ML20236Q177

Rev 9 to Surveillance Instruction SI-114.1, ASME Section XI Inservice Insp Program. Rev Corrects Deficiencies Shown in Caqr CH5870006 & CH5870010,adds Punchlist & Incorporates Icf 87-708

ML20236Q177
Person / Time
Site:	Sequoyah
Issue date:	08/07/1987
From:	Crane E, Emrath R, Nobles L TENNESSEE VALLEY AUTHORITY
To:
Shared Package
ML20236Q142	List: ML20236Q140 ML20236Q177
References
SI-114.1, NUDOCS 8711190225
Download: ML20236Q177 (541)

Text

{{#Wiki_filter:_. . _ _ _ _ _ - _ - _ _ - _ _ - _ - TENNESSEE VALLEY AUTHORITY SEQUOYAH NUCLEAR PLANT SURVEILLANCE INSTRUCTION , S l -114.1 ASME SECTION XI INSERVICE INSPECTION PROGRAM j Unit 1 Revision 9 PREPARED BY: E. D. Crane RESPONSIBLE SECTION: In-Service Inso Group-C REVISED BY: R. M. Emrath REVIEWED BY: M. R. Arroyo SUBMITTED BY: T to RHponsible Section SupervFsor

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\ l PORC REVIEW DATE: 'AUG 0 71987 APPROVED BY: P [ 4k Plant Manager DATE APPROVED: 7119 07'97 Reason for revision (include all Instruction Change Form Nos.): Revised to incorporate changes as needed to correct deficiencies as shown l' in CAOR Nos. CH5870006 and C35870010 to add punch 11st: to incorporate ICF

               #87-708, PORC reviewed and approved 6/2/87.                          See also SAL No. 947.                           This revision constitutes a biennial review in accordance with AI-4, Appendix H.

I Pages 130 through 530 renumbered to accommodate added drawings and revised Appendix G tables. The last page of this instruction is number: M 530 i i Rh Tliols1 9 8711190225 871117 PDR ADOCK 05000327 G PDR

l-SEQUOYAH NUCLEAR PLANT PLANT INSTRUCTION REVISION LOG a 1 SURVEILLANCE INSTRUCTION SI-114.1 REVISION !Date  ! Pages  ! REASON FOR REVISION (INCLUDE COMMIT-LEVEL  ! Approved! Affected! MENTS AND ALL ICF FORM NUM8ERS) { 0 107/29/82! ALL  ! 1 101/04/84f ALL  !

                         !               ! Revise: ' !.

l I 150-65, 189-191

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                         !              !Added:           !.

i 165A-65D, !? I  ! 188A,888, !

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                        !               !191A -          !

2 102/23/841191U1 1

                        !               !             .I 3       104/02/84f61-65D                 t
                        !               IPunchlist!
                       !                ! Table of I                                                                                              l
                       !               ! Contents !
                       !               f(pp 1-2) I
                       !               146-65,          !
                       !               f65A-65D, !                                    .
                       !               188,91,107!                                                                                               {
                      !                1116,177, !                                                                                               )'
                      !                1178,190, !

I (191VI, t

                      !                (191W1,         !
                      !                1191X1          !

4 !06/19/84! I I !121,122, !

                     !                1128-131, t i                1141,142, !
                     !                1144-147. !
                     !                !159,191F !                                                                                          ,
                    !                 1191H,191LI                                                                                              -
                    !                 !191Q,191T!
                    !                1191U,19121 h                    !                !191G1,         !

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                   !                 !191Il         !
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                   !                 I191R1,        !
                   !                 1191T1,        !

5 109/14/84! I '

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SEQUOYAH NUCLEAR PLANT o PLANT INSTRUCTION REVISION LOG j SURVEILLANCE INSTRUCTION SI-114.1 REVISION Date Pages REASON FOR REVISION (INCLUDE COMMIT-LEVEL Approved Affected MENTS AND ALL ICF FORM NUMBERS) 6 05/28/85 196 ALL Spec 1fic l Changed Pages: 1 - 5 , 9 ,15~, To'7efi~ectorganizat~1onal~ changes I' 18,20,35, general program revision,.and page 36,38-50, renumbering. . 54,58, ~ ~ ~ " ~ I 60-65,~ ~ ~ ~ ' ~ 67-71,73,

                    ,                                                                                                      75,77-82, b                                                                                                      86-96,124 1

170,217, ( 269-273, l 274-298, Specific reasons: \ 305,318, To~ comply. iJi th ~'r recommendations ~of QA-361,383, Discrepancy Report SQ-DR-86-05-119R, 388,389, NSRS Investigation Report No. 392,393, 1-85-738-NPS, CATS item No. 84-116, 396,399, recommendations of NRC' generic letter ) 400,411 85-02; and NRC commitments ^. See CCTS  !

                 \                                                                                                         417,421,. item Nos.: NCC-85-0284-004,.

L 433 NCO-85-0284-006, NCO-86-0119-001, Added: NCO-86-0119-002, NCO-86-0119-003,. l-273a,273b NCO-86-0119-004,NCO-86-0119-005, ~ ~ ~

                 !                                                                                                         298a,298b NCO-86-0199-006 and SPTS Item Nos.
                                                                                                  ~7          10/14/86 298c,298d 860752~and 860712E.

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                                    ' PLANT INSTRUCTION' REVISION LOG J

f SURVEILLANCE INSTRUCTION. SI-114.1 REVISION Date Pages REASON FOR REVISION (INCLUDE COMMIT- ) LEVEL Approved Affected MENTS AND ALL ICF FORM NUMBERS) l Revised to comply with requirements of-J l 2-4,47, NQAM Part I, Section 2.16, and AI-12, l [ 50,63,64, Part I; incorporate use of CAQR (see l l 69,71,79, SPTS Nos. 8611270 and 8701190); and to  ! 81,82,87, correct typographical errors.in Appendix .j 8 2/11/87 90-93,269 A, Table A. l Punchlist Table of: Revised.to incorporate changes as needed Contents, to correct deficiencies as shown in CAQR Page 2 of Nos. CH5870006 and CH5870010; to add

      ,'                       2, 22-28, punchlist; to incorporate ICF No. #87-708,              s 43-47,51,   PORC reviewed'and approved 6/2/87.      See 52,59,62,   also SAL No. 947;'This revision.consti--

89-95,97- tutes a biennial review in accordance- -- 99,130- with AI-4, Appendix H. Pages:130 through j 446,Added 530 renumbered'to. accommodate added draw- s 9 08/07/87 447-530 inos and-revised Appendix G tables. l 100-129, Corrected in accordance with AI-4,. Section 9.1. 315

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SQNP SI-114.1 Page 1 of 1 Rev. 7 Owner: Tennessee Valley Authority

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Address of Corporate Office: Office of Nuclear Power 1101 Market Street Chattanooga, Tennessee 37402-2801 Name and Address of Nuclear Power Plant: Sequoyah Nuclear Plant. P.O. Box 2000  ; Daisy, Tennessee 37319 ' Applicable Nuclear Power Units: Sequoyah Nuclear Plant, Unit 1 Commercial Operation Date: July 1, 1981  ! I i l l SI-114.1 1 e____--_ ._ . _ - _ _ . _ _ _ - _ _ _ _ _ _

9 [1 SQNP I

   ' l --                                          SI 114.1 Page 1 of_1:
                                                 - Rev. 9                                                           '

1- ' i 0 1 PUNCHLIST ' This procedure.is to be revised to incorporate the use of the ASME color-coded ] boundary classification drawings. Certain drawings added in this revision (9)- i have already been updated to reflect.the 'use-of ASME. code classifications and are annotated with ASME CC-1 (2 or.3) equivalent.  :)

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SQNP SI-114.1 Page 1 of 2 Rev. 7  : TABLE OF CONTENTS Page No. -

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0.1 Prerequisites i 0.2 Precautions i 1.0 Statement of Applicability 1 2.0 Purpose 1 l 3.0 Inspection Intervals and Inspection Periods 1 l l 4.0 Codes of Record 2 1 1 5.0 Method of Implementation and Responsibilities 2 l 6.0 Abbreviations and Definitions 5 7.0 Components Subject to Examination - TVA Safety Class A 6 8.0 Components Subject to Examination - TVA Safety Class B 33 9.0 Components Subject to Examination - TVA Safety Class C { and D 52 10.0 Authorized Inspector 55  ; 1  ! i 11.0 Examination Methods 55 i

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12.0 Qualifications of Nondestructive Examination Personnel 59 l 13.0 Acceptance Criteria 59 14.0 Repairs 59 15.0 Replacements 60 l , 16.0 Records and Reports 60 17.0 Notification of Indication 65 l 18.0 Calibration Blocks 66 19.0 Requests for Relief 67 20.0 Augmented Inspections 67 21.0 References 71 SI-114.1

SQNP SI-114.I Page 2 of 2 Rev. 9-

 .-                                              TABLE OF CONTENTS Page No.                                     ,
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Appendix A - Tables 72 Appendix B - Drawings 97 Appendix C - Valve Tables 278 l Appendix D - Data Sheets 253 Appendix E - Notification of Indication Form 294

                                                                                                                                                 >  l Appendix F --Requests for Relief                        ' - - - ~~

295 Appendix G - Support Load Criteria 329 l l 1

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I l SI-114.1 - REV. 9  ; 1

SQNP SI-114.1 Page i of-i Rev. 7 l 1 0.1 PREREQUISITES 0.1.1' When craft support of minor or similar maintenance (examples: - scaffolding, insulation removal, buffing of welds using scotchbrite ,_ pads, and cleaning bolts) is required to facilitate performance of this SI, a single work request (WR) may be used. This WR shall i be processed in accordance with Standard Practice SQM2 and the i system code for SI-114.1 (system code 114) will be refereneced on ) the WR.

                                                                                                                    -l 0.1.2    Contact Radiation Control (RC) for radiation work permit (RWP)/ALARA preplanning requirements.

0.2 PRECAUTIONS 9 1 0.2.1 Safety belts should be worn when working from scaffolding or i ladders in accordance with HCI-M2. I i 1 0.2.2 Protective clothing, such as long sleeve shirts or gloves, should be worn except in RWP areas when working around hot pipes and equipment.

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l 0.2.3 Care should be exercised when climbing on plant structures and ) i piping to ensure firm footing. Flexing of instrument lines and ]' electrical conduit, for example, could cause equipment damage as well as bodily injury resulting from a fall, a 0.2.4 Efforts should be made to ensure proper planning to reduce delays  ! and radiation exposure in performance of the work. 0.2.5 Read and observe all applicable precautions as indicated in SQN Administrative Instructions (AI)-26 " Prevention of Foreign Material in the Primary System" and AI-8 " Access To Containment". i I SI-114.1 w_______________________________ __

SQNP SI-116.1 Page 1 of 71 Rev. 7 1.0 STATEMENT OF APPLICABILITY This program outlines requirements for performing the first 10-year - interval inservice nondestructive examinations of the Sequoyah Nuclear _. Plant, unit 1, ASME Code Class 1, 2, and 3 (TVA Safety Class A, B, C, and D) components.(and their supports) containing water, steam, or radioactive material (other than radioactive waste management systems). The program has been organized to fulfill inservice examination requirements

     *of the Nuclear Quality Assurance Manual, Part II, Section 5.1 and comply as practical with the requirements of Section XI of the ASME Boiler and Pressure Vessel Code. In addition, this program implements applicable portions of the Sequoyah Technical Specifications. The Inservice                     3 Inspection Program (ISI) satisfies the requirements of Surveillance                  i Requirements 4.4.3.2.4, 4.4.5.0, and 4.4.10, and partially satisfies the             !

l requirements of Surveillance Requirement 4.0.5. Inspection frequencies .' are in accordance with Appendix A of this~ instruction and are generally - scheduled to coincide with outage periods. The requirements of this program are applicable beginning at the date of commercial operation of the unit. Specifics concerning performance of nondestructive examinations are not a part of this instruction, but are included in nondestructive examination procedures (Program Procedure 1502.07 (formerly N80E3) and SNP TI-51). 2.0 PURPOSE The ISI program shall be used for planning inspections and nondestructive examinations of the Sequoyah ASME Class 1, 2, and 3 components for the first interval. Personnel responsible for performance of the examinations should familiarize themselves with the requirements of this program prior I to performing the examinations. The examinations required by this program will establish acceptance of components for continued service. l 3.0 INSPECTION INTERVALS AND INSPECTION PERIODS The inservice examinations required by ASME Section XI shall be performed during each 10 year interval of service (inspection interval). The inspection intervals represent calendar years after the unit has been placed into commercial service. The commercial operation date for unit I was July 1, 1981. The first 10-year interval may be decreased or extended by as much as one year. If the unit is out of service continuously for six months or more, the inspection interval may be extended for an equivalent period. , The inspection interval shall be separated into three inspection periods. 'I Except for examinations that may be deferred to the end of the inspection l interval, the required examinations shall be performed in accordance with the following schedule. This instruction may be performed in any mode and is applicable for all operational modes. SI-114.1

1 1 i SQNP SI-114.1 Page 2 of 71' tj

                                          .Rev. 8 l

1 Minimum' Examinations LMaximum Examinations a Inspection Period Completed, Percent Completed, Percent _.  ; 3' Years 16 34 7 Years 50- 67 10 Years 100' 100 1 1 The examinations deferred to the end of the. inspection interval shal'1'be' l completed by the end of the inspection. interval.' '1 i 4.0 CODES OF RECORD AND CODE CASES 1 The Sequoyah ' unit 1 operating license '(low power) was issued on February- 29, . i i 1980. Thus, as aiminimum the ISI program shall not be. prepared to a Section XI Code Edition and Addenda prior to.the 1974 Edition, Summer-1975 Addenda. , 1 In accordance with 10 CFR Part 50'.55a(g)(4)(iv),1this program was prepared ' to meet the requirements of the 1977 Edition, Summer 1978 Addenda, of . Section XI of the ASME Boiler and Pressure Vessel Code. ' Steam Generator d Tubing Examination requirements are'in:accordance with Regulatory Guide-  ;

         -1.83, Rev. 1, and Technical Specification and surveillance requirement 4.4.5.3.

j In accordance with~10 CFR Part 50.55a(b)(2),'the- .i extent of examination for piping welds Examination Categories B-J and . C-F is in accordance with the'1974 Edition, Summer 1975 Addenda of ASME, Section.XI (Examination Categories B-J, C-F and C-G). Extent of examina-l tion is defined as criteria for'the selection of Class A and' Class B' I components for examination and 'as criteria for determining which .Clas~s B. components may.be exempt from examination., The extent of examination-specifies the length of. weld to be examined. I~ Preservice examinations were conducted'in accordance'with the 1974-Edition, Summer'1975 Addenda,.of ASME Section XI (SI-114); l The use of. Code cases N-209, N-234, N-307,.and N-235 have been approved' - by NRC as per Regulatory Guide 1.147. . In addition Code case N-401.has-  ! been specifically approved ' by the - NRC for .use in the ISI program. See the letter from Novak (NRC) to Parris, dated November 14, 1984 ((A02 841119 009). l ' 5.0 METHOD OF IMPLEMENTATION AND RESPONSIBILITIES. ~'

                                                                                                 .2 Weld maps and other pertinent component drawings and tables are included I

in Appendix A of this program to define areas subject to examination (in  ; addition to sections 7.0, 8.0, and 9.0). , The Mechanical Services, Operations Engineering Services, NDE Inspection

       *Section shall prepare scan plans using component-listings supplied by
       *the ISI Programs Section'and created from component drawings in this program for the inservice inspection. The plans.should include 1as'a minimum references'to components to be examined, methods of examinations, examination procedures,'and calibration standards. . Prior'to' performing examinations on a system or component, the scan' plans shall be approved by an NDE Level III individual from the NDE Engineering Section.

i SI-114.1' l' l  ! _ _ _ =

SQNP SI-114.1 Page 3 of 71 Rev. 8 1 and submitted to the Plant Manager for information. When inservice examinations ) are implemented by instructions other than this program (e.g., MI's), copies of I the instruction data sheets shall be submitted to Mechanical Services by the performing organization such that these examinations may be included in the reports discussed in Section 16.0. These additional implementing instructions are referenced in Sections 7.1.4, 7.1.6, 7.1.10, 7.2.5, 7.2.8, 7.3.6, 7.3.8, 7.4.8, 7.5.1, 7.5.2, 7.5.5, 7.5.6, 7,6.6, 7.8, 8.6.5, 8.8.2, and 8.11 of this i program. i

                                      *During implementation phases (usually outage periods), it may become necessary to change the scan plan. Scan plan changes can be initiated by the ISI              !

Inspections Section, the NDE Engineering, the ISI Programs Sections, or by  ! other personnel involved with the implementation of the scan plan. All changes shall be coordinated with the ISI programs engineer in charge of 3 the specific plant and unit for concurrence of the change and with the appropriate plant planning and scheduling personnel for facilitating the use of supporting craft personnel. Revisions to the scan plan shall be controlled in the same manner as the original. ) I When major portions of existing piping are replaced or whole new systems j are added, a system walkdown should be performed to identify the piping configuration, welds, and components that will be included in the inspection program. Walkdowns of individually repaired or replaced components are not ) a requirement prior to performing the examination. j l If variations in piping configurations are discovered or modification or repairs j and replacements to piping are made during the service life of the unit, these j changes shall be marked on field controlled copies of drawings. This i information shall be communicated to the ISI Programs Section which shall be responsible for revising the drawings and incorporating the revised drawings into this instruction. The Inspection Section scan plan shall also be revised to reflect these changes. 1 l The in-service examinations will be performed by either Mechanical Services, l QC personnel, ISI Group personnel or outside contractors. Contract preparation, l administration, and supervision will be the responsibility of the Mechanical l Services ISI Inspection Section. Inspection plans submitted by outside l contractors shall be reviewed and approved by the NDE Engineering Section I prior to use. All specific NDE procedures used during the inspection program shall be reviewed and approved in accordance with NQAM Part II, Section 6.3. I NDE procedures will be implemented in accordance with TI-51. The ISI Unit Supervisor will be responsible for notifying the plant manager of all unacceptable indications as soon as practical. Whenever ar. unacceptable indication is discovered, this procedure (Section 17.0) and the form in Appendix E shall be utilized. In those cases where an outside contractor is furnishing inservice examination services, the contractor will normally initiate the form in Appendix E under the supervision of the NDE Engineering Section representative. See Section 17.0 of this program. SI-114.1

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SQNP: . I SI-114.1 l Page.4 of 71 m. i, Rev. 8 i When the examination is completed.the NDE Engineering or Inspection ., q Section representative shall compare the' completed exam results to the' requirements of the scan plan, identify any limitations or impractical . examinations, and provide notificationito the ISI Programs Section for, possible action in accordance with Section 19.0 of this instruction. An NDE Level II or III individual shall evaluate the NDE results Lin- ) accordance with Section XI IWA-3000. The results shall'be compared:with -l recorded results of the preservice NDE and. previous in-service NDE J results. Following each refueling outage when inservice examinations-are performed,'the data package cover sheet in Appendix D shall be: completed by the NDE Engineering'Section representa'tive and submitted to i the plant'with the final report discussed in Section 16.0, ej l ISI program preparation is the responsibility of the ISI Programs Section-

• of Mechanical Services Branch. Any' revisions initiated by'other groups shall be submitted to the ISI Programs Section for approval prior' toz incorporating the revisions into this program.

6.0 ABBREVIATIONS AND DEFINITIONS 6.1 AIA--Authorized Inspection Agency. 6.2 AI--Authorized Inspector (may denote an ANI.or ANII). - l 6.3 ANI--Authorized Nuclear Inspector. 4 6.4 ANII--Authorized Nuclear Inservice Inspector. l 1 6.5 Components--Denotes items in a power plant such as' vessels, piping systems, pumps, valves, and component supports.

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6.6 Examination--Denotes the performance of all' visual . observation and nondestructive testing such as radiography, ultrasonic,' eddy current, liquid penetrant, and magnetic particle methods. 6.7 Inspection--Denotes verifying the performance of examinations and tests by a representative of an Authorized Inspection Agency. 6.8 Normal Operation--Normal plant operation conditions include reactor  ; startup, operation at. power, hot standby, and reactor cooldown to  ! cold shutdown conditions. . Test; conditions are excluded. 1 1 1 6.9 Pressure-Retaining Material--Applies to items such as vessel heads, j nozzles, pipes, tubes, fittings, valve bodies, bonnets, disks, pump ' castings, covers, and boltings which' join pressure-retaining items. i 6.10 Repair--Those operations involving welding, heat treatment, or ' defect removal which are required to restore an item to a safe and satisf actory operating condition. I l SI-114.1 i i

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SQNP SI-116.1 Page 5 of 71 Rev. 7 6.11 Replacement--Replacements include spare and renewal components, or i parts of a component (e.g., valve body bonnet, disc, bolting).

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also includes the addition of components such as valves and system  ; changes such.as rerouting of piping. For the purpose of this -- l procedure, the term replacement shall apply where attachment to the pressure boundary is by welding or mechanical means. {1 7.0 COMP 0KENTS SUBJECT TO EXAMINATION--TVA SAFETY CLASS'A. The Class A (ASME Class 1) components to be examined during the inspection j interval are outlined in the following paragraphs. The entire length of l each weld described will be examined for'the first 10-year ISI.unless 1 otherwise noted. When a portion of a weld length is to be examined during an inspection period, the areas examined each inspection period shall be documented on the examination' data sheets. All Class A components are subject to volumetric and/or surface examination i except components (and their supports) that are one-inch nominal pipe size and smaller (see section 7.7). Table A in Appendix A supplies additional information such as reference drawing numbers and Section XI, Table IWB-2500-1, examination categories. l l 7.1 Reactor Vessel 7.1.1. Reactor Vessel Seam Welds 7.1.1.1 Circumferential Shell Welds 1 There are four circumferential welds (each approxi- i mately 50 feet in length) in the vessel cylindrical shell, three of which are located behind the thermal shield. The entire length of each of these welds will be ultrasonically examined during the third inspection period using remote inspection-devices from the vessel I.D. with the core internals removed. The vessel shell sections are machined forgings fabricated of A-508, Class 2, manganese-molybdenum steel and are clad with weld deposited austenitic stainless steel. 7.1.1.2 Longitudinal Shell Welds 1 There are no longitudinal shell welds associated with the reactor vessel. 7.1.1.3 Closure Head Circumferential Weld The entire length of the closure head cap weld (approximately 41 feet in length) will be manually j ultrasonically examined from the head outside i diameter. The length of weld to be examined each inspection period is included in Table A of Appendix A. SI-114.1

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SQNP SI-114.1 Page 6 of 71 Rev. 7

                                                                   ,   'l During the conduct of the unit 1 preservice examina-tion a flaw indication in the closure head weld was observed (weld 09-10) . Flaw evaluation and accept-ability was based on Code Case N-209 (see nonconforming
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report 6P for additional information concerning flaw evaluation and location). In addition to the exami-nations above, the flaw indication volume shall be. examined during each inspection period. This .provides i examination of the flaw indication volume for-three  ; successive inspection periods.- Should these successive  ! examinations reveal that the flaw indication has remained essentially unchanged, then the examination frequency may revert to that of Examination Category. B-A of Table IWB-2500-1 of ASME Section XI. If the successive examinations reveal that the flaw indication size has increased, then' technical justification ' shall be presented to NRC for allowing continued l operations. The closure head ring is fabricated of A-508, Class 2, manganese-molybdenum' steel. The closure head hemispherical section is fabricated of-A-533, Gr. B, Class 1, manganese-molybdenum steel. Both sections are clad with weld deposited austenitic stainless steel. 7.1.1.4 Lower Head Circumferential Weld The entire length of the lower head circumferential weld (approximately 38 feet in length) will be ultrasonically examined during the third inspection l period using remote inspection devices from the vessel inside diameter with.the core internals removed (see Request for Relief .ISI-5). The lower head sections are fabricated of A-533, Gr. B, Class 1, manganese-molybdenum steel, and are clad with weld deposited austenitic stainless steel. 7.1.1.5 Closure Head Meridional Weld 1 The closure head does not include any meridional welds. l 1 SI-114.1

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                                                                                                                                                                             .1 SQNP SI-116.1 Page 7 of 71 Rev. 7 7.1.1.6    Lower Head Meridional Welds There are six meridional welds (each approximately-                                                                     l 4 feet in length) located in the lower head.                                                            The     __      j entire length of each of these welds will be; ultra-                                                                    i sonically examined during the third inspection period using remote inspection devices from the' vessel inside diameter with the core internals. removed.

The lower head section material is identified in section 7.1.1.4 of this program, j 7.1 1.7 Shell-To-Flange Weld i The entire length of the shell-to-flange weld j (approximately 50 feet in length) will be ultrason-ically examined from the vessel inside diameter i l using remote inspection devices during the third- l l inspection period. l The vessel flange section is fabricated of A-508, Class 2, manganese-molybdenum steel and is clad 1 internally and on the gasket face with weld deposited  ; I austenitic stainless steel. l 7.1.1.8 Closure Head-To-Flange Weld l l The entire length of the head-to-flange weld (approxi-l mately 45 feet in length) will be manually ultrasoni-l cally examined from the head outside diameter. The 1 length of weld to be examined each. inspection period is included in Table A of Appendix A. j The closure head flange section is fabricated of A-508, Class 2, manganese-molybdenum steel'and is clad internally and on the gasket face with weld deposited austenitic stainless steel. 7.1.1.9 Repair Welds Base metal weld repairs in the beltline region where the repair depth exceeds 10 percent nominal of the vessel wall shall be ultrasonically examined.

                                                      *There are no base metal repair welds in the belt-
                                                      *1ine region of the unit 1 vessel.

1 1 l l SI-114.1 L _ _ . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _

1 SQNP i SI-114.1 i Page 8 of 71 j Rev. 7 i 1 7.1.2 Reactor Vessel Nozzle-To-Vessel Welds J J There are four inlet nozzles (27.500 inch I.D.) and four. - outlet nozzles (29.937-inch I.D.). The eight nozzle-to-vessel __ welds will be ultrasonically examined from the inside diameter 1 using remote inspection devices. The four outlet nozzle-to-vessel welds shall be ultrasonically examined from the nozzle bore when_the upper internals are removed during the first inspection period. The inlet nozzles are not accessible until the core barrel is removed. ) The four inlet nozzle-to-vessel welds shall be ultrasonically l examined from the nozzle bore and from the vessel shell . 1 inside diameter during the third inspection period when the l core barrel has been removed. The outlet nozzle-to-vessel i welds shall also be ultrasonically examined from the vessel shell inside diameter during the third inspection period when the core barrel has been removed.  ! The nozzle forgings are fabricated of A-508, Class 2,. manganese-molybdenum steel and are clad with weld deposited austenitic stainless steel. 7.1.3 Reactor Vessel Nozzle Inside Radius Section The eight nozzle inside radius sections (including the outlet , nozzle integral extensions) shall be ultrasonically examined l at the same time as the examination of the nozzle-to-vessel < welds conducted from the nozzle bore (see Section 7.1.2). i Nozzle forging material is identified in Section 7.1.2 of l this program. 7.1.4 Reactor Vessel Partial Penetration Welds The vessel includes 4 upper head injection nozzles, 1 vent pipe nozzle, 78 control rod drive nozzles, and 58 instru-mentation nozzles with partial penetration welds. Approxi-mately 25 percent of each group of nozzles shall be visually examined from the vessel outside diameter in accordance with visual examination method VT-2 (see section 11.1). This 25 percent shall include 1 upper head injection nozzle, 1 vent pipe nozzle, 20 control rod drive nozzles, and 15 instrumentation nozzles. Examination of these nozzles during the inspection interval shall be distributed among the inspection periods in accordance with Table A of Appendix A. The ISI scan plan shall designate the nozzles requiring examination to be examined in accordance with SI-146 or SI-250. The examination results may be recorded on SI-146 or SI-250 data sheets. SI-114.1

SQNP. SI-114'.1-Page'9 of:71 Rev. 7 7.1.5 Reactor Vessel Nozzle-To-Safe End Welds-The inlet and outlet' nozzle-to-safe end welds sh'all be ultrasonically examined from the' inside' diameter using remote -- inspection devices. The ultrasonic examination shall.be performed at the same time an'the examination of the nozzle-to-vessel welds' conducted from the nozzle bore-(see Section-7.1.2). All of the nozzle-to-safe end welds'shall also be liquid . penetrant examined during the inspection; interval coincident [ l with the ultrasonic examinations. The Sequoyah Nuclear Plant Unit 2 Report--Evaluation of Cracking in Reactor Vessel Nozzle Stainless Steel Buttering, states that, Unit 1. nozzle ' to-safe end welds RC-9SE'and RC-32SE shall-be' examined' during the first inspection interval (see memorandum'from ' D. W. Wilson to H. L. Abercrombie, dated August _1, 1986 (L18 860730 899). -The remaining nozzles will be examined during the normal inservice inspection intervals. Each nozzle safe end weld is a stainless' steel' type 304-weld build up. 7.1.6 Reactor Vessel Pressure Retaining Bolting Larger Than Two Inches In Diameter During each refueling out' age all closure studs, nuts,.and-washers are removed. - All of the 54 closure studs and nuts

                                                            ~

shall be examined during the inspection _ interval'in'accordance; with Table A of Appendix A. The: closure nuts shall be magnetic particle examined and the. closure studs shall be ultrasonically and magnetic particle examined' The closure studs may be ultrasonically examined in place under tension, when the closure head is removed, or when the studs.are removed. 1 Provisions for this examination are included'in MI-1.2. Where needed the examinations of the studs should'be identified with the particular stud in'accordance with the-unique identification system for the studs and nuts. All of the 54 ligaments between the vessel flange: stud holes shall be ultrasonically examined during the inspection . interval in accordance with Table A of Appendix A. (This-provides for ultrasonic examination of the threads in base material.)

                                                          ^

The 54 closure washers shall be visually examined in accordance with visual examination method VT-1 (s'ee section 11.1) during the inspection interval in'accordance with Table'A of Appendix A. The 7-inch diameter studs, nuts, and washers are fabricated 1 of SA-540, Gr. B23 Nickel, chrome-molybdenum steel, o SI-114.1

• SQNP j SI-114.1 1 Page 10 of 71 Rev. 7 .

                                                                                             ,   1 7.1.7   Reactor Vessel Pressure Retaining Bolting Two Inches And~~~                     )

Smaller In Diameter ]

                                                                                               }'

There is no pressure retaining bolting two inches or smaller __ in diameter. 7.1.8 Reactor Vessel Integrally Welded Attachments ) There are no integrally welded vessel supports. 7.1.9 Reactor Vessel' Interior  !

                                                                                                )

The vessel interior shall be visually examined in accordance I with visual examination method VT-3 (see Section 11.1). . l These examinations shall include the space above and below I the reactor core that is made accessible for examination by. I removal of components during normal refueling outages. The examinations shall be performed at the first refueling outage and subsequent refueling outages at approximately three year intervals. 7.1.10 Reactor Vessel Removable Core Support Structures The visually accessible attachment welds and visually accessible surfaces of the core support structure shall be ) visually examined in accordance with visual examination I method VT-3 (see Section 11.1). This examination may be deferred to the third inspection period. The structure shall be removed from the reactor vessel for examination. These examinations are implemented by MI-1.4. 7.1.11 Reactor Vessel Control Rod Drive Housings I There are 78 control rod drive housings penetrating the closure head. Each housing includes a pressure retaining dissimilar metal butt weld and canopy seal weld. The canopy seal welds are exempted from volumetric or surface examination in accordance with IWB-1220(a). There are 20 peripheral control rod drive housings. Two-(10 percent) of the peripheral housing butt welds shall be ultrasonically examined during the inspection interval in accordance with Table A of Appendix A. The housings consist of a 6" 0.D. adapter of A-182, 304SS and'a 4" 0.D. body of SB-167. SI-114.1

SQNP..

                                                      .SI-114.1                                                ;

Page 11 of 71-Rev. 7' N 7.1.12 Reactor Vessel Auxiliarv' Head Adapters; Each of the four auxiliary head: adapters includes a pressurd retaining dissimilar metal weld. :The.four dissimilar metal --, welds shall.be ultrasonically and liquid penetrant examined

                                                                                          ~

during the inspection interval in accordance with Table /U of Appendix A. .The adapters ' consist of'a SA-182, 304SS upper-

                                   . portion and a SB-166l lower portion.                                    1 1

7.2 Pressurizer j 1 7.2.1 Pressurizer Circumferential Shell-To-Head Welds H

                                                                                                             'd There are two circumferential.shell-to-head welds,-each approximately 24 feet'in length'. The entire length of each weld shall be ultrasonically examined during.the inspection interval in- accordance with Table A of ' Appendix A.

1 All vessel shell and head sections are fabricated of SA-533, . 1 Class 2, manganese-molybdenum steel and are clad with j austenitic stainless steel. ' 3 7.2.2 Pressurizer Longitudinal Shell-To-Head Welds There is one longitudinal weld. intersecting each circumfer-ential shell-to-head weld. One foot of each longitudinal

                                                                           ~

weld shall be ultrasonically examined during the inspection periods in accordance with Table A of Appendix A. jThe one foot of weld examined during each examination shall include the length of weld as measured from-the point of intersection of the longitudinal weld with the-circumferential head-to-shell weld. The vessel shell section material is . identified in-Section: 7.2.1. 7.2.3 Pressurizer Circumferential and Meridional Head Welds l There are no pressurizer circumferential or meridional head' welds. 7.2.4 Pressurizer Nozzle-To-Vessel Welds and Nozzle Inside Radius: Section The pressurizer includes three 6-inch safety. valve. nozzles, one 6-inch relief valve nozzle, one.4-inch ~ nozzle,;and one 14-inch surge nozzle. All of the nozzle-to-vessel. welds,1 including nozzle inside radius section,'shall be; ultrasonic-ally examined during the inspection interval in accordance with Table A of Appendix A. The nozzles are fabricated of SA-508, Class 2, manganese-molybdenum steel. i t SI-114.1 L-__-_____--------_---------_'_----

1 SQNP SI-116.1 Page 12 of 71 1 Rev. 7 l 1 7.2.5 Pressurizer Heater Penetration Welds There are 78 heater penetration welds located in the pressurizer , lower head. Approximately 25 percent of the heater penetration _ l welds (20 welds) shall be visually examined during the j inspection interval in accordance with visual examination'  ! method VT-2 (see Section 11.1). Examination of'these pene-trations during the inspection interval shall be distributed among the inspection periods in accordance with Table A of Appendix A. ) The ISI scan plan shall designate the heater penetrations i requiring examination such that the organization performing' ] the examinations may document examination results on SI-146 or SI-250 data sheets.  ; 1 7.2.6 Pressurizer Nozzle-To-Safe End Welds Each of the six nozzles identified in section 7.2.4 includes a welded forging safe end. All of the nozzle-to-safe end welds shall be ultrasonically and liquid penetrant examined during the inspection interval in accordance with Table A of q Appendix A.  ! Safe end connections are SA-182, Gr. F-316L forgings. 7.2.7 Pressurizer Pressure Retaining Bolting Larger Than Two i Inches In Diameter There is no pressure retaining bolting larger than two inches in diameter. 7.2.8 Pressurizer Pressure Retaining Bolting Two Inches And Smaller In Diameter All of the pressurizer manway bolts shall be visually. examined in accordance with visual examination method VT-1 (see Section 11.1). The examinations shall be distributed _during the inspection interval in accordance with Table A of Appendix A. The bolts may be examined in place under tension or when the bolts are removed. It is preferrable to perform the examina-tions when the bolts are removed if possible. Removal of the manway cover is performed in accordance with MI-4.5'and. provides for examination of bolting. SI-114.1

SQNP r SI- 114 ~.1 Page 13 of 71 Rev. 7 The manway includes 16 bolts at 1.88 inches in diameter. For exam documentation purposes the'manway cover bolts should be uniquely identified in accordance with the - " following: __ X-MWCB-YY where; X is the unit (1) and YY is the bolt number (01 through 16)_in accordance with the closure torquing pattern shown in MI-4.5. Where possible this number should be stenciled on the bolt to facilitate identification. 7.2.9 Pressurizer Integrally Welded Support Attachments The entire length of the pressurizer support skirt-to-vessel weld (approximately 23 feet in length) shall be surface examined (magnetic particle) during the inspection interval in accordance with Table A of Appendix A. The support skirt is approximately 1.5 inches thick and is fabricated of SA-516, Gr. 70, carbon steel plate. 7.3 Steam Generators (4) 7.3.1 Steam Generator Primary Side Circumferential And Heridional Head Welds j There are no steam generator primary side circumferential or meridional head welds. 7.3.2 Steam Generator Primary Tubesheet-To-Head Weld Each steam generator includes a tubesheet-to-head weld (approximately 36 feet in length). The entire length of each weld shall be ultrasonically examined during the inspection interval. The entire length of a tubesheet-to-head weld shall be examined during the first and second inspection periods. The entire length of the two remaining welds shall be examined during the third inspection period. The tube plate is a SA-508, Class 2, steel forging, clad on the primary side with NiCrfe alloy. The hemispherical chamber is a SA-216, Gr. WCC casting, clad with austenitic stainless steel. l i

                                                                                                                                                        ?

SI-114.1 i - _ _ _ _ _ _ - . _ _ _ _ _ _ - . . _ _ _ - . _ _ _ _ _ _ _ _ _ __ __ _ _. .5

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                          .SQNP-                              -

SI-114.1 Page 14 of 71 J Rev.'7 .{ i

                                                                                         -. 1 7.3.3 Steam Generator Primary Nozzle-To-Vessel Welds And Nozzle                            !

Inside Radius Section 1 I The steam generator primary nozzles are an integral part of __.

                                                                                            -1 the vessel. The inside radii of all nozzles cannot be ultrasonically examined and achieve meaningful results due to                        i limitations of examining integrally cast material (see request for relief ISI-6).

The nozzles are fabricated to SA-216, Gr. WCC.  ; 7.3.4 Steam Generator Primary Nozzle-To-Safe End Welds. 4 Each steam generator includes two nozzles with buttered safe I ends. Each nozzle-to-safe end weld from each generator.shall be ultrasonically and liquid penetrant examined during the inspection interval.in accordance with Table A of Appendix A. The nozzles have buttered 308L safe ends. 7.3.5 Steam Generator Primary Pressure Retaining Bolting Larger Than } Two Inches In Diameter There is no pressure retaining bolting larger than two inches in diameter. 7.3.6 Steam Generator Primary Pressure Retaining Bolting Two Inches And Smaller In Diameter 1 Each steam generator includes two manways. All the manway -{ bolts from each steam generator manway shall be visually .! examined in accordance with visual examination method VT-1 (see Section 11.1). The examinations shall be distributed during the inspection interval in accordance with Table A of Appendix A. , The bolts may be examined in place under tension or.when the  ! l bolts are removed. It is preferrable to perform the examina- l tions when the bolts are removed if possible. Removal of. bolting is performed in accordance with MI-3.1 and provides for examination of bolting, For exam documentation i purposes the manway cover bolts should be uniquely identified in accordance with paragraph 5.1 of MI-3.1 and  ; the following: i HWCB-U-X-YY-Z where: U = unit no. (1) X = S/G loop (1 through 4) YY = bolt no. (01 through 16) Z = leg designation (H or C) 2 SI-114.I' \ 1

SQNP .. SI-114i1 Page 15 of.71 Rev. - H NOTE: -The bolt number-(B) usually corresponds.to the: closure torque sequence shown in paragraph.5.2.16

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of MI-3.1. , Each manway includes 16 bolts at 1.88-inches 'in- diameter. ' 7.3.7 Steam Generator! Primary Integrally Welded Support Attachments-There are no integrally. welded, vessel supports. The'four j main. support pads arefsecured'to the steam generator field  ; I support system by high strength bolts. L l 7.3.8 Steam Generator Tubing-  ; Each steam generator tube' bundle, consists of 3,388 NiCrFe-alloy (Inconel SB-163) U-tubes of 0.875 0.D. by 0.050 average ' wall thickness. During the inspection interval, steam generator. tubing shall undergo eddy current examination. .This examination is done in accordance with Sequoyah technical specifications and satisfies Surveillance Requirement 4.4.5.0. 7.3.8.1 Steam Generator Sample Selection And Inspection l Each steam generator shall be determined operable during the shutdown by selecting andLinspecting at least the minimum number of steam generators speci-l fied in Table 1. 7.3.8.2 Steam Generator Tube Sample Selection and Inspection The steam generator tube minimum sample size inspec-tion result classification,-and the corresponding. action required shall be as specified in Table SG-2. The inservice inspection of' steam generator tubes shall be performed at the. frequencies specified in Section 7.3.8.3, and the. inspected tubes shall be verified acceptable per the acceptance criteria of

                *section 7 3.8.4. Inspection of tubes shall

• include the entire length of the-tube. . Note that

                *the hot leg inspection sample and the cold leg

• inspection sample do not necessarily involve the  ;

                *same. tube, i.e., it does not preclude making
                                                                                ~

• separate entries.from the hot and cold leg sides'

                *and selecting different tubes on the hot leg and               .]

• cold leg sides to meet the minimum sample. The 1 tubes selected for each inservice' inspection shall  !

include at least 3% of the total number of tubes in all steam generators; the tubes selected for-thase inspections shall be selected on a random basis except: SI-114.1 i . _ _ _ _ _ _

                                                                       ]

SQNP

            ~ S I- 114.1 --

Page.16'of 71

            -Rev. 7-                                                     q
                                                                       .1
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a. Where experience-in similar plants.with -I similar water chemistrytindicates critical-areas.to'be inspected,.then at least 50% of the tubes-inspected shall be- .-

from these critical areas- . 4 a

                                                                          ]

b. The first sample of tubes selectedifor l each inspection (subsequent to the l preservice inspection):of each steam-generator shall include:

1. All nonplugged tubes that previously.

had detectable wall penetrations  ;

                     >20%.                                                j 1

2. Tubes in those areas where 'd expe'rience;has indicated potential problems. {

j l 3. A tube inspection (pursuant-to: 1 Section 7.3.8.4.a 8) shall be l' . performed on each selected tube. If 1 any selected tube does not permit i the passage of the eddy current { probe for a tube inspection, this _ j shall be evaluated and recorded'and-an adjacent tube shall be selected and subjected;to a tube. inspection. i i

c. The tubes selected as the second and _ _

third samples (if required by Table'2 of Appendix A) during each inservice inspection may be subjected to a partial tube inspection provided:

1. The tubes selected for these samples.

include the tubes'from'those areas of the tube sheef.. array where tubes. , with imperfections were previously ,{ found. -1

2. The inspections include those- I portions of the tubes where j imperfections were previously found. i The results of.each sample inspection shall ,

be classified into one of the following three .. : categories:  !

                                                                         'I SI-114.1 i

SQNP.

                 'SI-114.1=

Page 17 of 71 Rev. 7 Category Inspection Results Less than 5% of the total tubes C-1 inspected are degraded tubes - - - and none of the inspected tubes are defective. C-2 One or more tubes, but not more than 1% of the total tubes inspected are defective, or

                             'between 5% and 10% of the total' tubes inspected are degraded tubes.

C-3 More than 10% of the total tubes inspected are degraded tubes or more than 1% of the inspected tubes are defective. NOTE: In all inspections, previously degraded tubes must' exhibit significant (>10%) further wall penetrations to be included in the above percentage calculations. l 7.3.8.3 Inspection Frequencies

         *The above required inservice inspections of steam-

• generators shall be performed at frequencies
• indicated in the following paragraphs and in such

         *a manner that the maximum allowable time between.

• eddy current inspections on individual steam
• generators is 72 months.

a. The first inservice inspection shall be performed after 6 Effective Full Power Months but within 24 calendar nonths of initial criticality. Subsequent inservice inspections shall be performed at intervals of not less than 12 nor more than 24 calendar months after the previous inspection. If two consecutive inspections following service under AVT conditions, not including the preservice .

inspection, result in all inspection  ! results falling into the C-1 category or > if two' consecutive inspections demonstrate that previously observed l j degradation has not continued and no , additional degradation has occurred, the  ! inspection interval may be extended to a l maximum of once per 40 months. i SI-114.1

                                                          - - _ _ _ . - _ . _ - - -...-..-.-_____--a

SQNP SI-114.1 Page 18 of 71 Rev. 7 i

                                                                    )

b. If the results of the inservice inspec- 1 tion of a steam. generator conducted in accordance with Table 2'at 40-month ~

q intervals fall in . Category. C-3, the -  ; inspection frequency shall be increased

                                                                    ]

to at least once per 20 months. The q increase in inspection frequency shall ] apply until the subsequent inspections 'l satisfy the criteria of'section 7-.3.8.3.a; { the interval may then be extended to a { maximum of once per 40 months.

c. Additional, unscheduled inservice I inspections shall be performed on each ]

steam generator in accordance with the i first sample inspection specified in  ! Table 2 during the shutdown subsequent to  ! any of the following conditions. '

                                                                    )

1. Primary-to-secondary tubes leaks (not  !

including leaks originating from tube-to-tube sheet welds) in excess of the limits of Technical Specification , 3.4.6.2.

2. A seismic occurrence greater than the Operating Basis Earthquake'.

3. A loss-of-coolant accident requiring actuation of the engineered '

safeguards.

4. A main steam line or feedwater line i break. .j l

7.3.8.4 Acceptance Criteria  :

a. As used in Section 7.3.8:

1. Imperfection means an exception to the dimensions, finish or contour of a i tube from that required by fabrication drawings or specifications. Eddy-current testing indications below 20%

of the nominal tube wall' thickness, if detectable, may be considered as imperfections.

2. Degradation means a service-induced cracking, wastage, wear or general corrosion occurring on either inside or outside of a tube.

SI-114.1

SQNP SI-114.'1 -) Page 19 of.71' Rev. 7'

                                                                                                 ]

3. . Degraded Tube means a. tube'containing:

imperfections >20% of-the~ nominal wall thickness caused by degradation.

4. -Percent Degradation means.the percent . ,

age of the. tube;wallithickness. .I

                                      'affected or' removed by degradation.=                       !
                            '5.       Defect means:an: imperfection offsuch severity that it. exceeds'the plugging:
                                     ' limit. :A tube'containing a defect'is-
                                    ' de fective..                                                 l 1

6. Plugging Limit means.the. imperfection f' depth at or beyond which,the tuber shall be-removed from service:because

                                     'it mayLbecome unserviceable! prior to-the next' inspection and is equal to
                                     '40% of the nominal tube wall.
                                    . thickness.

7. Unserviceable describes the condition of a tube if it leaks or contains a defect:large enough to affect;its structural integrity in the event of' an Operating Basis Earthquake, a1 ,.

loss-of-coolant accident, or a steam- j line or feedwater line break as specified in-Section 7.3.8.3.c. l 8.

• Tube Inspection.means'an. inspection of' l l *the steam generator tube'from the.
• point of entry (hottleg' side).'com-

                                   *pletely around the U-bend _to the point of

• exit (cold leg' side) 1.e., tube end.to-
• tube end. Entries may.be made:from

                                                            ~

j

                                   *either the hot or cold. leg sides'and.                       '

• separate entries on the hot leg and cold
• leg sides on different tubes are
• allowed.

i,

9. Preservice Inspection'means'a tube

                                                                                              'q inspection of each. steam generator                         i
                                    = tube performed by eddy current                            ;

techniques' prior to. service to j establish ~a baseline condition of the  ; tubing. .This? inspection-shall be  ; performed prior to initial power l operation using the equipment and .

                                                                                               .]

techniques expected to be used during; a subsequent inservice inspections.

• SI-114.1

  -      .                                                     .                              .1 m _______   _ - - - - ---- -    __.           _
                                                                               -    -_        o

SQNP l' SI-114.1

                                                        ' Page 20 of 71 Rev. 7

b. The steam generator shall be determined operable after completing the corre-sponding actions (plug all tubes -

exceeding the plugging limit and all __ tubes containing through-wall cracks) required by Table 2. 7.4 Piping i All Class A piping systems to be examined are fabricated of stainless steel. The reactor coolant main loop piping straight lengths are centrifugal cast and the elbows are static cast. The upper head injection auxiliary head adapter is included in l Section 7.1.1.3. Specific material specifications for each piping system are included in weld map isometrics in Appendix A (see Request for Relief ISI-3). The following Class A piping systems are subject to examination: Reactor Coolant Chemical and Volume Control Residual Heat Removal Safety Injection Upper Head Injection l 7.4.1 Piping Dissimilar Metal Welds l There are no Class A dissimilar metal welds. 7.4.2 Piping Pressure Retaining Bolting Larger Than 2 Inches l In Diameter There is no piping pressure retaining bolting larger than 2 inches in diameter. 7.4.3 Piping Pressure Retaining Bolting 2 Inches and Smaller in Diameter The following sections define the number of bolted l piping flange connections in each system. All of the l bolts or studs and nuts in each flange connection l shall be visually examined during the inspection ! interval in accordance with visual examination method l VT-1 (See Section 11,1). The examinations shall be distributed during the inspection interval in accordance with Table A of Appendix A. The bolting may be examined in place under tension or when the bolting is removed. SI-114.1

                                                                                    .                 .I

SQNP SI-114.1 i Page 21 of 71 Rev. 7 i 7.4.3.1 Reactor Coolant System Piping Bolting i l i The Reactor Coolant System piping includes

                                                                 ~

eight bolted flange connections. -- 7.4.3.2 Chemical and Volume Control System Piping Bolting The Chemical and Volume Control System piping includes four bolted flange connections (from i' seal water injection). l 7.4.3.3 Residual Heat Removal System Piping Bolting i 1 ' The Residual Heat Removal' System piping does , not include any bolted connections.

                                                                          ]

l l 7.4.3.4 Safety Injection System Piping Bolting The Safety Injection System piping includes 1 four bolted. flange connections. 7.4.3.5 Upper Head Injection System Piping Bolting The Upper Head Injection System piping i includes twelve bolted clamp / seal ' (grayloc) connectors.  ! l 7.4.4 Circumferential and Longitudinal Pipe Welds The entire length of each circumferential pipe weld selected for examination shall be ultrasonically and/or liquid penetrant examined as practical. All Class A piping is seamless.  : Circumferential pipe welds four inches and greater nominal pipe size shall be ultrasonically and liquid penetrant examined. Circumferential pipe welds less than four-inch nominal pipe size shall be liquid penetrant examined. The examinations performed during the inspection interval shall include approximately 25 percent of the 40 year sample of circumferential welds. The examina-tions shall be distributed during the inspection interval in accordance with. Table A of Appendix A. SI-114.1 l t

SQMP SI-114.1 Page 22 of 71 Rev. 9 7.4.4.1 Reactor Coolant System Main Loop Piping j Circumferential Welds , The Reactor Coolant System main loop piping includes 63 circumferential pipe welds 4 inches and greater nominal pipe size. These welds shall be ultrasonically and liquid penetrant examined during the inspection interval (see Request for Relief ISI-7). 7.4.4.2 Reactor Coolant System Piping Circumferential Welds  ; {1 Reactor Coolant System piping includes 64 circumferential pipe welds 4 inches and greater.. nominal pipe size. These. welds shall. i be ultrasonically and liquid penetrant. examined during the inspection interval. There are 107 pipe welds.less than 4-inch nominal pipe size that shall be liquid penetrant examined during the inspection  ; interval. 7.4.4.3 Chemical and Volume Control System Piping Circumferential Welds The Chemical and Volume Control System piping (including seal water injection) includes 58 circumferential welds less than 4-inch I nominal pipe size that shall be liquid penetrant examined during the inspection interval. p 7.4.4.4 Residual Ifeat Removal System Piping

 ,                Circumferential Welds                                               '

The Residual Heat Removal System piping includes 49 circumferential welds 4 inches and greater nominal pipe size. These welds shall be ultrasonically and liquid penetrant examined during the inspection interval. There are no Class A pipe welds less than - 4-inch nominal pipe size in the 10m system. I U SI-114.1 - REV. 9

SQNP SI-114.1 Page 23 of 71 Rev. 9 7.4.4.5 Safety Injection System Piping

   ;                       Circumferential Welds                                -

t _ The Safety Injection System piping includes 102 circumferential pipe welds 4 inches and 'l greater nominal pipe size. These welds shall be ultrasonically and liquid penetrant examined during the inspection interval. There are 34 pipe welds less than 4-inch nominal pipe size that shall be liquid penetrant examined during the inspection interval. 7.4.4.6 Upper Head Injection System' Piping 1 Circumferential Welds The Upper Head Injection System piping includes 118 circumferential pipe welds l j j 4 inches and greater nominal pipe size. I These welds shall be ultrasonically and liquid penetrant examined during the inspection interval. There are no piping welds less than 4-inch nominal pipe size.  ; 7.4.5 Branch Piping Connection Welds The entire length of each branch pipe connection weld , selected for examination shall be examined. Branch  ; l pipe connection welds exceeding 2 inches nominal pipe .= size shall be ultrasonically and liquid penetrant i examined. Branch pipe connection welds 2 inches l nominal pipe size and smaller shall be liquid penetrant examined. The examinations performed during the inspection interval shall include approximately 25 percent of the-branch pipe connection welds. The examinations shall i 'E be distributed during the inspection interval in accordance with Table A of Appendix A. I 7.4.5.1 Reactor Coolant System Main Loop Branch Pipe i Connection Welds The Reactor Coolant System Main Loop piping includes 1 branch pipe connection weld a exceeding 2 inches nominal pipe size. These welds shall be ultrasonically and liquid L penetrant examined during the inspection I interval. There are 13 branch pipe connection welds 2 inches nominal pipe size and smaller that shall be liquid penetrant examined during the inspection interval. - SI-114.1 - REV. 9 1 1

 ]                      SQNP 1

SI-114.1 .

      ~

Page 24 of 71 Rev. 9 r 7.4.5.2 Reactor Coolant System Branch Pipe Connection f Welds ,_ The Reactor Coolant System piping includes j, 6-branch pipe connection welds e.xceeding 1 2 inches nominal pipe size. These welds shall be ultrasonically and liquid penetrant examined during the inspection interval. There are 7 branch pipe connection welds i 2 inches nominal pipe size and smaller that J shall be liquid penetrant examined during the l inspection interval. l 7.4.5.3 Chemical and Volume Control System Branch Pipe Connection Welds The Chemical and Volume Control System piping includes 3 branch pipe connection welds l exceeding 2 inches nominal pipe size. These welds shall be ultrasonically and liquid penetrant examined during the inspection interval. There is one branch pipe connection weld 2 inches nominal pipe size and smaller that shall be liquid penetrant I examined during the inspection interval. I 7.4.5.4 Residual Heat Removal System Branch Pipe l Connection Welds The Residual Heat Removal System piping includes 3 branch pipe connection welds l exceeding 2 inches nominal pipe size. These  ! u welds shall be ultrasonically and liquid penetrant examined during the inspection interval. There are 2 branch pipe connection welds 2 inches nominal pipe size and smaller in the RHR System. 7.4.5.5 Safety Injection System Branch Pipe Connection Welds The Safety Injection System piping includes 5 branch pipe connection welds exceeding  ! 2 inches nominal pipe size. These welds shall be ultrasonically and liquid penetrant examined during the inspection interval. i There are 9 branch pipe connection welds l 2 inches nominal pipe size and smaller that shall be liquid penetrant examined during the inspection interval. i 1 -1 l 1 l h l SI-114.1 - REV. 9 l I , L I 1  ;

                                                                         )

                                                                                                                                                             'SQNP' SI-114.1 Page 25 of 71                                                                                                l Rev. 9                                                                                                     j
          .c                                                                                                             7.4.5.6               Upper Head Injection System Branch Pipe Connection' Welds                                                                                                 ,

i The; Upper Head Injection System piping includes 2 branch. pipe connection welds 2 inches nominal- {- pipe. size and smaller that shall be liquid penetrant examined during the: inspection interval.

             !                                                                                                                                                                                                                                                            -1
             ;                                                                                                    7.4.6 Piping Socket Welds                                                                                                                                 j 1

The entire length of each socket weld selected for , '

                                                                                                                                                                                                                                                                          ~l; examination:shall be liquid penetrant examined.                                                                                                       l i

The examinations; performed ;during-.the inspection' interval . shall include .approximately; 25 percent of the socket welds. ] l The examinations shall be distributed during the inspection l l interval.in accordance:with Table Arof Appendix A. 1 u , , 7.4.6.1 Reactor' Coolant System Piping Socket Welds; l

                                                                                                                                            'The Reactor: Coolant System pipingsincludes.

l 247 socket welds. Of these weld's, 62: welds will j be examined during the inspection interval. -3

                                                                                                                                                                                                                                                                             )

7.4.6.2 Chemical and Volume Control Systsm Piping Socket Welds l . . g The Chemical and Volume Control System piping includes 249 socket welds. Of these. welds, 62 welds will be examined during the.inspec-tion interval.. - l . . u. L' 7.4.6.3 Residual Heat Removal System Piping Socket l Welds I The Residual Heat Removal. System' piping includes

                                                                                                                                            .18 socket. welds. Of these-welds,:5: welds will-i
                                                                                                                                             .betexamined during the inspection interval.

4

                ."                                                                                                      7.4.6.4               Safety Injection System Piping Socket Welds.
          ^                                                                                                                                                                                                   '

The. Safety' Injection' System piping '~ncludes i 188 socket welds. Of these welds, 47 welds will be' examined during the inspection interval. _l: -l 6

                                                                                                                                                                                        ,8 1[L 7.4.6.5               Upper. Head: Injection System PipingiSocket-                                             a
          -+

Welds - '

                                                                                                                                                                                                                                                                          .i, C/     a;                                  I                                             '

L The > Upper Head :Inj ection t System: piping includes . in- 161 socket welds. .0f-these' welds, 4Twelds:will be examined during the inspection interval.

                                                                                                                                                                                               >..      .   -         ..                                               -~
          <~

SI-114.1 - REV. 9

         .)-

L: . .

SQNP SI-114.1 Page 26 of 71 p Rev. 9

      . 7.4.7 Piping and Valve Integrally-Welded Support Members
                                                                                      ~

Integrally-welded support members include the support. attachments of piping required to be examined by-Examination Category B-J. Included are those supports which have attachment welds to the valve and piping- <

                . pressure retaining boundary and those attachments whose support base material design thickness is 5/8 inch and greater. The entire length of each support attachment t

weld selected for examination shall be surface examined. The examinations performed during the inspection interval'. 1 shall include 100 percent of the integrally-welded support  ; members. The examinations shall.be distributed during the . I r inspection intervalJin?accordance~with Table ~A of' Appendix A. L 7.4.7.1 Reactor. Coolant System Piping and Valve l Integrally-Welded Support Memoers , s The Reactor Coola'nt System piping includes j 9 integrally-welded support members. All of these I shall be examined during the inspection interval. j 7.4.7.2 Chemical and Volume Control System Piping l and Valve Integrally-Welded Support Members l The Chemical and' Volume. Control. System. piping includes 1~ integrally-welded support member. l This support shall be examined during the l s inspection interval. i 7.4.7.3 Residual Heat Removal System Piping and Valve I u Integrally-Welded Support Members TheResidual-HeatRemoval[Systempipingincludes 4 integrally-welded support members. . These ld supports shall be examined during the inspection interval. , b . 7.4.7.4 i Safety Injection' System Piping ~and Valve-Integrally-Welded Support Members e o The Saf'ety Injection System: piping.inclu' des . 10 integrally-welded support members. All of these shall be examined during the' inspection. interval. 7.4.7.5 Upper' Head' Injection System Piping andLValve Integrally-Welded Supports s 7 The' Upper Head Injection' System piping' includes 2 integrally-welded support member. This support shall be examined during the inspection interval. . m SI-114.1 - REV. 9 l L . . _,_.______-_-_-J

[ SQNP SI-114.1 Page 27 of 71 Rev. 9 7.4.8 Piping and Valve Component Supports All piping and valve component supports of piping required' toffexaminedbyExaminationCategoryB-Jshallbevisually .; examined during the inspection interval in'accordance with visual examination methods VT-3 and VT-4 as applicable (see section 11.1). This examination includes integrally-welded 1 and nonintegrally-welded component supports. Component l supports extend from the piping and valves to.and including the attachment to the supporting structure. i The setting of snubbers, shock absorbers, and spring-type hangers shall be verified in accordance with the acceptance criteria shown in Appendix G or the applicable I

   /                work instruction. The setting of snubbers and shock                 i l    q               absorbers is performed in accordance with SNP SI-162.2 or the MI-6.13 series.                             .

The examinations shall be distributed during the-inspection interval in accordance with Table A of Appendix A. t 7.4.8.1 Reactor Coolant System Piping and Valve

                                                                                       ]

Component Supports j The Reactor Coolant System piping includes 151 component supports. All of these shall I , i be examined during the inspection interval. 7.4.8.2 Chemical and Volume Control System Piping and Valve Component Supports The Chemical and Volume Control System piping includes 125 component supports. All of these i o shall be examined-during the inspection interval. 1 l:U l 7.4.8.3 Residual Heat Removal System Piping and Valve Component Supports The Residual Heat Removal Syntem piping includes 18 component supports. All of these shall be examined during the inspection interval. l 7.4.8.4 Safety Injection System Piping and Valve Component Supports

    'e The Safety Injection System piping includes 106 component supports. All of these shall be i                              examined during the inspection interval.           l l

1 I g l L SI-114.1 - REV. 9 1

I _ i SQNP SI-114.1

,.                                   Page 28'of 71                                          l Rev. 9 r                   7.4.8.5   Upper Head Injection System and Valve Piping

.{' Component Supports , .j i

 .~                            The Upper Head Injection System piping includes
                              - 87 component supports. All of these shall be..        l examined during the inspection interval.

7.5 Reactor Coolant Pumps (4) - RCP 7.5.1 RCP Pressure Retaining Bolting Larger Than Two Inches g In Diameter i' . The. main flange on each pump: includes 24 bolts at k

   ,                4-1/2 inches in diameter.and 30-1/2 inches in length.

All of the bolts from each pump.shall be ultrason-6 ically examined,during.the' inspection interval. The. bolts may be examined in place under tension -or when. removed. All of'the bolts from one pump shall be examined during the first inspection period,.and.all- 3 of the bolts from a different pump.shall be examined during the second inspection' period. All of the- . bolting from the two remaining pumps shall be examined

                                                                                          '{

i during the third inspection period. I Removed, the bolts shall be ultrasonically and magnetic . particle. examined. This examination needs to~be performed' 3 only once during the inspection interval and may be deferred j to the third inspection period. Provisions for this examination are included in SNP MI-2.2. Where needed, the examinations of the bolts should be identified with the:

   ,                particular bolt in accordance with the unique identification-system for the bolts.                                                   i When a main flange connection is disassembled, the threads              l l4                  in the base material.and flange ligaments between threaded (j                  bolt holes shall be visually examined'in accordance with                ;

visual examination method VT-1 (see-Section 11.1). Provisions " for.this examination are included'in MI-2.2.  ! The main flange bolts are fabricated of 4340 steel,

                                                              ~
                                                                                          'I heat treated.to A-540, Gr B24'.

7.5.2 RCP Pressure Retaining Bolting 2 Inches and Smaller - in Diameter

o. .;

'g'                 Each RCP' includes two sets of pressure retaining'                      ;

bolting 2 inches and smaller in diameter. The bolting sets are the number 1 and 2 seal assembly bolting.

    ,               The number I and 2 seal assembly bolting from each pump shall be visually examined in accordance with visual examination method VT-1.(see Section 11.1).
                                                                                        ~
;                                                          SI-114.1 - REV. 9 L           .                                                       .

SQNP.: SI-114.1 Page 29.of'71'

                                                 ,  Rev.- 7L The bolting may be. examined in place under tension or~when       '

removed. It is : preferable to. perform the'. examinations: when

                                 -the bolts'are removed if the connection (s) is: disassembled."-

Removal of bolting ~is performed in accordance with MI-2.1 a. which provides for examination of the bolting. .. Where' needed, the examinations of.the bolting;should be identified-with the particular bolt'..in accordance with the unique. identification system.for the bolting. All of the-bolting from one RCP,shall be examined during

                                                        ~

j the first inspection period., and all.of the bolting from a different pump shall.be. examined.during;the second-inspection- , period. .All of the bolting from.the remaining.two_ pumps ~ '7 T! l shall^be examined during the' third inspection period. i The Number 1 and 2. seal. housing bolting includes.12 socket-hea'd cap screws'at'2 inches.in diameter, and 12 socket head. cap. screws at 1 inch in diameter. 7.5.3 RCP Integrally-Welded Support Members There are no integrally-welded support' components associated with the RCP; 7.5.4 RCP Component Supports J Each RCP includes three integrally cast pump. feet bolted to the support system. All. component supports from each pump shall be visually examined during the inspection interval j in accordance with visual examination method VT-3 (see i Section 11.1). Support components' extend from the RCP to and including the attachment.to the supporting structure. 1 1 All of the supports from one RCP shall be examined during the first inr.pection period', and all of the supports from a I j different pump shall be examined during the'second inspection. j period. All of the supports from the remaining two pumps shall be-examined during the' third inspection period. l 7.5.5 RCP Casing Welds Each RCP casing includes.a'two piece welded type 304SST- { casting. The casing welds'cannot be ultrasonically examined j and achieve meaningful results due,to limitations of. j examining integrally cast material. The entire length of i

                                 .one RCP casing weld shall be liquid penetrant examined during the inspection' interval. This examination may be-                    ;

deferred to the third inspection' period. (See-Request for .! Relief ISI-8.) I I i i f SI-114.1

SQNP SI-114.1 Page 30 of 71 Rev. 7 7.5.6 RCP Casing If a pump is disassembled for maintenance during the - inspection interval, the internal pressure boundary . surfaces shall be visually examined in accordance with visual examination method VT-1 (see Section 11.1). Disassembly of RCP's is performed in accordance with MI-2.2 and provides for these visual examinations. If during the inspection interval a pump from either unit 1-or unit 2 is not disassembled for maintenance, a pump from one unit shall be examined from the exterior by ultrasonic thickness measurements. (See Request for Relief ISI-1') 7.5.7 RCP Flywheel At approximately 3-year intervals each pump flywheel shall undergo an in-place ultrasonic examination of areas of higher stress concentration at the bore and keyway. A complete in place ultrasonic examination shall be conducted at approximately 10-year intervals along with a surface examination of exposed surfaces. (See Regulatory

                                                          ' Guide 1.14.) This examination is done in accordance with Sequoyah technical specifications and satisfies Surveillance Requirement 4.4.10.

1 The flywheel consists of 2 plates, approximately 5 inches I and 8 inches thick, bolted together. Each plate is fabricated from vacuum degassed A-533, GR. B, Class 1, steel. l l 7.6 Valves Systems including class A valves subject to examination are I identified in Section 7.4. 7.6.1 Valve Pressure Retaining Bolting Larger Than 2 Inches , in Diameter There are no valves with pressure retaining bolting larger than 2 inches in diameter. 7.6.2 Valve Pressure Retaining Bolting 2 Inches and Smaller in Diameter The following sections define the number of valves with  ; bolted bonnet connections in each system. All of the bolts , or studs and nuts in each connection shall be visually i examined during the inrpection interval in accordance with  ! visual examination method VT-1 (see Section 11.1). The examinations shall be distributed during the inspection interval in accordance with Table A of Appendix A. SI-114.1 i

SQNP SI-114.1 Page 31 of 71 Rev. 7 The bolting may be examined in place under tension or I when the bolting is removed. It is preferable to examine the bolting when removed if possible. Valve - 3 disassembly is performed in accordance with MI-6.15 _ _ _ . 1 and provides for examination of bolting. 1 7.6.2.1 Reactor Coolant System Valve Bolting The Reactor Coolant System includes 15 valves with bolted bonnet connections. 7 6.2.2 Chemical and Volume Control System Valve Bolting The Chemical and Volume Control System includes 3 valves with bolted bonnet connections. 7.6.2.3 Residual Heat Removal' System Valve Bolting i The Residual Heat Removal System includes I 6 valves with bolted bonnet conenctions. 7.6.2.4 Safety Injection System Valve Bolting The Safety Injection System includes 19 valves with bolted bonnet connections.

               ~.6.2.5 Upper Head Injection System Valve Bolting The Upper Head Injection System includes 8 valves with bolted bonnet connections.

7.6 3 Valve Integrally-Welded Support Members Examination of valve integrally-welded support members is included in Section 7.4.7. 1 7.6.4 Valve Component Supports Examination of valve component supports is included in Section 7.4.8. 7.6.5 Valve Body Welds There are no valves with body welds. 1 i , SI-114.1 l

SQNP 3I-114.1 Page 32 of 71 Rev. 7 7.6.6 Valve Bodies i The internal pressure boundary surfaces of valve bodies - exceeding 4-inch nominal pipe size shall be. visually _ _ _ . examined in accordance with visual examination method VT-1 (see Section 11.1). Examinations are limited to one valve within each group of valves that are of the same constructional design (i.e., globe, gate, or check valve), manufacturing method, and that are performing similar functions in the system. 8 When it becomes necessary to disassemble any valve, subject to internal surface visual examination, for i normal maintenance purposes, the interior surface of the valve body will be visually examined and the results recorded. Disassembly of valves solely for visual examination will not be performed (See ASME j Section XI, Table IWB-2500, Examination Category B-M-2; also see Request for Relief ISI-2). A tabulation of valves by groupings is presented in Table 1 of Appendix C. Disassembly of valves is performed in accordance with MI-11.4 and provides for i l examination of valve internal pressure boundary surfaces. l l 7.7 Exempted Components l l Components exempted from examination include component l connections, piping, and associated valves and their support that are one inch nominal pipe size and smaller, except for 1 . steam generator tubing; components connected to and part of 4 ) the reactor coolant preusure boundary (defined in 10 CFR 50,

                                                                         }g l

Section 50.2(V); revised January 1, 1975) but exempted from Class 1 requirements by regulations of the regulatory l authority having jurisdiction at the plant site; reactor .4 vessel head connections and associated piping, 2 in, nominal pipe size and smaller, made inaccessible by control rod b drive penetrations. 7.8 Successive Examinations Areas of flaw indications evaluated in accordance with IWB 3122.4 and TI-51 that qualify for continued service shall be reexamined during the next three inspection periods listed in the inspection i schedules. If the re-examinations reveal that the flaw indications remain essentially unchanged for three successive inspections, then the component examination schedule may revert to the original schedule. Exceptions to this requirement may occur when the i examination schedule is dictated by the augmented inspection l- requirements (see Section 20.0). ' SI-114.1

SQNP SI-114.1 Page 33 of 71 Rev. 7 7.9 System Pressure Tests All Class A pressure-retaining components.shall be. subjected to a- - system leakage test in accordance with IWB-5221 of ASME Section XI __ each refueling outage. This is performed in accordance with SI-146. In addition, all Class A pressure-retaining. components shall undergo a system hydrostatic pressure test in accordance with IWB-5222 of ASME Section XI at the end of the inspection interval. This is performed in accordance with SI-250. The components shall be visually examined during the pressure tests in accordance with-visual examination method VT-2 (see Section 11.1). All Class A (ASME Class 1) system pressure tests shall be performed in accordance with Program Procedure 1502.03 (DPM SEQ 82EI). 8.0 COMPONENTS SUBJECT TO EXAMINATION - TVA SAFETY CLASS B l l The Class B (ASME Class 2) components to be examined during the inspection interval are outlined in the following' paragraphs. Extent of examination piping welds will be in accordance with paragraph IWC-2411 and Table IWC-2520 of the 1974 Edition, Summer 1975 Addenda, ASME Section XI. The ISI Programs Section shall select areas to be examined or the NDE Engineering Section and Inspection Section may assist in selecting areas to be examined. Components that are exempted from examination in accordance-with IWC-1220 of ASME Section XI are discussed in Section 8.13 of this program. Where examinations specify a percentage of the total length of weld to be examined, the areas (s) examined shall be documented in the examination report. Where a percentage of weld length is not referenced, the entire weld length shall be examined. (See Request for Relief ISI-3.) Table B in Appendix A supplies additional information such as reference drawing numbers and ASMI Section XI Table-IWC-2500-1 examination categories. 8.1 Steam Generators (4) 8.1.1 Steam Generator Secondary Side Circumferential Shell Welds There are three circumferential shell welds.at gross structural discontinuities on each generator. The entire length of these three shell welds from one steam generator shall be ultrasonically examined during the inspection interval. The number of welds to be examined during each inspection period shall be in accordance with Table B of f Appendix A. 1 SI-114.1 L-_____._ _ _ _ _ _ _ _ _ _ ___________m. _ _ _ _ _ _ _ . . _ _ . . , _ _ . _ _ _ _ _ _ _ _ _ _ . _

SQNP SI-114.1 I Page 34 of 71 Rev. 7 l One of the three welds on each steam generator is partially 1 inaccessible for examination due to the upper steam generator 1 support arrangement: (weld nos. SGW-DI, D2, D3, and- D4; see - ) Request for Relief ISI-4). The weld selected for examination _ j shall be ultrasonically examined on a best-effort basis. J t The vessel shell sections are fabricated of SA-533, GR. A, I Class 1, steel plate. 8.1.2 Steam Generator Secondary Side Circumferential Head Welds Each steam generator includes a circumferential head-to- i shell weld. The entire length of one head-to-shell weld i shall be ultrasonically examined during the inspection interval in accordance with Table B of Appendix A. The

• weld selected for ' examination may be from the generator ,

selected for examination by Section 8.1.1. ) The vessel head section is fabricated 'of SA-533,. GR. = A, Class 1, steel plate. 8.1.3 Steam Generator Secondary Side Tubesheet-To-Shell Weld Each steam generator includes a tubesheet-to-shell weld. The entire length of one tubesheet-to-shell weld shall be ultrasonically examined during the inspection interval in l accordance with Table B of Appendix A. The weld selected for examination may be from the generator selected for examination by section 8.1.1 The tube plate is a SA-508, Class 2, steel forging. 8.1.4 Steam Generator Secondary Side Nozzle-To-Vessel Welds . Each steam generator includes one feedwater nozzle (3.62 inches nominal vessel thickness) and one main steam nozzle (3.62 inches nominal vessel thickners). I All of the nozzle-to-vessel welds from each generator I shall be ultrasonically and magnetic particle examined j during the inspection interval in accordance with  ;

• Table B of Appendix A. The nozzle inside radius sections '

I

                  *on each nozzle will be ultrasonically examined once during
                  *the inspection interval.                                                       )

The nozzles are fabricated of SA-508, Class 2, steel. l l o SI-114.1

SQNP SI-114.1 Page 35 of 71 Rev. 7 8.1.5 Steam Generator Secondary Side Integrally-Welded , Support Attachments There are no integrally welded vessel support attachments. -- 8.1.6 Steam Generator Secondary Side Component Supports ') J There are no component supports (including mechanical.and I hydraulic supports) which are in contact with the vessel.  ;

                                                                                                                                                              )

8.1.7 Steam Generator Secondary Side Pressure Retaining Bolting Exceeding 2 Inches in Diameter There is no steam generator secondary side bolting exceeding 2 inches in diameter. 8.2 Residual Heat Removal Heat Exchangers (2) - RERHX 8.2.1 RHRHX Circumferential Welds 8.2.1.1 RHRHX Shell Circumferential Weld-There is one circumferential shell weld l located at a gross structural discontinuity on each FOUUDC. The entire length of this shell weld from one heat exchanger shall be ultrasonically examined during each inspec- , tion interval in accordance with Table B of  ! Appendix A. The FGUUDC shell section is fabricated from SS, SA-182-F304. i i 8.2.1.2 RHRHX Head Circumferential Weld There is one circumferential head-to-shell 1 weld per FUUUDC. The entire length of one head-to-shell weld shall be ultrasonically ' examined during the inspection interval in accordance with Table B of Appendix A. The weld selected for examination may be from the heat exchanger selected for examination by section 8.2.1.1. The channel cylinder section (shell) and channel head are one inch thick fabricated from SS, SA-240, TP-304. SI-114.1

SQNP SI-114.1' Page 36 of 71 Rev. 7 8.2.1.3. RRRHX Tubesheet to Shell Weld There are no RHRHX tubesheet-to-shell welds. - 8.2.2 FuGUDC Nozzle-to-Vessel Welds The channel cylinder section of each RHRHX includes one inlet nozzle (14-inch I.D.) and one outlet nozzle (14-inch I.D.) over 1/2-inch nominal thickness. A total of four nozzle-to-vessel welds from the two FOUUDC will be ultrasonically and liquid penetrant

• examined during the inspection interval. .The nozzle

                   *inside radius sections will be ultrasonically examined
                   *during the inspection interval.

The nozzles are 2.5 inches thick, fabricated from SS, SA-240, TP-304, 8.2.3 FOUUDC Integrally-Welded Support Attachments l There are two integrally-welded support attachments l (1-inch) on each RHRHX whose base material excee'ds l 1/2-inch nominal thickness. A total of two support I pad-to-vessel welds from the FUUUDC will be liquid penetrant examined during each inspection interval in accordance with Table B of Appendix A. The welds , selected for examination may be conducted on one heat I exchanger and shall cover 100 percent of the required area of each support attachment. The support pad is fabricated from SS, SA-240, TP-304. 8.2.4 RHRHX Component Supports There are two component supports on each RHRHX which are in contact with the vessel. All component supports from each beat exchanger shall be visually examined during the inspection interval in accordance with visual examination method VT-3 (see Section 11.1). This examination includes integrally-welded and nonintegrally-welded component supports. Component supports extend from the heat exchanger to.and including the attachment to the supporting structure. The examinations shall be distributed during the inspection interval in accordance with Table B of Appendix A. SI-114.1 { *

                             .SQNP .

SI-114.1-Page'37 of'7'1 Rev. 7. x There are-no mechanical'(snubbers).and/or. hydraulic (shock absorbers) supports which are in contact with the' vessel..

   -8.2.5  'RHRHX Pressure Retaining' Bolting Exceeding 2'In'hesc         . _ - -

in Diameter There is no RHRHX bolting exceeding 2 inches in diameter. 8.3 Regenerative ' Heat Exchanger (One) - RHX 8.3.1 RHX Circumferential Welds

          .8.3.1.1    RHX Shell Circumferential Welds The regenerative heat exchanger is' composed of three heat exchangers interconnected with piping. There..are-twelve circumferential welds located in at structural discontinuity'ies on the heat exchanger; There are 'six channel cylinder to channel head welds and.there'are six tubesheet-to-shell welds.

The channel cylinder: sections are fabricated to SS, SA-351, CF8. The channel flanges are fabricated.to SS, SA-182, F304. 8.3.1.2 RHX Head Circumferential Welds There are six channel cylinder to channel head welds. Relief from' performing these examinations is requested in ISI-12. The channel heads are fabricated to SS, SA-240,. 304L. 8.3.1.3 RHX Tubesheet to Shell Weld There are six RHX tubesheet-to-shell welds. Relief from performing these exmainations-is requested in ISI-12. The tubesheet is fabricated to SA-182,-F304 SS. 8.3.2 RHX Nozzle-to-Vessel Welds There are not'any nozzles greater'than four inch . y diameter. The nozzles are fabricated to SA-479, 304 SCH 160 material.

                                                       .SI-114.1,

n SQNP SI-114.1-Page 38 of~71 Rev.. 7

       .8.3.3   RHX Integrally-Welded Supports-There are not any-integrally-welded: support attach-ments on the heat. exchanger. There'are three' stops,           _ . _ .

5/8" x 5/8" x 1-3/4" welded'to the. heat exchanger. See Request for Relief'ISI-12. 8.3.4 RHX Component Supports } There are two component supports on the regenerative. heat exchanger. See Request.for. Relief ISI-12. '

                                                                                                ]
       '8.3.5   RHX Pressure Retaining Bolting Exceeding Two Inches.                       q-in Diameter.                                                            -

l I There is not any pressure retainin' g' bolting associated- 'j with the heat exchanger.

                                                                                          -l
  *8.4  Excess Letdown Heat' Exchanger-(One)=- ELHX.                                         l  1 J

8.4.1 ELHX Circumferential Welds .] 8.4.1.1 ELHX Shell Circumferential Welds There are not any shell circumferential welds:-  ; l associated with the ELHX. ' 8.4.1.2 ELHX Head Circumferential Welds { t

                        *There is one c'ircumferential weld, the'channe'l.

l flange to channel head, located at;a structural f discontinuity on the head' side of the ELHX. -

• Relief from performing this examination is 1
• requested in'ISI-12, The channel flange and the channel head are fabricated to SA182, F316'and SA-240, TP316, respectively.

8.4.1.3 ELHX Tubesheet to Shell Weld I I . There are not any ELHX tubesheet to shell. welds. H 8.4.2 ELHX Nozzle to Vessel Weld-There are not any nozzles greater than four-inch j diameter. The' nozzles are fabricated to SA-312, 316. SI-114.1 - :i

1 SQNP  ;

                              -SI-114.1                                                      <

Page 39 of 71-Rev.'7 8.4.3 ELHX-Integrally-Welded Supports 1 There are no integrally-welded supports to the head ride _of~ the ELHX. .- 8.4.4 ELHX Component Supports i There are no component supports to the head, side of the ELHX. 8.4.5 ELHX Pressure Retaining Bolting' Exceeding Two Inches. .! in Diameter ' l The channel flange. bolting' associated with the ELHX is .I less than.two inches in diameter. . The' flange includes 12 studs with nuts at 1-5/8 inch- 3 diameter. The~ studs and nuts are' fabricated to SA-193, GRB7.and SA-194, GR2H, respectively. q

• 8.5 Boron Injection Tank (One) ' BIT 8.5.1 BIT Circumferential Welds (Shell and~ Head)

There are two circumferential head-to-shell' welds located at structural discontinuities on the BIT .l These welds shall be ultrasonically examined'during the inspection interval in accordance with Table 2 of Appendix A. The examination shall cover.100 percent of the weld length. The head and shell are SA-264 material consisting of SA-516, GR70 steel backing outside_with 1/8 inch SA-240, TP304L cladding inside. 8.5.2 BIT Nozzle-to-Vessel Welds There are two nozzles, one located on each head with a six-inch inside diameter whose nominal thickness (2.00 in.) is greater than 1/2 inch. .These nozzle to vessel welds shall be ultrasonically and surface - examined during the inspection interval in accordance with Table B of Appendix A. The examination shall cover 100 percent of the weld length. The nozzles are. fabricated to SA-350, LF2. . SI-114.1

• _ . _ _ _ . _ . _ - _ M

1 SQNP SI-114.1 l Page 40 of 71 Rev. 7 j q 8.5.3 BIT Integrally-Welded supports There are four integrally-welded support attachment pads ~ j welded to the shell, whose base material design thickness --

                                                                                          )

is 3/8 inch and therefore requires no examination in' ' accordance with Table IWC-2500-1 of ASME Section XI. k 8.5.4 BIT Component Supports I There are four component supports associate'd with the { boron injection tank. All of these supports shall be visually examined (VT-3) during the inspections interval , in accordance with Table B of Appendix A. j J 8.5.5 BIT Pressure Retaining Bolting Exceeding Two Inches I in Diameter I There are 16 manway cover studs at 2-1/2 inches in diameter. l l All 16 studs shall be ultrasonically examined during the .) inspection interval in accordance with Table B of Appendix A. 1 The studs may be examined in-place under tension or when l they are removed. It is preferrable to perform the l examinations when the studs are removed if possible. For exam documentation purposes the manway cover studs should be uniquely identified in accordance with.the following: X-BITMWCB-YY where, l X = the unit no. (1) YY = the stud no. (01 through 16) NOTE: The stud number usually corresponds to the closure torquing pattern shown in M1-6.15. Where possible this number should be stenciled on the stud i to facilitate identification. The studs and nuts are fabricated to SA-193, GRB7 and SA-194, GR2H, respectively.

 *8.6 UHI Water Accumulator (One) WA 8.6.1  WA Head and Shell Circumferential Welds-There are two circumferential welds located at struc-tural discontinuities.      These two head to shell welds                  ,

shall be ultrasonically examined during the inspection interval in accordance with Table B of Appendix A. The examinations shall cover 100 percent of the weld length. The head and shall are fabricated to SA-516-71-70. l SI-114.1 i _ _ _ ____ _ _ o

l. SQNP l SI-114.1 Page 41 of 71 Rev. 7 1 8.6.2 WA Nozzle to Vessel' Weld

                                                                                                            ~

The WA has three 12-inch nozzles whose nominal thickness , is over 1/2 inch, one on the top head and two on the bottom --- I head. These nozzles to vessel welds shall-be surface and ultrasonically examined during the inspection interval in accordance with Table B.of Appendix A. t The nozzles are fabricated to SA-350, LF2. 8.6.3 WA Integrally-Welded Supports The water accumulator:has an integrally' welded support skirt attached to the bottom head. The support skirt-to- { vessel weld hshall be surface examined during the inspection i interval in accordance with Table B of Appendix A. 'The j examination shall cover 100 percent of the weld length. 1 The integrally welded portion of the suppor skirt is l fabricated to SA-516, GR70. J 8.6.4 WA Component Supports The water accumulator has a component support skirt attached to the bottom head. The component support shall be visually examined (VT-3) during the inspection interval in accordance with Table B of Appendix A. l 8.6.5 WA Pressure Retaining Bolting Exceeding Two Inches in Diameter There are 32 manway cover studs on two manways at 2-1/2 inches in diameter-. All 32 studs shall be ultrasonically examined during the inspection interval in accordance with Table B of Appendix A. The studs may be examined in place under tension or when they are removed. It is preferrable to perform the examinations when the studs are removed if possible. For exam documentation purposes the manway cover studs should be uniquely identified in accordance with the following: , X-UHWAMWCP-Y-ZZ where; X = unit no. (1) Y = manway mark no. MH-(1 or 2) reference ISI-0070-A ZZ = stud number (01 through 16) NOTE: The stud number usually corresponds to the closure torquing pattern shown in MI-6.15. SI-114.1 E--_-----_-------------------------1------_-------- - -

                                                                                          !                          J

q d SQNP j SI-114.1- I Page 42 of 71  ! Rev. 7  ! 1 Where possible this. number should.be stenciled on the stud 'i to facilitate identification. The studs and nuts are fabricated to SA-193, GRB7 and _ SA-194, CL2H, respectively. t

 *8.7 UHI Surge Tank (One) - ST                                                  j 8.7.1   ST Head and Shell Circumferential Welds There are two circumferential welds located at structural discontinuities. These two head to shell welds shall be ultrasonically examined during the inspection interval in accordance with Table B of Appendix A. The examinations         {

l shall cover 100 percent of the weld length. { l The head and shell are. fabricated to SA-240, TP304. 8.7.2 ST Nozzle to Vessel Weld ' There are.not any nozzles greater than four-inch diameter associated with the surge tank.  : 1 The nozzles are fabricated to SA-479, TP304, and SA-182, ' F304. 8.7.3 ST Integrally-Welded Supports There are two saddle type supports pads integ.311y welded j to the shell. These pad to vessel welds shall.be surface ] examined during the inspection interval in accordance with ( Table B of Appendix A. The examination shall cover 100 .] l percent of the weld length. The support pads are fabricated to SA-240, TP304. 8.7.4 ST Component Supports There are two component supports associated with the surge tank. Both these component supports shall be visually examined (VT-3) during the inspections interval in accordance ] with Table B of Appendix A. 8.7.5 ST Pressure Retaining Bolting Exceeding Two Inches in Diameter There are not any pressure retaining bolting exceeding two , inches in diameter. There are 24 1-inch studs and nuts associated with the surge tanks two handholes. The studs and nuts are fabricated to SA-193, GRB7 and SA-194, GR2H. l SI-114.1 L .

l l SQNP SI-114.1  ! Page 43 of 71' )

 ,j                                                                                                                                                                                 Rev. 9                                                   1
         '                                                                                                                                                                                                                                    i l-                                                                                                                                                3.7.A Seal Water Injection Filters (2) SWIF.

l

                                                                                                                                                                                                                                  .        .i 8.7.A.1 SWIF Shell and Head'Circumferential Welds Each SWIF has 2.circumferential welds, one. top                         'l J]                                                                                                                                                               flange-to-shell and one bottom head-to-shell weld.                       !

8.7.A.2 SWIF Integrally Welded Supports e Each SWIF has 3 integrally welded support legs. The legs are 21 /2" x 21 /2" X /8" angle iron of SA 304 stainless steel and are exempt from examination due to their thickness being less than 1/2"- 8.8 Piping i Material specifications for each piping system are'. included in weld map isometrics in Appendix A. The following-Class B 3 piping systems are subject.to examination: ,  ! l l Residual Heat Removal l Safety Injection Main Steam , Feedwater i h Containment Spray i Upper. Head Injection- I 1 g 8.8.1 Piping and Valve Integrally-Welded Support Members { Integrally-welded support members include the support L i attachments:of pipingirequired'to be examined by Examination ] Category C-F. Included are those supports which have i attachment welds to the valve and piping pressure retaining. I boundary, and those attachments whose support base material' design thickness exceeds 3/4 inch. The entire length of l each support attachment weld selected for examination shall be surface examined. ' 1 l The examinations performed'during.the inspection interval, f: shall include 100 percent cif the integrally.-welded support

i. '

members. The examinations shall be distributed during the-l Inspection interval in accordance with Table B of-Appendix A. 8.8.1.1 Residual Heat Removal System Piping and Valve t Integrally-Welded Support: Members The Residual. Heat Removal System piping includes - 4 integrally-welded support members. All of. , these.shall be examined during the inspection interval. - - 8.8.1.2 Safety Injection System Piping and Valve Integrally-Welded' Support Members

                                                                                                                                                                                                    ~

The. Safety. Injection System piping.inc1'udes i 3 integrally-welded support members. ~A ll of i-these shall be examined during the inspection I interval. , L SI-114.1 - REV. 9 l k . .

~ SQNP I SI-114.1 .! Page 44 of 71 e Rev.'9

.-              8.8.1.3      Main Steam System Piping and Valve Integrally-          j Welded Support Members                                    i L

The Main Steam System piping includes 11 integral'ly- ' welded support members. All of these.shall-be j 1 examined during the inspection interval.-  ; 8.8.1.4 Feedwater System Piping and Valve Integrally-i I Welded Support Members i The Feedwater System piping includes 14-ir.tegrally- )' welded support members. All of these shall~be examined during the inspection interval. j 8,8.'1.5. Containment Spray System Piping and Valve Integrally-Welded Support Members J

                           ' The Containment Spray Sy' stem-piping does not include any integrally-welded support members.            ;

8.8.1.6 Upper Head Injection System Piping and Valve - Integrally-Welded Supports j The upper head injection system piping includes 4 ) i integrally-welded supports. 'All of these shall be i examined during'the inspection interval. i 8.8.2 Piping and Valve Component Supports All piping and valve component. supports shall be visually examined during the inspection interval ~in accordance with i visual examination methods VT-3 and VT-4 (see Section 11.1). This examination includes.. integrally-welded and nonintegrally-  ! welded ' component . supports . Component' supports' extend from

  ,             the piping and' valves to and including the attachment to              ;

the supporting structure. b The setting of snubbers, shock absorbers and spring-type

                                                               ~

P hangers shall be verified in accordance with the acceptance criteria shown in Appendix;G or the applicable work instruction. The setting of ' snubbers and' shock absorbers  ; c.; is performed in accordance with,the SI-162.2 or the MI 6.13 series. The examinations shall be distributed during the inspection ..i interval in accordance with: Table B of Appendix A.

  . . .         8.8.2.1     Residual Heat Removal System Piping and Valve L                             Component Supports l
    '                                      ~

The; Residual Heat Removal System pip'ing includes y 84 component supports. All"of these'shall'be examinedLduring the inspection interval. SI-114.1 - REV. 9 \ L . .

SQNP SI-114.1-Page 45 of 71 Rev. 9 8.8.2.2 Safety Injection System Piping and Valve Component Supports The Safety Injection System piping includes 55 component supports. All of these shall be examined during the inspection interval. l-8.8.2.3 Main Steam System Piping and Valve Component Supports The Main Steam System piping includes 70 component l supports. All of these shall be examined during the inspection interval. 8.8.2.4' Feedwater System Piping and Valve Component Supports The Feedwater System piping includes 34 component supports. All of these shall be examined during l the inspection interval. j 8.8.2.5 Containment Spray System Piping'and Valve Component Supports The Containment Spray System piping includes 5 component supports. All of these shall be examined during the inspection interval. 8.8.2.6 Upper Head Injection System Piping and Valve

   ,L Component Supports t

The upper head injection system piping includes 7 component supports. All of these shall be examined during the inspection interval. 8.8.3 Pressure-Retaining Bolting l I There is no Class B Pressure-Retaining Bolting larger than two inches in diameter. I <, 8.8.4 Circumferential and Longitudinal Pipe Welds 1 The entire length of each weld selected for examination . shall be ultrasonically and/or surfaced examined. Selection

    ,               of welds for examination is based on Table IWC-2520, p..

Paragraph IWC-1220, and Paragraph IWC-2411 (Summer 1975 l h Addenda). All of the welds selected shall be' examined

      '             during the inspection interval and distributed in accordance with Table B of Appendix A.

i > ( l SI-114.1 - REV. 9 l L . , l

1, '

SQNPL

SI-114.1.

                                 -Page 46 of 71 Rev. 9 L
               'Circumferential'and'1 longitudinal piping welds in piping 1

l

               ,with a nominal wall thickness of 1/2 inch or less shall be, surface examined.' Circumferential and: longitudinal piping
        '       welds in piping with a nominal wall thickness. greater than.

1/2 inch shall be' ultrasonically and surfaced examined. d' The areas subject to examination include circumferential r- Pipe welds, at structural discontinuities' within 3 ; pipe - l diameters of the. centerline of rigid pipe anchors, anchors at the penetration of primary containment or at rigidly : anchored components, and longitudinal . weld joints .in pipe.

                                                                             ~

fittings. 8.8.4.1 Residual Heat Removal Piping The Residual Heat Removal Piping System. includes- . 26 Class B circumferential and 5 Class B' longitudinal; piping welds with a nominal wall thickness greater: than 1/2 inch subject to. examination. .There:are 124 circumferential and_49 longitudinal pipeJ g welds with a' nominal wall thickness of 1/2 inch or , y less subject to examination. Seven circumferential.

                                            ~

and two longitudinal piping welds with a' nominal wall thickness greater than .1/2 inch shall bei ultrasonically and surfaced examined each inspection' interval. There are 31 circumferential and 12 longitudinal pipe welds'with a' nominal wall' ..{

   .                      thickness of 1/2 inch or,less that shall be l                      surface examined each inspection interval. See.

u Table B of Appendix- A for scheduled inspections.- 8.8.4.2 Safety Injection Piping The Safety Injection! Piping S'ystem includes 39 Class B circumferential'and 1l Class B l longitudinal piping, welds with a nominal wall thickness greater than 1/2-inch' subject to

     ,,                  examination. There are'42 circumferential and 18 longitudinal pipe welds with a nominal

t. wall thickness of 1/2~ inch or less subject to examination. Ten circumferential piping. welds

d. . .

and the one longitudinal weld with a nominal-wall thickness. greater than:1/2 inch shallobef ' ultrasonically and surface. examined.each inspection

      ,,                 interval. There are 11 circumferential and<

5 longitudinal pipe welds with'a nominal wall i O thickness of 1/2 inch or less that shall be surfaced examined each inspection interval. See. Table B of. Appendix A for for schedule inspections, w

                                                      'SI-114.1   .REV. 9                          :

1 SQNP-SI-ll4.1 Page 47 of 71  ; Rev. 8 ' 8.8.4.3 Main Steam Piping The Main Steam Piping System includes 46 Class B circumferential and 11 Class B longitudinal piping welds with a nominal wall thickness greater.than 1/2 inch subject to examination. The piping size is 32" 0.D. x 1.088 vall unless noted. ' Twelve circumferential and three longitudinal piping welds shall be ultrasonically and surfaced examined each inspection interval . TVA intends to terminate main steam C1sss B on each main' steam loop.after

        *the MSIV's (1-FCV-!-4,-II,-22,-29) for ISI purposes. See Table B of Appendix A for scheduled inspections.

8.8.4.4 Feedwater Piping The Feedwater Piping System includes 34 Class B circumferential welds and I longitudinal weld with' a nominal wall thickness greater than 1/2 inch subject to examination. The one longitudinal weld is on Loop 4 at.the reducing elbow (18" x 16"). There are 9 circumferential and the one longitudinal piping welds that shall be ultrasonically and surfaced examined each inspection interval. See-Table B of Appendix A for scheduled inspections. 8.8.4.5 Containment Spray Piping The Containment Spray Piping System includes 10 circumferential and 3 longitudinal pipe welds with a nominal wall thickness of 1/2 inch or less, subject to examination. Three circumferential and I longitudinal pipe welds shall be surface examined each inspection interval. The nominal wall thickness for the containment spray. system is 0.406 inches. See Table B of Appendix A for scheduled inspections. 8.8.4.6 Upper Head Injection Piping The upper head injection piping system includes 42 Class B circumferential welds and no Class B longitudinal piping welds with a nominal wall thickness greater than 1/2 inch subject to examination. Seven welds shall be ultrasonically and surface examined during the inspection interval. SI-ll4.1

1 SQNP SI-114.1 Page 48 of 71 Rev. 7

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8.8.5 Branch Piping Connection Welds-3 There are no Class B Branch Pipe Connection Welds. -

                                                                                                                                               )

8.9 Pumps

                                                                                                                                             .q 8.9.1  Residual Heat Remonal Pumps (2) - RHRP
                                                               -8.9.1.1              RHRP Integrally-Welded supports                           )

i There are no integrally-welded supports associated. . with the RHRP. 8.9.1.2 -RHRP Support Components Each RHRP includes three support components. bolted

• i to the pump feet which' are integrally forged with' j i the pump. All component supports from each pump

l i shall be visually examined during the inspection-interval in accordance with visual examination { method VT-3 (see Section 11.1). Support components extend from the RHRP to and including the attachment-to the supporting structure. Two of the supports from one RHRP shall be examined during the'first inspection period. The' final. (3rd) support from the same RHRP shall be examined j during the second inspection period. All of i l the supports from the remaining RHRP shall be examined during the third inspection period. l { 1 l 8.9.1.3 RHRP Supports - Mechanical and Hydraulic { l There are no mechanical and hydraulic- I l supports associated with the RHRP. 'I 8.9.1.4 RHRP Pressure Retaining Bolting l l The stuffing box extension to pump casing i l connection bolting is not greater than two inches in diameter. I

                                                                                                                                                \

' The connection includes 24 studs at 1-1/4 inches in diameter with nuts and washers. The studs are. fabricated to SA-193, GR. B7, and the nuts to SA-194, GR, 2H. 8.9.1.5 RimP Casing Welds The RimP does not include any casing' welds. The casing is a one piece forging fabricated to SA-182 F304. SI-114.1

SQNP SI-114.1 Page 49 of 71 Rev. 7 i i

                              *8.9.2    CVCS Centrifugal Charging Pumps (2) CCP-J Examination of these pumps, and their associated component ~                            ]

supports, pressure retaining bolting, and casing welds are -- exempted under previsions outlined in table IWC-2500-1 and accompanying footnotes, examination categories C-C, C-G, which limit the exam requirements to components in piping , examined under examination. category C-F. i

                            *8.9.3      Safety Injection Pumps (2) SIP
                                       - Examination of these pumps, and their associated component supports, pressure retaining bolting, and casing welds are exempted under previsions outlined in table IWC-2500-1 and accompanying footnotes, examination categories'C-C, C-G,                                j which limit the exam requirements to components in piping                                 1 examined under examination category.C-F.

8.10 Valves 8.10.1 Valve Integrally-Welded Supports Examination of valve integrally-welded support members. is included in Section 8.8.1. 8.10.2 Valve Component Supports

Examination of valve component supports is included in l

Section 8.8.2. i 8.10.3 Valve Pressure-Retaining Bolting- l There is no Class B pressure-retaining bolting greater j than 2 inches in diameter. J

i 8.10.4 Valve Body Welds There are no Class B valves with body welds.

8.11 Pressure Retaining Components l All Class B pressure retaining components in systems or portions; of systems which are not required to operate during normal reactor. , operation but for which periodic system or component functional tests i are required (excluding open-ended portions of systems), shall be l subjected to a system functional leakage test with each inspection period in accordance with IWC-5221 of ASHE Section XI. This is performed in accordance with the SI-267. series. Those Class B pressure retaining components in' systems or portions of systems-SI-114.1 i _ . . . _ _ _ _____ m._m

SQNP SI-114.1 J Page 50 of 71 Rev. 8

                                                                                                                              ]

{ u not subject to the. functional leakage tests (excluding open-ended j portions of systems), shall be subjected to a system hydrostatic test with each inspection interval in accordance with IWC-5222 of ASME Section XI. .This is performed in accordance with the SI-265 series. The components shall be visually examined during the pressure tests in accordance with visual examination method VT-2 j (see Section 11.1). 8.12 Exempted Components 8.12.1 Exempted Components (Except Piping Welds) i i

                                                            * -Components exempted from examination include:
                                                            * (a) components of systems or portions of systems that

• during normal plant operating conditions are not required
• to operate or perform a system function but remain flooded
• under static conditions at a pressure of at least 80% of
• the pressure that the component or system will be
• subjected to when required to operate; or (b) components-
• of systems or portions of systems, other than Residual
• Heat Removal Systems and Emergency Core Cooling Systems,
• that are not required to operate above a pressure of 275'
• psig or above a temperature of 200'F; or (c) component
• connections (including nozzles in vessels and pumps),
• piping and associated valves and vessels (and their
• supports) that are 4 in nominal pipe size and smaller.

8.12.2 Exempted Components (Piping Welds Only)

• Piping exempted from examination include: (a) Piping
• systems where both the design pressure and temperature are
• equal to or less than 275 psig and 200*F, respectively;

                                                            * (b) piping systems or portions of systems other than              ]

• emergency core cooling systems which do not function during
• normal reactor operation; (c) piping that is 4-inch nominal l
• pipe size and smaller.

l' 8.13 S_u_ccessive Examinations l Components with flaw indications evaluated in accordance with IWC-3000 and T1-51 that qualify for continued service shall be i reexamined during the next inspection period listed in the l inspection schedule. If the reexamination reveals that the flaw j indications remain essentially unchanged the component examination schedule may revert to the original schedule. Exceptions to this i requirement may occur when the examination schedule is dictated by l the augmented inspection requirements (see Section 20.0). I SI-114.1 __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ J

i T SQMP { SI-114.1 Page 51 of 71 l e Rev. 9

        -     9.0 COMPONENTS SUBJECT TO EXAMINATION - TVA SAFETY CLASSES C AND D                                                                      l 3

h

• Classes C and D (ASME Class 3) pressure retaining components iden-tified in sections 9.1.1 and 9.1.2 shall be visually examined, i VT-2, in conjunction with the system pressure test in accordance I with IWA-5000, IWD-2000, and IWD-5000.

1 The component supports and restraints within the boundaries iden-cI tified in sections 9.1.1 and 9.1.2 for components exceeding 4-inch 1 nominal pipe size shall be visually examined, VT-3, during each ) inspection period. 1 i Mechanical and hydraulic snubbers, spring loaded and constant. weight supports within the boundaries identified in sections 9.1.1 { and 9.1.2 for components exceeding 4-inch nominal pipe size shall j { be visually examined, VT-4 during each inspection period,. i 9.0.1 Piping and Valve Component Supports- j All piping and valve component supports shall be visually examined j during each inspection period in accordance with visual examination ' i methods VT-3 and VT-4 (see Section 11.1) This examination includes l integrally-welded and nonintegrally-welded component supports. j Component supports extend from'the piping and valves to and including j l the attachment to the supporting structure. The setting of snubbers, j l shock absorbers and spring-type hangers shall be verified in- j accordance with the acceptance, criteria shown in Appendix G or the j applicable work instruction. The examinations (100%) shall be j , conducted during each inspection period during.the inspection l interval in accordance with Table C of Appendix A. l ~ 3 l i i i l f 9.0.1.1 Auxiliary Feedwater System Piping and Valve- i Component Supports l The auxiliary feedwater system piping includes 44 . f component supports. All of these shall be L examined during each inspection period. 9.0.1.2 Chemical and Volume Control System Piping and 4 . Valve Component Supports The chemical and volume control system piping includes:eight component supports. All of:these .I shall be examined.during each inspection period. f 9.0.1.3 Component Cooling System Piping and Valve: } Ccmponent Supports-i The' component cooling system piping includes 338 L: component supports. All of these shall be examined l during each inspection period. w SI-114.1 - REV. 9 l L .

SQNP . j SI-114.1' Page 52 of.71 Rev.:7 j 1 ( -I 9.0.1.4 Containment Spray System Piping and Valve 1 Component Supports. The. containment spray system piping includes 25- ' component' supports. All of these shall be

                                                                                                                       ~~ '

examined during'each inspection' period. 9.0.1.5 Essential Raw Cooling Water System Piping and )

                                                   . Valve Component Supports.                                                  1 The essential,' raw cooling water system piping
                                                                                 .                                                 i includes 342 component supports. All of these shall be examined during each inspection' period.

9.0.1.6 Fuel Pool Cooling System Piping'and Valve Component Supports -i 1 The fuel pool cooling system piping includes 47 " component. supports. All of these shall'be examined during each inspection period. a 9.0.1.7 Residual Heat Removal System Piping and Valve ) Component Supports i l The residual- heat removal' system piping includes seven component supports. All of these shall be examined during each inspection period.' t 9.0.1.8 Safety-Injection System Piping and Valve Component Supports The safety' injection system piping includes 24' l component supports. All of these shall be' examined during each inspection period. 9.1 System Pressure Tests i

                                                                                                                                .1 9.1.1    System Inservice Tests Pressure retaining components.within the boundary of systems                  j or portions of. systems required to operate in support of                     )

normal-plant' safety functions of shutting down'and' .j maintaining ~the reactor'in the cold' shutdown condition, and- 1 pressure retaining piping, pumps,-and valves within'the s boundary or systems or portions of systems required to . j operate in support of residual' heat removal-from spent fuel  ; storage ' pool, shall be visually examined in accordance with .j visual examination method VT-2-(see section 11=.1);while the 1 applicable systems are in service under operating pressure - in accordance with IWD-5221 of ASME Section XI. This is-performed in accordance with'the'SI-267 series. < These examinations and. tests shall be_ performed during each inspection period. 1 1 4 SI-114.1 l k 1

                                                                                                                              .j

                                      .SQNP-SI-114.1                                            ,

Page 53 of.71 Rev. 7

             .9.1.2   System Functional Tests.

Pressure retaining components within the boundary of systems.or portions of systems required;to operate'in. - support of the:postaccident:safetyifunctions of. emergency core cooling, containment heat removal'and' atmospheric cleanup, and'long-term' residual ~ heat removal.from the reactor vessel shall be visually . examined in accordance with' visual: examination methodL VT-2 (see Section 11.1):during a' system. functional' test conducted'to verify operability in systems in: accordance with IWD-5222 of ASME Section XI'and in' accordance with the SI-267 s'eries. 9.1.3 System Hydrostatic Tests. Pressure retaining components identified in Sections 9.171 and 9.1.2 shall be:visuallyfexamined in accordance with visual examination method VT-2~(see Section 11.1) during'a system hydrostatic test conducted =in.accordance with IWD-5223: of-ASHE Section XI andlthe SI-265. series. .These' examinations and tests shall be ' performed over each inspection interval. 9.2 Component Supports and Restraints Component; supports and' restraints.within the boundaries.of the-systems identified in Sections.9.1.1 and 9.1.2 for; components exceeding 4-inch nominal pipe' size shall be. visually l examined each inspection period'in accordance with visual examination method VT-3'(see Section 11.1). 9.3 Snubbers and Hangers Mechanical and hydraulic snubbers, spring loaded,'and constant weight support hangers for components exceeding.4-inch nominal. pipe size shall be visually examined each inspection period in accordance with visual' examination method VT-4 (see Section 11.1.) 10.0 AUTHORIZED INSPECTOR TVA shall employ an Authorized Inspector (s) in accordance with-ASME Section XI for inservice examinations,. repairs,'and replacements of TVA Class A, B, C, and D components at Sequoyah' Nuclear Plant. The inspector shall. verify, assure, or. witness that code requirements have been met. :He'shall have the prero-gative,and authorization to require requalification of any. operator or procedure when.he has reason to believe.the requirements are not being met. TVA shall provide access for the AI in accordance with IWA-2140 of ASME Section XI. ISI-114.1

SQNP l SI-114.1 i

                                            'Page 54 of.71 Rev. 7
                                                                                                  ,        l 1

TVA's interface with the Authorized Inspector for inservice  !

• inspection, repairs, and replacements'is defined in NQAM Part II, Section 2.3 and Part II, Section 5.1 and in MI 6-21. ~

11.0 EXAMINATION METHODS 11.1 Visual Examination Visual examinations that require clean surfaces or decontamination for valid interpretation of results shall be preceded by appropriate cleaning processes. 11.1.1 Visual Examination VT-1 The VT-1 visual examination shall be conducted to determine ' the condition of the part, component,.or surface examined, s including such conditions as cracks, wear, corrosion, erosion, or physical damage on the surfaces of the part or components. I 11.1.1.1 Direct Visual Examination VT-1 j Direct VT-1 visual examination may be' conducted. when access is sufficient to place the eye 24 j inches (610 mm) of the surface to be examined and . at an a'agle not less than 30 degrees to the surface. . Mirrors may be used to improve the angle of vision.  ! Lighting, natural or artificial shall be sufficient I to resolve a 1/32 inch-(0.8 mm) black line on an i 18% neutral gray card. I 11.1.1.2 Remote Visual Examination VT-1 1 Remote VT-1 visual examination may be' substituted- I for direct examination. . Remote examination may use aids such as telescopes, borescopes, fiber i optics, cameras, or other suitable instruments provided such systems have a resolution capability ' at least equivalent to that attainable by direct visual examination. 11.1.2 Visual Examination VT-2 1 The VT-2 visual examination shall be conducted to locate evidence of leakage from pressure retaining components, or abnormal leakage from components 4 l with or without leakage collection systems as required during the conduct of system pressure or functional test. l' SI-114.1

• _. ______ _ ____ _ Q

SQNP. SI-114.1 .

                                                          ~,                                                        .]

Page 55;of 71'. Rev.~7 j 1

)

                -The visual examination, VT-2; may belconducted.

j

                -without-the: removal of insulation:by" examining the  .

1 accessible and exposed surfaces;and joints of the. - insulation. Essentially vertical. surfaces ofs - insulation need only.be' examined at"the/ lowest-elevation where leakage may be detectable. . j Essentially horizontal" surfaces ~of insulation:shall-be examined ' at' each insulation joint. 15

                                                                                                                '       I For components whose external-insulation surfaces are inaccessible for direct examination','.only the.

examinationiof surrounding. area, including floor ,'

                                                                                  ,3                                 q areas or equipment surfaces. located underneath the i

components, for evidence ~of leakage,'or other areas-

                                                                                                                    ')

to which such leakage mayLbe channeled,'shall be , required. Discoloration or residue on surfaces. examined'shall be given particular attention-to detect evidence.~of.-

                . boric acid accumulations from borated reactor                                                          i coolant leakage.                                                                                       I The visual examination shall'be conducted'during                                                       q the system: leakage' tests' conducted after refueling'.                                                i outages and prior to startup.

l VT-2 visual examination shall'be.. conducted in ' accordance with'ASME.Section-XI,'.IWA-5240 and TI-51. 11.1.3 Visual Examination VT-3 The VT-3 visual examination shall be conducted to 'l determine the general mechanical and structural'  : :! conditions of components and their; supports such as the presence of loose parts,' debris', or' abnormal corrosion products, wear, erosion,' corrosion,.and-the loss of integrity at bolted or welded connections. VT-3 may require, as applicable to determinei structural integrity, the measurement of l clearances, detection of physical displacement, h structural adequacy of supporting elements,- connections between load; carrying structural' .l members, and tightness of: bolting. For component supports and componentLinteriors, the visual examination may be. performed remotely with- 1 or without optical aids toLverify the structural integrity of the component. i i 11

                                                                                  ~

S I- 114.1.. 3 aJ

 .                                                                  ._          -    -.A. _ _ - _ _ _ _ _

SQNP S I- 114.,1 Page 56 of 71 Rev. 7 11.1.4 Visual Examination VT-4 The VT-4 visual examination shall be conducted to

• determine conditions relating to the operability of __

components or devices such as. mechanical and hydraulic snubbers, component supports, pumps, valves, and spring loaded and constant weight i hangers. VT-4 sha'11 confirm functional adequacy, verifi-cation of the settings, or freedom of motion. This examination may require (1) disassembly of components or devices and (2) operability test. 11.2 Surface Examination 11.2.1 Magnetic Particle Examination Magnetic particle examination (MT) shall be conducted in accordance with Article 7,'Section V of the ASME Code. 11.2.2 Liquid Penetrant Examination 1 Liquid penetrant examination (PT) shall be conducted in accordance with Article 6, Section V of the ASHE Code. 11.3 Volumetric Examination 11.3.1 Radiographic Examination i Radiographic techniques, employing penetrating ] radiation such as X-rays, gamma rays, or therma- 4 lized neutrons, may be utilized with appropriate ] image recording devices such as photographic film or papers, electrostatic systems, direct-image orthicons, or image converters. For radiographic examinations employing either X-ray equipment or radioactive isotopes and photographic films, the procedure shall be as specified in Article 2, Section V, of the ASME Code. 11.3.2 Ultrasonic Examination ( (a) Ultrasonic examination of Class 1 and Class 2 vessel welds in ferritic material greater than 2 inch (51 mm) in thickness shall be conducted in accordance with Article 4 of'Section V of the ASME Code and TI-51. SI-114.1

                                                                                                           )

SQNP' SI-114.1 Page 57 of 71 Rev. 7' (b) Ultrasonic examination of Class 1 and Class 2 ferritic steel piping-systems shall be_ conducted i in accordance with Appendix III, amended as follows~:

                                                                                                         ]y (1) For examination of welds, reflectors that             j produce a response greater than 50% of               '

the reference level shall be recorded.  ; 1 (c) If the requirements of.(a) and (b) above are not ( applicable, the ultrasonic examination shall be i conducted in accordance with the applicable requirements of Article 5 of Section V amended as follows: i (1) For examination on welds, reflectors that produce a response greater than 50% of the reference level shall be recorded. I (2) For examination of welds, all reflectors which l produce a response greater than 100% of the l reference level shall be investigated to the extent that the operator can determine the- 3 shape, identity, and location of all such reflectors in terms of the acceptance-rejection standards of IWA-3100(b). (3) The size of reflectors shall be measured between points which give amplitudes equal to 100% of the reference level. 11.3.3 Eddy Current Examination j Eddy current examination of heat exchanger tubing shall be 4 l conducted in accordance with the provisions of Appendix IV 1 of Section XI of the ASME Boiler and Pressure Vessel Code. 12.0 QUALIFICATIONS OF NONDESTRUCTIVE EXAMINATION PERSONNEL  ! Personnel performing nondestructive examination operations shall , be qualified in accordance with IRA-2300 of ASME Section XI implemented in Progran Procedure 0202.14 (formerly DPM N75C01), 13.0 ACCEPTANCE CRITERIA All acceptance standards for Class A, B, C, and D components shall be in accordance with IWA-3000, IWB-3000, IWC-3000, or IWD-3000 of ASME Section XI, except where ASME Section III examinations are employed to satisfy ASME Section XI requirements. l SI-114.1 i

y SQNP j SI-114.1' Page 58 of 71 Rev. 7 14.0 REPAIRS All ASME Section XI-components and their supports (ASME Classes - 1, 2, and 3) shall be' repaired in accordance with the Repair and . _ .

• Replacement Program included in NQAM Part.II, Section 2.3 and implemented by Program Procedure 1402.02 (SQ82M1) and MI 6.21.

15.0 REPLACEMENTS 1 Replacement of ASME Section XI components (ASME Classes 1,'.2, j and 3) shall be in accordance with the Repair and Replacement 1

• Program in NQAM Part II, Section 2.3 and implen.ented by Program Procedure 1402.02 (DPM SQ82M1) and MI-6.21. )

1 ASME Section XI repairs and replacements may be coordinated as j necessary with the Applications Engineering Group of the Mechanical  ! Branch. ) 16.0 RECORDS AND REPORTS 1 16.1 Recording of and Report of Examinations A detailed report of all examinations shall be prepared by the performing or responsible organization and should contain but not be limited to the following information: Title Page Table of Contents I I. Introduction - The introduction should include the .1 following information: Plant, unit number, l preservice or inservice inspection and cycle number,  ; systems, components and vessels examinations were j l performed on, organization examinations were l l performed by, dates examinations were performed, ASME Section XI Code of Record.  ! l II. Summary - The summary should include a brief I Program, description of the overall inspection: j performance, personnel, equipment, procedures, evaluations, and results. III. Discussion - The discussion should discuss the governing documents (ASME Code, Technical Specifi-cations, etc.), inspection schedule, materials, calibration standards, calibration performance,  ; reporting, recording, interpretation, and brief evaluation. SI-114.1 -

                                                                                 -____________i

a'  ;

                   ,                              SQNP;
                                                'SI-114.11 P

Page 59 of.71; Rev.s 9 : IV. Evaluation.- Evaluation 1is. based on the' indication's ' location, metal path,. general shape, and :any tests  :. that could befapplied,Jsuch as: damping. The:evalu . g ation section also should contain:a listing of each examination performed.and the evaluated;results

            ~

V. Summary of Notification:- The' summary lof notifi-cations.shall-'give'a short summary of each notifi-.

      .;                       cation report along with the indication discrepancy                                                      {

and its location.: It should also contain the. final ' i disposition and the'date of completion. VI. Scan Plan ~-;The Scan Plan shall give a detailed' ,

    . _                        description 3of all areas..: subject:to examination, during.the inspection. It shall contain'the-i following'information: -Examination'. Area, Code-                                                      '{

Category, LWeld -Size 'and/or Number; . Reference .' Drawing, Examination Method, Procedure,1 Calibration Block,and any' reference details: pertaining to the' , exam area, such as the weld' number, meridional welds, pump studs,.etc. , j VII. Weld and Hanger Map's - The' Weld >and Hanger. Maps are-the reference drawings for the: inspection. The weld > ) maps are isometric. drawings showing-the i location'of' I_ both field.and' shop welds on each~ vessel, component,. and piping system subject'to examination. LThe? U hanger maps are also isometrics showing the, location 4 of hangers, snubbers and supports for each; vessel, component, or piping system subject to' examination.: I' VIII. Log by SystemF-1Theflog.-'is.the: daily status of the.. inspection section' representative of the areas.. subject to examination'during the; inspection M This' log keeps an'up-to-date status 7of work complete and' j (.; incomplete. l .i' 39 IX. Personnel < Certifications: ' X. Equipment Certifications "^ j

             ..          XI. NDE Procedures d                                                                              '
                                                                                                                                         .q XII. Calibration Block Drawings                                          '
                                                                                                              ~

i

    .a          '                                           .~     ,    ,     ,       ; ,     8     ..

3 XIII. Calibration Sheets' 0 ' ' L., l

                     .XIV.
                                                ~

Examination Data Sheets- , +

u. - 4 g j

/  ; .t i l

        ,                                                                                                                             -i L

i - l

      -{                                                                       SI-114.1 - REVS 9                              ,q L                -
                                                                     +

__--_.__-_--__'(._ . I,

i

~

                                                                                                                                       -SQNP SI- 114 :.1 Page 60 of 71 Rev. 7 l

For eddy current examination'of heat exchanger tubing, the report. .' shall include a record indicating the tube (s) examined (this may be marked on a tube sheet sketch or drawing), the extent to which. ~ each tube was examined, the location and depth of each reported - -- indication, and the identification or the operator (s) and data evaluator (s) who conducted each examination or part thereof, and magnetic tape and strip charts. All procedures and equipment shall be identified sufficiently to permit duplication of the examination at a later date. This shall include initial. calibration data for the equipment and any . j significant changes. All required and pertinent information will be recorded on the appropriate data sheets by the performing organization. When portions of the inspection work are contracted, a detailed report-  ! will be submitted to TVA by the contractor with all pertinent and- ' required information. TVA will retain the original copies of all. raw data taken.

                                                                                                          *The MS NDE Engineering Section shall. review and submit the final
                                                                                                                                                                                                      ]

report to the Plant Superintendent for review. These final. reports.  ? shall be filed at the plant site with the data sheets of Appendix D of this program as discussed in Section 5.0 of this program. Data ) Sheet 1 in Appendix D will be completed and used as a' cover sheet for the final report and to document the review process. J 16.1.1 Repair and Replacement Reports Repairs and Replacements summary reports shall be prepared in accordance with MI 6.21. 16.2 ISI Report for Class A and B Components J

                                                                                                          *The MS NDE Engineering Section shall prepare an ISI Summary Report                           !

for Class A and B components to be submitted within 90 days after '

                                                                                                          *the completion of the inservice inspection to the Nuclear Regulatory Commission Region II Office in accordance with IWA-6220, ASME Section XI.

1 The ISI Report shall have a cover sheet providing the following l information: i s (1) Date of document completion. (2) Name and address of owner. (3) Name and address generating plant. (4) Name or number assigned to the nuclear power unit by TVA. (5) Commercial operation date for unit. 1

                                                                                                                                            -                   SI-114.1 i

e

SQNP SI-114.1 Page 61 of 71 Rev. 7 All reports shall provide the following'information as a minimum. (a.) Numbers assigned to the components by the state. -- (b.) National Board Number assigned to the components by the manufacturer. (c.) Names of the components and descriptions including size, capacity, material, location, and drawings to aid identification. (d.) Name and address of principal manufacturer (e.g., Westinghouse, GE, etc.) and the principal contract number which will identify the subcontractors. , (e.) Manufacturer's component identification numbers. (f.) Date of completion of the examination, (test, replacement, or repair), (g.) Name of ANII who witnessed or otherwise verified l the examinations, (tests, replacements, or repairs), and his employer and business address, when required. (h.) Abstract of examinations, (tests, replacements, or . repairs performed); conditions recorded; and corrective measures recommended or taken. f l 4 (i.) Signature of ANII, when required. (j.) Owner's Data Report for inservice inspection, Form NIS-1, as shown in Appendix II of ASME Section XI.

                                                                                                                          ]

(k.) Completed examination reports. (1.) Completed calibration reports. (m.) List of component drawings. ') (n.) List of TVA NDE personnel and/or copies of contractor personnel certifications. (o.) List of TVA NDE equipment and/or copies of contractors equipment certifications. (p.) List of TVA NDE procedures used and/or copies if contractor NDE procedures. i SI-114.1 1 L: - . _ . - _ _ _ _ _ - - - - - - - - - _ - - - - - - - - - - - - >

l

                                                                                                                                           'SQNP                   .
                                                                                                                                          'SI-114.1-
                                                                                                                                          'Page 62 of 71                                                             .j Rev. 7
                -                                                                                                          The NDE' Engineering Section shall submit the. inservice
       .g                                                                                                                ~

examination report to the plant. manager for retention , i - as a quality assurance record in accordance:with NQAM, Part III, Section 4.1. The-NDE Engineering Section shall maintain a copy of.the report for-

          /                                                                                                                information, and shall submit applicable summaries.

of the report with' a cover sheet as described above .! to the NRC via the' Nuclear Licensing Branch.- 1' 16.3 Records for Classes A, B, C, and D Components The plant (master files) shall assure the availability.and storage j of the following records-(1) Examination Plans and Schedules (2) Reports of. Examination Results + (3) Examination Methods'and Procedures (4) Reports of Evaluations of Results-( t (5) Reports.of Corrective Actions, Repairs,1and Replacements-16.4 Records of System Pressure Tests - , Records of the visual examinations conducted'during system l 1eakage or hydrostatic tests shall-consist of an itemi-zation of the number and location of leaks found in a i system and the corrective actions taken. I: 16.5 Augmented Examination Reports l Augmented examination special reports shall be' submitted to the y ' Nuclear Regulatory Commission Region II Office within the time  ; o period specified for each report. For. specific details'on records,  ; reports and reporting see Section'20.0, Augmented Inspections, of' 1 this program.

                  .,4 l
        ,2-                                                                                           16.6 Status of Completed Work The ISI Programs Section maintains a computer based status-listing                                        ,

of the completed work taken as credit for examinations performed -  ! over the period and interval. This listing at a minimum identifies the component examined, ASME class, exam method,.and outage period when the work was performed. This listing may:also > d be used to identify components to be inspected in the future. ,

        'Ii                                                                                                                                                                                                             !
        }                                                                                                                                                                                                            -l L-SI-114.1 - REV. 9          l
       'l                                                                                                                                                                                                              ,

t . . E _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - _ _ _ - - _ _ . - - __ ___ _ _ _ . _ _ _ _ _ _ _ _ ___o

SQNP SI-114.1 Page 63 of 71 Rev. 8 17.0 NOTIFICATION OF INDICATION Plant management shall be formally notified of the presence of unacceptable indications detected during the performance of nondestructive examinations (excluding VT-2, visual examinations performed during system pressure tests). Unacceptable indications are defined by the applicable NDE procedure. Formal notification shall consist of completing and submitting to the Plant Manager

                                                                 *or his designee the " Notification of Indication" (NOI) form in Appendix E of this program. The NOI form shall only be used to report unacceptable indications'of components within the scope of Section .XI and which have been scheduled for examination. Any other discrepancies should be reported in accordance with the appropriate plaat procedure (e.g. , MR, WR, etc.).
                                                                *NOIs initiated prior to the requirement of a Condition Adverse to Quality

• Report (CAQR) and the implementation of Revision 8 of this instruction shall

                                                                *be handled as NOIs for which no Condition Adverse to Quality has been

• identified.

                                                                *Part I of the NOI form shall be completed and signed by the NDE Level II or
                                                                *III examiner detecting the indication. The examiner detecting the indication
                                                                *can initiate a CAQR at this time or defer the decision to the individual

• responsible for the disposition in Part II of the NOI form. The NOI form and

                                                                *the CAQR are to be processed together. The ISI Group (NDE Inspection Section)

• representative shall assign a sequential number, review, and sign the NOI form. If the indication is detected by an outside contractor, the contractor's

, field supervisor or his designee shall review and sign the NOI form. A NOI log j i shall be maintained on a plant / unit 1 cycle basis by the Inspection Section 1 for each NOI issued. This log shall contain as a minimum:- NOI No., component, I.D., date issued examination report No., unsatisfactory condition, and KR/WR No, and work instruction and/or DCR numbers as applicable. The original

                                                                *shall be sent to the plant manager or his designee and a copy to the ISI

• Group (ISI Programs Section).

                                                                *In the case of N0ls for which no Condition Adverse to Quality (CAQ) has
                                                                *been identified, the nuclear site directors organization (plant manager or
                                                                *his designee) shall be responsible for determining which organization (Construction Modifications, Plant Maintenance, etc.) shall be responsible                                     !

Afor preparing a disposition in Part II of the NOI form and performing the

• associated corrective action. If the organization assigned responsibility

                                                                *f or disposition is unable to determine a satisf actory disposition, then the
                                                                *N01 form should be sent to the Mechanical Services Branch for disposition.

l

                                                                *The organization assigned responsibility for the disposition shall

• evaluate the NOI for the need of a CAQR in accordance with the NQAM

                                                               *Part I, Section 2.16 and plant instruction AI-12 (Part I).                                  The CAQR
                                                               *shall be processed in accordance with AI-12 (Part I).                                 If a CAQR is
                                                               *needed, enter the identifying number of the CAQR in the space shown on
                                                               *the NOI form. The NOI form and the CAQR are to be processed together.

l SI-114.1 i

l SQNP , SI-114.1 .j Page 64 of 71 1 Rev 8 i i l The individual responsible for preparation of the disposition shall sign f

  *and date Part II of the NOI form and ensure that the disposition agrees               j
  *with the corrective action proposed it the CAQR if one was initiated. The cognizant supervisor or his designee or the appropriate organization shall

• review and approve the disposition and sign and date Part II of the NOI j form. Copies of the form shall be distributed to the plant manager or his a designee and the ISI Programs Section. The original shall be returned to the <

  *lSI Group (NDE Inspection Section) representative. One copy shall be filed with the examination report,                                                         )j Dispositions to correct the condition under the plant maintenance program shall be processed in accordance with NQAM, Part II, Section 2.1 (see SQM-2). Dispositions other than restoring to original requirements              ,

shall be processed as modifications in accordance with NQAM, Part II, {

  *Section 3.2 (see AI-19). Repair and replacement activities, including .               ]

coordination with the Authorized Inspection Agency (AIA), shall be j performed in accordance with the requirements of NQAM, Part II, Section 2.3

 *(MI 6.21). Dispositions to accept the condition as-is shall include
 *in Part II of the NOI form the basis for the disposition. In addition for dispositions to accept the condition as-is, a USQD shall be prepared by the appropriate organization in accordance with established procedures.

The organization responsible for corrective action shall include preservice j examination requirements in the repair or replacement work instruction i described in NQAM, Part II, Section 2.3 (see MI-6.21).

 *Upon completion of corrective action,the ISI Group'(NDE Inspection Section)            {

representative shall verify completion of corrective action, enter the work '

• instruction and/or DCR numbers on the NOI form, enter the examination report ,
• number if re-examination was performed, and sign and date the NOI form,  !

 *Part III. The signed NOI form shall remain with the examination report
 *for use as a quality assurance record. If re-examination was performed,
 *a copy of the signed NOI form shall also remain with the re-examination

• report. Copies of the NOI form shall also be distributed to the plant
• manager and the ISI Group (ISI Programs Section).

l SI-114.1

SQNP SI-114.1 Pagm 65 of 71 Rev. 7 18.0 CALIBRATION BLOCKS Calibration blocks will be used for ultrasonic examinations (a calibration tube will be used for eddy current examination of steam generator tubing). The blocks will be fabricated to the ' I general requirements of ASME Section V and ASME Section XI. The blocks shall be fabricated of the material to be examined or , equivalent P numbers. Mill test reports shall be obtained and retained by the Inservice Inspection Group for all calibration blocks. The blocks shall employ drilled holes and/or notches for calibration reflectors-(See Request for Relief ISI-2). The Inspection Section shall maintain as-built calibration block drawings. Copies of the original drawings and any revisions 3 shall be submitted to the ISI Programs Section. The calibration blocks shall be stored at the plant site and maintained by the plant NDE Inspection Section personnel. 19.0 REQUESTS FOR RELIEF Where TVA has determined that certain code requirements or examinations are impractical, TVA will submit written requests for relief to NRC with information to support the determinations and any proposed alternate examinations. The impractical code requirements or examinations shall be identified in this program, and references to particular requests for relief shall be included. s When impractical examination requirements are identified in the field, the NDE Engineering or Inspection Section shall notify the ISI Programs Section such that the information may be included in l this program and requests for relief may be prepared if necessary. The Requests for Relief are listed in Appendix F. 20.0 AUGMENTED INSPECTIONS

                                         ~

Augmented inspections are performed in addition to ASME Section XI code requirements. The augmented inspections may be required

                                                    ~

by the NRC or self-imposed by TVA. l l SI-114.1

l cSQNP-SI-114.1 i

                                 .Page 661of 71                                                .i Rev.:7                               ,,

J 20.1 Feedwater Nozzle-to-Pipe Welds and Adjacent Pipe'and Nozzle' - Areas .

                                                                                             ,     l

The requirements of NRC IE Bulletin 79-13 were satisfied during!the __:

U unit 1,' cycle 1; outage. .In' order'to maintain an' effective ongoing inservice inspection program of feedwater. nozzle-to pipe welds ands adjacent pipe and nozzle areas, the following augmented inspection ; q shall be initiated. One feedwater nozzle-to-pipe weld-and; adjacent? 1 pipe and nozzle areas shall be; inspected each. refueling' outage; using ultrasonicLtesting (UT) techniques.in accordance with sensitivity requirements of IE Bulletin 83-02. This examination plan.shall-be adequate to' monitor feedwater line  ! fatigue cracking and provide a planned maintenance program. . This. 1 augmented examination is'self.imposedLby TVA (L29 840105-856).and' does not require a report. The examination data sheets-shall.be. included in the 90-day ISI report discussed in'section'16.2.of-this program, ) a 20.2 RPV Nozzle Safe Ends l The augmented examination requirements of the'RPV nozzle-to-safeL end welds are included in the final report'- Sequoyah' Nuclear-Plant - Evaluation of cracking.in reactor: vessel nozzle stainless

                                                       ~

steel buttering. The examinationsLfor unit 1'will be monitored at. the normal inservice inspection-intervals for dissimilar metal welds as required by Section'XI of the ASME Code.' This augmented examination does not require a special report. .The examination data sheets shall be included in the 90 day ISI report' discussed in-section 16.2 of this program. 20.3 Reactor Coolant Pump Flywheel

                                                         ~

The augmented examination requirements of.the reactor coolant pump flywheel are included in Regulatory Position C.4.b of Regulatory Guide 1.14; (1) an inplace ultrasonic examination of the areas of higher stress concentration at' the bore and keyway at approximately three year' intervals during the refueling or maintenance shutdown coinciding. with the inservice inspection schedule as required by Section XI of the ASME Code, and (2) a surface examination of all exposed surfaces and complete ultrasonic examination at approximately 10-year intervals'during the-plant shut-down coinciding'with the inservice inspection schedule as required by Section XI of the ASME Code. 1 1 f SI-114.1 l

SQNP SI-114.1 Page 67.of 71-Rev. 7 i This augmented examination does not require a special report unless the examination reveals a flaw. If the examination and evaluation indicate an increase in flaw ~ size or growth rate greater than predicted for the service. . _ _ . life of the flywheel, the results of the examination and:  : evaluation should be submitted to the NRC for evaluation. Refer to Regulatory Guide 1.14 for information to be j included. The examination data sheets shall be included i in the 90 day ISI report discussed in section 16.2 of this program. 4 20.4 Pressurizer Relief Line I The augmented examination requirements of the pressurizer relief _ _ { line are included in the Technical Specifications 4.0.5 and 4.4.3.2.4. The pressurizer relief line and repair welds shall be examined in ] j

                                                        *accordance with TVA procedure N-UT-25 using improved ultrasonic                        j detection and evaluation procedures prior to entering Mode 4                           I whenever the plant has been in cold shutdown for 72 hours or more if the examination has not been performed in the previous six                         j

• months. This procedure has been qualified in accordance with NRC i

                                                        *IE Bulletin 83-02 by demonstrating proficiency in detecting.                            ;
                                                        *Intergranular Stress-Crack Corrosion (IGSCC). All future                                I

• examination of the pressurizer relief line and repair welds will  !

                                                        *be performed using this procedure or a procedure demonstrated to

• equivalent or superior for detecting IGSCC.

l In the event these six-month period examinations find the i piping free of unacceptable-indications for.three successive I inspections, the inspection interval shall be extended to 1 36 month intervals (112 months to coincide with a scheduled  ; refueling outage). The report shall be submitted with the I Final Inservice Inspection Report.  ! 20.5 Steam Generator Tubing The augmented examination requirements of the steam generator l tubing are included in Technical Specifications 4.0.5, 4.4.5.0 and section 7.3.8 of this program. Following each I inservice inspection of steam generator tubes, the number of tubes plugged in each steam generator shall be reported to the NRC within 15 days. Plant management shall report this information to the Nuclear Regulatory Commission Region II Office within the time period specified. See Plant Instruction AI-18 for , reporting instructions, i j SI-114.1 U_-_-----__ - - - - - - _ . - _ - - - - .--_.__--_L__

SQNP. SI-114.1.

                                                                                                                            -Page 68 of 71 Rev. 7 The complete results.of the steam: generator tube inservice inspection'shall be submitted.to the Nuclear Regulatory Commission in a special report pursuant to Technical                  '~

Specification 6.9.2 within 12 months .following completion of the: __ inspection. The NDE Engineering Section shall" prepare this - special? report and submit the report of.the Nuclear. Regulatory Commission Region II Office:within the stated time period.' This speciali report shall include:

1. -Number and extent of tubes inspected.

2. Location and percent of wall-thickness penetration.for each indication of an imperfection.

3. Identification of' tubes plugged.

Results of steam generator tube inspections;which fall into Technical Specification Category C-3 require prompt 1 notification of the Nuclear Regulatory Commission pursuant to Technical Specification 6.9.1 prior to resumption of plant operation. The written followup of this report shall' provide.a description of investigations conducted to. determine cause of the tube' degradation and corrective measures to prevent recurrence. Refer to Technical Specifications 4.0.5 and 4.4.5.0 and sect' ion 7.3.8 of this program for information to be included. 20.6 RPV Nozzle Cladding All vessel nozzles cladding shall be ultrasonics'lly. examined at the end of each 10 year inspection interval, using techniques at least as sensitive as those used to conduct.the' supplemental examinations performed prior to fuel loading. The results of this examination shall be reported to NRC. This examination is'done in accordance with Sequoyah technical specifications and satisfies Surveillance Requirement 4.4.10. This-augmented examination does not require a special report. This examination data sheets shall be included in the 90 day ISI report discussed in section 16.2 of this program. Nozzle forging material and cladding is identified in section 7.1.2 of this program. 20.7 RPV Closure Head Circumferential Weld-(WO9-10) See subsection 7.1.1.3 of this program- for augmented examination requirements. This augmented examinationLdoes not require a special report. The examination data sheets shall be included in the 90 day ISI report discussed in section 16.2 of this. program.

                                                                                                                                  -                 SI-114..I t"         ~

SQNP SI-ll4.1 Page 69 of 71 Rev. 8 20.8 Steam Generator Feeding and J-Tubes The carbon steel J-tube nozzles have been replaced with Inconel 600 J-tube nozzles. This material is resistant to erosion corrosion damage. Inspection of the J-tube nozzles is not necessary. A ultrasonic thickness checks of the feed ring header and tee shall be performed on a frequency of every 10 years. This augmented examination is self-imposed by TVA (SOI 860515 828) and does not require a special report. The examination data' sheets shall be included in the 90-day ISI report discussed in section 16.2 of this program. ) 20.9 Control Rod Guide Tube Flexures Due to the potential of intergranular stress corrosion cracking of j guide tube flexures, the following control rod guide tube flexure j augmented examination plan shall be initiated, j i The control rod guide tube flexures shall be visually examined in i accordance with visual examination method VT-3 (see section 11.1) f during each refueling outage. These examinations shall be performed J in accordance with SMI-0-68-15. At each scheduled refueling outage k the tops of all guide tubes shall b2 visually examined to assure that all flexures are in their proper orientation. If any flexure heads are discovered to be broken from their stems, the heads should be retrieved and flexureless inserts installed. If

                              *flexureless inserts are not installed after a break has occurred, a   j safety evaluation will be required to confirm continued safe plant   j operation. A copy of the VT data sheets shall be forwarded to the    ]

appropriate cognizant engineer in the Mechanical Maintenance Section ( for enclosure in SMI-0-68-15. This augmented examination is self imposed by TVA and does not require a report. The examination data sheets shall be included in 1 the 90-day ISI report discussed in section 16.2 of this program. Any revisions ot waivers of this examination plan shall be i initiated by the Mechanical Maintenance Supervisor. ' 20.10 Rod Control Cluster Assembly (RCCA) Cladding Wear Observations As recommended in a Westinghouse memorandum to J. R. Ratliff from N. R. Metcalf, dated February 9, 1984 (Westinghouse letter No. 84TV*-G-027) visual examinations of the RCCA's will be performed during the unit 1, cycle 10 outage period. The RCCA's will be visually examined for the existence of wear ' marks on the cladding of the RCCA absorber rodlets which exceed  ; the current Westinghouse acceptance criteria for wear depth. Examination may be performed through the use of a' remote camera. SI-114.1 i m___.__________.____-_ --

l SQNP SI-114.1. Page 70 of 71 Rev. 7

                                                                                                           ~
                                                                                               .               \
                               *A random sample of'5 (approximate 10%) of the 53 RCCA's will be
                                                                         .                                     l

• examined. Determination which RCCA's to be examined.and the exact -{
• method used will be determined at a later date and based on the -

                               *available RCCA' usage data. Resolution of the camera's used'should     _ _ .

• allow for the use of an analytical model to infer,the depth of 1
• wear indications from the observed wear scar widths as measured by

                               *the use of photography.
                               *The wear indications are predominantly on the portion of the                    i

• cladding surface facing the center or hub of the RCCA at l
• elevations along the rodlet length' corresponding to the guide {
• plate surfaces. Note that, by design, some wear is expected due. t

                               *to contact between the RCCA rodlets and the guide surfaces.                    )

1

• Measurement and wear indication data should be sent to l
• Westinghouse for evalatuion. This augmented examination.is '

I

                               *self-imposed by TVA (L22 840501'803) and does not require a                    l
                               *special report. The examination data sheets shall be included in                ;

I

                               *the 90-day ISI report discussed in section 16.2 of this program.              l
                                                                                                             .1

21.0 REFERENCES

                                                                          -)

1 21.1 ASME Boiler and Pressure Vessel Code - Section XI 1974 Edition Summer 1975 addenda, 1977 Edition, Summer 1978 addenda. 21.2 ASME Boiler and Pressure Vessel Code - Section V. ' 1 21.3 Instruction Manual - 173-inch I.D. Reactor Pressure Vessel - Rotterdam Dockyard Company, Contract No. 68C60-91934, N2M-2-3. l 21.4 Sequoyah Nuclear Plant Instruction SI-1.

                                                                                                             ,i 21.5 Sequoyah Nuclear Plant Final Safety Analysis Report.                            1 L                          21.6 Westinghouse Technical Manual - Pressurizer, TM 1440-C225,                       !

Contract No. 68C60-91934, N2M-2-6. j l 21.7 Westinghouse Technical Manual - Vertical Steam Generators, TM 1440-C224, Contract No. 68C31-91934, N2M-2-4. 21.8 Westinghouse Instruction Manual - Auxiliary Heat Exchangers, Contract No. 68C60-91934, N2M-2-25. 21.9 Westinghouse Instruction Book - Reactor Coolant Pump, Contract No. 68C60-91934, N2M-2-5. 21.10 Ingersoll-Rand Instruction Manual - Residual Heat Removal Pumps,  ! i Contract No. 68C60-91934, N2M-2-30. l SI-114.1 l l

SQNP SI-114.1 Page.71 of'71 Rev. 8

  *21.11   Nuclear Quality Assurance Manual, Part II, Sections 2.3, 3.2 '5.1, and 6.3, and Part I, Sections 2.16.

21.12 Sequoyah Nuclear Plant Technical Instruction TI-51. l 21.13 Sequoyah Nuclear Plant Technical. Specifications Unit.1, 21.14 Program Procedures and Technical Standards: 0202.14'(N75C01), i l 1403 - T.S. 09.02.03 (N76A10), 1502.07 (N80E3), 1502.01-(N83A3), 1502.06 (SEQ 80M7),1502.03 (SEQ 82E1),1402.02 (GQ82MI). l 21.15 Memorandum from D. W.' Wilson to H. L. Abercrombie,Jdated I August 1, 1986 "Sequoyah Nuclear Plant.. Units 1 and 2,' " Indications in' Class 1 Welds" (L18 860730 899). l l l l l l l l 1 l SI-114.1 j 1

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 ~[._                                                              SQNP 8                                                             'SI-114.1 Page 1 of 181                                                    l 7                                                               Rev. 9 APPENDIX B LIST OF DRAWINGS - UNIT 1 Reactor Vessel
      '                                                                                                 Program Drawing No.                                       Title                                   Page No.

CH-M-2337-C Upper Head Injection System 167 } g- CH-M-2341-B Reactor Vessel Stud Locations and Details 100-101 l CH-M-2343-B Reactor Vessel Seam Welds- 102 CH-M-2358-A Reactor Vessel Closure Head 103 CH-M-2359-A Control Rod Drive Housing 104-105 l CH-M-2360-A Reactor Vessel Inlet Nozzles 106 j CH-M-2651-C CRD, UPI and Vent Pipe Penetrations 107-108  ; CH-M-2361-A Reactor Vessel Outlet Nozzles 109 { f ISI-0014-A Auxiliary Head Adapter 110 ' j ISI-0016-A Reactor Vessel Clad Patches (PSI only)' 111 MSG-0001-B Closure Head Cladding Patches (PSI only) 112 j MSG-0004-C Reactor Vessel Bottom Head Penetrations 113 i Presurizer Program " Drawing No. Title Page No. j i l CH-M-2362-A Pressurizer Support Skirt Weld 114 l CH-M-2663-A Pressurizer Seam Welds 115 ( MSG-0002-B Pressurizer and Steam Generator Cladding Patches' 116 i l MSG-0006-A Pressurizer Heater Penetrations. 117  : l f Steam Generators Program Drawing No. Title Page No. t

    ,        CH-M-2345-B          Steam Generator                                                              118 76H1                 Vertical Steam Generators Tube Sheet Arrangement                            119 g          MSG-0002-B           Pressurizer and Steam Generators Cladding Patches                            116 MSG-0005-A           Steam Generator /Feedwater Transition Spool Piece                           120 l          ISI-0134-A           Steam Generator /Feedwater Ring and J-Tubes                                 121-123 l

Heat Exchangers Program Drawing No. Title Page No. CH-M-2404-A Residual Heat Removal Heat Exchanger Channel . Welds 124 ISI-0066-A Regenerative Heat Exchanger 125-127 ISI-0067-A Excess Letdown Heat Exchanger 128 ISI-0068-A . Letdown Heat Exchanger 129 ISI-0231-B . Centrifugal Cha~rging Pump Oil & Gear Cooler 138 ISI-0235-A Safety Injection ~ Pump Oil Cooler 142 i ISI-0232-B Waste Gas Compressor Heat Exchanger 139 ISI-0230-A Gross Failed Fuel Detector Heat Exchanger 137 ISI-0229-A Positive Displacement Pump 011 Cooler 136 . m SI-114.1 APPENDIX B - REV. 9 I. l L_

                          ,                                      _97_                          .

_ _ _ _ _ - _ _ . _ _-__ _ __ m

[ SQNP h SI-114.1 Page 2 of 181 Rev. 9 APPENDIX B

LIST OF DRAWINGS'- UNIT 1 Heat Exchangers (Continued)

Program Drawing No. Title Page No. f ISI-0237-A Seal Water Heat Exchanger 144 ISI-0233-B Centrifugal Charging Pump Mechanical Seal 140 Heat Exchanger ISI-0234-C RHR Pump Seal Water Heat Exchanger 141 ISI-0236-A Safety Injection Pump Mechanical Seal 143 Heat Exchanger f ISI-0215-A Containment Spray Heat Exchanger 130 l ISI-0226-B Gas Stripper & Boric Acid Evaporator Package 132-135 ISI-0216-A Non-Regenerative Letdown Heat Exchanger , 131 7 L Piping and Valve Weld Maps Program. l Drawing No. Title Page No. CH-M-2333-B Reactor Coolant Piping (Main Loops) 145-146 CH-M-2333-C Safety Injection System -147-153 3 CH-M-2334-C Reactor Coolant System 154-160 1 CH-M-2335-C Chemical and Volume Control System ~ 161-162 j { CH-M-2336-C Residual Heat Removal System 163-166 i_ CH-M-2337-C Upper Head Injection System 167-169  : CH-M-2338-C Seal Water Injection (Chemical and Volume ' Control System) 170-173 l CH-M-2339-C Feedwater System 174-175  ! [ CH-M-2340-C Main Steam System 176-177 CH-M-2422-C Containment Spray System 178

                                                                                                                   ]

Class A and B Piping and Valve Support Drawings 'l Program

      .                  Drawing No.                        Title                             Page No. _

CH-M-2432-C Reactor Coolant System 179-185  ; CH-M-2433-C Chemical and Volume Control System- 186-187 . CH-M-2434-C Seal Water Injection (Chemical and Volume Control) 188-191 CH-M-2435-C Residual Heat Removal System _192-195 L: CH-M-2436-C Safety Injection System 196-202 CH-M-2437-C Upper Head Injection System 203-205-h CH-M-2438-C Main Steam Line System. 206-207 4 CH-M-2439-C Feedwater System 208-209-CH-M-2440-C Containment Spray System 210 k.. SI-114.1 APPENDIX B - REV. 9 l-J

E 1 t i [ SQNP SI-114.1 _ Page 3 of 181 Rev. 9 APPENDIX B a LIST OF DRAWINGS - UNIT 1 Class C and D Piping and Valve Support Drawings Program Drawing No. Title Page No. r ISI-0113-C Auxiliary Feedwater System 220-221 (see also 232, 244, and 245) ISI-0114-C Chemical and Volume Control System 222 ISI-0115-C Residual Heat Removal System 223 f ISI-0116-C ISI-0123-C Safety Injection System Essential Raw Cooling Water System 224-225 226-252 ISI-0125-C Containment Spray System . 253-254 ISI-0126-C Component Cooling Water System 255-270

       ,               ISI-0127-C   Fuel Pool' Cooling System                                271-273 i

Pumps Program-Drawing No. Title Page No. s CH-M-2675-B Reactor Coolant Pump Main Flange and Lower Seal House Bolt Pattern 211 i F MSG-0003-B Reactor Coolant Pump Casing 212 l ISI-0099-A Residual Heat Removal Pump Supports 213 ISI-0146-A Centrifugal Charging Pump Supports 274-

     ,                ISI-0147-B    Safety Injection Pump Supports                           275 ISI-0148-B Centrifugal Charging Pump Case Welds                     276 ISI-0238-A    Thermal Barrier Booster Pump                             277 Tanks Program

. Drawing No. Title Page No.

n; ISI-0069-A Boron Injection Tank (Unit 1) 214 ISI-0070-A Upperhead Injection Water Accumulator 215-216 ISI-0071-A Accumulator Surge Tank 217 i ISI-0225-A Seal Water Injection Filter 218 . ISI-0227-B Component Cooling Surge Tank 219 a r i SI-114.1' APPENDIX B - REV. 9 1

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