve LBS Cast Iron Secondary Water Loss of material Water Chemistry VIII.B 1-11 3.4.1.04 A (Gray Cast (Int) (B2.1.2) and One-Time Iron) Inspection (B2.1.16) Valve LBS CopperAlloy Raw Water (Int) Loss of material Inspection of Internal VIII.A-4 3.4.1.32 E, 5 (> 15% Zinc) Surfaces in MiscellaneousPiping and Ducting Components (B2.1.22) Valve LBS Copper Alloy Raw Water (Int) Loss of material Selective Leaching of VIII.A-6 3.4. 1.35 A (Aluminum > Materials(B2. 1.17) _8%) Notes for Table 3.4.2-2: Plant Specific Notes: 8 Components are associatedwith the boric acid evaporatorsubsystem which is abandoned-in-place. Thus, aging of the components will be managed by the Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components aging management program. Section 3.4 PG&E Letter DCL-1 1-136 AGING MANAGEMENT OF STEAM AND Page 70 of 98 POWER CONVERSION SYSTEM Table 3.4.2-4 Steam and Power Conversion System - Summary of Aging ManagementEvaluation - Condensate System Component Intended Material Environment Aging Effect Aging Management NUREG- Table 1 Item Notes Type Function Requiring Program 1801 Vol. Management 2 Item Valve LBS, PB Cast Iron Plant IndoorAir Loss of material External Surfaces VIII.H-7 3.4.1.28 B (Gray Cast (Ext) Monitoring Program Iron) (B2.11.20) Valve LBS, PB Cast Iron Secondary Water Loss of material Selective Leaching of VIII.E-23 3.4.1.36 A (Gray Cast (Int) Materials (B2.1.17) Iron) Valve LBS, PB Cast Iron Secondary Water Loss of material Water Chemistry VIII.E-34 3.4.1.04 A (Gray Cast (Int) (B2.1.2) and One-Time Iron) Inspection (B2.11.16) Valve PB Cast Iron Secondary Water Wall thinning Flow-Accelerated VIII.E-35 3.4.1.29 B (Gray Cast (Int) Corrosion (B2.1.6) Iron) Valve LBS Cast Iron Steam (Int) Loss of material Water Chemistry VIII.A-16 3.4.1.02 A (Gray Cast (B2.1.2) and One-Time Iron) Inspection (B2.1.16) Valve PB Ductile Iron Plant IndoorAir Loss of material External Surfaces VIII.H-7 3.4.1.28 B (Ext) Monitoring Program S(2.1.20) Valve PB Ductile Iron Secondary Water Loss of material Water Chemistry VIII.E-34 3.4.1.04 A (Int) (B2.1.2) and One-Time Inspection (B2.1.16) Section 3.5 PG&E Letter DCL-11-136 AGING MANAGEMENT OF CONTAINMENTS, Page 71 of 98 STRUCTURES AND COMPONENT SUPPORTS Table 3.5.2-1 Containments, Structures, and Component Supports - Summary of Aging Management Evaluation - Containment Buiildinai Component Intended Material Environment Aging Effect Aging Management NUREG- Table 1 Item Notes Type Function Requiring Program 1801 Vol. Management 2 Item Hatch SH, SS Stainless Plant IndoorAir None None VII.J-15 3.3.1.94 C Steel (Structural) (Ext) Structural Steel MB, SS Carbon Steel Plant Indoor Air Loss of material Structures Monitoring III.A4-5 3.5.1.25 A (Structural) (Ext) Program (B2.1.32) Section 4 PG&E Letter DCL-1 1-136 TIME-LIMITED AGING ANALYSES Page 72 of 98 4.2.1 Neutron Fluence Values Summary Description Loss of fracture toughness is an aging effect caused by the neutron embrittlement aging mechanism that results from prolonged exposure to neutron radiation. This process results in increased tensile strength and hardness of the material with reduced toughness. The rate of neutron exposure is defined as neutron flux, and the cumulative degree of exposure over time is defined as neutron fluence. As neutron embrittlement progresses, the toughness/temperature curve shifts down (lower fracture toughness as indicated by Charpy upper-shelf energy or Cv USE), and the curve shifts to the right (brittle/ductile transition temperature increases). Neutron fluence projections are made in order to estimate the effect on these reactor vessel material properties (Section 4.2.2 and Section 4.2.3), and to determine if additional reactor vessel materials will be exposed to fluence greater than 1 x 1017 n/cm 2 (E>1.0 MeV) as a result of license renewal (extended beltline). Analysis Unit 1 The last capsule withdrawn and tested from Unit 1 was Capsule V at the end-of-cycle (EOC) 11. At that point, Unit 1 had operated for 14.27 EFPY. This capsule had a lead factor of 2.26 resulting in an exposure equivalent to 32.25 EFPY of operation. The results were documented in WCAP-15958 [Reference 2]. This exposure is less than that expected at EOLE. In PG&E Letter DCL-08-021, PG&E requested a change to the withdrawal date of Unit 1 Capsule B from 20.7 EFPY to 21.9 EFPY in order to capture enough fluence data for EOLE. The change was approved by the NRC in a Safety Evaluation dated September 24, 2008, Diablo Canyon Nuclear Power Plant, Unit No. I - Approval of Proposed Reactor Vessel Material Surveillance Capsule Withdrawal Schedule (TAC No. MD8371) [Reference 2]. During the scheduled Unit 1 Sixteenth Refueling Outage (1R16), refueling personnel were not able to remove the Capsule B access plug on the reactor core barrel flange. In PG&E Letter DCL-10-141, dated October 25, 2010, PG&E requested a change to the withdrawal date of Unit 1 Capsule B from 21.9 EFPY to 23.2 EFPY. The change was approved by the NRC in a Safety Evaluation dated October 29, 2010, Diablo Canyon Nuclear Power Plant, Unit No. 1 - Approval of Proposed Reactor Vessel Material Surveillance Program Withdrawal Schedule (TAC No. ME4924) [Reference 38]. Unit 2 The last remaining capsule withdrawn and tested from Unit 2 was Capsule V at EOC 9. At that point, Unit 2 had operated for 11.49 EFPY. This capsule had a lead factor of 4.58 resulting in an exposure equivalent to 52.62 EFPY of operation. This exposure is Section 4 PG&E Letter DCL-1 1-136 TIME-LIMITED AGING ANALYSES Page 73 of 98 comparable to the predicted EOLE exposure of 54 EFPY, i.e., within the 20 percent limit specified as the acceptance criteria in Regulatory Guide 1.190. The results were documented in WCAP-1 5423 [Reference 3]. Both Units Based on the guidance specified in Regulatory Guide 1.190, a neutron fluence assessment of the beltline and extended beltline regions was performed Fesults Of he-Capsu!e V analyses provided by Westinghouse in WCAP45958 17299-NP [Reference 240], for Units 1 and 2, through EOLE.Cycles 1-11 and \W"AP 15782 [RefeRc- "e 17], for Unit 2 CyleS 11-0,, t The peak calculated fast neutron fluence values at the pressure vessel clad/base metal interface inner surface of the DCPP reactor vessels are shown in Table 4.2-1 and Table 4.2-2 for Units 1 and 2, respectively. These fluence data tabulations include fuel cycle specific power distributionsexpoewes-through the end of Cycle 4-1-16 for Units I and 2, (Unit 1) and Gy'le 10 (Un .- 2) as well as fluence projections at several intervals out to 54 EFPY. The fluen"e values were projected Us*ig ENO"F8n B/VI cro66 se**ons, and the Capsule V analyses meet the requirements of Regulatory Guide :14100, Calculational and Dos6imetr MethodsI for De term=.ining PrFeSSUr% V.__~esIsAl eutron Flu4ence. The calculations account for a Unit 1 core power uprate from 3338 MWt to 3411 MWt at the onset of Cycle 11. Fluence projections beyond the end of Cycle 11-6 on Units 1 and GyG*.1.. GA. .Unit 2 are based on the assumption that the spatial core power distributions are defined by the average of Unit**--Cycles 4-1413-15 for Units 1 and 2.and Unit 2-Cycles 5 10. Power distributions for Cyclero 1 4 on both Units are not incl!uded sinc they are not representative of the ve.' low leakage cre loading patterns now being used*. For license renewal, Westinghouse performed additional calculations to define which materials in the DCPP pressure vessels, other than beltline materials, are projected to exceed the threshold neutron fluence of lx1017 n/cm 2 at 54 EFPY (extended beltline materials). The results of these calculations are documented in WCAP-17299-NP [Reference 40], for Units I and 2, through EOLE.LTR REA 09 90, Neutron F'-en-e Emvaluation for the Diable Canyon Units I and 2 ReactOr P-ressure Vessel Extended Bol*t-mo Mate^÷ril [ReferenGe 37]. For both units, although the nozzle shell course and the associatednozzle shell to intermediateshell weld are projected to exceed the lx1017 n/cm 2 threshold,the nozzles themselves as well as the nozzle to nozzle shell welds remain below the lx1017 n/cm2 threshold through 54 EFPY. Likewise, the lower shell to lower head weld remains below lxI107 n/cm2 through 54 EFPY for both units. The extended beltiIne material for both Units :neudes the upper shell plates, associated longitudinal welds, and the upper shell to intermediate Shell GiFcUmnferentia! weld Table 4.2-3 shows the EOLE fluence values for all beltline and extended beltline materials for both Units 1 and 2. As discussed in Section B2.1.15, both units currently use ex-vessel monitoring dosimetry. Section 4 PG&E Letter DCL-11-136 TIME-LIMITED AGING ANALYSES Page 74 of 98 Disposition: Revision, 10 CFR 54.21(c)(1)(ii); and Aging Management, 10 CFR 54.21(c)(1)(iii) Revision The fluence projections were revised to quantify expected fluence at the end of the period of extended operation in accordance with 10 CFR 54.21 (c)(1)(ii). Aging Management Neutron fluence will be monitored and its effects managed for the period of extended operation by the DCPP Reactor Vessel Surveillance program, which is summarized in Section B2.1.15. The validity of these parameters and the analyses that depend upon them will therefore be managed to the end of the period of extended operation in accordance with 10 CFR 54.21 (c)(1)(iii). Section 4 PG&E Letter DCL-11-136 TIME-LIMITED AGING ANALYSES Page 75 of 98 Table 4.2-1 Unit 1 Ma ximum CalculatedFluence (E>1.0 Me V) Cumulative Neutron Fluence (E>1.0 MeV) Irradiation [n/cm 2] Cycle Time (EFPY) 00 150 300 450 4416 14.27-21.77 21-- 3.22 .52- 5.08 439 6.31 6.07- 8.63 E+18 E+18 E+18 E+18 Rf-ejeeGte6.0 2.44 4 3.91 E+19 486:+18 6.68- E+! RfojeGti _ 2400 .81 E+1-8 5-.1-.48 7 F2-E+14 9.62-E--48 Projection 32.007.77.26 9.39-9.05 1261.23 E+18 E+18 E+18 E+19 P4QfGt4Gfl_4070 E+918E9.61 E+1-8 1.1 .7E+*1- 1.65 E+49 74W 6.85 14.5- 1.07 449- 1.33 -984 1.80 E+18 E+19 E+19 E+19 o7-94-7,68 4-.29-1.19 1,56-1.49 2,06-2.02 E+18 E+19 E+19 E+19 Table 4.2-2 Unit 2 Maximum CalculatedFluence (E>1.0 MeV) Cumulative Neutron Fluence (E>1.0 MeV) Irradiation [n/cm 2] Cycle Time (EFPY) 00 150 300 450 232-65.24 4r93 7.91 4v92 7.98 5.-7-9 9.42 E+18 E+18 E+18 E+18 RGOjeGtiea 1600 4.01-F*+8 6.04- F=1 6.03 E+!8 7.11 E+18 PvQJvGP 24700 5 93F-*4 8.89-F*+1 8.90-E*18 4.05 E+-19 7,867.51 4-48 1.13 -4841.14 47391.34 E+18 E+19 E+19 E+19

    -fG*OGtie     40.00        @-7g-E--+-18    14-6-F+9       1!         4      .73E+19 4-4-71.11      1-7-51.67       4-.75 1.69     2706.1.96 E+19            E+19           E+19            E+19 1421.24        4-7W6 1.87      4:-.6 1.89     2,322.19 E+19            E+19           E+19            E+19 Section 4 PG&E Letter DCL-11-136                                      TIME-LIMITED AGING ANALYSES Page 76 of 98 Table 4.2-3 Units I and 2 CalculatedFEuenc e (E>I.0 MeV) Values at EOLE (54 EFPY)

Unit 1 Unit 2 Material Fluence Material Fluence [n/cM2] [n/cm 2 ] Upper Shell Plate(a) Upper Shell Plate(a) B4105-1 2-.N3.41 E+17 B5453-1 5-2-06.77 E+117 B4105-2 2-63.41 E+17 B5453-3 5-.206.77 E+17 B4105-3 2-863.41 E+17 B5011-1R &2-06.77 E+17 Intermediate Shell Plate Intermediate Shell Plate B4106-1 2-062.02 E+19 B5454-1 2-22.25 E+1 9 B4106-2 2,062.02 E+ 19 B5454-2 24212.25 E+ 19 B4106-3 2-062.02 E+19 B5454-3 2-,22.25 E+1 9 Lower Shell Plate Lower Shell Plate B4107-1 2-042.01 E+19 B5455-1 2-402.22 E+1 9 B4107-2 2,042.01 E+19 B5455-2 2-302.22 E+1 9 B4107-3 2,042.01 E+19 B5455-3 24302.22 E+1 9 Upper Shell Long. Welds(a) Upper Shell Long. Welds(a) 1-442 A 2462.45 E+17 1-201 A 4-06.33 E+17 1-442 B 4-.241.49 E+17 1-201 B 4.-26.29 E+17 1-442 C 2-573.06 E+17 1-201 C 3-Q35.14 E+17 Upper Shell to Intermed. Shell Weld(a) Upper Shell to Intermed. Shell Weld(a) 8-442 2-863.41 E+17 8-201 &.2-06.77 E+17 Intermed. Shell Long. Welds Intermed. Shell Long. Welds 2-442 A 4-4561.49 E+19 2-201 A 4,321.24 E+19 2-442 B 4-61.49 E+19 2-201 B 4-,51.53 E+19 2-442 C 746 7.68 E+18 2-201 C 4461.30 E+19 Intermed. Shell to Lower Shell Weld Intermed. Shell to Lower Shell Weld 9-442 2,042.01 E+19 9-201 2-402.22 E+19 Section 4 PG&E Letter DCL-11-136 TIME-LIMITED AGING ANALYSES Page 77 of 98 Table 4.2-3 Units I and 2 CalculatedFluence (E>1.0 Me V) Values at EOLE (54 EFPY) Unit I Unit 2 Material Fluence Material Fluence [n/cm 2] [n/cm2] Lower Shell Long. Welds Lower Shell Long, Welds 3-442 A :21.19 E+19 3-201 A 4-,31.28 E+19 3-442 B 4-281.19 E+19 3-201 B 4,341.23 E+19 3-442 C 2-,042.01 E+19 3-201 C 4-.-1.51 E+19 Section 4 PG&E Letter DCL-1 1-136 TIME-LIMITED AGING ANALYSES Page 78 of 98 4.2.2 Pressurized Thermal Shock Summary Description 10 CFR 50.61(b)(1) provides requirements for protection against pressurized thermal shock (PTS) events for pressurized water reactors. Licensees are required to perform an updated assessment of the projected values of reference temperature whenever a significant change occurs in projected values of the adjusted reference temperature for pressurized thermal shock (RTPTS), or upon request for a change in the expiration date for the operation of the facility. Irradiation by high energy neutrons raises the value of RTNDT for the reactor vessel. The initial RTNDT is determined through testing of unirradiated material specimens. The shift in reference temperature, ARTNDT, is the difference in the 30 ft-lb index temperatures from the average Charpy curves measured before and after irradiation. Regulatory Guide 1.99 defines the calculation methods for ARTNDT (and end-of-life Cv USE). RTPTS is defined as the RTNDT value evaluated at the end of life fluence at the clad/base metal interface for each of the vessel beltline materials. 10 CFR 50.61(c) provides two methods for determining RTPTS. These methods are also described as Positions 1 and 2 in Regulatory Guide 1.99. Position 1 applies for material that does not have credible surveillance data available and Position 2 is used for material that does have two or more credible surveillance data sets available. The criteria for credible data are also provided in Regulatory'Guide 1.99. The adjusted reference temperatures are calculated for both Positions 1 and 2 by following the guidance in Regulatory Guide 1.99 (Sections 1.1 and 2.1, respectively), using the copper and nickel content of DCPP reactor vessel materials, and the EOLE fluence projections. 10 CFR 50.61(b)(2) establishes screening criteria for RTPTs as 270'F for plates, forgings, and axial welds and 300°F for circumferential welds. If the RTPTs does not exceed the PTS screening criteria, then only the reactor pressure vessel is relied on to demonstrate compliance with 10 CFR 50.61, the PTS rule. Analysis PG&E's original response to the issuance of the PTS rule, 10 CFR 50.61, indicated that the projected RTPTS for both units do not exceed the PTS screening criteria, 270'F, and 300'F, based on 32 EFPY. Since Cycle 1, several actions taken by PG&E have resulted in changes to input parameters used to calculate RTPTS. Fluence projections for both units were reduced following Cycle 1 as a result of fuel management changes to lower-leakage core designs. Also, copper and nickel content for the Unit 1 beltline longitudinal welds have been updated to reflect chemical analyses performed for the evaluation of surveillance Section 4 PG&E Letter DCL-11-136 TIME-LIMITED AGING ANALYSES Page 79 of 98 capsules. 10 CFR 50.61 was revised in June 1991, which changed the method used to calculate RTPTS. The most recent coupon examination results for both units show that the increase in RTNDT in plate and weld materials are bounded by that predicted by Regulatory Guide 1.99 Revision 2 for Units 1 and 2. The results demonstrate that the DCPP reactor vessel material ages consistent with Regulatory Guide 1.99 predictions, and provide a conservative means to satisfy the requirement of 10 CFR 50.61; thus providing assurance of the reactor vessel integrity. Unit I The data from the most recently withdrawn surveillance capsule, Capsule V, were not deemed credible [Reference 2,- Appendix D]. Using Regulatory Guide 1.99 PositieFi4A. metheds, RTPTS values were generated for beltline and extended beltline region materials of the Unit 1 reactor vessel for EOLE fluence values. The RTPTS values for the Unit 1 materials are provided in Table 4.2-4. The projected RTPTS values for EOLE dk4-Pet-meet the 10 CFR 50.61 screening criteria in all cases. The calculation [Reference 1-439] indicates the limiting weld material for Unit 1 is lower shell longitudinal (axial) weld 3-442C with a projected EOLE RTPTS value of 289"43°F, using Position 2.1. LeweF-ru.hpfl Inn I ~ V yq *fllflný lc 2~ 44:2 ii fk* OT I -f gLIn~ ~III ^r~p; iinfN rego-i I 1 43 E vPY. All other m.ateria.li-, m.eet the 10 C-Fn R 5-0.6-1 creenn' criteria. The limiting plate material on Unit 1 is the lower shell plate B4107-1 with a projected EOLE RTPTS value of 156.2-F, using Position 1.1 [Reference 39]. The Unit 1 reactor Vessel fluencce will continuc to be moneitorcd in accordanGe wt 10 C.FR 50.61 as part of the DCPP21 Reactor Versel Sur.'eillance program (132.1.15) to ensure that the reactor Vessel mnaterial does Rot violate the PTS criteria. In 2000, the NRC approved the Fina! Rule 10 CFR 50.61 a, Afternate FrFactUr Toughness Roguiromante for-Pr-etection Against Pr-essurzed Thermal ShGck Eivents toughnes

   *l~ IE   ~I rqIremeants based on V%*Vl    1**    V~       WI    vV~ I i    ~ updated analysis mnethods for protection against PTS tI  1Ili l     i-    * -  * -     -  -! I             I--- II~
                                                                                                                       -II       1I events for PWVR pressure vessels. it is anticipated that DCPP Unit 1 will m~eet these revised requirements_ through EOLE.

PG&FE will impIWment the revised PTS (10 CER 50.61 a) rule at least three years prior to exc~eeding the PTS screening criFterion Of 10 CFR 50.61. in the event that the poiin of 10Q C-F=R 50.61 a cannot be mnet, PG&E= wil! implement alternate4)options, such~ _As flux reduction, as provided in; 10 CFR 50.61. The extended beltline materials were also evaluated. The results (Table 4.2-4) confirm the materials will not become limiting.

Enclosure 2 Section 4 PG&E Letter DCL-1 1-136 TIME-LIMITED AGING ANALYSES Page 80 of 98 Unit 2 The data from the most recently withdrawn surveillance capsule, Capsule V, was deemed credible [Reference 3, Appendix D]. RTPTS values were generated for beltline and extended beltline region materials of the Unit 2 reactor vessel for fluence values at EOLE. The RTPTS values for the Unit 2 materials are provided in Table 4.2-5. The projected RTPTS values for EOLE meet the 10 CFR 50.61 screening criteria. The I calculation [Reference 4439] indicates that the limiting weld material for Unit 2 is intermediate shell longitudinal (axial) weld 2-201 B with a projected EOLE RTPTS value of 244.2207'F using Regulatory Guide 1.99 Position 4-2.1. The limiting plate material on Unit 2 is the intermediate shell plate B5454-2 with a projected EOLE RTPTS value of I 223-.20 F. The extended beltline materials were also evaluated. The results (Table 4.2-5) confirm the materials will not become limiting. Disposition: Revision, 10 CFR 54.21(c)(1)(ii); and Aging Manag.m. nt, 10 CFR 54.21 (G)(1)(iiii) Unit I - Aging MapnagemeniRevision The RTpTs was projected to the end of the period of extended operation in accordance with 10 CFR 54.21(c)(1)(ii). RTpTs remains within acceptable values for the period of extended operation.The Unit 1 reactor vessel fluence will continue to be monitored as pa~t of the DCPP Reactor Vessel Surveillance program (B2. 1.15) and its effectS will be adequately managed to the end of the period of extended operation in a*cordance with 10 CFR 54.21 (G)(4)(4ii. Unit 2 - Revision The RTPTS was projected to the end of the period of extended operation in accordance with 10 CFR 54.21 (c)(1)(ii). RTPTs remains within acceptable values for the period of extended operation. Section 4 PG&E Letter DCL-1 1-136 TIME-LIMITED AGING ANALYSES Page 81 of 98 TRhk~ 4 2-4 flCPP unit I ~ PT,,,-~, ~f !54 FFP ~') Material Description SSeurG Chemical Extend eR.G Composition Chemistry Initial EOLE ART Screening ed 0 1.2 u N Fa r Fluence Fluence RTNDT Margin RTpTs Criteria ed 1.99, Factors RTN-T 1019 nlcm' Factor -F F F Beltline Location Heat No. Type Positl Wt% Wt% E>1.0 MeV -F Region on Upper Shell Plate C2624 A 533B 1.1Ref 0.120 0.56 82.2 28 0028960.03 0.21360. 4-7,619. 3 39, 8"387 <270 Yes B4105-1 --44 1 41 2365 4 2 1 Upper Shell Plate C2624-2 A533B .lRef 0.120 0.57 82.4 9 0-2860.03 024360. 47-619. 3"39. 6"68 <270 Yes B4105-2 C642 A53 .-144 1 41 2365 5 2 Upper Shell Plate C2608- A 533B 11Ref 0 0.02980.03 0,2:3160. 24-023, 2,091. 4-,978 <270 Yes B4105-3 2B A.-430,140 0.56 98.2 14 41 2365 2 2 Intermediate Shell 1,1PRef ,1. 45332 -t02-1 Plate B4106-1 2884-1 A 533B -4 125 0.53 85.3 -10 282.02 1917 01.7 34 1264 <270 No Intermediate Shell C2854-2 A 533B 1.lRef 0.12 0.50 81 -3 2-%2.02 4 1961. 09696, 34 42791 Plate B4106-2 5270 No

                                             -44                                              1                  1917        5                 28 Intermediate Shell    C2793-1      A 533B   1.1ef       0.086     0.476       55.2       30       2-062.02      i.49681.   "'465. 48.1     1444.-       270        No Plate B4106-3                              -.44             1                                                  1917        8
  -- Using non-credible        C2793-1      A 533B     2.1        0.086    0.476       37.4       30          2.02        1.1917    44.6       48.1      123       !5270        No surveillance data Lower Shell Plate     C3121-1      A533B    1.1Ref       0.13      0.56       89.8       15       2-042,01     41.9431. 407*21        34      1562       <270         No B4107-1 Loer Shell Plate             1.--14      1,lRe4                                                                1904 4t-40431. 06.9 98.297.       3 C3131-2      A 533B                0.12      0.56       82.2       20       2,042,01        19 B4107-2                                 -.--

44 1904 4 899 34 1524 *5270 No Lower Shell Plate 03131-1 A 533B 1.41 0.12 0.52 81.4 -22 2,042.01 97496.

                                                                                                                          -40421. 34      1094       !5270        No B4107-3         C3131-4      A4                    0           .24                                          1904       9 Upper Shell Long.      27204/       Linde   1.1,o4      0.190     0.970      215.7      -20      0024-60.02    0-A4040.         42 3842.      &-64        S270        Yes Weld 1-442 A        12008        1092     -44                                                      45          1948                  0 Upper Shell Long. 27204/        Linde   1.Ref       0.190     0.970                          001270.01     0470. 2-7430,    27-830. 3"42        !270        Yes Weld 1-442 B        12008        1092     ,-44                                                     49          1428       8          8 Upper Shell Long. 27204 /       Linde   1.e         0190      0.970      215.7      -20      002570.03     00040. 4 47.             7.

Weld 1-442 C 12008 1092 -.1-4 1 06 2222 9 9 Upper Shell to Intermediate Shell 13253 Linde 1.1Re" 2 030 0-2860,03 021360. 42,46. -257 40448 300 Yes Circumferential 1092 -44 05 .7 197.5 -56 41 2365 7 8 Weld 8-442 1 1 1 1 1 1 Section 4 PG&E Letter DCL-11-136 TIME-LIMITED AGING ANALYSES Page 82 of 98 Table 4.2-4 DCPPUnit I Vessel RTPTs at 54 EFPY(") Material Description eR.G eR.G Chemical Composition Ceit Chemistry Initial Exted ARET Screening Extend Rev.299 .9,Fcos FactorsF RNT RTNDTOF Fluence 1019 nlcm2 Fluence Factor RTNVOT F Margin F RTp~s OF Crtra OF ed Beltline Location Heat No. Type Posltl Wt% Wt% E>1.0 MeV OF Region on Intermediate Shell Linde 11Ref 4-12291, 2M 7 264 2 Long. Welds 2- 27204 1092 44 0.203 1.018 226.8 -56 4 1.49 1104 51.8 65.5 61 5270 No 442A, B IIII_

 -. Using credible     27204    Linde      2.1     0.203     1.018     214.1     -56          1.49     1.1104       237.7     44.0       226        <270        No surveillancedata                1092 Intermediate Long. WeldShell   27204     Linde   1 1Ref                                                          9259*e0     -10.02-   655*4-*270                        No 2-442C                    1092      -44      0.203    1.018      226.8    -56      0,7W.768       9259         10.0     655         20!-20
-. Using credible      27204               2.1     0.203    1.018      214.1     -56         0.768     0.9259       198.2     44.0       186        <270        No surveillance data               1092             _                 I                   III Lower Shell Long.      27204     Linde   1.1Ref     0.203    1.018      226.8    -56        4--1.19    446W71.      24242      65.5     2-.-92      <270         No Welds 3-442A, B                 1092     -44                                                            0485         37.8                47
-- Using credible               Linde      2.1     0.203    1.018      214.1     -56          1.19     1.0485       224.5     44.0       213        <-270       No surveillance data     27204     1092 Lower Shell Long.                Linde   1.lRef                                                        41-4941. 270-92              2-02 Weld 3-442C        2    4    1092     4         0.203    1.018      226.8    -56        2,042.01     1904         7050                80
-'Using credible                Linde      2.1     0,203    1.018      214.1     -56          2,01     1.1904       254.9     44.0       243        -270        No surveillance data      27204    1092 Intermediate to Lower Shell                 Linde   1.1PRef                                                               140-LwrSel       21935     Lid      .1Rf      0.183    0.704      172.2    -56        2-"42.01   1 49421. 20fi7230N 6.5       25 Circumferential                1092      .-4-4                                                         1904         05.0     65.5     215,2       -300         No Weld 9-442 Notes:

(i) Reference 39, WCAP-1 7315-NP

Enclosure 2 Section 4 PG&E Letter DCL-11-136 TIME-LIMITED AGING ANALYSES Page 83 of 98 Table 4.2-5 DCPPUnit 2 Vessel RTPTs at 54 EFPY(') R.G Chemical, Etn Material Description 1.99, Ccreening Composition Chemistry ARG Extend Initial Fluence 2 Fuenc RTT Margin 0 RTPT Screening Rev.2 Factors RTNDT 1019n/cm Factor Mg F Criteria ed Ni OF OF E >1.0MeV Factor OF OF BRegion Location Heat Type Position Cu No. Tye o.Fae Wt% Wt% Rgo Upper Shell C5162-1 A 533B 1.1Ref- 0.110 0.600 74 28 045N0.06 04-W0 2-2-425 2-22425 '72-2279 <270 Yes Plate B5453-1 4-4 77 3434 4 4 Upper Shell 05162-2 A 533B 1.ef 0.110 0.600 74 5 0.06200.06 0.2900. 2-2-425. 404642. 67,773 <270 Yes Plate B5453-3 -44 77 3434 4 4 Upper Shell C417el-, 00107200.06 02099-0. 2-425. 40742. §348 5270 Yes Plate B5011-1R 4377-1 A 533 44 0110 0.650 748 077 3434 7 6 Intermediate ef. 1 22741. 42401 *00 Shell Plate 5161-1 A 533B 0.140 0.650 086101.3 52 2-422.25 2196 23.5 10 B5454-1 Using credible C5161-1 A 533B 2.1 0.140 0.650 105.7 52 2.25 1.2196 128.9 17 198 <270 No surveillance data Intermediate 1.1 12 2222 Shell Plate C5168-2 A 533B 0.14 0.59 99.6 67 2,322.25 219 21 34 222 <270 No B5454-2 44 2196 21.5 22 Intermediate 1414ef- 42741. 43661 Shell Plate C5161-2 A533B 4-4 0.15 0.62 110.5 33 22,2.225 2196 34.8 34 202-6 *270 No B5454-3 ___2196_34.8 Lower Shell 05175-1 A 5338 R1 0.14 0.56 98.2 -15 2,302.22 122f521. 420.31 34 -13*1 <270 No Plate B5455-1 4-4 2161 19.4 38 Lower Shell C5175-2 A 533B 16Re4- 0.14 0.56 98.2 0 2,302.22 4,2621 34 <270 No Plate B5455-2 44 1 1 2161 19.4 53 Lower Shell 1CARef- 0.1 0.62 6572 15 2,W2.22 34 128-9 *270 No Plate B5455-3 05176-1 A 533B 062 2161 3 Upper Shell 21935/ Linde 1. 1Re,00 15 0 0.06 0.29690. 62470 5 Long. Weld 12008 1092 44 0.220 0.870 211.2 -50 33 3317 1 5270 Yes 1-201 A 33I33t7__ I-.Using credible Usincedata 21935 1 / Linde 1092 2.1 0.220 0.870 204.6 -50 surveillancedata 120081 1092 0.0633 0.3317 67.9 28 46 5270 Yes Upper Shell 21935/ Linde 1.1Ref4- 04820.06 0.287-00. 6§069. Long. Weld 12008 1092 0.220 0.870 211.2 -50 2956.0 6"76 !270 Yes 1-201 B 12008 I9 I_ I 9 3306_8

Enclosure 2 Section 4 PG&E Letter DCL-1 1-136 TIME-LIMITED AGING ANALYSES Page 84 of 98 Table 4.2-5 DCPPUnit 2 Vessel R.G RTpTs at 54 EFPY(i) Chemical Material Description 1.99, Composition Chemistry Initial Fluence AgG Screening Screening Extend eRTd Rev.2 Factors RTNDT 10W9 nlcm2 Fluence RTNDT Margin RTpTs Criteria ed HeNo. Position Cu Ni °F OF E >1.0MeV Factor FF OF OF Beltline Location Heat Type Saa C t F Region

  -. Using credible     21935 /     Linde suveillance data       12008       1092       2.1      0.220      0.870        204.6    -50       0.0629      0.3306    67,6     28        46     <270         Yes Upper Shell        21935/      Linde    1.IRef-                                             0-0300.05    0-.2-40. 54462.

Long. Weld 12008 1092 4- 0.220 0.870 211.2 5014 2971 7 64456 849,69 *5270 Yes 1-201 C

  -~Using credible      219351/     Linde       21       020        080          246       -0       001           .91     6.         8       3       57           e surveillance data       12008      1092 Upper Shell to Intermediate       21935       Linde    1.1Re     .17                                       0 036200.06  02900. 55.--4265.        sa469     <300        Yes Shell          21935       1092        4-4      0.22077                                      14         3434        1      5               5300        Y
  --,Using  credible Circumferential      21935 /     Linde surveillance Weld_8-201data      12008      1092    ____

Intermediate 21935/I Linde 1 1~ef- 4-07741. 227-52 23222 *70N Shell Long. 12008 1092 44 0.22 0.87 211.2 -50 14-21.24 0599 23.9 56 30 20N Weld 2-201 A Usillacedata 1208 1 2.1 0.22 0.87 204.6 -50 1.24 1.0599 216. 28 195 !270 NO Intermediate 21935/ Linde 1.lRe- 1-284I1. 225922 24462 -270 No Shell Long. 12008 1092 4-4 0.22 0.87 211.2 -50 4491.53 1176 3610 56 42 Weld 2-201 B I I

 -. ULsing credible
 -MUsing    credible    21935 219351//    Linde Linde       21        02          .7         246      -0         15          A7        2.        8      27      :20N surveillance data       12008 Isurveillance    data     12008 110921 1092       2.          .2        08            0.      5          .3          .16    287       2         0       20N Intermediate        21935/      Linde    1.                                                               448341.

1 22842 22442 Shell Long. 0219322 0.87 211.2 -50 4-61.30 073 2 56 33 <270 No Weld 2-201A 12008 1092 44 0730 26.6 33

   -Usincedata           1208     1            2.1        0.22       0.87        204.6    -50        1.30       1.0730   219.5     28       198     <270         No Lower Shell                    Linde    1. lRef-               01.                                                 42        6       4454      *270         No Long. Weld 3-       33A277        124        4-4      0.258      0.16          26.3    -56      1.         0687     35.0     56       44 201 A                                            ______ I____         __________

I________

 -Using     credible   33A277       Linde      2.1       0.258      0.165        115.9    -56        1.28       1.0687   123.9    44.0      112     *270         No surveillance data     12008         124  1           1__11_

Section 4 PG&E Letter DCL-11-136 TIME-LIMITED AGING ANALYSES Page 85 of 98 Table 4.2-5 DCPP Unit 2 Vessel RTPTs at 54 EFPY') R.G Chemical Material Description 1.99, Composition Chemistry Initial Fluence ART-pT Screening Extend Rev.2 Factors RTIDT 10'9n/cm2 Fluence RTNDT Margin RTpTS Criteria ed HeatPosition Cu Ni F F E >1.0MeV F Beltline No. Type Ar- Wt% Wt% Region Lower Shell Long. Weld 3- 33A277 L4 124 0577 33.6 65.5 43 201 B -'Using credible 33A277 Linde 2.1 0.258 0.165 115.9 -56 123 1.0577 122.6 44.0 111 <270 No surveillance data 124 Lower Shell Linde 1 lRef, 1-12461, 44201 44441 Long. Weld 3- 33A277 124 4-4 0.258 0.165 126.3 -56 4-1:71.51 1141 40.7 65.5 50 <270 No 201CC_11 0 65 -- Using credible Linde 2.1 0.258 0.165 115.9 -56 1.51 1.1141 129.1 44.0 117 s270 No surveillance data 33A277 124 Intermediate to Lower Shell 10120 Linde 1.12Ref- 0.046 0.082 34 -56 2 ,302.22 .22521. 44441. 6354 53. 39 -4 <300 No Circumferential 0091 4 2161 3 5 Weld 9-201 Notes: (i) Reference 39, WCAP-17315-NP Section 4 PG&E Letter DCL-1 1-136 TIME-LIMITED AGING ANALYSES Page 86 of 98 4.2.3 Charpy Upper-Shelf Energy Summary Description Per Regulatory Guide 1.99, Radiation Embrittlement of Reactor Vessel Materials, the Charpy upper-shelf energy (Cv USE) is assumed to decrease as a function of fluence and copper content. Figure 2 of the guide determines this magnitude of decrease when surveillance data is not used (Position 1.2). In addition, if surveillance data is to be used (Position 2.2), the decrease in upper shelf energy may be obtained by plotting the plant surveillance data on Figure 2 of the guide and fitting the data with a line drawn parallel to the existing lines as the upper bound of all the data. This line can then be used in preference to the existing line. The Cv USE can be predicted using the corresponding 1/4T fluence projection, the copper content of the beltline materials, and the results of the capsules tested to date using Figure 2 of the guide. 10 CFR 50, Appendix G requires that the reactor vessel beltline materials must have a Cv USE of no less than 75 ft-lb initially, and must maintain Cv USE throughout the life of the vessel of no less than 50 ft-lb unless it is demonstrated in a manner approved by the Director, Office of Nuclear Reactor Regulation, that lower values of Cv USE will provide margins of safety against fracture equivalent to those required by ASME Section Xl, Appendix G (10 CFR 50, Appendix G, Section IV.A.1 .a). Analysis The most recent coupon examination results for both units show that the decline in Cv USE in plate and weld materials are bounded by that originally predicted by Regulatory Guide 1.99, Revision 2. Thus the results demonstrate that the DCPP reactor vessel material ages consistently with Regulatory Guide 1.99 predictions and provides a conservative means to satisfy the requirements of 10 CFR 50, Appendix G. This provides assurance of the reactor vessel integrity. Unit 1 In accordance with Regulatory Guide 1.99, the Cv USE data from Unit 1 surveillance Capsule V were determined not to be credible and were, therefore, not included in the EOLE Cv USE projections. The Cv USE values were projected to 54 EFPY of operation using Regulatory Guide 1.99 Position 1.2. The EOLE Cv USE values for the Unit 1 beltline and extended beltline materials are provided in Table 42-6. The limiting value was 58-.58.2 ft-lbf for lower shell longitudinal weld 3-442C. Section 4 PG&E Letter DCL-1 1-136 TIME-LIMITED AGING ANALYSES Page 87 of 98 The extended beltline materials were also evaluated to confirm they will not decrease below the 10 CFR 50, Appendix G criterion of 50 ft-lbf. Unit 2 In accordance with Regulatory Guide 1.99, the Cv USE data from Unit 2 surveillance Capsule V were deemed credible for intermediate shell plate B5454-1. The Cv USE values were projected to 54 EFPY of operation using Regulatory Guide 1.99 Position 1.2. The EOLE Cv USE values for the Unit 2 beltline and extended beltline materials are provided in Table 4.2-7. The limiting value was 53.7 ft-lbf for lower shell longitudinal weld 3-201 C. The extended beltline materials were also evaluated to confirm they will not decrease below the 10 CFR 50, Appendix G criterion of 50 ft-lbf. Disposition: Revision, 10 CFR 54.21 (c)(1)(ii) The Cv USE values were re-evaluated with projections to the end of the period of extended operation in accordance with 10 CFR 54.21(c)(1)(ii). The re-evaluations demonstrated that the Cv USE in the limiting material of each unit will remain above the 10 CFR 50 Appendix G acceptance criterion of 50 ft-lbf for the period of extended operation.

Enclosure 2 Section 4 PG&E Letter DCL-1 1-136 TIME-LIMITED AGING ANALYSES Page 88 of 98 Table 4.2-6 DCPPUnit 1 Reactor Vessel Material Cv USE at EOLE(') EOOLC1/ US Material Description Unirradiated EOL 1/4T Projected EOL C, USE Reactor Vessel Beltline Region Heat Cu wt% Cv USE Fluence 1019 n/cm2 % Drop USEin Ci, CC, S USE Acceptance Criterion Location Number Type ft-lbf (E>A MeV) ft-lbf ft-lbf Intermediate Shell Plate B4106-1 C2884-1 A 533B 0.125 116 1.204 2-223 _0089.3 ?50 Intermediate Shell Plate B4106-2 C2854-2 A 533B 0.12 114 1.204 22 9"808.9 2>50 Intermediate Shell Plate B4106-3 C2793-1 A 533B 0.086 77 1.204 4-120 92461.6 >50 -'Using surveillance data C2793-1 A 533B 0.086 77 1.204 7.2(') 71.5 >50 Lower Shell Plate B4107-1 C3121-1 A 533B 0.13 110 1.198 23 84"84.7 >50 Lower Shell Plate B4107-2 C3131-2 A 533B 0.12 103 1.198 22 8".80.3 ?50 Lower Shell Plate B4107-3 C3131-1 A 533B 0.12 116 1.198 22 4",690.5 Ž50 Intermediate Shell Long. Welds 2-442A, B 27204 Linde 1092 0.203 91 0 ,J00,888 34 6"-60.1 >50 -. Using surveillance data 27204 Linde 1092 0.203 91 0.888 331" 61.0 ;50 Intermediate Shell Long. Weld 2-442C 27204 Linde 1092 0.203 91 0-4630458 29 64-"646 ?50 -. Using surveillance data 27204 Linde 1092 0.203 91 0.458 28.51"' 65,1 a50 Lower Shell Long. Welds 3-442A, B 27204 Linde 1092 0.203 91 0Q7450,709 32 64461.9 ?50 -. Using surveillance data 27204 Linde 1092 0.203 91 0.709 31('" 62,8 >50 Lower Shell Long. Weld 3-442C 27204 Linde 1092 0.203 91 1.198 36 1 &458.2 >50 -- Using surveillance data 27204 Linde 1092 0,203 91 1.198 351" 59.2 1 50

Enclosure 2 Section 4 PG&E Letter DCL-11-136 TIME-LIMITED AGING ANALYSES Page 89 of 98 Table 4.2-6 DCPPUnit 1 Reactor Vessel Material Cv USE at EOLEJi) EOLLC'/US Material Description Unirradiated EOL %/DT Projected EOLcC, USE _______________________Cu UE Fluence % Drop in Cv,~ S Acceptance Reactor Vessel Beltline Region Heat wt% Cv USE 1019 n/cm 2 USE C, USE Criterion Location Number Type ft-lbf (E>1 MeV) ft-lbf ft-lbf Intermediate Shell to Lower Shell 21935 Linde 1092 0.183 109 1.198 34 7-471.9 a50 Circumferential Weld 9-442 Upper Shell Plate B4105-1 C2624 A 533B 0.120 80 Q-0170.020 8.6 7-3.673.1 >50 Upper Shell Plate B4105-2 C2624-2 A 533B 0.120 74 0 04-70.020 8.6 &9467.6 a50 Upper Shell Plate B4105-3 C2608-2B A 533B 0.140 81 004-70.020 9.4 74973.4 >50 Upper Shell Long. Weld 1-442A 27204/12008 Linde 1092 0.190 86 0.fA-0.015 4-274 T4474.0 250 Upper Shell Long. Weld 1-442B 27204/12008 Linde 1092 0.190 86 0-00-70.009 4414 -7674.0 ?50 Upper Shell Long. Weld 1-442C 27204/12008 Linde 1092 0.190 86 1 Q-0460.018 414 17-674.0 >50 Upper Shell to Intermediate Shell Weld 8- 13253 Linde 1092 0.250 111 0-4-7-0.020 442 41-17 44492.1 a50 Notes: (i) Per the guidance of 10 CFR 50.61 and Position 1.2 unless otherwise noted. (ii)PercentageUSE decrease is based on Position 2.2 of Regulatory Guide 1.99, Revision 2. Section 4 PG&E Letter DCL-1 1-136 TIME-LIMITED AGING ANALYSES Page 90 of 98 Table 4.2-7 DCPP Unit 2 Reactor Vessel Material C,, UISP at P01 L".i EOL 1/4T Projected EOL C, USE Material Description Cu Unirradiated Fluence % Drop in Cv Acceptance Reactor Vessel Beltline Region Heat wt% Cv USE 1019 n/cm 2 USE Cv USE Criterion Location Number Type ft-lbf (E>1 MeV) ft-lbf ft-lbf Intermediate Shell Plate B5454-1 C5161-1 A 533B 0.14 91 4451.341 25 68"68.3 >50 --Using surveillancedata C5161-1 A 533B O 14 91 1.341 22"'1 71.0 >50 Intermediate Shell Plate B5454-2 C5168-2 A 533B 0.14 99 4451.341 25 7*4-674.3 Ž50 Intermediate Shell Plate B5454-3 C5161-2 A 533B 0.15 90 41-.31.341 26 6"166.6 >50 Lower Shell Plate B5455-1 C5175-1 A 533B 0.14 112 4-*341.323 25 "4=484.0 >50 Lower Shell Plate B5455-2 C5175-2 A 533B 0.14 122 4-441,323 25 92-091.5 >50 Lower Shell Plate B5455-3 C5176-1 A 533B 0.1 100 4-341.323 2021 7-"79.0 >50 Intermediate Shell Long. Weld 2- 21935/12008 Linde 1092 0.22 118 0-_7680.739 3834 7-3477.9 Ž50 -- using surveillance data 21935/12008 Linde 1092 0.22 118 0.739 37.5"" 73.8 Ž50 Intermediate Shell Long. Weld 2- 21935/12008 Linde 1092 0.22 118 0,9250.912 3036 7-1-675.5 >50 U--,sing surveillance data 21935/12008 Linde 1092 0.22 118 0.912 39.5"" 71.4 250 Intermediate Shell Long. Weld 2- 21935/12008 Linde 1092 0.22 118 0-.7-80.775 201 C 3835 7-4376.7 Ž50 -- Using surveillance data 21935/12008 Linde 1092 0.22 118 0.775 3e' 73.2 >50 Lower Shell Long. Weld 3-201A 33A277 Linde 124 0.258 88 0-7-740,763 38 6"054.6 >50 Lower Shell Long. Weld 3-201B 33A277 Linde 124 0.258 88 0.7-620.733 3738 56.454.6 Ž50 Lower Shell Long. Weld 3-201C 33A277 Linde 124 0.258 88 0Q9430900 39 53.7 Ž50 Intermediate Shell to Lower Shell 10120 Linde 0091 0.046 125 4-441.323 2021 400498.8 >50 Circumferential Weld 9-201 Section 4 PG&E Letter DCL-11-136 TIME-LIMITED AGING ANALYSES Page 91 of 98 Table 4.2-7 DCPPUnit 2 Reactor Vessel Material Cv USE at EOLE(_) EOL 1/4T Projected EOL C, USE Material Description Cu Unirradiated Fluence % Drop in Cv Cv USE Acceptance Reactor Vessel Beltline Region Heat wt% Cv USE 1019 n/cm2 USE Ct USE Criterion Location Number Type ft-lbf (E>1 MeV) ft-lbf Upper Shell Plate B5453-1 C5162-1 A 533B 0.110 82 00300.040 9.4 7-4474.3 a50 Upper Shell Plate B5453-3 C5162-2 A 533B 0.110 86.5 0.0300.040 9.4 7-"78.4 Ž50 Upper Shell Plate B5011-1R C4377-1 A 533B 0.110 72 094300.040 9.4 6&8-65.2 ?50 Upper Shell Long. Weld 1-201A 21935/12008 Linde 1092 0.220 118 0-0300.038 18 96,96,8 250 -- using surveillance data 21935/12008 Linde 1092 0.220 118 0.038 20PI 94.4 >50 Upper Shell Long. Weld 1-201B 21935/12008 Linde 1092 0.220 118 00280.037 18 97496.8 >50 -4Using surveillance data 21935/12008 Linde 1092 0.220 118 0.037 20"01 94.4 -50 Upper Shell Long. Weld 1-201C 21935/12008 Linde 1092 0.220 118 0.0230.031 17 0-497.9 ?50 -Using surveillance data 21935/12008 Linde 1092 0.220 118 0.031 1901) 95.6 -50 Upper Shell to Intermediate Shell 21935 Linde 1092 0.183 109 0-0300.040 4416 24391.6 a50 Weld 8-201 Notes: (i) Per the guidance of 10 CFR 50.61 and Position 1.2 unless otherwise noted. (ii) PercentageUSE decrease is based on Position 2.2 of Regulatory Guide 1.99, Revision 2. Section 4 PG&E Letter DCL-11-136 TIME-LIMITED AGING ANALYSES Page 92 of 98

4.9 REFERENCES

39. Westinghouse Report WCAP-17315-NP. Diablo Canyon Units 1 and 2 Pressurized Thermal Shock and Upper-Shelf Energy Evaluations.Rev. 0. July 2011. Westinghouse Non-ProprietaryClass 3.

40. Westinghouse Report WCAP-17299-NP. Fast Neutron Fluence Update for Diablo Canyon Unit I and Unit 2 Pressure Vessels. Rev. 0. February2011. Westinghouse Non-ProprietaryClass 3.

Appendix A PG&E Letter DCL-1 1-136 Final Safety Analysis Report Supplement Page 93 of 98 A1.15 Reactor Vessel Surveillance The Reactor Vessel Surveillance program manages loss of fracture toughness due to 1 7 neutron embrittlement in reactor materials exposed to neutron fluence exceeding 1.0E n/cm2 (E>1.0 MeV). The program is consistent with ASTM E 185-70 and ASTM E 185-73 for Units 1 and 2, respectively. Capsules are periodically removed during the course of plant operating life. Neutron embrittlement is evaluated through surveillance capsule testing and evaluation, ex-vessel neutron fluence calculations, and monitoring of reactor vessel neutron fluence. The testing program and reporting conform to requirements of 10 CFR 50 Appendix H, Reactor Vessel Material Surveillance ProgramRequirements. Data resulting from the program is used to: Determine pressure-temperature limits, minimum temperature requirements, and end-of-life Charpy upper-shelf energy (Cv USE) in accordance with the requirements of 10 CFR 50 Appendix G, Fracture Toughness Requirements; and, Determine end-of-life RTPTS values in accordance with 10 CFR 50.61, Fracture Toughness Requirements for ProtectionAgainst Pressurized Thermal Shock. The Reactor Vessel Surveillance program provides guidance for removal and testing or storage of material specimen capsules. All capsules that have been withdrawn and tested were stored. For Unit 1, the last capsule is expected to be withdrawn during the currcnt opFraFing term1R17 refueling outage after it has accumulated a fluence equivalent to 660 years of operation. The remaining four standby capsules have low lead factors, will remain inside the vessel throughout the vessel lifetime, and will be available for future testing. There are no capsules remaining in the Unit 2 vessel. All capsules were removed because high lead factors produced exposures comparable to the fluences expected at the end of the period of extended operation. DCPP Units 1 and 2 currently use ex-vessel monitoring dosimetry, which consists of four gradient chains with activation foils outside the reactor vessel, which will be used to monitor the neutron fluence environment within the beltline region. Appendix A PG&E Letter DCL-1 1-136 Final Safety Analysis Report Supplement Page 94 of 98 A3.1.2 Pressurized Thermal Shock The most recent coupon examination results for both units show that the increase in RTNDT in plate and weld materials are bounded by that predicted by Regulatory Guide 1.99, Radiation Embrittlement of Reactor Vessel Materials, Revision 2 for Units 1 and 2. The results demonstrate that the DCPP reactor vessel material ages consistently with Regulatory Guide 1.99 predictions, and provides a conservative means to satisfy the requirement of 10 CFR 50.61; thus providing assurance of the reactor vessel integrity. Unit 1 Using Regulatory Guide 1.99 Position 2.1 and 1.1 methods, RTPTS values were generated for beltline and extended beltline region materials, the upper shell plates and associated welds, of the Unit 1 reactor vessel for EOLE fluence values. The projected RTpms values for EOLE did nRt meet the 10 CFR 50.61 screening criteria for beltline and extended beltline materials. The Unit I RTpTs was projected to the end of the period of extended operation in accordance with 10 CFR 54.21(c)(1)(ii). RTpTs remains within acceptable values through the period of extended operation. The Un~it 1 reactor Vessel fluence Will continue to be monitored as pa~t of the IDCPP1 Reactor Vessel Surwe;iance program, deScrFibed in Section A!.16 and therefore will be managed to the end of the period of extended operation in accordance with 10 CFR 54.21 (G)(4)(4~i. Unit 2 The RTPTS values generated for beltline and extended beltline region materials, the upper shell plates and associated welds, of the Unit 2 reactor vessel for fluence values at EOLE meet the 10 CFR 50.61 screening criteria. The Unit 2 RTPTS was projected to the end of the period of extended operation in accordance with 10 CFR 54.21(c)(1)(ii). RTPTs remains within acceptable values for the period of extended operation. Appendix A PG&E Letter DCL-1 1-136 Final Safety Analysis Report Supplement Page 95 of 98 Table A4-1 License Renewal Commitments Item # Commitment LRA Implementation Section Schedule 23 DCD 11l replac he rnt ca;rbo÷n steel with stai8nles steel cl'aRd P 2 2 pump casing in 3-3-2-2-1-4 Prier to the period of the G"\/CS* with a completely stainless . teel PmUP casing*.Completed edeided epefatkmCompleted 24 PG&E will implement the revised PTS rule (10 CF-R 50.61 a). in the event that the prvss 472-2 At least 3 yearsprier of 10 CFR -50.61(a)cannot be mnet, PG&E will implement alternate eptions, such as lu A3.1.2 te eXceeding the PTS edUctiona *prvided in 0CFR=D50.1 Deleted c ing criterioA *f 10 CFR 50.U6 Delete d 31 The Unit 2 gap repair work will be completed prior to the period of extended 2.,27 PDrier to the period epCat9 omCompleted of-e-xtepded-epeatiGR.Complet ed 35 DGPP will revise the test procedure acceptance criteria to specifically preclude repositioning a B2.4.21 Prior to the period tub...e mo.re than oce without capping or replacing. This will preclude repositioning a tube Of. oeded having chrom~e plated 6U~fi9es fromA the chrome being moved out of the a;reas of known ope~ation-.Complet wear-.Completed ed 62 Implementation upgrades is plannedfor allforUnit 2 Diesel April, Generator Stating Air and Turbocharger Air Compressr 2011.Completed Pror of e to the period

                                                                                                                                                  ".....

epwafieR Complete d 71 The intake Structure will bereturned to (a)(2) status pior tothe period of exended operatin. 92..32 Prio to the pered of The Inta;;ke Structure is currently scheduled to be returned to (a)(2) status by the end of AkteRdt4-2-044Completed GpewatjenComp/eted Appendix B PG&E Letter DCL-1 1-136 AGING MANAGEMENT PROGRAMS Page 96 of 98 B2.1.15 Reactor Vessel Surveillance Program Description The Reactor Vessel Surveillance program manages loss of fracture toughness due to neutron embrittlement in reactor materials exposed to neutron fluence exceeding 1.0E 17 n/cm 2 (E>1.0 MeV). The program is consistent with ASTM E 185-70 and ASTM E 185-73 for Units 1 and 2, respectively. Capsules are periodically removed during the course of plant operating life. Neutron embrittlement is evaluated through surveillance capsule testing and evaluation, ex-vessel neutron fluence calculations, and monitoring of reactor vessel neutron fluence. The testing program and reporting conform to requirements of 10 CFR 50 Appendix H, Reactor Vessel Material Surveillance Program Requirements. Data resulting from the program is used to:

Determine pressure-temperature limits, minimum temperature requirements, and end-of-life Charpy upper-shelf energy (Cv USE) in accordance with the requirements of 10 CFR 50 Appendix G, Fracture Toughness Requirements; and,
Determine end-of-life RTPTS values in accordance with 10 CFR 50.61, Fracture Toughness Requirements for ProtectionAgainst PressurizedThermal Shock.

The Reactor Vessel Surveillance program provides guidance for removal and testing or storage of material specimen capsules. All capsules that have been withdrawn and tested were stored. For Unit 1, the last capsule is expected to be withdrawn during the current Opeatng te-mlR17 refueling outage after it has accumulated a fluence equivalent to 660 years of operation. The remaining four standby capsules have low lead factors, will remain inside the vessel throughout the vessel lifetime, and will be available for future testing. There are no capsules remaining in the Unit 2 vessel. All capsules were removed because high lead factors produced exposures comparable to the fluence expected at the end of the period of extended operation. DCPP Units 1 and 2 currently use ex-vessel monitoring dosimetry, which consists of four gradient chains with activation foils outside the reactor vessel, which will be used to monitor the neutron fluence environment within the beltline region. NUREG-1801 Consistency The Reactor Vessel Surveillance program is an existing program that is consistent with NUREG-1801, Section XI.M31, Reactor Vessel Surveillance. Appendix B PG&E Letter DCL-11-136 AGING MANAGEMENT PROGRAMS Page 97 of 98 Exceptions to NUREG-1801 None Enhancements None Operating Experience Reactor Vessel Surveillance program experience at DCPP is evaluated and monitored to maintain an effective program. This is accomplished by promptly identifying and documenting (using the Corrective Action Program) any conditions or events that could compromise the program. In addition, industry operating experience provides input to ensure that the program is maintained. The DCPP operating experience findings for this program identified no unique plant specific operating experience; therefore DCPP operating experience is consistent with NUREG-1801. The Reactor Vessel Surveillance program has provided materials data and dosimetry for the monitoring of irradiation embrittlement since plant startup. The use of this program has been reviewed and approved by the NRC during the period of current operation. Surveillance capsules have been withdrawn during the period of current operation, and the data from these surveillance capsules have been used to verify and predict the performance of DCPP reactor vessel beltline materials with respect to neutron embrittlement. Calculations have been performed as required to project the reference temperature for pressurized thermal shock (RTPTs) and Charpy upper-shelf energy (Cv USE) values to the end-of-license-extended (EOLE). DCPP pressure-temperature limit curves are valid up to a stated vessel fluence limit, and must be revised prior to operating beyond that limit. Neutron Fluence The last capsule withdrawn and tested from Unit 1 was Capsule V at the end-of-cycle (EOC) 11, which yielded an exposure less than that expected at EOLE. Capsule B will be withdrawn at 23.2 EFPY in order to capture enough fluence data for EOLE. The last capsule withdrawn and tested from Unit 2 was Capsule V at EOC 9, which yielded an exposure comparable to that expected at EOLE. The EOLE fluence projections include the use of lower-leakage cores and the Unit 1 power uprate. PressurizedThermal Shock All of the beltine and extended beitline materialsin the Diablo Canyon Units 1 and 2 reactorvessels are projected to remain below the PTS screening criteria values of 270°F, for axially oriented welds and plates / forgings, and 300°F, for circumferentially oriented welds (per10 CFR 50.61), through EOL (32 EFPY) and EOLE (54 EFPY). T-he-projected Unit 4 RTPTv.alUe did not meAet thI CFR 501 Ecrening Q1*0 crGitria for beitline and extended bcftline m~aterials. The Unit 2 RTp~-was-p3+*eted to the end e-Appendix B PG&E Letter DCL-1 1-136 AGING MANAGEMENT PROGRAMS Page 98 of 98 the period of extended operation. The Unit 1 reactor vessel fluenrce will cntepinue to be moni~tored as part of the Reactor Vessel SurveiIlaRce program. Charpy Upper-Shelf Energy The most recent coupon examination results for both units demonstrate that the DCPP reactor vessel material ages consistently with Regulatory Guide 1.99 predictions and provides a conservative means to satisfy the requirements of 10 CFR 50, Appendix G. The Cv USE values were revised with projections to the end of the period of extended operation. The Reactor Vessel Surveillance program operating experience information provides objective evidence to support the conclusion that the effects of aging will be adequately managed so that the component intended functions will be maintained during the period of extended operation. Conclusion Continued implementation of the Reactor Vessel Surveillance program provides reasonable assurance that the aging effects will be managed so that the systems and components within the scope of this program will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation.}}

DCL-11-136, Annual Update to the DCPP License Renewal Application and License Renewal Application Amendment Number 45

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DCL-11-136, Annual Update to the DCPP License Renewal Application and License Renewal Application Amendment Number 45

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Dear Commissioners and Staff:

4.9 REFERENCES

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