ML20206D342

Rev 13 to Surveillance Instruction SI-114.2, Inservice Insp Program

ML20206D342
Person / Time
Site:	Sequoyah
Issue date:	10/15/1988
From:	TENNESSEE VALLEY AUTHORITY
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ML20206D332	List: ML20206D328 ML20206D342
References
SI-114.2, NUDOCS 8811170050
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SEQUOYAH NUCLEAR PLANT PLANT INSTRUCTION REVISION LOG SURVLILLANCE INSTRUCTION SI-114.2 REVISION Date Pi. gas REASON FOR REVISION (INCLUDE COMMIT-LEVEL Approved Affected MENTS AND Al.,L ICF FORM NUM8ERS) ,

0 07/22/83 ALL ,

61, 62 1 09/02/83 231 ISI Program 2 09/27/83 Coversheet Table of '

Contents, l 28,29,33,49-52C, 62-67,74, 82,93, 95-99, 119,126,

. 130,132, 135-137, 145-148, 164-167, 176,177, -

179,180, '

183,185, 187.196 199,200, 214,215, 218, .

4 08/17/84 228-283 Rev se:

282, I 283-331 Added:

1220, -

282A thru L 4

6 09/04/84 282A67 , ,

6 05/16/8$ 264 Revised to reflect organizational changes, plant configuration changes, comply with discrepancy report SQ-DR-86-05-119R, NRC commitments CCTS control numbers: NCO-85-0284-004,  ;

NCO-86-0119-004, NCO-86-0119-003, j NCO-86-0119-002,.$nd NCO-86-0119-001, 7 10/14/86 ALL and_SPTS ltem No. 86075?A and 867012F.

0401C/1ds G811170050 0911Q9 PDR a ADOCK0500gjp3 .

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n-SEQUOYAH NUCLTAR PLANT PLANT INSTRUCTION REVISION LOG SURVEILLANCE INSTRUCTION SI-114.2 REVISION Date Pages REASON FOR REVISICiN (INCLUDE COMMITH2NTS AND l.EVEL Approved Affected ALL ICF FORM NUMBERS) 8 12/23/86 3,4 .

Revised to satisfy requirements of SPTS 860752A.

Table of Contents, i Delete Punchlist 2,4,7,9, Revised to comply with recer.t revision to NQAM, ,

15,17,t9 Part I, Section 2.16, requiring use of CAQR 46,51,63- (see SPTS Nos. 8611270 and 870119E) and to 9 02/11/87 70,272 _ correct typographical and minor errors.

Table of Contents, 4.5, 20, 21,22,16, 27.30,22, 33,36-SS 40 - 54 ,

58,62.63, Revised to add component support and welds to 73-75,39- vartous systems and deleted component support 102,105 ;and welds in others to comply with new ASME 339,341- Section XI code class boundary drawings. (SQN 404,Adeled st&rtup activity list No. 947 and CAQR No.

10 04/02/87 Punch 1 fist CHS87005). ,,_

Revised Appendix H added Appendix J (support ..

boundary), deleted Punchlist by adding seal water injection filter exam. Incorporated SPTS No. 870906B and 8710078. Incorporated ICF #

Delete 87-607 -1002, -1537, -1802,'-229B. -2344, and Punchlist CAQR No. CHS810005 and CHS 870011. The NOI form Title Chg and Section 17.0 were revised. Organizational 11 12/17/87 All _ _ changes were made.

Revised to incorporate ICF 88-0565, approved '

• 03/08/88 (OCN X 00105A, HP 0105-01); -

ICF 88-0222, approved 02/11/88 (NQAM Part II, Section 5,1, 9PlS 8709068, A71007R, and 4,51,57, 880111C); ICF 88-0117, approved 01/20/88 62,63.64, (HP 12101, ECN 6631); ICF 88-0066, approved -

69,98,105 01/15/88 (ECN 7295, HP 12687; ECN 7296.

130A.200, HP 12690; ECN 7303, HP 12710; ECN 7312, 237,241, HP 7312-01); ICF 88-0014, approved 01/10/88 242,247, (HP 12671. ECN 7293); ICF 87-2411, approved 257,258, 12/29/87 (ECN L7324, HP 732401; ECN L7293, 259,263. WP 12672; ECN L7304, HP 730401). Also. Updated 303-341, tables in Appendix H and incorporated SPTS 12 _

08/06/88 345 8806011.

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SEQUOYAH NL' CLEAR PLANT PLANT INSTRUCTION REVISION LOG SURVEILLANCE INSTRUCTION SI-114.2 REVISION Date Pages REASON FOR REVISION (INCLUDE COMMITMENTS AND LEVEL Approved Affected ALL ICF FORM NUMBERS)

This is a general revision to todr ,-a long-Title term commitment (C.1, NCO 870 036 vue) to Change; implement the accelerated field weld 1 354; program (L44 870130 304); new drawing

()(ff 1O lbbb Added: numbers, new weld counting, and miscellaneous 355-377 changes. Incorporated SPTSNo. 8805040.

13 Incorporated thimble tube guide examinations.

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SQNP ,

SI-114.2 Cover Sheet Page 1 of I Rev. 13

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Inservice Inspection Program .

Cover Sheet

, Owner: Tennessee Valley Authority Address of Corporate Office: Chattanooga Office Complex -

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 2 Commercial Operstion Date: June 1, 1982 0867e/COC4

D SQNP SI-114.2 Page 1 of 2 Rev. 13

_ TABLE OF CONTENTS Page No.

I. Prerequisites 1 II. Precautions 1 1.0 Statement of Appilcability 1 2.0 Purpose 1 3.0 Inspection Intervals and Inspection Periods 1 4.0 Codes of Record 2 5.0 Method of Implementation and Responsibilities 3 ,

t 6.0 Abbreviations and Definitions 5 7.0 Components Subject to Examination - ASHE Code Class ! (equivalent) 6 8.0 Components Subject to Examination - ASME Code Class 2 (eq91va16nt) 36 9.0 Components Subject to Examination - ASME Code Class 3 (equivalanv) 54 10.0 Authorized Inspector 65 11.0 Examination Methods 55 12.0 Qualifications of Nondestructive Examination Personnel 69 13.0 Acceptance Criteria 69 14.0 Repairs 69

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15.0 Replacements 69 16.0 Records an'd Reports 69 17.0 Notification of Indication 34 18.0 Calibration Blocks 76 19.0 Requests for Relief , 76 20.0 Augmented Inspections 76 21.0 References 82 0867e/COC4

. l SQNP 51-114.2 Page 2 of 2

. Rev. 13 l TABLE OF CONTENTS (Continued)

Pace No.

Appendix A - Tables and Drawings84-299 Appendix 8 - ------

Appendix C - Data Sheets 300 Appendix 0 - Notification of Indication Form 301 Appendix E - Requests for Relief 302-328 Appendix H - Piping Component Supports Load Criteria 329-363 Appendix ! - Guldelines for Determining Piping Component Support Examination Boundarles 364-376

• Appendix J - Commitment List for SI-114.2 377 h

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SQNP SI-114.2 Page i Rev. 13 I.. Prerequisites A. When craft support of minor or similar maintenance (Examples: ,

Scaffolding, insulation renoval', buffing of welds using scotchbrite pads, and cleaning bolts) is required to facilitate performance of this SI a single work request (HR) may be used per SQM-2.

B. Contact Radiation Control (RC) for radiation work permit (RHP), ALARA preplanning requirements. *

' Pressurizer loop seal insulation may not be removed using a generic MR.

II. Precautions A. Safety belts should be worn when working from scaffolding or ladders.

B. Protective clothing, such as long sleeve shirts or gloves, should be worn except in RWP areas when working around hot pipes and equipnient.

C. Care should be exercised when climbing on plant structures and 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.

D. Examinations should be planned to reduce delays and radiation exposure during performance of the work.

E. Read and observe all applicable precautions as indicated in SON Administrative Instru;tions (AI)-26

• Prevention of roreign Material in the Primary System" and Al-8 "Access to Containment".

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0867e/CCC4 SQNP -

SI-114.2 Page 1 of 83 Rev. 13 1.0 STATEMENT OF APPLICABILITY This program outilnes requirements for performing the first 10-year interval inservice nondestructive examinations of the Sequoyah Nuclear Plant, unit 2. ASME Code Class 1, 2, and 3 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, (NQAM) Part !!, Section 5.1 and comply as practical with the requirements of Section XI of the ASME Boller and Pressure -

Vessel Code. In addition, this program implements applicable portions of the Sequoyah Technical Specifications. The Inservice Inspection

. Program (ISI) satisfies the requirements of Surveillance Requirements 4.4.5.0, and 4.4.10, and partially satisfies the requirements of Surveillance Requirement 4.0.5 and 4.7.9. 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 (PHP 1502.07 and QHP 110.5).

2.0 PURPOSE The ISI program shall be used for planning inspections and nondestructivo examinations of the Sequoyah ASME Class 1, 2, and 3 components for the first interval. Personnel responsible for performance of the examinations should famillarize themselves with the requirements of this program prior to performing the examinations.

The examinations required by this program will establish acceptance of components for continued service.

3.0 INSPECTION INTERVALS AND INSPECTION PERIOOS The inservice examinations required by ASME Section XI shall be performed during each 10-year intery!! of service (Inspection interval). The inspection intervals represent calendar years after the .

j unit has been placed into cocynercial service. The commercial operation date for unit ? was June 1, 1982. The first 10-year interval may be decreased or execnded by as much as one year. If the unit is out of service continuously for six months or more, the inspection irterval may be extended for an equivalent period. This SL may be performed in any mode and is applicable for all operational modes.

The insoection interval shall be separated into three 'nspection l periods. Except for examinations that may be deferred to the end of the inspec'.lon Interval, the required examinattens shall be performed in i accoNance with the following schedule.

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SQNP SI-114.2 Page 2 of 83 Rev. 13 Minimum Examinations Maximum Examinations Inspection Period Comoleted. Percent Completed. Percent _

3 Years 16 34 7 Years 50 67 10 Years 100 100 On August 21, 1985 Sequoyah unit 2 went off line and it stayed off line untti Hay 13, 1988. In accordance with INA-2400(c) we will extend our first interval by 996 days. This will make our first interval end o'n February 21, 1995. The period duration will be as follows: 1) Ist period 6-1-82 thru 5-31-85, 2) 2nd period 6-1-85 thru 2-21-92, and

3) 3rd period 2-22-92 thru 2-21-95.

The examinations deferred to the end of the inspection interval shall be completed by the end of the inspection interval.

4.0 CODES OF RECORD AND CODE CASES The Sequoyah unit 2 operating Ilcense (Iow power) was issued on June 26, 1981. Thus, as a alntmum the ISI program shall not be prepared to a Section XI Code Edition and Addenda prior to the 1974 Edition.

Summer 1975 Addenda.

In accordance with 10 CFR Part 50.55a(g)(4)(lv), this program was prepared to meet the requirements of the 1977 Edition, Summer 1978 Addenda, of Section XI of the ASME Boller and Pressure Vessel Code.

Steam Generator Tubing Reporting and Examination requirements are in accordance ulth a modified version of the R5gulatory Guide 1.83, Rev.1 (Technical Specification and Survelliance Requirement 4.4.5.0). In accordance with 10 CFR Part 50.55a(b)(2), the extent of examination for piping wcIds Examination Categories 84J and C-F !s in accordance with the 1974 Edition, Summer 1975 Addenda of A!ME,Section XI (Examination

Categories B-J. C-F and C-G). Extent of examination is defined as criteria for the selection of Class 1 and Class 2 components for examin4 tion and as criteria for determining which Class 2 components may be esempt from examination. The extent of examination also specirles the location on the comporents to be examined (i.e.,1(ngth of weld).

Preservice examinations were conducted in accordance with the 1974 Edition, Summer 1975 Addenda, of the ASHE Section XI (SI-114). - -

The use of Code cases N-234 N-235, N-307-1, N-308, N-341, N-356, N-401, and N-416 have been approved by NRC, as per Regulatory Guide 1.147.

TVA can utilize Regulatory Guide 1.150, Rev.1, "Ultrasonic Testing of Reactor Vessel Welds During Preservice and Inservice Examinations" for it's examinations, r

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SQNP SI-114.2 Page 3 of 83 Rev. 13 5.0 METHOD OF y LEMENTATION AND RESPONS!8II.ITIES Weld maps and other pertinent component drawingt and tables are included in Appendix A of this program to define areas subject to examination (in addition to sections 7.0, 8.0, and 9.0).

, ONQA shall prepare scan plans using component listings supolled by the ISI Programs Section for the Inservice inspection and a list of steam generator tubes to be examined supplied by the Steam Generator Support Group for the inservice inspection. The plans should include as -

alnimum 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 DNQA and submitted

, to the Plant Manager for information. When inservice examinations are 4

Implemented by instructions other than this program (e.g. , MI's), copies of the instruction data sheets shall be submitted to ONQA by the performing organtration such that these examinations may be included in the reports discussed in Section 16.0. These additional implementing instructions are referenced in Sections 7.1.6 7.1.10, 7.2.3, 7.3.6, 7.5.1, 7.5.6, 7.6.2, and 7.6.6 of this program.

During implementation phases (usually outage periods) It may become necessary to change the scan olan. Scan plan changes can be initiated by the DNQA, the ISI Programs Section, or by other personnel involved with the implementation of the scan plan. All changes shall be ccordinated with the ISI Programs engineer in charge of the specific plant and unit for concurrence of the change and with the appropriate

plant planning and scheduling personnel for facilitating tne use of supporting craft personnel. Revisions to the scan plan shall be controllea in the same matiner as the original.

When major pcrtions of existing piping are replaced or new systems are -

added, a system walkdown shall be performed to identify tne piping

. configuration, welds, and components that will be included in the

' Inspection program. Walkdowns of individually repaired or replaced componee.ts are not a requiremwnt prior to performing the eramination.

If variations in piping configurations are discovered or modification or repairs and replacements to piping are made during the service life of the unit, these changes shall be marked on field controlled copies of .

drawings. This information shall be communicated to the IS! Programs Section which shall be resDonsible for revising the drawings and incorporating the revised drawings into this instruction. The NDE Inspection Section scan plan shall also be revised to reflect these changes.

The in-service examinations will be performed by either QA personnel or outside contractors. Contract preparation, administration, and supervision will be the responsibility of the ONQA. Inspection plans submitted by outside contractors shall be reviewed and approved by ONQA 0867e/COC4 3

'QNP 11-114.2 Page 4 of 83 Rev. 13

- prior to use. All specific NDE procedures used during the inspection program shall be reviewed and approved in accordance with NQAM Part !!,

Section 6.3. NDE procedures will be implemented in accordance with TI-51.

All snubber visual examinations required by SI-162.1 shall be coordinated through site quality organization (SQO) by the cognizant organization responsible for SI-162.1, to optimize the technict.1 specification's and the ISI snubber examinations. When the examination of a support required by SI-162.1 falls within the timeframe of an -

examination of the same support required by this procedure, both examinations shall be performed by SQO. The cognizant organization shall provide the applicable support number and the SI-162.1 data sheets to the 500. The SQO shall fill out the data sheets and return them to the cognizant organization for operability determination and inclusion in the SI-162.1 data package.

DNQA personnel will be responsible for notifying the plant manager of unacceptable indications found during inservice inspections as soon as practical. Whenever an unacceptable indication is discovered, this procedure (Section 17.0) and the form in Appendix 0 shall be uttllzed.

In those cases where an outside contractor is furnishing inservice examination services, the contractor will normally initiate the form in Appendix D under the supervision of the NDE Engineering Section representative. See Section 17.0 of this program.

When the examination is complet2d the DNQA representative shall compare the completed exam results to the requirements of the scar. plan, identify any limitations or impractical examinations, and provide notification to 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 in accordance with Section XI IHA-3000. The. result 2 shall be compared with recorded results of the preservice NDE and previous in-service NDE results. Following each refueling outage when Inservice examinations are performed, the data package cover sheet in Appendix C shall be completed by the NDE Engineering Section representative and submitted to the plant with the final report discussed in Section 16.0.

ISI program preparation is the responsibility of the IS! Programs .. ,

Section of Hechanical Services Branch. Any revisions initiated by other groups shall be submitted to the ISI Programs Section fer approval prior to incorporating the revisions into tnis program.

The ISI Programs Section maint- <" a computertzed data base system for status and Section XI credit e 11eted 15! examinations.

The ISI Progr/ms Section shall bi responsible for preparing and revising the color co'ed flow diagrams to show the ASME Section XI Code Classes 1, 2 and 3 (Equivalent).

0857e/CCC4

SONP SI-114.2 Page 5 of 83 Rev. 13 These classifications have been prepared in accordance with 10 CFR 50.2(v), Regulatory Guide 1.26 R3, ASHE Section XI and guidelines in 10 CFR 50.55a.

It must be understood that these d'awings are to be used for ASME Section XI activities only.

The ISI Programs Sect ], shall be responsible for preparing and revising the Piping Component Support Examination Boundarles (Appendix J). .

6.0 ABBREVI.ATIONS AND DEFINITIONS 6.1 AIA Authorized Inspection Agency.

6.2 A1 Authorized Inspector (may denote an ANI or AN!!).

6.3 ANI--Authorized Nuclear Inspector.

5.4 AN!!~ Authorized Nuclear Inservice Inspector.

6.5 ComWlmsnts--Denotes items in a power plant such as vessels, piping cystems, pumps, valves, and component supports.

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--Denctes verifying the performance of examinations and tests by a representative of an Authorized Inspection Agenr.j.

6.8 Norma! Operatten-Normal plant operation conditions includa reactor startup, operation at power, hot standby, and reactor cooldown to cold shutdown conditions. Test conditicns are

excluded.

6.9 Pressure-Retaining Material--Appiles to itens such as vessel heads, nozzles, pipes, tubes, fittings; valve bcdles, bonnets, oisKs, pump cm. stings, covers, and boltings which join pressure-retalning items.

6.10 Roostr--Those operations involving welding, heat treatment, or .

defect removal which are required to restore an item to a safe and satisfactory operating condition.

6.11 Replacement--Replacements include spare and renewal components, '

or parts of a component (e.g., valve body bonnet, disc, '

bolting). It also includes the addition of cceponents such as ,

valves and system changes such as rercuting of piping. For the purpose of this procedure, the term replacement shall apply where attachment to the pressure boundary is by welding or mechanical means.

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SQNP S1-114.2 Page 6 of 83 Rev. 13

-- 6.12 NOI--Notification of Indication 6.13 CAQR--Condition Adverse to Quality Report 6.14 USQO--Unresolved Safety Question Determination 6.15 NQAM--Nuclear Quality Assurance Manual 6.16 DCR--Design Change Request .

i 6.17 MR--Maintenance Request 6.18 WR--Work Request 6.19 ONQA--Olvision of Nuclear Quality Assurance 6.20 Examination Boundary Type A--The type of boundary to be used for

< those supports that are attached to building floor, walls, ceiling, or eebedded plated.

6.21 Examination Boundary Type B--The type of boundary to be used for those supports that are attached to another existing support.

6.22 Examination Boundary Type C--The type of boundary to be used for those supports that are attached to existing steel.

6.23 Examinaticn Boun_dary Type 0--The type of boundary to be used for those supports that are attached to an intervening' element.

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7.0 CCNPONENTS SUBJECT TO EXAMINATION-..ASME CODE Cli4SS 1 (EOUIVALENT)

The ASHE Code Class 1 (Equivalent) components to be examined during the 1

. inspection interval are outlined in the following paragraphs. The i

entire length of each weld described will be examined for the first 10-year ISI unlest otharwise noted. When a portion of a weld length is

to be examined during an inspection period, the areas examined each '

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inspectica period shall be documented on the examination data sheets.

t All ASME Code Class 1 components (except their supports) are subject to volumstric and/or surface examination except components (and their supports) that are one-inch nominal pipe size and smaller (see secticn .

7.7). For Code Class I compenent supports see section 7.4.3.

Table A in Appendix A supplies additional information such as reference drawing numbers and Section XI, Table IHB-2500-1, examination categories.

The following are the relutrements for additional examinations:

(a) Examinations performed during any inspection that reveal indications exceeding the allowable indications standards of  :

IHB-3000 shall be extended to include an additional number of 0867e/COC4 SONP -

SI-114.2 Page 7 o' 83 Rev. 13 c.omponents (or areas) within the same examination category, approximately equal to the number of components (or areas) examined initially during the inspection.

(b) If the additional examinations reveal further indications exceeding the allowable standards, the remaining number of

. stellar components (or areas) within the same examination category shall be examined to the extent speelfled in Table IW8-2500-1 except as modified by (c) and (d) below.

(c) Where the required piping examinations are Ilmited to one loop or branch run of an essentially symmetric piping configurations, examinations that reveal indications exceeding the allowable indications standards of IW8-3000 shall require the additional examinations of (a) above and shall be extended to include examination of a second loop or branch run to the extent spec; fled in Table IW8-2500-1.

(d) If the examination of the second loop or branch run reveals further indications exceeding the allowable standards of IW8-3000, the remaining number of loops or branch runs that perform similar functions shall 5e examined.

7.1 Reactor Vessel 7.1.1 Reactor Vessel Seam Welds .

7 1.1.1 Circumferential Shell Welds .

There are four circumferential welds (each approximately 50 feet in length) in the vessel cylindrie 'e shell, tnree of which are located behind the 'hermal shleid. The entire length '

of each of these selds will be ultrasonically examined durlog the th!rd inspection period cstng remote inspection devices from the vessel

,  !.0. with the core internals removed.

The vessel shell sectlens are machined forgings fabricated of A-508 Class 2, manganese-molybdenum steel and are clad with .

weld deposited austenttic stainless steel.

7.1.1.2 Lonaltudinal Shell Welds There are no longitudinal shell welds associated with the reactor vessel.

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SONP SI-114.2 Page 8 of 83 Rev. 13 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 ultrasonically examined from the head outside diameter. The length of weld to be examined each inspection period is included in Table A of Appendix A.

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. 8, Class 1, manganese-molybdenum steel. Both sections are clad with weld deposited austenttic 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 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 veld deposited austenttic stainless steel.

7.1.1.5 Closure Head Meridional Wel_d The closure hcAd.does not include any  !

merldlonal welds.

7.1.1.6 lower Head Meridional Wek65 There are six merldlonal welds (each approximately 4 feet in length) located in the  !

lower head. The entire length of each of these . !

welds will be ultrasonically examined during the third inspection per.od using remote ,

inspection devices from the vessel inside  !

diameter with the core Internals removed. The ,

lower head section material is identified in I section 7.1.1.4 of thi s program.

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. Rev. 13 7.1.1.7 Shell-To-Flange Weld The entire length of the shell-to-flange weld (approximately 50 feet in length) will be ultrasonically examined from the vessel inside diameter using remote inspection devices during 1 the third inspection period.

The vessel flange section is fabricated of A-508. Class 2, manganese-molybdenum steel and is clad internally and on the gasket face with weld deposited austenttic stainless steel.

7.1.1.8 Closure Head-To-Flange Weld ,

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The entire length of the head-to-flange weld (approximately 45 feet in length) will be -

manually ultrasonically examined from the head outside diameter. The length of weld to be examined each inspection period is included in Table A of Apnendix A.

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 austenttic stal,nless steel.

N 7.I.1.9 Repatr_ Welds Base metal weld repairs in the belt',ine region  ?

where the repair depth exceeds 10 Jercent  !

nominal of the vestel wall shall be ultrasonically examined. There are no base

metal repair welds in the beltline region of the unit 2 vessel.

7.1.2 ReactorVesselNozzleTo-VetselWekds There ara four inlet nozzles (27-1/2-inch I.D.) and four outlet nozzles (29.937-inch !.0.). The eight nozzle-to-vessel welds will be ultrasonically examined .

from the inside diameter using remote inspection devices.

The four outlet nozzle-to-vessel welds shall be ultrasonically examined frco the nozzle hore when the upper internals are removed during the first inspection period. The inlet nozzles are not accessible until the core barrel 15 removed. The four inlet nozzle-to-vessel welds shall be ultrasonically examined from the nozzle bore and from the vessel shell inside diarreter during the third inspection period when the core barrel has been

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SQNP SI-il4.2 Page 10 of 83

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- removed. The outlet nozzle-to-vessel welds shall also t,e ultrasonically examined from the vessel shell inside diameter during the third inspection period when the coro barrel has been removed.

1 The nozzle forgings are fabricated of A-508. Class 2, <

manganese-molybdenum steel and are clad with weld '

deposited austenttic stainless steel.

7.1.3 Reactor Vessel Nozzle Inside Radius Section

• The eight nozzle inside radius secticns (including the outlet nozzle integral extensions) shall be ,

ultrasonically examined at the same time as the examination of the nozzle-to-vessel welds conducted from the nozzle bore (see Section 7.1.2).

Nozzle forging material is identified in Section 7.1.2 of this progran.

i 7.1.4 Reactor Vessel Partial Penetration Welds The vessel includes 4 upper head injectic'1 nozzles, 1  ;

vent pipe nozzle, 78 control rod drive nozzles, and 53 instrumentation nozzles with partial penetration welds.

Approximately 25 percent of ea d group of nozzles shall ,

be visually exaatned from the vessel outside 'dlamet2r in (

accordance with visual examination method VT-2 (ste

section 11.1). This 25 percent shall triclude I upper l head injection coule,1 vent pipe no:'zle, 20 control rod i drive nozzles, and 15 Instru:rentation nozzles.

' Examination of the:e nozzles during the inspection -

interval shall be distributed among the inspection ' '

periods in accordance with. Table A of Appendix A.

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ONQA shall indicate in scan plans the no:zles requiring cramination to be performed in accordance with SI-146 or 1

51-250. The examination examination results may be t recorded on 51-146 or SI-250 data sheets.

, b 7.1.5 Reactor Vessel Nozzle-To-Safe End Weld; .. .

[

The inlet and outlet nozzle-to-safe end welds shall be ultrasonically examined from the inside diameter using remote Inspectica devices. The ultrasonic examination  !

shall be performed at the same, time as the examination of l the nozzle-to-vessel velds conducted from the nozzle bore i (see Section 7.1.2).

i All of the nozzle-to-safe end welds shall also be liquid penetrant examined during the inspection period ,

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SQNP .

SI-114.2 Page 11 of 83

. Rev. 13 coincident with the ultcasonic examinations. The Sequoyah Nuclear Plant Unit 2 Report--Evaluation of Cracking in Reactor Vessel Nozzle Stainless Steel Buttering, Unit 2 nozzle-to-safe end welds 2RC-175E and 2RC-24SE shall be examined during the first inspection interval (see memorandum from D. H. Wilson to

. H. H. Abercromble, dated 08/01/86, 1.18 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 Retainino Boltino I.aroer Than Two Inches In Diameter During each refueling outage all closure studs, nuts, and washers are removed. All of the 54 closure studs nuts, i

washers, and ligaments between the vessel flange stud holes shall be examined during the inspection interval in f

accordance with Table A of Appendix A. The closure nuts l shall be magnetic particle examined. The closure studs l shall be ultrasonically and magnetic particle examined. l The ligaments between the vessel flange stud holes shall '

be ultrasonically examined. (This provides for ,

ultrasonic examination of the threads in base m3terial.)

The closure washers shp.ll be visually examined in

accordance with vitual examinat'ons method VT-1 (see l section 11.1). The bolting ray be examined in place t under tension, when the connection is disassemoled, or j when the bolting is removed.

Provisions for this examination arte included ir. MI-1.2. '

Where needed the examinations of the studs should be L Identified with the particular stud in accordance w;th -

the unique Identification system for the studs and nuts. '

The 7-inch diameter studs, nuts, and washers are  !

, fabricated of SA-540, Gr. 823 Nickel, chreat-molybdenum I steel.

l 7.1.7 Reactor Vessel Pressure Retalnino Boltino Two Inches knd  !

Smaller 1r. Olameter I i

There is no pressure retalning tolting two inches or  !

smaller in diameter. '[

1 7.1.8 Reactor Vessel Inte1 rally Welded Attachments  !

i'  !

j. There are no integrally welded vessel supports.

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SQNP SI-114.2 Page 12 of 83

- Rev. 13 7.1.9 Reactor Vessel interior  !

The vessel interior shall be visually examined in accordance wit' visual examination method VT-3 (see -

Section 11.1). Ihese examinations shall include the space above and below the reactor core that is made accessible for examination by 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 Interva~1s.

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 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. The removal of the core support

• • ructure is implemented by HI-1.4.

7.1.11 Reactor Vessel Control Rod Orive Housings There are 78 control rod drive housings penetrating the

closure head. Each housing includes a pressure retalning

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dissimilar metal butt weld and canopy seal we'Id. The  !

canopy seal welds are exempted from volumetric or surface examination in accordance with ASHE Section XI, '

IHB-1220(a).

Thers are 20 peripheral control rod drive housings. Two l (10 percent) of the peripheral housing butt welds shall ,

be ultra nnically examined during the inspection interval in accord ete with Tdble A of Appendix A. The housings consist of 4 6" 0.0. adapter of A-182. 3045$ and a 4" 0.0. cody of $8-167.

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7.1.12 Reactor Vessel Auxiliary Head Adapters  ;

Each of the four auxillary head adapters includes a . .

pressure retalning dissimilar metal weld. The four t dissimilar metal welds shall be ultrasonically and liquid penetrant examined during the inspection interval in accordance with Table A of Appendix A. The adapters * '

consist of a SA-182. 30455 upper portlen and a 58-166  ;

lower portion. '

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SQNP S!-114.2 Page 13 of 83 Rev. 13

-. 7.2 Pressurtzer 7.2.1 Pressurizer Circumferential Shell-To-Head Welds 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.

All vessel shell and head sections are fabricattd of SA-533 Class 2, manganese-molybdenum steel and are clad with austenttic sta!ntess steel.

7.2.2 Pressurizer longitudinal Shell-To-Head Welds There is one longitudinal weld intersecting each circumferential shell-to-head weld. One foot of one longitudinal weld shall be ultrasonically examined during the inspection periods in accordance with Table A of Appendix A. The 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 CireWerential and Meridional _ Head Welds There are no pressurizer circumferential or meridional head welds.

7.2.4 Pressurizer Nozzle-To-Vessel Welds and No221e Inside Radius Section The pressurizer includes three 6-Inch safety vahe nozzles, one 6-inch relief valve nozzle, one 4-inch nozzle, and one 14-inch surge nozzle. All of the nozzle-to-vessel welds, including nozzle inside radius section, shall be ultrasonically examined during the . .

Inspection interval in accordance with Table A cf Appendix A.

The nozzles are fabricated of SA-508. Class 2, manganese-mlybdenum steel.

7.2.5 P_ressurizer Heater penetration Welds There are 78 heater penetration welds located in the pressuriter lower head. Approximately 25 percent of the 0357e/COC4

SQNP 51-114.2 Page 14 of 83

. Rev. 13 heater penetration welds (20 welds) shall be visually examined during the inspection interval in accordance with visual examination method VT-2 (see Section 11.1).

Examination of these penetrations during the inspection Interval shall be distributed among the Inspection periods in accordance with Table A of Appendix A.

ONQA shall designate in scan plans the N eer penetrations requiring examination c .a that the organization performing the eFdnations may document

• examination results on SE.146 or 51-250 data sheets.

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 Appendix A. Safe end connections are SA-182. Gr. F-316L forgings.

7.2.7 Pressurizer Pressure Retalning Bolting larger Than Two Inches in Olameter There is no pressure retalning bolting larger than two inches in diameter. ,

7.2.8 Pressurizer Pressure Retaining Bolting Two' Inches Ag

'Smil p r in Diameter All of the pressurizer manway bolts shall be visually examinad 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 Appenjit A. The bolts may be osaminej in place under tension ?,r when the bolts are remnved. It is preferrable A perform the examinations when the bolts 1

are removed if possible. Removal of the manway cover is performed in accordance with HI-4.5 and provides for exarination of bolting.

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. The manway includes 16 bolts at 1.88 inches in diameter.

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.

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SQNP l S1-114.2 1 Page 15 of 83 Rev. 13 '

The support skirt is approximately L , Inches thick and is fabricated of SA-516, Gr. 70, caroon steel plate.

i 7.3 Steam Generators (4) 7.3.1 Steam Generator Primary Side Circumferential And ,

Meridional Head Helds i 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 examinto 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. .

7.3.3 Steam Generator Primery Notzle-To-Vessel Welds And Nozzle Inside Radius Section  ;

The steam generator primary nozzles are an lategral part of the vessel. The inner radius exan w111 be started 4

during the second interval (see request for relief ISI-6).

The nozzles are fabricated to SA-216. Gr. WCC. ,

7.3.4 Steam Generator Primary Nozzle-To-Safe fnd Welds Each steam generator includos two nozzles with buttered safe ends. Each nozzle-to-safe end weld from each generator shall be ultrasonically and liquid penetrant . ,

examined during the inspection ' m+.... n accordance  !

with Table A of Appendix A.  :

O The nozzles have buttered 308L safe ends.

l 7.3.5 Steam Generator primary Pressure Retaining _ Bolting larger

• Than two Inches in Diameter

• There is no pressure retalning botting larger than two inches in diameter. '

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S1-114.2 Page 16 of 83

, Rev. 13 7.3.6 Steam Generator Primary Pressure Retaining Bolting Two Inches And Smaller In Olameter 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 bolts are removed. It is preferrable to perform the examinations when the bolts are removed if possible.

Removal of bolting is performed in accordance with HI-3.1 and provides for examination of bolting.

Each manway includes 16 bolts at 1.88 inches to diameter.

7.3.7 Steam Generator Primary Integrally Welded Support Attachments There are no integrally welded vessel supports. The four main support pads are secured to the steam generator fleid support system by high strength bolts.

7.3.8 S_ team Generator Tubing Each steam generater tube bundle consists of 3.388 NICrFe alley (Inconel 58-163) IJ-tubes of 0.875 0.0. 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 tect9tcal spec'.ftcations and satisfies Surveillance Pequirement 4.4.5.0. The initial and aaditional samples (as required) lists identifying the~ steam generator tubes to be examined shall be created and supplied by the Steam Generator Support Group to the ONQA for inclusion In the Sean Plans.

7. 3. 8.1 Steam Generator Suple Selection And inspection Each steam generator shall be determined operable during the shutdown by selecting and inspecting at least the minimum number of steam generators specified in Table 1 of Appenjix A.

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S1-114.2 Page 17 of 83 Rev. 13 n

- 7.3.8.2 Steam Generator Tube Sample Selection and

nspection l

The steam generator tube minimum sample size inspection result classification, and the '

corresponding ac ;on required shall be as specified in Ta' a 2 of Appendix A. The full length of the it;Js selected for inspection .

will be examined (TVA cognitment to NRC  !

L44 850617 401). The inservice inspection of steam generator tubes shall be performed at the ,

frequencies specified in Section 7.3.8.3, and l the inspected tubes shall be vertfled acceptable per the acceptance triteria of 7 section 7.3.8.4. Inspection of tubes shall '

include the entire length of the tube. Note i that the hot leg inspection sample and the cold i leg inspection sample do not necessarily i involve the same tube, l.e., it does not '

preclude saking 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 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 these ,

inspections shall be selected on a randem basis  ;

except: -

l i

a. Where experletice in $1milar plants with i similar water chemistry indicates critical  !

areas to be inspected, then at least 50% of i the tubes inspected shall be from these '

erltical areas.

b. The first ';3'Aoie of tubes $414cted for each l Inspection isubnquent to the preservice i inspection) of Jach steam generator shall include:

1. All nonplugged tubes that previously , i had detectable wall penetrations >20%.

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2. Tubes in those areas where experience  ;

has indicated potential prchlems.- -

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3. A tube inspec'tlon (pursuant to Section i 7.3.8.4.a.8) shall be performed on each  !

selected tube. If any selected tube  !

does not permt t the passage of the eddy current probe for a tube inspection,

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SONP SI-114.2 Page 18 of 83 Rev. 13 this shall be evaluated and recorded and an adjacent tube shall be selected and subjected to a tube inspection.

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 .

proylded: .

1. The tubes selected for these samples  ;

include the tubes from those areas of '

the tube sheet array where tubes with imperfections were previously found.

2. The inspections include those portions of the tubes where imperfections were .

previously found.

The results of each sample inspection shall be classified into one of the following three categories:

Category Insoection Results C-1 Less than 5% of the total tubes inspected are degraded tubes and none'of the inspected tubes are defective.

C2 One or more tubes, but not more tha- 1% of the total a tubes inspected are **

i defective, or between 5% and  !

10% of the total tubes Ingpected are degraded tubes.

t C-3 Nore than 10% of the total t'Jbes inspected are degraded ,

i tubes or more than 1% of the  !

Inspected tubes are defective. .  !

(

NOTE: In all inspections, previously degraded  !

tubas must cahlbit significant 010%) '

further wall penetrations to be -

included in the above percentage ' '

calculations. ,

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SQNP SI-114.2 Page 19 of 83 '

Rev. 13 7.3.8.3 Inspection Frequencies The above required inservice inspections of steam generators shall be performed at  :

frequencies Indicated in the following paragraphs Lnd 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 months 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 cbserved degradation has not continued and no additional degradation has occurred, the inspection interval may be extended to a ,.

maximum of once per 40 months. * '

b. If the resuits of the inservice Inspection of a steam generator conducted in accordance with Table 2 at 40-month Intervals fall Ir Category C-3, the ,

Inspection frequency shall be increased to l 4 at least once per 20 months. The increase l l in inspection frequency shall apply until [

, the subsequent inspections satisfy the criteria of section 7.3.8.3.a: the interval l may tha be extended to a maximum of once  !

per 40 months. j

' c. Additional, unscheduled intervice .. . [

inspections shall be performed on each steam generator in accordance with the '

first sample inspection specified in Table 2 of Appendix A during the shutdown -

i subsequent to any of the following '

conditions, i

1. Primary-to-secondary tubes leaks (not j including leaks originating from  ;

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SONP -

51-114.2 Page 20 of 83 Rev. 13 tube-to-tube sheet welds) in excess of the ilmi'. of Technical Specification 3.4.6.2.

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

2. A loss-of-coolant accident requiring actuaiian of the engineered safeguards.

4. A main steam line or feedwater line <

break.

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 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

ra:Alng, wastage, wear ~ro general corro',lon occurring on either inside or outside of a tube.

3. Degraded Tube means a tube containing imperfections >20% of the nominal wall "

thickness caused by degradation.

4. g gpnt Oeoradation means ths O

percentage or' the tube wall thickness affected or removed by degradation.

5. Defect means an leperfection of such severity that it exceeds the plugging .

limit. A tube containing a defect is defective.

6. Pluccina Limit means the imperfection ceptn at or beyond which the tube shall be reeoved from service because it may be:ome unserviceable prior to the nert inspection and is equal to 4% of the nominal tube wall thickness.

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SQNP  !

SI-114.2 Page 21 of 83 Rev. 13

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, a l loss-of-coolant accident, or a steam  ;

line or feedwater line break as i specified in Sectic.t 7.3.8.3.c. l l

8. Tube inspection means an inspection of i the steam generator tube from "le point {

of entry (hot leg side) ccepletely i around the U-bend to the point of exit j (cold leg side) 1.e., tube end to tube  ;

end. Entries uay be made from either j the hot or cold leg sides and separate  !

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

9. Preservice Inspection means a tube inspection of each steam generator tube performed by eddy current techniques l prior to service to establish a l

• baseline condition of the tubiny. This i Inspection shall be performed prior to initial power operation using the equipment and techniques expected to be used during subsequent inservice inspections.

b. The steam generator shall be determined operable after completing the corresponding 'l 4

actions (plug all tubes exceeding the l plugging limit and all tubes containing i

through-wall cracks) required by Table 2.

7,4 Ploino i 4

All ASME Code Class I 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 auxillary head adapter is included in 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 151-3).

l The following C; ass 1 piping systems aie subject to examination: l l

Reactor Coolant I Chemical and Volume Control Residual Heat Removal 0867e/CCC4

SONP SI-114.2 Page 22 of 83 Rev. 13

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Safety Injection Upper Head Injection 7.4.1 Piping Olssimilac Metal Welds

, There are no Class 1 dissimilar metal welds.

7.4.2 Ploing Pressure Retaining Bolting ' groer Than 2 inches in 01ameter .

There is no piping pressure retalning bolting larger than 2 inches in diameter. .

7.4.3 Piping Pressure Retaining Bolting 2 Inches and Smaller in

,0tameter The following sections de Ine the number of bolted piping flange connections in eaci system. All of the bolts or studs and nuts ta each flange connection shall be visually examined during the inspection interval in accordance with visual examinatien method VT-1 (See Section 11.1). The examinations shall be distributed during the inspection interval ta acce,rdance with Table A of Appendix A.

The bolting may be examined in place under tension or when the bolting is removed.

7.4.3.1 Reactor Coolant Sygrem Piping Boltina The Reactor Coolant System piping includes bolted flange conrections. ' '

7.4.3.2 Chemical and Voieme Control System Plotna Bolting The Chem; cal ane Volume Control System piping includes oolted f'ange connections (from seal water injection-7.4.3.3 Residual Heat Re noval Systen Ploina Bolting The Retidual Heat Removal System piping does not include any bolted connectisns.

7.4.3.4 Safety injection System Picing Boltina The Safety Injection System piping includes bolted flange connections.

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SONP SI-114.2 Page 23 of 83 Rev. 13

- 7.4.3.5 Upper Head Injection System Piping Boltino The Upper Head Injection System piping includes

,, bolted grayloc connectors.

7.4.4 Ctrcumferential and I.onettudinal Ploe Welds The entire length of each circumferential pipe weld selected for examination shall be ultrasonically and/or Ilquid penetrant examined as practical. All Class 1 -

piping is seamless.

Circumferential pipe welds four inches and greater nominal pipe size shall be ultrasonically and liquid penetrant examined. Circumferential pipe welds less th.n four-inen nominal pipe size shall be liquid penetrant examined. ,

The examinations parformed during the inspection interval >

shall include approximately 25 percent of the 40-year ,

sa'rple of circumferential welds. The examinations shall be distributed during the inspection interval in accordance with Table A of Appendix A.

7.4.4.1 Reactor Coolant System Main 1.000 Ploino-Circumferential Pelds ,

Tne Reactor Coolant System main loop piping includes circumferential pipe welds A Inches and greater nominal pipe size. The welds selected for examination shall be ultrasonically and 11guld penetrant examined in accordance with Table A of Appendix A during -

the inspection inc3rval (see Request for Relief ISI-7).

7.4 4.2 Reactor Coolant System Ptolno circumferentiat Eields I

Reactor Coolant System piping inc' circumferential pipe welds 4 inche, . greater ,

nominal pipe size. The welds selected for '

examination shall be ultrasonically and liquid penetrant examined during the inspection inter- i val in accordance with Table A of Apptndix i -

3 There are pipe welds.less than 4-inch nominal .

pipe size. The welds selected for examination I shall be Ilquid penetrant examined during the  :

Inspection interval in accordance with Table A  :

of Appendix A.

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SI-114.2 Page 24 of 83

. Rev. 13 7.4.4.3 Chemical and Volume Cetrol Syttem Pipino Circumferential Welds The Chemical and Volume Control System piping (including seal water injection) includes circumferential welds less than 4-loch nominal pipe size. The welds selected for examination shall be Ilquid penetrant examined during the inspection interval in accordance with Table A of Appendix A. There are no class I pipe welds 4 inches and greater in the CVC5 system.

7.4.4.4 Residual Heat Removal System Ploing Circumferential Helds The Residual Heat Removal System piping includes circumferential welds 4 inches and greater nominal pipe size. The welds selected for examination shall be ultrasonically and liquid penetrant examined during the inspection interval in acLordance with Table A of Appe.idix A. There are no Class I pipe welds less than 4-inch nominal pipe si:e in the RHR system.

7.4.4.5 Safety Injection System Ploine Circumferential Welds

• The Safety Injection System piping includes circumferential pipe welds 4 inches and greater nominal pipe size. The welds selected for examination shall be ultrasonically and liquid penetrant examined during the inspection inter- -

val in accordance with Table A of Appendix A.

There are pipe welds less than 4-Inch nominal pipe size. The welds selected for 2: amination shall be 11guld penetrant examined during the inspection interval in accordance with Table A of Appendix A.

7.4.4.6 Upper Head injection System Pipinq , ,

Circumferential Welds The Upper Head Injection System piping includes circumfereiitial pipe welds 4 inches and greater nccinal pipe size. The welds selected for examinition shall be ultrasonically and 11guld penetrant examined during the inspection inter-val in accordance wit.: Table A of Appendix A.

There are no piping welds less than 4-inch nominal pipe size.

0257e/COC4

SQNP SI-114.2 Page 25 of 83 Rev. 13 7.4.5 Branch Ptolna Connec'clon Welds The entire length of each branch pipe connection veld selected for examination shall be examined. Branch pipe connection welds exceeding 2 inchas nominal pipe size shall be ultrasonically and liquid penetrant examined.

Branch pipe connection welds 2 inches 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 be distributed during the inspection interval in accordance with Table A of Appendix A.

In the case of branch pipe connections 2 inches nominal pipe size and smaller the welds of all the systems affected have been added and shall be evenly distributed over the four intervals. There are 36 welds and TVA shall do 9 welds per interva' 7.4.5.1 Reactor Coolant System Main loop Branch Pipe Connection Heids The Reactor Coolant System Main Loop piping includes branch pipe connection welds exceeding 2 inches nominal pip, size. The welds selected for examination shall be ultrasonic' ally and liquid penetrant examined during'the inspection Interval in accordance with Table A of Apper. dix A. There are branch pipe connection welds 2 inches nominal pipe size and smaller. The welds selected for examination shall be 11guld penetrar.t examined during the inspection Inter- -

val in accordance with Table A of Apr adix A.

NOTE: Each of these branch pipe connections 2 inches nominal pipe size and smaller has a special boss. This is a special boss for use with temperature elements with outside diameter (00) of 0.875". The special boss has an 00 = 2 1/2" : .01 with an inside diameter (JD) .

of 0.9" reamed to provide 0.015" - 0.020" clearance with i 0.010" misalignment. Assuming the worst possible case (the weld to pipe falls) the largest hole is < that for a 2" plee (any schedule). Therefore, we shall treat it as a 12" branch pipe for ASHE Section XI purposes. See contract 68C60-91934, (N2M-2-8) drawing nos. 206C470, 206C471 and installation detail N2H-2-50.

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SI-il4.2 Page 26 of 83

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-. 7.4.5.2 Reactor Coolant System Branch Ploe Connection We ds The Reactor Coolant System piping includes branch pipe connection welds exceeding 2 inches nominal pipe size. The welds selected for exaelnation shall be ultrasonically and liquid penetrant examined during the inspection inter-val in accordance with Table A of Appendix A.

There are branch pipe connection welds 2 Inches nominal pipe size and smaller. The welds selected for exaalnation shall be liquid pene-trant sxamined during the Inspection interval in accordance with Table A of Appendix A.

7.4.5.3 Chemical and Volume Control System Branch Ploe Connection Helds The Chemical and Volume Control System piping includes branch pipe connection welds exceeding 2 inches nominal pipe size. The welds selected for examination shall be ultrasonically and liquid penetrant examined during the inspection interval in accordance with Table A of Appendix A. There are no branch pipe connection welds 2 inches nominal pipe size and smaller that shall be liquid penetrant examined during the inspection interval.

7.4.5.4 Residual Heat Removal System Branch Ploe Connection Welds The Residual Heat Removal System piping -

includes branch pipe ccanection welds exceeding 2 inches nominal pipe size. The welds selected for examination shall be ultrasonically and liquid penetcant examined during the inspection interval in accordance with Table A of Appendix A. There are branch pipe connection welds 2 inenes nominal pipe size and smaller.

These welds shall be liquid penetrant examlned .

during the 40 year life in accordance with Table A of Appendix A.

7.4.5.5 Safety injection System _ Branch Ploe Connection -

Welds The Safety injection System piping includes branch pipe connection welds exceedirig 2 inches nominal pipe site. The welds selected for examination shall be ultrascnically and liquid 0867e/COC4

SQNP SI-114.2 Page 27 of 83 Rev. 13 penetrant examined during the inspectica interval in accordance wtth Table 1. of Appendix A. There are branch pipe connection walds 2 inches nominal pipe size and smaller.

The welds selected for examination shall be liquid penetrant examined during the inspection interval in accordance with Table A of Appendix A.

7.4.5.5 Upoor Head injection System Branch Ploe

• Ccnnection Welds The Upper Head Injection System piping includes branch pipe connection welds 2 Inches nominal pipe size and smaller. The welds selected for examination shall be liquid penetrant examined during the inspection interval in accordance with Table A of Appendix A.

7.4.6 Pipina Socket Welds Tw entire ler.gth of each socket weld selected for

camination shall be liquid penetrant examined.

The examinations perforned during the inspection Interval shall include apprortsately 25 percent of the socket welds. The examinations shall be distributed'during the inspection interval in accordance with Table A of Appendix 5.

7.4.6.1 fleactor Coolant System Ptoing Socket Welds The Reactor Coolant System piping includes '

socket welds. The welds selected for examination will be examined during the inspection interval in accordance with Table A of Appendix A.

7.4.6.2 Chemical and Volume Control System Piping Socket Welds

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The Chemical and Volume Control System piping includes socket welds. The welds selected for examination will be examined during the inspection interval in accordance with Table A of Appendtx A.

7.4.6.3 Residual Heat Remval System Ploing Socket Welds The Residual Heat Removal System piping includes socket welds. The welds selected for 0867e/COC4

SQNP SI-114.2 Page 28 of 83

, Rev. 13 examination will be examined during the inspection interval in accordance wtth Table A of Appendtx A.

7.4>5.4 Safety T ijection System Ploine Socket I4 elds The Safety Injection System piping includes socket welds. The welds selected for examination will be examined during the inspection interval in accordance with Tab 1'e A

)f Appendix A.

~.A.

/ Upper Head injection System Ploino Socket Welds The Upper Head Injection System piping includes socket wel.ts. The welds selected for examination shall be examined during the inspection interval in accordance with Table A of Appendix A.

7.4.7 Piping and Valse Intearally-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 boundt.ry and those attachments whose 1 support ba*e material deston thickness is 5/8 inch and greater, the entire length of eacn support attachment weld salected for examination shall be surface exaalned.

The examinations performed during the inspection interval sh11 include 100 percent of the integrally-welded '

support members. The examinations shall be distributed during the inspection interval in accordance with Table A of Appendix A.

7.4.7.1 Recctor Coolant System Piping and Valve Integrally-delded Support Members The Reactor Coolant System piping includes - .

Integrally-welded support rembers. All of these shall be examined during the inspection interval in accordance with Taole A of Appendix A.

7.4.7.2 Chemical and Volume Control System Pleing and Valve Integrally-Welded Support Members The Chemical and Volume Control System piping includes a integrally-welded support eember.

0857e/COC4 SQNP SI-ll4.2 Page 29 of 83

, Rev. 13 This support shall be examined during the inspection interval in accordance with Table A of Appendix A.

7.4.7.3 Residual Weat Removal System Piping and Valve Intetrally-Welded Support Members The Residual Heat P.emoval System piping includes integrally-welded support member. All supports shall be examined during the

• Inspection interval in accordance with Table A of Appendir A.

7.4.7.4 Safety injection System Piping and Vrive Integrally-Welded Support Members The Safety Injection System piping includes  !

integrally-welded suppore members. All of these shall be examined during the it.spection interval in accordance with Table A of Appendix A.

7.4.7.5 Upper Head Injection System Pipino and Valve Inteorally-Welded Supports The Upper Head Injection System piping includes a integrally-welded support member.' This support shall be examined during'the inspection Interval in ac:.ordance with Table A of Appendix A. f 7.4.8 Piping and Valve Comognent Supports l

l All piping and valve component supports of piping required to examined by Examination Category 8-J shall be visually examin'id during the inspection interval in i

accordance with visual examination methods VT-3 and VT-4 I (see section 11.1). This examination includes integrally-l . welded and nonintegrally-welded component supports.

Component supports extend from the piping and valves to i and including the attachment to the supporting structure. .

l l

The setting of snubbers. shock absorbers. and spring-type hangers shall be verified in accordance with the accepted criteria shown in the Scan Plan or applicable work instruction. The setting of snubbers and shock absorbers l 1s performed in ac:ordance with SNP SI-162.2 or M1-6.13 l series.

The examinations shall be distributed during the inspection interval in accordance with Table A of Appendix A.

0867e/COC4

SQNP SI-il4.2 Page 30 of 83 ,

Rev. 13 7.4.8.1 Reactor Coolant System Ploina and Valve Component Supports The Reactor Coolant System piping includes component supports. All of these shall be examined during the inspection interval in

- accordance with Table A of Appendix A.

l 7.4.8.2 Chemical and Volume control System Pipino and Valve Component Sucoorts -

l The Chemical and Volume Control System piping includes component supports. All of these shall be examined during the inspection interval in accordance with Table 4 of '

Appendix A.

7.4.8.3 Residual Heat Removal System Flpinc and Valve

~

Component Supports The Residual Heat Removal System piping i includes component supports. All of there shall be examined during the inspection interval in accordance with Table A of Appendix A.

7.4.8.4 Safety Injection System Piping and Valve Component Supports The Safety Injection System piping includes component supports. All of these shall be examined during the inspection interval in accordance with Table A of Appendix A. -

7.4.8.5 Upper Head Iniection System and Valve Pipinq Component Supports The Upper Head inj.ection System piping includes component supports. All of these shall be i examined during the inspection Interval in accordance with Table A of Appendix A. - .

, f 7.8 8.6 Reactor Coolant System Main loep Piping and ~

Valve Cceponent Support f The Reactor Coolant System main piping includes component supports. All of these shall be examined during the inspection Interval in ,

accordance with Table A of Appendlx A.

0867e/COC4

SQNP SI-Il4.2 Page 31 of 83 Rev. 13

- 7.5 Reactor Coolant Pumps (4) - RCP 7.5.1 RCP Pressure Retalning Bolting larger Than Two Inches In Diamater The main flange on each pump includes 24 bolts of 4 1/2 inches in diameter and 301/2 inches in length.

Bolting may be examined either (a) In place under tension (b) when the connection is disassembled, or -

(c) when the bolting is removed.

All the bolts from each pump shall be ultrasonically examined during the inspection intervals. All threads in the base material and flange ligaments between threaded bolt holes shall be visually examined in accordance with visual examination method VT-1 (see section 11.1) when the connection is disassembled.

When the bolts are removed each shall be magnetic particle examined. This exam may be deferred until the end of the interval.

Provisions for this examination are included in M!-2.2.

The main flange bolts are fabricated of 4340 steel, heat treated to A-540, GR. 24 7.5.2 RCP Pressure Retalning Bolting 2 Inches and Smaller in Diameter Each RCP includes two sets of pressure retalning bolting 2 inches and smaller in diameter. The bolting sets include the number 1, and 2 seal assembly bolting. The

, number I seal assembly bolting from each pump shall be visually examined in accordance with visual examination method VT-1 (see Section 11.1). The number 2 seal assembly bolting is Class 2 and does not require examination (see meno to C. R. Brainer from V. A. Blanco dated January 10,1987, No. 825870109045).

The tolting 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 HI-2.1 and provides for examination of bolting, t All of the bolting from one RCP shall be examined during l tne first inspection period, and all of the bolting from a different pump shall be examined during the second l

i 0867e/COC4

i l

SQNP SI-11402 Page 32 of 83

. Rev. 13 Ir.spection period. All of the bolting from the remaining two pumps shall be examined during the third Inspection period.

The number 1, and 2 seal housing bolting includes 12 socket head cap screws at 2 inches in diameter,12 socket  !

- head cap screws at 1 inch in diameter, respectively.

7.5.3 RCP Integrally-Welded Sucoort Members  ;

There are three unit 2 reactor coolant pumps, serial numbers 566 (RCP-1 casing), 704 (RCP-3 casing), and 709

-(RCP-4 casing), with integrally welded supports. Each ,

pump has three integrally welded pump feet. These integrally welded pump feet whose design base is 1 5/8 of ,

an inch shall be surface examintd during the inspection '

interval in accordance with Table A of Appendix A. The examination shall cover 100 percent of the required area  ;

of each support attachment. '

All of the supports from one RCP shall be examined during ,

the first inspection period, and all of the supports from a different pump shall ba examined during the second inspection period. All of the supports from the  :

remaining pump shall be examined during the third inspection period. ,

j 7.5.4 RCP Component Supports Three of the RCPs N ye three cast feet integrally welded l to the pump casing, the fourth pump has integrilly casted l feet. These feet are bolted to the support system. All component supports from each pump shall be visually '!

examined during the inspection interval in accordance with visual examination method VT-3 (see Section 11.1) and Table A of Appel its A. Support components extend '

from the RCP to and including the attachment to the l

supporting structure.  :

All of the supports from one RCP shall be examined during the first inspection period, and all of the supports.from . ,

a different pump shall be examined during the second inspection period. All of the supports from the  !

remaining two pumps shall be examined during the third  !

Inspection period. l i

7.5.5 RCP Castnq Welds i i

The unit 2 reactor coolant pumps do not include casing welds.

i

! I 0867e/COC4 l

SQNP S1-114.2 Page 33 of 83 Rev. 13 i 7.5.6 RCP Casinq 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 t 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.) L 7.5.7 RCP Flywheel l

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 i surface examination of exposed surfaces. (See Regulatory 4

i Guide 1.14.) This examination is done in accordance with l Sequoyah technical specifications and satisfies i Surveillance Requirerent 4.4.10. .

. The flywheel consists of 2 plates, approximately 5 inches and 8 inches thick, bolted together. Eac5 plate is i f.abricated from vacuum degassed A-533, GR. B, Class I,  ;

4 steel. ,

7.6 Valves Systems including Class 1 vstves subject to examination are  !

identified in Section 7.4. (A tabulation of valves is presented .

In Appendix A. Table D Part I, and Part 2.)  !

F 7.6.1 Valve Pressure Retalning Boltino larger Than 2 inches in -

Di arre t er ,, ,

[

There are no valves with pressure retaining bolting [

larger thin 2 inches in diameter.

7.6.2 Valve Pressure Retainino Bolting 2 inches and Scaller in Diameter l 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 examined during the inipection interval in  ;

I 0867e/COC4 l

! i i

SQNP SI-114.2 Page 34 of 83 Rev. 13 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. (All the valves pressure retaint.7 bolted connections have been combined for all the systems for category 5-G-2.)

The bolting may be examined in place under tension or when the bolting is removed. It is preferable to examine tha bolting when removed if possible. Valve disassembly 15 performed in accordance with MI-6.15 and provides for examination of bolting.

7.6.2.1 Reactor Coolant System Valve Bottina The Reactor Coolant System includes valves with bolted bonnet connections. All of these valves shall be examined during the inspection interval in accordance with Table A of Appendix A.

7.6.2.2 Chemical and Volute Control System Valve Bolting The Chemical and Volume Control System includes valves with bolted bonnet connections. All of these valves shall be examined during the inspection interval in accordance with Table A of Appendix A.

7.6.2.3 Residual Peat Removal System Valve Bolting The Residual Heat Removal System inclu' des ,

valves with bolted bonnet connections. All of these valves shall be examined during the inspection interval in acecreance with Table A of Appendlx A. ~

7.6.2.4 Safety injection System Valve Boltig Tho Safety Injection System includes valves,. ,

with bolted bonnet connections. All of these valves shall be examined during the inspection interval in accordance with Table A of Appendix A 7.6.2.5 Upper Head Injection ' System Valve Bolting the Upper Head Injection System includes valves with bolted bonnet connections. All of these valves shall be examined during the inspection interval in accordance with Table A of Appendix A.

0867e/COC4

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SQNP SI-114.2 Page 35 of 83  :

Rev. 13  ;

i 7.6.3 Valve Integrally-Welded Support Members  !

Examination of valve integrally-welded support members is t' included in Section 7.4.7.

7.6.4 Valve Component Sucoorts  !

Examination of valve component supports is included in ,

Section 7.4.8. , j 7.6.5 Valve Body Welds T'here are no valves with body welds.

7.6.6 Valve Bodies The internal 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 slmtbr functions in the system.

1 When it becomes necessary to otsassemble any valve, subject to internal surface visual examination, for l

~

normal maintenance purposes, the interior surface of the valve body will be visually examined and the results recorded. Olsassembly of valves niely for visual examination will not be performed ,'ee ASME Section XI,

, Table IWS-2500. Examination Category S-M-2; also'see ..

1 Request for Relief ISI-2).

A tabulation of valves by groupings.is presented in Table O Part I of Appendix A. Olsassembly of valves is performed in accordance with HI-11.4 and provides for examination of valve internal surfaces.

7.7 Exempted Components , ,

Coepenents exempted from examination include component connections piping, aid associated valves and their support that are ene inch nominal ripe size and smaller, except for steam generator tubing; ccesonents connected to and part of the rLactor coolant pressure bout Jary (defined in 10 CFR 50, Section 50.2(v);

revised January 1. ' H 5) but exempted from Class 1 requirements by regulations of ihe regulatory authority having jurisdiction at the plant site; reactor vessel head connections and associated piping. 2 in, nominal pipe size and smaller, made inaccessible by control rod drive penetrations.

0867e/COC4 SQNP SI-Il4.2 Page 36 of 83 Rev. 13

~7.8 Successive Examinations Areas of flaw Indications evaluated in accordance with IWB 3122.4 and applicable NDE procedures that qualify for continued service shall be reexamined during the next three inspection periods listed in the inspection schedules. If the rirexaminations 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 examination schedule is dictatdd by the augmented inspection requirements (see Section 20.0).

7.9 System Pressure Tests All ASHE Code Class 1 pressure-retalning components shall be subjected to a system leakage test in accordance with IHB-5221 of ASitE Section XI each refueling outage. This is performed in accordance with S1-146. During this test, attention must also be given to the cono-seal in the CRDM's (reference remorandum from J. F. Hurdock to D. L. Williams dated August 22, 1988: B46 88 0822 582.) In addition, all Class 1 pressure-retalning ccmponents shall undergo a system hydrostatic pressure test in acco* dance with !HB-5222 of ASME Section XI at the end of the inspection interval. This is performed in accordance with 51-250. The components shall be visually examined during the pressure tests in accordance with visual esamination c9ethod VT-2 (see Section 11.1). All Class 1 System Pressure Tests shall be performed in accordance with Program Procedure 1502.03.

8.0 CCMPONENTS SUBJECT TO EXAMINATION - ASME CODE CLASS 2 (E00! VALENT)

The ASHE Ccde Class 2 (Equivalent) components to be examined during the ,

inspection interval ara outlined in the following paragraphs. Extent of examination for piping welds will be in accordance with paragraph IWC-2411 and Table IWC-2520 of the 1974 Edition. Sumer 1975 Addenda.

ASME Section XI. The ISI Programs Section shall select areas to be examined.

Components that are exempted from esamination in accordance with

!WC-1220 cf ASHE Section XI are discussed in Sectica 8.11 of this '

• program.

l l

Where esaminations specify a percentage of the total length of . eld to be esamined, the areas (s) examined shall be dee pented in the examinat toa *eport. Where a percentage of weld length is not referenced, the entire weld length shall be esamined. (See Request for 1 Relief ISI-3,)

l l Table B in Appendix A supplies additional information such as reference dra.ing nu:cers and ASME Secticn XI Table-IWC-2500-1 examination categories.

i

SQNP  !

l S1-114.2 Page 37 of 83 ,

Rev.13 i

The following are the requirements for additional examinations:  !

(a) Examinations that detect indications exceeding the .Ilo-able '

l standards of IWC-3000 shall be extended to include an additional number of components (or areas), within the same examination f category, approximately equal to the number of components (or  !

areas) examined initially during the inspection.

(b) If these additional examinations detect further indications -

exceeding the allowable standards of IWC-3000, the remaining [

number of similar components (or areas) within the same i

! examination category shall be examined to the extent specified in ,

Table IWC-2520-1 except as modified by (c) and (d) below, f (c) Where the required piping examinations are limited to one loop or branch run of an essentially stellar piping configuration, examinations that reveal indications exceeding the allowable standards of IWC-3000 shall require the additional examinations of (a) above and shall be extended to include examination of a second loop or branch run to the extent specified in Table IWC-2520-1.

(d) If the examination of the second loop or branch run reveals l further indications exceeding the allowable standards of I IWC-3000, the remaining number of loops or branch runs that perform similar functions shall be examinea. .

8.1 Steam Generators (4) l 8.1.1 Steam Generator Secondary Side Circumferential Shell_W;.lds There are three circumferential shell welds at grcss ..

structural discontinulties 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 alth Table B of Appendix A.

One of the three welds on each steam generator is , ,

partially inaccessible for examination due to the upper steam generator support arrangement (weld nos. SCH-01 02, 03, and 04; see Request for Relief ISI-4). The weld selected for examination shall be ultrasonically examined on a best-effort basis.

The vessel shell sections are fabricated of SA-533 GR. A. Class 1. steel plate.

0867e/COC4

s SQNP SI-114.2 Page 38 of 83 Rev. 13 8.1.2 Steam Generator Secondary Side Circumferential Head W 1ds .

Each steam generator includes a circumferential .

head-to-shell weld. The entire length of one t head-to-shell weld shall be ultrasonically examined  !

during the Inspection Interval in accordance with Table 8 of Appendix A. The weld selected for ensination any be . i from the generator selected for enel'ation by

• Section 8.1.1. ,

The vessel head section is fabricated of SA-533, GA. A.

Class 1. steel plate. ,

8.1.3 Steam Ganerator Secondary side Tubesheet-To-Shell Weld Each steam generator includes a tubesheet-to-shell weld.

The entire length of one trbesheet-to-shell held shall be ultrasonically examined during the inspection interval in accordance with Table 8 of Appendix A. The weld selected i 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-Vessk1 Welds Each steam generator includes one feedwater nozzle .

(3.62 in:hes nominal vessel thickness) and Cne main steam ,

nozzle (3.62 inches nominal vessei thickness). All of the nozzle-to-vessel welds from each generator shall be ultrasonically and magnetic particle examined during the '

inspection interval in accordance with Table B of '

Appendix A. All the welds under category C-8 have been '

ceabined. r The nozzles are fabricated of 54-508, Class 2, steel. f 8.1.5 Stean Generator Secondary Side inteorally-Welded Support f Attachments - .

There are no integrally welded vessel support attachmentc.

8.1.6 Stean Generator Secondary Side Cmponent Supeorts There are no coeponent supports (including reshanical and  ;

hydraulle supports) which are in contact with the sessel. l 3.1.7 Steam Generator Secondary Side Pressure Retalning Boltty Exceedinq 2 Incnes in Diameter ,

r there is no steam generator secondary side bolting i exceeding 2 liiches in diameter.

33_ 0067e/COC4 l l

~

SQNP SI-ll4.2 Page 39 of 43 Rev. 13 8.2 Residual Heat Resaval Heat Euchanaers (2) - RHRHX 8.2.1 RHRMX Circumferential Welds 8.2.1.1 RNRHX Shell Circumferential Weld There is one circumferential shell weld located at a gros structural discontinuity on each RHRHX. The entire length of this shell weld .

from one heat exchanger shall be ultrasonic 411y examined during the inspection interval in accordance with Table 8 of Appendix A.

The RHRHX shell section is fabricated to SS, SA-182 F304.

8.2.1.2 RHRHX Head Circumferential Weld There is one circumferential head-to-shell weld

per RHRHX. The entire length of one i head-to-shell weld shall be ultrasonically J

examined during the inspection interval in accordance with Table 8 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 fabrliated frca j 55. SA-240, TP-304.

8.2.1.3 RHRHX Tubesheet to Shell Weld There are no RHRHX tubesheet-to-shell welds. ,,

8.2.2 RHRHX Nozzle-to-Vessel Welds l

The channel cylinder section of,each RHRHX includes one

) inlet nozzle (14-inch I.D.) 39d one outlet nozzle t 4-inch I.D.) over 1/2-inch nominal thickness. A total of four nozzle-to-vessel welds from the two RHRHX will be ultrasonically and liquid penetrant examined during the inspection interval. All the welds under category C-8 .

have been combined.

The nozzles are fabricated from $$. SA-240. TP-304 ,

8.2.3 RHRHX Integrally-Welded Support Attachments There are two integrally-welded support attachments (1-inch) on each RHRHX whose base material exceeds 1/2-inch nominal thickness. A total of two support pad-to-vessel welds from the RHRHX will be liquid 0867e/COC4 SONP .

SI-11402 l

Page 40 of 83 i

. Rev. 13 penetrant examined during each inspection interval in accordance with Table 5 of Appendix A. The welds selected for examination may be conducted on one heat exchanger and shall cover 100 percent of the required area of each support attachment. All the welds under category C-C have been combineo.

The support pad is fabricated from SS. SA-240 TP-304.

8.2.4 RHRHX Component Succorts

• There are two component supports on each RHRHX which a.*

In contact with the vessel. All component support- from each heat exchanger shall be visually examined & .Ing the inspection interval in accordance with visual examination me* hod VT-3 (see Section 11.1).

This examination includes integrally-welded and nonintegrally-welded component supports. Component supports extend from the heat exchancer to and including the attachment to the supporting structure.

The examinations shall be distributed during the inspection interval in accordance with Table 8 of

, Appe9 dix A.

l There are no ciechanical (snubbers) and/or hydraulle (shock absorbers) supports which are in contact with the vessel.

8.2.5 RHRHX Pressure Retainino Boltino Exceeding Two inches in Otamter 4

There is not any RHRHX bolting exceeding two inches in l diameter, j S.3 Regenerative Heat Exchancer (One) - RHX 8.3.1 RHX Circumferential Welds 3.3,l.1 RHX Shell Circumferential Welds .. .

The regenerative heat exchanger is ccerosed of three heat exchangars Interconnected with piping. There are twelve circumferential welds j located at structural discontinuities on the heat exchanger. There are six channel cylinder to channel head welds and there are six tubetheet-to-lhell welds. See Request for l Relief 151-12.

l l

0367e/COC4 L

1 SQhp .

SI-114.2 Page 41 of 83  :

. Rev. 13  :

7

- The channel cylinder sections are fabrleated to SS, SA-351, CF8. The channel flanges are fabricated to SS, SA-182, F304. ,

8.3.1.2 RMX Head Circumferential Welds f There are sia channel cylinder to channel head i welds. Refer to Rollef Request 151-12. }

The channel heads are fabricated to SS, SA-240, 304L.

4.3.1.3 RHX Tubesheet to Shell Weld There are sin RHX tubetheet-to-shell welds.

Refer to Relief Request ISI-12.  ;

The tubesheet is fabricated to SA-182, F304 SS. '

8.3.2 RHX Nozzle-to i/essel Welds f i

There are not any nozzles greater than four inch  ;

diameter. The nozzles are fabricated to SA-479, 304 SCH -

160 material. See Request for Rollef ISI-12. i 8.3.3 RHX Intearally-Welded Sucoorf},

I There are not any integrally-welded support attachments on the heat exchanger. There are three stops ,

S/8" x S/8" x l-3/4" welded to the heat exchanger. Refer  !

to Rollef Request 151-12.  ;

8.3.4 RHX Component Sueoorts i There are two component supports on the regenerative heat exchanger. These supports are not required to be [

examined in accordance with footnote 4 of Table  !

IWC-2500-1 Examination Category C-C and C-E. See j Request for Relief 151-12.  ;

8.3.5 RHX Pressure Retalnino Bolting Exceeding Two Inches in , i Otameter ,

There is . lot 4ny pressure retalning bolting associated I with the heat exchanger.

-a:

) 0857e/CCC4

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SQNP S!-114.2

, Page 42 of 83 Rev. 13

- 8.4 Excess Letdown Heat Exchancer (One) - ELHX 8.4.1 (LHX Circumferential Welds 8.4.1.1 ELHX Shell Circumferentlaf Welds There are not any shell circumferential welds associated with the ELHX.

8.4.1.2 ELHX Head Circumferential Welds There is one circumferential weld, the channel flange to channel head, located at a structural discontinuity on the head side of the ELHX.

Refer to Relief Request 151-12. The channel flange and the channel head are fabricated to SA182, F316 and SA-240. TP316, respectively.

See Request for Relief 151-12, 8.4.1.3 ELHX Tubesheet to Shell Weld There are not any ELHX tubesheet to shell welds.

8.4.2 ELHX Nozzle to Vessel Welds There are not any nozzles greater than four-inch diameter. The nozzles are fabricated to SA-312, 316.

8.4.3 ELHX Integrally-Welded Supports There are no integrally-welded supports to the head side of the ELHX.

8.4.4 ELHX Coeponent Supports

.There are no eceponent supports to the head side of the ELHX.

8.4.5 ELHX Pressure Retalnino Bolting Exceedino Two inches in Dipeter The channel flange bolting associated with the ELHX is less than two inches in diar 4ter.

The flange includes 12 studs with nuts at 1-5/8 inch diareter. The studs and nuts are fabricated to SA-193.

GRB7 and SA-194 GR2H, respectively.

I 0867e/COC4 i

SQNP S!-114.2 Page 43 of 83 Rev.13 L

~ 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 discontinultles on the 817. These welds sht11 be ultrasonically examined during the inspection interval in accordance with Table 8 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 l (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 witn Table B of Appendix A. The examination shall cover 100 percent of the weld length. All the Welds under category C-8 have been combined.

The nozzles are fabricated to SA-350 LF2.

8.5.3 8_IT Inteorally Welded Supports There are four integrally-welded cupport attachment pads welded to the shell, whose base material design thickness is 5/8 inch and therefore requires a surface examination in accordance with Table IWC-2500-1 of APE Section XI.

All the welds under category C-C have been combined.

8.5.4 EIT Cceoonent Supports There are four component supports associated with the boron injection tank. All of these supports shall be visually esamined (VT-3) during the inspection interval in accordsnce with Table 8 of Appendin A. . .

8.5.5 BIT Pressure Retainino Boltina Exceedino Two Inches in Olameter There are 16 manway cover studs at 2-1/2 inches in diame ter . All 16 studs shall be ultrasonically examined during the inspection interval in accordance with Table 8 of Appendix A. The studs may be esamined in place under tension or when they are removed. It is preferrable to perform the examinations when the studs are removed if possible.

,I 0867e/C0C4

SQNP SI-114.2

. Page 44 of 83

, , Rev. 13 The studs and nuts are fabricated to SA-193. GRB7 and SA-194. GR2H respectively.

8.6 UH! Water Accumulator (Oce) WA The UN! water accumulator is exempted from examination because of I' IWC-1220(a) of ASME Section XI.

l 4.7 .UNT Surge Tank (One) ST ,

I The UNI surge tank 15 exempted from exaalnation because of l IWC-1220(a) of ASME Sectio.) XI.  !

[

8.8 Seal Water Injection Filters (2) SWIF ,

8.8.1 SWIF Shell and Head Circumferential Welds Each SWIF has 2 circumferential shell welds one top flange to shell a H one bottom head to shell weld.  !

According to Tabis iWC-2500-1 Category C-A footnote 3 we  !

will ultrasonically examine 2 welds of either the same  :

filter or 2 different onits of each filter in accordance

] with table B of Appendix A. These exams should be coordinated with the plant so as to perform the exams ,

I when the filters are drained or flushed to reduce  !

radiation exposure to the personnel. '

1 8.8.2 SWIF Integrally Welded Supports Each SWIF has 3 integrally welded supports legs. The '

legs are 2 1/2" X 2 1/2" X 3/8" angle fron of SA304 I stainless steel and are everpt fre,i examination due to i

, their thickness being less than 1/2". I 8.8.3 SWIF Component supports l Each SWIF component support consists of 3 Integrally

welded support legs. The supports are erenpt by footnote ,

4 to Category C-E of Table IWC-2500-1 since the piping to  !

, the filters are not required to be examined under  !

categories C-F or C-G. - . ,

8.9 Pipinq Material specifications for each piping system are included in i weld esp isometrics in Appendia A. The following Class 2 piping i systems are subject to examination

l t

. Residual Heat Renoval l l Safety Injection i l Main Steam l f-4'- 0867e/COC4 h i

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Feedwater l

Containment Spray Upper Head Injection 8.9.1 Plotna and Valve Intearally-Welded Supports Integrally-welded supports include the support attachments of piping required to be examined by i Examination Category C.F. Included are those supports t which have attachment welds to the valve and piping

• l pressure retalning boundary, and those attachments whose support base material desian thickness exceeds 3/4 Inch. ,

The entire length of each support attachment weld <

selected for examination shall be surface examined.

The examinations performed during the inspection interval shall include 100 percent of the integrally-welded r support members. The examinations shall be distributed L during the inspection interval in accordance with Table 8 of Appendix A.

8.9.1.1 Residual Heat Removal System Piping and Valve Integrally-We led Supports The Residual Heat Removal System piping does l

not include any integrally-welded supports.

8.9.1.2 Safety ISjection System Ploing and Valve Integrally-Welded Suppor g .

TheSafetyinjectionSystempipingincludes I Integrally-welded supports. All of these shall I

be examined during the inspection Interval in L accordance with Table 8 of Appendix A.

8.9.1.3 Main Steam Systen Ptolna and valve integrally Welded Supports The Main Steam System piping includes integrally-welded supports. All of these shall '

be examined during the inspection interval in .  !

accordance with Table 8 of Appendix A. l l 8.9.l.4 Feed 5ater System Piping and Valve Integrally-Welded Supoorts The feedwater System piping includes integrally-welded supports. 'All of these shall be examined during the inspection interval in accordance with Table B of Appendix A.  !

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j. SQNP S1-114.2 l , Page 46 of 83 l Rev. 13 8.9.1.5 Containment Soray System Ptolna and Valve Intearal y-Welded Succorts l The Containment Spray System piping does not include ar.y integrally-welded supports. [

l 8.9.1.6 Vocer NNd Injection System Ptolna and Valve Intears y-Welded Suncorts The upper head injection system piping includes I integrally-welded supports. All of these shall i be examined during the inspection interval in  :

accordance with Table B of Appendix A. ,

8.9.2 Ptolna and Valve Component Succorts  !

All piping And valve component supports shall be visually  :

i examined during the inspection interval in accordance  ;

I with visual examination methods VT-3 and VT-4 (see  ;

l Section 11.1). This examination includes integrally-welded and nonintegrally-welded component supports.

Component supports entend from the piping and valves to i and including the attachment to the supporting structure.

l l The setting of snubbers, shock absorbers and spring-type hangers shall be vertfled in accordance with the acceptance criteria shown in the Scan Plan or the ,

applicable work instruction. The setting of snubbers and shock absorbers is performed in accordance with the . i SI-162.2 U.d NI 6.13 series.  ;

i The examinations shall be distributed during the t inspection interval in accordance with Table B of ,

Appendix A. ,

t 8.9.2.1 Residual Heat Rereval System Ploing and Valve [

CoNcnent Supports The Residual Heat Removal System piping l includes component supports. All of these  ;

shall be examined during the inspection - .

l Interval in accordance with table B of  !

Appendix A.

8.9.2.2 laftw t injection System Ploino and Valve Cos ont Sueports The Safety Injection Systes piping includes ceaponent supports, All of these shall be examined during the inspection interval in accordance with Table 6 of Appendix A.

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Rev. 13 8.9.2.3 Main Steam System Ptolno and Valve Comoonent '

Suonorts The Main Steam System piping includes component '

supports. All of these shall be examined ';

during the inspection interval in accordance with Table 8 of Appendix A.

8.9.2.4 Feedwater System Ptolne and Valve Component "

Svooorts The feedwater System piping includes component supports. All of these shall be examined i during the inspection interval in accordance i with Table 8 of Appendix A.  ;

8.9.2.5 Containment Soray System Ptolna and Valve Component Sucoorts The Contsinment Spray System piping includes component supports. All of these shall be t examined during the inspection interval in i

accordance with Table 5 of Appendix A. f 8.9 2.6 theer Head Injection System Piping and Valve  ;

i Component Svooorts .

l The upper head injection system piping includes  !

component supports. All of these sha!! be .

I examined during the inspection interval in (

, accordance with Table 8 of Appendix A.

8.9.3 Pressure Retatntoo Boltino {

There are no Class 2 Pressure-Retalning Bolting larger than two inches in diameter. i l

) 8.9.4 Circumferential and lonettudinal Ploe Welds The entire length of each veld selected for examination  ?

shall be ultrasonically and/or surfaced examined. .. .

I Selection of welds for examination is based on Table  !

IWC-2520, Paragraph IWC-1220. and Paragraph IWC-2411 L I

(Sunvrer 1975 Addenda). All of the welds selected approntmately 25 percent of the 40-year sample shall :e  :

esamined during the inspection interval. The ,

examinations shall be distributed in accordance with '

lable B of Appendix A.

Circumferential and longitudinal piping welds in piping

]

with a nominal wall thickness of 1/2 inch or less shall  !

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- be surface exaalned. Circumferential and "ongitudinal piping welds in piping with a nominal wall thickness ,

greater than 1/2 inch shall be ultrasonically and  ;

surfaced examined. The areas subject to examination include circumferential pipe welds, at structural ,

discontinuttles within 3 pipe dlaaeters of the centerline of rigid pipe anchors, anchors at the penetration of I primary contalnnent or at rigidly anchored components, and longitudlntl weld joints in pipe fittings. All longseas welds under C-F/C-G and all circumferential -

welds under C.F/C-G have been combined.

4.9.4.1 Residual West Removal Ptolno ,

The Residual Heat Removal Pipinq System includes Class 2 circumferentla' and Class 2 longitudinal piping welds with a nominal wall . .

thickness greater than 1/2 inch subject to ' !

existnation. There are circumferential and I longitudinal pipe welds with a ncelnal wall f thickness of 1/2 Inch or less subject to exastaation. The welds selected for examination with a nominal wall thickness ?L greater than 1/2 inch shall be ultrasonically '

and surfaced examined each inspection Interval in accordance ith Table 8 of Appendix A. The welds selected for examinaticn with a noelnal .iI wall thicknest of 1/2 inch or less that shall l be surface examined each inspection interval in .

I accordance with Table 8 of Appendix A. [

t 8.9.4.2 Safety injection Pipino t

The Safety Injection Piping Systen includes  :

Class 2 circumferential and no Class 2 '

longitudinal piping welds alth a nominal wall i thickness greater than 1/2 inch subject to '

e r aal na *.t en. There are circuaferential and j longituatnal pipe welds with a nominal wall l thickness of 1/2 inch or less suDject to .i exasinatten. The welds selected for .. . .

enastnaticn with a ncalnal wall thickness ,

greater than 1/2 inch shall te ultrasenically p and surf ace examined each Inscection interval  ;

in accordance with Table B of Apperdix A. Tht welds selected for examination with a nominal wall thickness of 1/2 inch or less that shall i be surfaced examined each intcectlen interval i in accorcance with Table B of Appendix A.

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, Page 49 of 83 Rev. 13 8.9.4.3 Main Steam Ptolna The Main Steam Piping System includes Class 2 circumferential and (. ass 2 tongitudinal piping welds with a nominal wall thickness greater than 1/2 inch suiject to estelnation. The piping size is 32" 0.0. x 1.048 wall unless noted. The welds selected for esamination shall be ultrasonically and surfaced examined each Inspection interval in accordance with-Table B of Appendix A. TVA intends to terminate main steam Class 2 on each main steam loop af ter the M5!V's (1-FCY-1-4.1-11.1-22, and 1 29) for !$1 purposes.

8.9.4.4 feedwater Ptolno l The Feedwater Piping System includes Class 2 circumferential welds and a longitudinal weld with a nominal wall thickness greater than 1/2 inch subject to examination. The one longttudinal weld is on Loop 4 at the reducing elbow (18" x 16"). The welds selected for examination shall be ultrasonically and surfaced enanined each inspection intetyt1 in accordance with Table 5 of Appendix A.

8.9.4.5 Containment $0 ray Pietnq The Containment Spray Piping System includes circumferential and lengttudinal pipe welds with a nominal wall thickness of 1/2 inch or less, subject to enastnatten.. The welds selected for erastnatten shall be surface examined each inspectica interval in accordance with Table 8 of Appendin A. The nominal wall

., t5tekness for the contatteent spray system is 0.406 inches.

8.9.4.6 t}pper Head Injectiot Picing The upper head injectico piping system includes

Class 2 circumferential telds and no Class 2 fongituC nal pipir,g melds with a nostnal wall thlch. ness creater tnan 1/2 inch subject to examinatto . The melds selected for examination shall te ultrasonically and surface examined during the inspection interval in accordance with Table B of Appendix A.

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,, 8.9.5 Branch Piping Connection Welds There are no Class 2 Branch Pipe Connection Helds.

Pumos 8.10.1 Residual Heat Removal Pumos (2) - RHRP 8.10.1.1 RHRP Intecrally-Welded Supports _

There are no integrally-welded supports associated with the RHRP.

8.10.1.2 RHRP Support Components Each RHRP includes three support components bolted to the pump feet which are integrally forged with the pump. All component supports from each pump shall be visually examined during the inspection interval tn 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.

The st'pports from one RHRP shall be examined during the first inspection period. The

supports from the remaining RERP shall be examined during the third inspection period. .

8.10.1.3 TP Supports - Hechanical or Hydraulle There are no mechanical or hydraulic supports associated with the RHRP.

8.10.1.4 RHRP Pressure Retaininq Bolting The stuffing box extension to pump casing connection bolting is not greater than two inches la diameter.

The connection inc5ULos 24 studs at 1-1/4 inthes in diameter with nuts and washers. The studs are fabricated to SA-193, GR. 87, and the nuts to SA-194, GR. 2H.

8.10.1.5 RHRP Cising Welds The RHRP does not include any casing weld <!.

The casing is a one piece forging fabricated to SA-IS2, F304.

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-4.10.2 CVCS Centrifuqal Charging Pumps (2) CCP 8.10.2.1 CCP-Component Supports and Casing Welds The CCP is not in a piping run examined under Examination Category C-F therefore the component supports and casing welds are not required to be examined except for system pressure tests.

8.10 2.2 CCP Pressure Retaining Bolting There is no CCP bolting greater than two inches in diameter.

8.10.3 [yfR Posittye D!sclacement Pump (1) POP /Reciprccattna Charging Pump 8.10.3.1 PDP Compo_ntnt Supports The PDP is not in a piping run examined under Examination Category C-F therefore, the component supports are not required to be examined, 8.10.3.2 PDP Pressure Retaining Bolting The cylinder tie, cylinder head and valve cover, and the stuffing box flange bolting connections are not greater than 2 inches in diameter.

The connection includes 8 studs at 1-1/8" In diameter with nuts and washers for the cylinder ties: 40 cylinder head and valve cover studs at 1 1/4" in diameter wich nuts and washers; and 20 studs at 1 1/4" In diameter with nuts and washers for the stuffing box . iange. The studs are fabricated to SA-193 GR87 and the nuts to SA-194, GR7.

8.10.3.3 PDP Casing Welds 5 The PDP casing does not include any casing welds. The casing is fabricated to SA-182 F304, SA-204 Type 304, SA-479 T304, and SA-479, 410.

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8.10.4 Safety injection Pumps (2)-SIP 8.10.4.1 SIP Component Supports The SIP is not in a piping run examined under Examination Category C-F therefore, the component supports are not required to be examined.

8.10.4.2 SIP Pressure Retalning Bolting The SIP case capnuts are not greater than 2 inches in diameter. The casing bolting includes 32 studs at 2 inches in diameter with nuts and washers and 10 studs at 1 inches in diameter with nuts and washers. The studs are fabricated to SA-193, GRB7 and tne nuts to SA-194, GR7.

8.10.4.3 SIP Casing Welds The SIP casing does not include any casing welds. The casing consists of upper and lower housing fabricated to A351 GF8.

. 8.!! Valves ,

Systems including ASME Code Class 2 valves subject to examination are identified in Section 8.9. A tabulation of valves is presented in Table E of Appendix A.

8.11.1 Valve Integrally-Welded Supports Examination of valve integrally-welded support members is included in Section 8.9.1.

8.11.2 Valva Component Supports Examination of valve component supports is included in Section 8.9.2. . .

8.11.3 Valve Pressure-Retalning Bolting There is no Class 2 pressure-retalning bolting greater than 2 inches in diameter.

8.11.4 Valve Body Welds -

There are no Class 2 valves with body welds.

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- 8.12 Pressure Retalning Components All Class 2 pressure retalning 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 are required (excluding open-ended portions of systems), shall be' subjected to a system functional leakaw test with each inspection period in accordance with IWC-5221 of ASNE Section XI. This is performed in accordance with the SI-267

' series. Those Class 2 pressure retalning components in systems or portions of systems not subject to the functional leakage tests (excluding open-ended 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 (see Section 11.1). All Class'2 system pressure tests shall be performed in accordance with Program Procedure 1502.03.

8.13 Exempted Components 8.13.1 Exempted Components (Except Ploing Welds)

Components exempted from examination include:

(a) Components in systems or portions of syster.: 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 percent of the pressure that the componer.t or system will be subjected to when required to operate; (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; (c) ccmponent connections (including nozzles in vessels and pumps), piping and associated valves and vessels (and their support.1) that are 4-inch nominal pipe size and smaller.

8.13.2 ExemptedComponents(PiopqWeldsOnly) . .

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 pipe size and smaller.

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_ 8.14 Success 1re Examinations Components with flaw indications evaluated in accordance with IHC-3000 and tt.e appilcable NDE procedure that qualify for continued service sh.111 be reexamined during the next inspection period listed in the inspection schedule. If the reexamination reveals that the flaw Indications remain essentially unchanged, the component examination schedule may revert to Pe original schedule. Exceptions to this requirement may occar when the examination schedule is dictated by the augmented inspection -

requirements (see Section 20.00).

9.0 COMPONENTS SUBJECT TO EXAMINATION - ASME CODE CLASS 3 (E00! VALENT)

ASHE Code Class 3 (Equivalent) pressure retalning components identified in sections 9.1:1 end 9:1,2 shall be visually examined, VT-2, in conjunction with the system pressure test In'accordance with INA-5000, IHO-2000, and IHO-5000.

The component supports and restraints within the boundarles identified in sections 9.1.1 and 9.1.2 for components exceeding 4-inch nominal pipe size shall be visually examined, VT-3, during each inspection period.

Mechanical and hydraulle snubbers, spring loaded and constant weight supports within the boundarles identified in sections 9.1.1 and 9.1.2 for components exceeding 4-inch nominal pipe size shall be visually examined, VT-4, during each inspection period.

9.1 Piping and Valve _ Component Supports All piping and valve component supports shall be visually examined during each inspection period in accordance with 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. The setting of snubbers, shock absorbers and spring-type hangers shall be verified in accordance with the acceptance criteria shown in the Scan Plan or appilcable work instruction. The examinations (100%) shall be conducted during each inspection period during the inspection Interval in . .

accordance with Table C of Appendix A.

Examinations performed during any one inspection that reveal indications exceeding allowable standards of IWD-3000 (IH8-3000)(and for which 100% of the supports for a given category are not being examined) in a component of an examination l category examinations shall be extended to include an additional number of components within the same category, approximately

, equal to the number of components examined durirg the inspection. In the event further Indications in excess of the allowable standards t

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SQ.4P SI-il4.2 Page 55 of 83 Rev. 13 .

are revealed, all of the remaining components within the same examination category shall be examined to th? extent specified in Table IHO-2500-1.

9.1.1 Auxiliary Feedwater System Piping and Valve Component Supports The aux 111ary feedwater system piping includes component supports. All of these shall be examined during each inspection period in accordance with Table C of Appendix A.

9.1.2 Chemical and Volume Control System Piping and Valve Component Supports The chemical and volume system pip!ng has component supports. They are not required to be examined because there is no examination category for this piping. (The change in support numbers during the second period was due to new code class boundarles).

9.1.3 Component Cooling System Piping and Valve Component Supports The component cooling system piping includes component supports. All of these shall be examined during each inspection period in accordance with Table C of Appendix A. (The change in support numbers during the second period was due to new code class boundarles).

9.1.4 Containment Spray System Piping and Valve Component Supports .

The containment spray system piping has no component supports. (The change in support numbers during the second period was due to new code class boundaries.

9.1.5 Essential Raw Cooling Water L: tem Ptolno and Valve Component Supports

~

The essential raw cooling water system piping includis component supports. All of these shall be examined during each inspection period in accordance with Table C of Appendix A. (The change in sapport numbers dJring the second period was due to new code class boundaries).

9.1.6 Fuel Pool Cooling System Piping and Valve Component ,

Supports The fuel pool cooling system component supports are examined in accordance with SI-114.1, Unit I program.

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SQNP SI-114.2 Page 56 of 83

.Rev. 13 9.1.7 Residual Heat Removal System Piping and Valve Component Supports The residual heat removal system piping has no component supports. (The change in support numbers during the second period was due to new code class boundarles).

9.1.8 Safety Injection Syftem Piping and Valve Component '

Supports .

The safety injection system piping has no component supports. (The change in support numbers during the second period was due to new code class boundarles).

9.2 Equipment Component Supports The equipment component support and the associated integrally-welded support attachment will be (VT-3 or VT-4 as applicable) examined together.

9.2.1 Containment Spray Heat Exchanger (?)-CSH: ERCW System 9.2.1.1 CSH Integrally-Welded Support Attachment There are four Integrally-welded support attachments on each CSH. All of these attachments shall be (VT-3) examined during the inspection interval in accordance with Table C of Appendix A.

9.2.1.2 ~CSH Component Support There"Is one component support on each CSH.

This support shall be (VT-3) examined during the inspection interval in accordance with Table C of Appendix A.

9.2.2 Nonregenerative Letdown Heat Exchancer(1)-NRLHX: CCS 9.2.2.1 NRLHX Integrally-Welded Support Attachment .

There is one Integrally-welded support attachment on the NRLHX. This attachment shall be (VT-3) examined during the inspection Interval in accordance with Table C of Appendix A.

9.2.2.2 NRLHX Comoonent Support There is one component support on the NRLHX.

This support shall be (VT-3) examined during I

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-- the inspection interval in accordance with Table C of Appendix A.

9.2.3 Gas Stripper and Bortc, Acid Evaporator (I)-GSBAE: CCS 9.2.3.1 GSBAE q;.tcrator Condensor-EC 9.2.3.1.1 EC Intears11v-Welded Support Attachment There are no integrally-welded support attachments on the EC.

9.2.3.1.2 EC Component Support There are two component supports on the EC. These supports shall be (VT-3) examined durin9 the inspection interval in accordance with Table C of Appendix A.

9.2.3.2 GSBAE Olstillate Cooler (I)-DC: CCS

) 9.2.3.2.1 DC Integrally-Welded Support Attachment There are two integrally-welded support attachments on the DC. All of these attachments shall be (VT-3) examined during the inspection Interval in accordance with Table C of Appendix A.

9.2.3.2.2 OC Component Support There are two component supports on the OC. These supports shall be (VT-3) examined during the inspection Interval in accordance with Table C of Appendix A.

9.2.3.3 GSBAE Vent Cooler (I)-VC: CCS 9.2.3.3.1 VC fat:grally-Welded Support Attachment There are no integrally-welded rapport attachments on the VC.

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SQNP SI-114.2 Page 58 of 83 Rev. 13 9.2.3.3.2 VC Component Support There are two component supports on the VC. These supports shall be (VT-3) examined during the inspection Interval in accordance

- with Table C of Appendix A.

9.2.3.4 GSBAE Support Frame (1)-SF: CCS 9.2.3.4.1 SF Integrally-Welded Support Attachment There are no integrally-welded support attachments on the SF.

9.2.3.4.2 SF Component Support The SF consists of one component support. This support shall be (VT-3) examined during the inspection Interval in accordance with Table C of Appendix A.

9.2.4 Component Cooling Surge Tank (1)-CCST:CCS 9.2.4.1 CCST Integrally-Welded Support Attachment ,

The entire length of each CCST support skirt-to-tink weld shall be (VT-3) examined during the inspection interval in accorcance with Table C of Appendix A.

9.2.4.2 CCST Component Support There is one component support on each CCST.

This support shall be (VT-3) examined during the inspection interval in accordance with Table C of Appendix A.

9.2.5 Positive Olsplacement Charging Pump 011 Cooler (1)-PDOC: .

l C

9.2.5.1 P00C Integrally-Welded Suppcet Attachment There are no integrally-welded support attachments on the PDOC.

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Rev. 13 9.2.5.2 POOC Component Supporj, There are two component supports on the PDOC.

These supports shall be (VT-3) examined during the inspection interval in accordance with Table C of Appendix A.

9.2.6 Gross Falled Fuel Detector (l)-GFFO: CCS 9.2.6.1 GFF0 Integrally-Welded Support Attachment There are no integrally-welded support attachments on the GFFD.

9.2.6.2 GFFD Component Support There is one component support on the GFFD.

This support shall be (VT-3) examined during the inspection !nterval in accordance with Table C of Appendix A.

9.2.7 Centrifugal Charging Pump Gear Oil Cooler (2)-CCPGOC (ERCW) 9.2.7.1 CCPGOC Integrally-Welded Support Attachment There are no integrally-velded support attachments on the CCPG0C.

9.2.7.2 CCPGOC Component Support There are two component supports en each CCPGOC. These supports shall be (VT-3) examined during the inspection interval in accordance with Table C of Appendix A.

9.2.8 Centrifugal Charging Pump Oil Cooler (2)-CCPOC (ERCW) 9.2.8.1 CCPOC Integrally-Welded Support Attachment There are no integrally-welded suppurt attachments on the CCP0C. . .

9.2.8.2 COPOC Component Support There are two component supports on each CCPOC. These supports shall be (VT-3) examined during the inspection Interval in accordance with Table C of Appendix A. -

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- Page 60 of 83 Rev. 13 9.2.9 Waste Gas Compressor Heat Exchancer(1)-WGCHX: CCS 9.2.9.1 WGCHX Integrally-Welded Support Attachment There are no integrally-welded support attachments on the NGCHX.

9.2.9.2 WGCHX Component Support There are t.o component r4 ports on the NGCHX.

These supoorts shall be (VT-3) examined during t1e insp1ction interval in accordance with Taule C of Appendix A.

9.2.10 Centrifuoal Charging Pump Mechanical Seal Cooler (4)-CCPMSC: CCS 9.2.10.1 CCPMSC Intecrally-Welded Support Attachrent There are no integrally-welded support attachments on the CCPMSC.

9.2.10.2 CCPMSC Component Support There is one component support on each CCPHSC.

This support shall be (VT-3) examined during the inspection Interval in accordance with Table C of Aopendix A.

9.2.11 RHR Pump Seal Cooler (2)-RHRSC: CCS 9.2.11.1 RHRSC Integrally-Welded Support Attachment There are no integrally-welded support attachrents on the RHRSC.

9.2.11.2 RHRSC Component Supeort There is one ccmponent support on each RHRSC.

This support shall be (VT-3) examined during the inspection Interval in accordance with - .

Table C of Appendix A.

9.2.12 Safety injection Pumo 011 Cooler (2)-S!POC: ERCH 9.2.12.1 S!POC Integrally-Welded Suoport Attachment There are no integrally-welded support attachments on the SIPOC.

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. Page 61 of 83 Rev. 13 9.2.12.2 SIPOC comm ent Support There are two component supports on each SIPOC. These supports shall be (VT-3) examined during the inspection interval in accordance with Table C of Appendix A.

9.2.13 Safety Injection Pump Seal Cooler (4)-SIPSC 9.2.13.1 SIPSC Integrally-Welded Support Attachment There are no integrally-welded support attachments on the SIPSC.

9.2.13.2 SIPSC Component Support There is one component support on each SIPSC.

This support shall be (VT-3) examined during the inspection interval in accordance with Table C of Appendix A.

9.2.14 Seal Water Heat Exchanger (I)-SWHX: CCS 9.2.14.1 SWHX Integrally-Welded Support Attachment There is one integrally-welded support attachment on the SWHX. This support shall be (VT-3) examined during the inspection interval in accordance with Table C of Appendix A.

9.2.14.2 SWH)_Cc;ponent_ Support There is eno component support on the SWHX.

This support shall be (VT-3) examined during the inspection interval in accordance with Tabit C of Appendix A.

9.2.15 Component Cooling System Thermal Barrier Booster Pump (2).TBBP_

9.2.15.1 TB8P Integrally-Welded Support Attachment . .

There are no integrally-welded support attachments on the TBBP.

9.2.15.2 TB8P Component Support There are two component supports on each TBBP.

These supports shall be (VT-3) examined during the inspection Interval in accordance with Table C of Appendix A.

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. Page 62 of 83 Rev. 13 9.2.16 Turbine Driven Auxillary Feedwater Pumo(1)-T0AFP 9.2.16.1 TDAFP Integrally-Walded Support Attachment There are no integrally-welded support attachments on the TDAFP.

9.2.16.2 TDAFP Component Support There are two ccyponent supports on the TDAFP.

These supports shall be (VT-3) examined during the inspection interval in accordance with Table C of Appendix A.

9.2.17 Motor Driven Aux 111a.-/ Feedwater Pumo(2)-MOAFP 9.2.17.1 MOAFP Integrally-Welded Support Attachment There are no Integrally-welded support httachments c') the NOAFP.

9.2.17.2 MOAFP Compor it Sucoort There are two component supports on each NOAFP. These supports shall be (VT-3) examined during the inspection interval in accordance with Table C of Appendix A.

9.2.18 Cccoonent Cooling System Water Pumos(2)-CCSWP i

9.2.18.1 CCSWP Integrally-Welded Support Attachment There are no integrally-welded support attachments on the CCSWP.

9.2.18.2 CCSWP Componert Support There is one component support on the CCSWP.

This support shall be (VT-3) examined during the inspection interval in accordance with Table C of Appendix A. . .

9.2.19 Cocoonent Cooling Heat Erchanger(2)-CCHX 9.2.19.1 CCHX integrally-Welded Support Attachment There are two Integrally-welded support attachments on the CCHX. All of these attachments shall be (VT-3) examined during the inspection Interval in accordance with Table C of Appendix A.

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-- 9.2.19.2 CCHX Component Support There are three component supports on each CCHX. These supports shall be (VT-3) examined during the inspection interval in accordance with Table C of Appendix A.

9.2.20 Essential Raw Cooling Water System Strainer Support (2)-ERCNS 9.2.20.1 ERCHS Integrally-Welded Support Attachment There is one integrally-welded support attachment (consisting of 24 lugs on each) on each ERCHS. All of these attachments shall be (VT-3) examined during the inspection interval in accordance with Table C of Appendix A.

9.2.20.2 ERCWS~ Component Support There is one component support on each ERCHS.

This support shall be (VT-3) examined during the inspection trterval in accordance with Table C of Appendix A. ,

9.2.21 RHR Heat Exchanger Secondary Site Supports (2) RHRHSXH: CCS 9.2.21.1 RHRHSXH Integrally-Welded Support Attachment There are two Integrally-welded support attachments on each RHRHSXH. All of these attachments shall be (VT-3) examined during the inspection interval in accordance with Table C of Appendix A.

9.2.21.2 RHRHSXH Component Support There are two component supports on each RHRHSXH. These supports shall be (VT-3) examined during the inspection interval in accordance with Table C of Appendix A. . ,

9.2.22 ERCH Strainer Support (2)-ERCHSH 9.2.22.1 ERCHSH Integrally-Welded Support Attachment There are 24 Integrally-welded support attachments on each ERCWSH, All of these attachments shall be (VT-3) examined during the inspection interval in accordance with Table C of Appendix A.

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. Page 64 of 83 Rev. 13 9.2.22.2 ERCWSH Component Support o

There is one component support on each ERCNSH.

This support shall be (VT-3) examined during the inspection interval in accordance with Table.C of Appendix A.

9.3 System Pressure Tests

' All ASME Code Class 3 (Equivalent) system pressure tests shall be performed in accordance with Program Procedure 1502.03, 9.3.1 System Inservice Tests Pressure retalning components within the boundary of systems or portions of systems equired to operate in support of normal plant safet) . unctions of shutting down and maintelning the reactor in the cold shutdown condition, and pressure retalning piping, pumps, and valves wlthin the boundary or systems or portions of systems required to operate in support of residual heat removal from spent fuel storage pool, shall be visually examined in accordance with visual exaalnation method VT-2 (see section 11.1) while the applicable systems are in service under operating pressure in accordance with IWD-5221 of ASME Section XI. This shall be performed in accordance with SI-267 series. .

Thess examinations and tests shall be performed during .

each inspection period.

9.3.2 S J stem Functional Tests Pressure retalning components within the boundary of systems or portions of systems required to operate in support of the postaccident safety functions cf emergency  ;

core cooling, containrent heat removal and atmospheric cleanup, and long-term residual heat remval from the reactor vessel shall be visually examined in accordance with visual examination method 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. This shall be performed in accordance with SI-267 series.

9.3.3 System Hydrostatic Tests Pressure retalning components identified in Sections 9.1.1 and 9.1.2 shall be visually examined in accordance with visual examination method VT-2 (see I 0867e/COC4

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SQNP SI-114.2

, Page 65 of 83 Rev. 13 Section 11.1) during a system hydrmtatic test conducted in accordance with 1140-5223 of AShi Section XI. These examinations and tests shall be performed over each inspection interval. This shall be performed in accordance with SI-265 series.

9.4 Component Supports and Restraints Component supports and restraints within the boundarles of the

' systems identified in Sections 9.1.1 and 9.1.2 for components-exceeding 4-inch nominal pipe size shall be visually examined each inspection period in accordance with visual examination method VT-3 (see Section 11.1).

9.5 Snubbers and Hangers Hechanical and hydraulle 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 ASME Code Class 1, 2 and 3 components at Sequoyah Nuclear Plant. The c inspector shall verify, assure, or witness that code requirements have been met. He shall have the prerogative 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 IHA-2140 of ASME Section XI.

TVA's interface with the Authorized Inspector for inservice inspection, repairs, and replacements is defined in NQAM Part II, 56ction 2.3 and Part II, Section 5.1, Program Procedure 1402.02, HI 6.21, end AI-19 Part IV and Part VI.

11.0 EXAMINATION HETH005 If during an examination it is determined by an NDE Level III that a full code exam cannot be performed, the fact shall be documented on the .

data sheet and a best effort examination shall be cerformed. The IS!

Programs Section shall be Informed in writting of the Ilmited scan.

Data must be provided on the exam sheet so as to determine the percentage of the exam done, 11.1 Visual Eramination

• Visual examinations that require clean surfaces or decontamination (c. valid interpretation of results shall be preceded by appropriate cleaning processes, j 0867e/COC4

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. Page 66 of 83 Rev. 13 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, including such conditions as cracks, wear, corrosion, erosion, or physical damage on the surfaces of the part or components, 11.1.1.1 Direct Visual Examination VT-1 .

Olrect VT-1 visual examination may be conducted when access is sufficient to place the eye 24 inches (610 mm) of the surface to be examined and at an angle 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' to resolve a 1/32 inch (0.8 mm) black line on an 18% neutral gray card.

11.1.1.2 Remote Visual Examination VT-1 Remote VT-1 visual examination may be substituted for direct examination. Remote examination may use aids such as telescopes, borescopes, fiber 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 The VT-2 visual examination shall be conducted to locate evidence of leakage from pressure retalning cceponents, or abnormal leakage from components with or without leakage collection systems as required curing the conduct of system pressure or functional test.

The visual examination, VT-2; may be conducted without the removal of insulation by examining the accessible and exposed surfaces and joints of the insulation. ~ .

Essentially vertic21 surfaces of insulation need only be examined at the lowest elevation where leakage may be detectable. Esser.tlally horizontal surfaces of insulation shall !e examined at each insulation joint.

For twponents whose external insulation surfaces are inaccessible for direct examination only the examination of surrounding area, including floor areas or equipment surfaces located underneath the components, for evidence of leakage, or other areas to which such leakage may be channeled, shall be required.

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- Discoloration or residue on surfaces examined shall be given particular attention to detect evidence of boric acid accumulations from borated reactor coolant leakage.

The visual examination shall be conducted during the system leakage tests conducted after refueling outages

. and prior to startup.

s VT-2 visual examination shall be conducted in accordance with ASME Section XI .IWA-5240, and the applicable NDE Procedure.

11.1.3 Visual Examination VT-3 The VT-3 visual examination shall be conducted to determine the general mechanical and structural con::ltions of ccaponents 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 appilcable to determine structural integrity, the measurement of clearances, detection of physical displacement, structural adequacy of supporting elements, connections between load carrying structural members, and tightness of bolting.

For component supports and component interiors, the visual examination may be performed remotely with or without optical aids to verify the structural integrity of the component.

11.1.4 Visual Examination VT-4 The VT-4 visual examination shall be conducted to deter.-Ine conditions relating to the operability of components or devices such as mechanical and hydraulle snubbers, component supports, pumos, valves, and spring loaded and constant weight hangers.

VT-4 shall ccnfirm functional adequacy, verification of ,

the settings, or freedom of motion. This examination may require (1) disassembly of corrponents or devices and (2) operability test.

11.2 Surface Examination 11.2.1 Hagnetic Particle Examination Ray. etic particle examination (MT) shall be conducted in accordance with Article 7,Section V of the ASME Code.

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+ Rey, 13 11.2.2 1.lauid Penetrant Examination Liquid penetrant examination (PT) shall be conducted in accordance with Article 6 Section V of the ASME Code.

11.3 Volumetric Examination 11.3.1 Radiographic Examination Radlographic techniques, employing penetrating radiation such as X-rays, gamma rays, or thermalized neutrons, may be utilized with appropriate Imr.ge 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 the applicable NOE Procedure.

(b) Ultrasonic examination of Class I and Class 2 ferritic steel piping systems shall be conducted in accordance with Appendix III, amended as follows:

(1) For examination of welds, reflectors that produce a response greater than 507. of the reference level shall be recorded.

(c) If the requirements of (a) and (b) above are not applicable, the ultrasonic examination shall be conducted in accordance with the applicable requirements of Article 5 of Section V amended as follows:

' ~

(1) For examination on welds, reflectors that produce a response greater than 507. of the reference level shall be recorded.

(2) for examination of welds, all reflectors which produce a response greater than 1007. of the reference level shall be investigated to the extent that the operator can determine the shape, Identity, and location of all such reflectors in terms of the acceptance-rejection standards of IHA-3100(b).

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+ -

(3) The size of reflectors shall be measured between points which give amplitudes equal to 1007. of the reference level.

11.3.3 Eddy Current Examination Eddy current examination of heat exchanger tubing shall be conducted in accordance with the provisions of Appendix IV of Section XI of the ASME Boller and Pressure Vessel Code. ~

12.0 00ALIFICATIONS OF NONDESTRUCTIVE EXAMINATION PERSONNEL Personnel performing nondestructive examination operations shall be quallfled in accordance with IWA-2300 of ASME Section XI as required in progra: procedure 0202.14 (or QMP 102.4),

13.0 ACCEPTANCE CRITERIA All acceptance standards for ASME Code Classes 1, 2, and 3 (Equivalent) components shall be in accordance with IHA-3000, IHB-3000, IWC-3000, or IWO-3000 of ASME Section XI, except where ASME Section III examinations are employed to satisfy ASME Section XI requirements.

14.0 REPA!RS All ASME Section XI components and their supports (ASME Classes 1, 2, and 3) shall be repaired in accordance with the Repair and Replacement i Program included in NQAM Part II, Section 2.3 and Implemented by Program Procedure 1402.02, MI-6.21, and A!-19 Part IV and Part VI.

15.0 REPLACEMENTS Replacements of ASME Section XI components (ASME Classes 1, 2, and 3) shall be in accordance with the Repair and Replacement Program in NQAM Part II, Section 2.3 and Implemented by Program Procedure 1402.02 (SQNP), MI-6.21, and AI-19 Part IV and Part VI.

' ASME Section XI repairs and replacements may be coordinated as necessary with the ISI Programs Section.

16.0 RECORDS AND REPORTS 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

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Title Page

Table of Contents

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$1-114.2

, Page 70 of 83 Rev. 13 I. Introduction - The introduction should include the following Information: Plant, unit number, preservice or

• Inservice inspection and cycle number, systems, compon-ents and vessels examinations were performed on, organt-zation examinations were performed by, dates examinations were performed, ASME Section XI Code of Record.

II. Summary - The suanary should include a brief description .

of the overall inspection: Program, performance, personnel, equipment, procedures, evaluations, and '

results.

III. Discussion - The discussion should discuss the governing documents (ASME Code Technical Specifications, etc.),

inspection schedule, materials, calibration standards, calibration parformance, reporting, recording, interpretation, and brief evaluation. .

IV. Evaluation - Evaluation is based on the Indication's location, metal path, general shape, and any tests that could be applied, such as damping. The evaluation  !

section also should contain a listing of each examination performed and the evaluated results.

V. Summary of Notifications - The summary of notifications shall give a short summary of each notification report along with the Indication discrepancy and its location.

It should also contain the final disposition and the date of completion. -

VI. Scan Plan - The Scan Plan shall give a detailed '

description of all areas subject to examination during the inspection. It shall contain the following information: Examination Area Code Category, Weld Size and/or Number, Reference Drawing, Eramination Method, Procedure Calibration Block, and any reference details pertaining to the eram area, such as the weld number, merldlonal welds, pump studs, etc.

VII. Weld Maps an'd Support Orawings - The Held Haps and Support Orawings are the reference drawings for the .. .

inspection. The weld maps are isometric drawings showing the location of both field and shcp welds on each vessel, ccmponent, and piping system subject to examination. The support drawings are also isometrics showing the location of hangers, snubbers and supports for each vessel, component, or piping system subject to examination.

VI!!. Log by System - The log is the daily status of the inspection section representative of the areas subject to examination during the inspection. This log keeps an up-to-date status of work complete and incceplete.

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IX. Personnel Certifications  :

X. Equipment Certifications XI. N0E Procedures ,

XII. Calibration Block Orawings '

XIII. Calibration Sheets ,

XIV. Examination Data Sheets t 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 tubG W&5 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 as needed. These reports shall be made in compilance with paragraph 20.4 and SON Technical Speelfication surveillance requirement 4.4.5.5.

g All procedures and equipment shall be identifled sufficiently to permit duplication of the examination at a later date. This  !

+

shall include initial calibration data for the equipment and any significant changes, y

[

All required and pertinent Information will be recorded on the i appropriate data s h ets by the performing organization. When -

portions of the inspection work are contracted, a detailed report 4

will be submitted to TVA by the contractor with all pertinent and i~ required information. TVA will retain the original copies of all ,

raw data taken. .

I l DNQA 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 C of this program as discussed in Section 5.0 of this program. Data Sheet 1 in j Appendix C will be completed and used as a cover sheet for the

final report and to document the review process.

i 16.1.1 Repair and Replacement Reports 4

Repairs and Replacements Summary Reports shall be i prepared in accordance with Program Procedure 1402.02 MI-6.2 1 and AI-19 Part IV and Part VI.

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-- 16.2 ISI Report for Class I and 2 Components DNQA shall prepare an ISI Summary Report for Class I and 2 components (with the exemption of Steam Generator Tubing examinations - see paragraph 20.4) to be submitted within 90 days after the completion of the Inservice Inspection with the Nuclear Regulatory Commission Region II Office in accordance with i IRA-6220, ASME Section XI.

'The ISI Report shall have a cover sheet providing the following information: ,

(1) Date of completion of report.  :

(2) Name of owner and address of corporate offices.

(3) Name and address of nuclear generating plant in which the ,

nuclear power unit is located. t (4) Name and number assigned to the nuclear power unit by TVA.

(5) Commercial operation date for unit.

All reports shall have a summary providing the following information:

(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 numeer which will identify the subcontractors. Manufacturer's component identification numbers. -

(e) Date of completion of the examination. . .

(f) Name of AN!! who witnessed or otherwise vertfled the examinations, and his employer and business address, when required.

t (g) Abstract of examinations, conditions observed, and corrective measures recommended or taken.- r (h) Signature of AN!!, when required.

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SQNP SI-114.2

. Page 73 of 83 Rev. 13 (1) Owner's Data Report for Inservice inspection, Form NIS-1, as shown in Appendix II of ASME Section XI,' and Form NIS-2 as shown on Program Procedure 1402.02.

(j) Completed examination reports.

(k) Completed calibration reports.

(1) List of component drawings.

(m) List of TVA NDE personnel and/or copies of contrector personnel certifications.

(n) List of TVA NDE equipment and/or copies of contractors equipment certifications.

(o) List of TVA NDE procedures used and/or copies of contractor NDE procedures.

(p) Completed summary reports.

The DNQA shall submit the Intervice examination report to the plant manager for retention as a quality assurance record in accordance with NOAH, Part III, Section 4.1. The ONQA 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 Ofrector, ONP Nuclear Safety and Licensing.

16.3 Records for ASME Code Class 1, 2, and 3 (Equivalent) Components The plant (master files) shall assure the availability and storage of the following. records:

(1) Examination Plans and Schedules I

(2) Report'. of Examination Results (3) Exam' nation Methods and Procedures (4) Reports of Evaluation of Results . .

(5) Reports of Corrective Actions, Repairs, and Replacements 16.4 Records of System Pressure Vests Records of the visual examinations conducted during system leakage or hydrostatic tests shall consist of an itemization of the number and location of leaks found in a system and the i

corrective 4ctions taken.

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SQNP SI-114.2 Page 74 of 83 Rev. 13 16.5 Auamented Examination Reports Augmented examinatMn special reports shall be submitted to the l Nuclear Regulatory alssion Region II Office wtthin the time l period specified for each report. For specific details on i records, reports and reporting see section 20.0, Augmented l Inspections, of this program. The status of every augmented I examination requested by the ISI Programs Section and implemented by ONQA shall be maintained in a computerized data base, i

. l 17.0 NOTIFICATION OF INDICATION Plant management shall be formally notified of the presence of unaccept- ,

able indications found during inse vice inspections and detected during l the performance of nondestructive exaelnations (excluding VT-2, visual  ;

exastr.-t!:.n performed during system pressure tests). Unacceptable  ;

indications are defined by the applicable NDE procedure. Formal I notification shall consist of completing and submitting to the Plant 1 Manager or his designee the "Notification of Indication" (NOI) form in )

Appendix 0 of this program. The NOI form shall only be used to report 1 unacceptable Indications of components within the scope of Section XI i and which have been scheduled for examination. Scheduled examinations refer only to those components that are inservice inspection samples and exclude those examinations performed following repair or replacement of components. Any other discrepancies should be reported in accordance with the appropriate plant procedure (e.g., PRD, WR, etc.).

N0ls initiated prior to the requirement for a Condition Adverse to Quality Report (CAQR) and the loplementation of Revision 9 of this Instruction do not require "rollover" to the CAQR form.

Part I of the NOI form shall be completed and signed by the NDE Level II  :

or !!! 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 N01 form and the CAQR are to be processed together. If the indication is detected by an outside contractor, the contractor's field supervisor (when supplied by the contract) or his designee shall review and sign the N01 form. The ONQA representative shall assign a sequential number and review and sign the N0! form. A N01 log shall be maintained on a plant / unit 2 cycle basis by ONQA for each N01 issued. .

This log shall contain as a minimum: N01 No. , Component, I .D. , date I issued examination report No., unsatisfactory condition, and HR.H8 No.,

and work instruction and/or DCR numbers as appitcable. The original shall be sent to the plant manager or his designee and a r.opy to the ISI Prograrbs Section.

In the case of N0!$ for which No Condition Adverse to Quality Report (CAQR) has been identified, the Nuclear Site Director's Organization (plant manager or his designee) shall be responsible for determining which organization (Construction Modifications, Plant Maintenance, etc.)

shall be responsible for preparing a disposition in Part II of the N0!

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, Page 75 of 83 Rev. 13 organization assigned responsibility for disposition is unable to determine a satisfactory disposition, then the NOI form shall be sent to the NE for disposition.

The organization assigned responsibility for the disposition shall evaluate the NOI for the need of a CAQR in accordance with the NOAH Part I, Section 2.16 and plant instruction AI-12 (Part III)'. The CAQR shall be processed in accordance with AI-12 (Part III)'. 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.

If a CAQR 1s not required but the organization responsible for the disposition determines that a CAQ exists the CAQ shall be implemented in accordant.e with NQAM, Part I, Section 2.16 (AI-12 (Part III])'. The generated CAQ shall be identified, documented, evaluated, corrected, tracked, trended and reported to the appropriate level of management by the organization responsible.for the disposition usin one of the administrative programs spectfled in AI-12 (Part III)

The Individual responsible for yrt-... tion of the disposition shall sign and date Part II of the N01 fort. .:nd ensure that the dispositten agrees with the corrective action psoposed in the CAQR if one was initiated.

The cognizant supervisor or his designee of the appropriate organization shall review and approve the disposition and sign and date Part II of the N0! form. Coples of the form shall be distributed to the plant manager or his designee and the ISI Programs Section. The original shall be returned to the DNQA representative. One copy shall be filed with the txamination report. A copy of the dispositioned N01 should be attached to the work generating document used in correcting the unacceptable indication.

Dispositions to correct the condition under the plant maintenance program shall be processed in accordance with NQAM, Part II, Section 2.1 (SCH 2). Dispositions other than restoring to original requirements shall be processed as modifications in accordance with NOAH, Part !!,

Section 3.2 (AI-19, Parts IV and VI). Repair and replacement, activities, including coordination with the Authorizeo Inspection Agency (AIA), shall be performed in accordance with the requirements of NQAM, Part II, Section 2.3 (HI-6.21 and AI-19 parts IV and VI). The organization responsible for corrective hti:n shall include preservice examination requirements in the repair or replscement work instruction .

described in NQAM, Part II, Section 2.3 (see HI-6.21 and AI-19 parts IV and VI). In scoe instances the N0! may be dispositioned based on additional information available to the individual responsible for the disposition (e.g., design drawings, drawing nctet, specifications, etc.). In this case the NOI should be categorized as "other," and a documented justification will be included with the disposition. A USQO is not required to disposition N0!s categnrlzed as "other." The dispositten shall include re-examination if work was performed (e.g.,

tightening of loose bolts, etc.). Re-examination may be limited to area of component where work was performed.

'A!-12 (Part !) to be used uatti Al-12 (Part III) is approved.

I SQNP SI-Il4.2 Page 76 of 83 Rev. 13

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Upon completion of corrective action, the DNQA representative shall verify completion of corrective action, enter the work instruction and/or DCA numbers on the NOI form, enter the examination report number if re-examination was performed, and sign and date the N0! form, Part III. The signed NOI form shall remain with the original

, examination report for use as a quality assurance record. If re-examination was performed, a copy of the signed NOI form shall also ren,ain with the re-examination report. Copies of the NOI form shall i also be distributed to the plant manager and the ISI Programs Section.

i 18.0 CALIBRATION BLOCKS Calibration blocks will be used for ultrasonic examinations (a calibration tube will be used for eddy current examination of steam 1 generator tubing). The blocks will be fabricated to the general

requirements o' ASME Section V and/or ASME Section XI as applicable.

i The blocks sFais be fabricated of the material to be examined or l equivalent P numbers. The blocks shall employ drilled holes and/or notches for calibration reflectors (See Request for Relief ISI-2).

i The as-built calibration block drawings and mill test reports or j

certificates of compilance shall be controlled and distributed by the Document Control Center. The calibration blocks shall be stored at the plant site and maintained by the DNQA.

3 19.0 REQUESTS FOR RELIEF _

j Where TVA has determined that certain code requirements or examinations 3

are Impractical, IVA will submit written requests for relief to dRC with information to support the determinations and any proposed alternate

. examinations. The lepractical code requirements or examinations shall l be identified in tnis program,.and references to particular requests for j relief shall be included.

! , When Impractical examination requirements are identified in the field, 1

DNQA shall notify the ISI Programs Section such that the information may 1 be included in this program and requests for relief may be prepared if necessary.

J

! The Requests for Relief are listed in Appendix E. .. .

{ 20.0 AUCHENTED_ INSPECTIONS 3 Augmented inspections are performed in addition to ASHE Section XI code

requirements. The augmented inspections may be required by the NRC or self-imposed by IVA.

9 I Augmented examination'. of components that require reporting (verbal or

, written) to the NRC shall be the responsibility of the organization

, designated in the particular examinatloe. These reports shall be submitted to the Nuclear Regulatory Commlision Region !! Cffice within l

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SONP S1-114.2 i Page 77 of 83 the time period specified for each report. Each augmented exam shall ,

state the required reporting time and the document requiring the  :

information to be included in the report.

20.1 F*edwater System Ptolna and Supports ,

The requirements of NRC.IE Bulletin 79-13 wert satisfled during l the unit 2, cycle 1 outage. Due to the safety-related ramift-cations of the steam generator nozzle transition section cracking problem TVA will perform an augmented inspection (reference '

memorandum 1.29 831222 836 and memorandum from David Goetcheus to

. John T. l.ewis) of four feedwater nozzle during each refueilng outage. The augmented examination of the steam generator nozzle '

transition section shall include nozzle-to-transttlon piece welds and transition piece-to-pipe welds. These welds shall be ultrasonically examined and ultrasonic sensitivities should be equivalent to those required by NRC-!E Bulletin 83-02. The 3

i examination data sheets shall be included in the 90 day ISI report discussed in section 16.2 of this program.

20.2 RPV Nozzle Safe Ends The augmented examination requirements of the RPV nozzle-to-safe end welds are included in the final report - Sequoyah Nuclear

Plant - Evaluation of cracking in reactor vessel nozzle stainless steel buttering. TVA reinspected nozzles 2RC-175E and 2RC-24SE at the first regularly st

heduled cold shutdown outage. Future examinations for unit 2 will be monitored at the normal inservice

inspection intervals for dissimilar metal welds as required by Section XI of the ASME Code. This augmentid examination does not

requirr a special report. The examination data sheets shall be included in the 90 day ISI report discusad in section 16.2 of this program.

20.3 Reactor Ccolant Pump Flywheel The augmented examination requirements of th e reactor coolant

, pump flywheel are included in RegVlatory Pos tion C.4.b of

. . Regulatory Guide 1.141 (1) an inplace ultrasunic examination of the areas of higher stress concentration at the bore and keyway 1 at approdleately three-year intervals during the ref;eling or i

maintenance shutdown coinciding with the inservice inspection schedule as required by Sectlen XI of the ASME Code, and (21 a .

, surface examination of all exposed surfaces and complete

ultrasonic examination at sporoxht.ately 10-year intervals during

the plant shutdown r.oincidtrg wlth the intervice inspection schedule as required by Section XI of the ASME Code.

this augmented examination does not require a special report t

unless the examination rs oeals a flaw. If the examination and l evaluation Indicate an increase in flaw size or grosth rate J

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 Wegulatory Culde 1.14 for

}

0867e/CC<4 SQNP S1-114.2 Page 78 of 83 Rev. 13 information to be included. The examination data sheets shall be included in trie 90 day ISI report discussed in section 16.2 of this program.

Aft ** August 1, 1988 the in place examinations shall be recorded using the following ID's:

RCP-X-FLYWH-BORE RCP-X-FLYWH-KEY.

Fo'.* the 10 year exam the ID's will be:

RCP-X-FLYWH-SUR

• RCP-X-FLYWH-VOL 20.4 Steam Generator Tubing The augmented examinction requirements of the st wn ga"rato' ,

tubing are included in Technical Specifications 4.0.f , 4.5.0 and section 7.3.8 of th!s program. Following each ine etce 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 t Nuclear Regulatory Commission Region II Office within t%e time period specified. See plant instruction AI-18 for reperting instructions. 4 The complete results of the steam generator tube inservice <

inspection shall be submitted to the Nuclear Regulatory Comission in a special report pursuant to Technical Specification 6.9.2 within 12 months following conpletion of the inspection. The Steam Generator Support Group shall prepare this special report and submit the report to the Nuclear Regulatory Comission Region II Office within the stated time period. This special report shall include:

' l. N aber and extent of tubes inspected. [

2. Location and pe cent of wall-thickness penetration for each Indication of an Imperfection. ,

3. Identificatloa of tubes p'ug>,ed.

Results of steam generato.' tube inspections which fall into Techr.lcr.1 Soecification Category C-3 require prcept notification of the Nuclear Regulatory Comission pursuant to Technical ,

Specification 6.6.1 prior to resumption of plant operation.  !

The written folicwup of this report shall provide a uescription of InvestigAttons conducted to determine cause of the tube degradation and corrective measures to prevent recurrence.

l OS57e/COC4

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SQNP SI-Il4.2

. Page 79 of 83 Rev. 13 Refer to Technical Specifications Surveillance requirements 4.0.5 and 4.4.5.0 and section 7.3.8 and 16.0 of this program for ,

additional information. <

20.5 RPV Nozzle Cladding All vessel nozzles cladding shall be ultrasonically 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 reyutre a special report. The examination data sheets shall be included in the 90 day ISI report discussed in section 16.2 of this program, i Nozzle forging material and cladding is identifled in section 7.1.2 of this program.

20.6 Steam Generator reedring J-Tubes The carbor, steel J-tube nozzles have been replaced with Inconel 500 J-tube nozzles. This material is resistant to erosion  !

corrosion damage. Inspection of the J-tube nozzles is not

• necessary. A ultrasonic thickness check of the feed ring heater r and tee shall be performed on a frequency of every 10 years. This l augmented examination is self-imposed by TVA (501 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 -f this program.

20.7 Control Rod Guide Tube Flexures 1

Oue to the potential of intergranular stress corrosion cracking ,

of guide tube flexuret, the following control rod guide tube  !

flexure augmented examination plan shall be initiated.  ;

The control rod guide tube flexures shall be visually examined in accordance with visual examination method VT-3 (see section 11.1) ,

during each refueling outage. These examinations shall be . . (

performed in accordance wtth SMI-0-68-15. At each scheduled  ;

refueling outage the tops of all flexures are in their proper l 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 ,

af ter a failure has occurred, a safety evaluation will be  ;

required to confirm continued safe plant operation. A copy of l the VI data sheets shall be forwarded to the oppropriate i cognizant engineer in the Mechanical Maintenance Section for  ;

enclosure in SMI-0-68-15.

} 0867e/COC4

SQNP S!-114.2

, Page 80 of 83 Rev. 13 This augmented examination is self imposed by TVA and does not recuire a report. The examination data sheets shall be included it, the 90-day ISI report diccussed in section 16.2 of this program.

Any revisions or walvers of this examination plan shall be initiated by the Mechanical Maintenance Supervisor.  ;

20.8 Rod Cluster Control Assembly (RCCA) Claddina 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 e1aminations of the RCCA's will be performed during the unit 2, 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 acceptan.'s criteria for wear depth.  :

Examination may be performed through the use of a remote camera.

A random sample of 5 (approximate 101.) of the 53 RCCA's will be 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. 'lesolution of the camera's used should allow for the use of an .alytical model to infer the depth of wear indications fre che observed wear scar widths as measured by the use of photo <g aphy.

The wear indications are predominantly on the portion of the cladding surface facing the center or hub of the RCCA at elevations along the rodlet length corresponding to the guide plate surfaces. Note that, by design, some wear is expected due to contact between the RCCA rodlets and the guide surfaces.

Measurement and wear indication data should be sent to Westinghouse for evaluation. This augmented examination is self-imposed by TVA (122 840501 803) 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 Accelerated Field Weld Program (C.1) . .

In accordance with the letter from R. L. Gridley to

8. J. Youngblood dated January 30, 1987 (1.44 870130 804), TVA comitted to implement an accelerated field program for Sequoyah Unit 2 . This augmented and accelerated program requires completion of 1001, of ASME Classes I and 2 piping, piping support, and component (reactor vessel, steam generator, ,

pre,surizer, and reactor coolant pumps) support field welds that are in the first 10-year program in the two (2) consecutive refueling outages following restart. We are submitting a relief request (RFR-14).

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SQNP 51-114.2

. Page 81 of 83 Rev. 13 Appt.ndix A will still contain the schedule of exams as they were f scheduled prior to the accelerated fleid weld program for historical records. Appendix 8 will contain the revised schedule -

of examinations Implementing the accelerated fleid weld program.

This revised plan is the one we will follow for the rest of the first interval. The examination data sheets and results shall be included in the 90-day ISI report discussed in section 16.2 of i this program.

20.10 ' Thimble Tube Guide -

Due to the potential thinning of thimble tube guides as reported on NRC Bulletin 88-09 and information Notice No. 87-44 supplement 1 TVA will perform an augmented examination of the i thimble tubes using Eddy Current Exaneination (ET) during cycle 3. See memorandum from R. H. Fortenberry to S. J. Smith dated July 21, 1988 (557 880721 821) and memorandum from '

J. F. Murdock to J. 8. Hosmer dated June 3, 1988 (L29 880531 914).

Future examinations shall be scheduled according to the results '

of the cycle 3 exams.

Results of the examinations and actions taken shall be sent to the hRC.  !

20.11 Examination of pleing connected to the reactor coolant system due E thermal stresses.

1 Due to the potential thermal stresses on unisoluble piping .

attached to RCS (see NRC Bulletin 88-08) TVA will examine the following areas: (1) the four 1.5 inch high head injection  !

Ilnes, (2) the 2-inch pressurizer spray line from the charging path, (~l) the 3-inch alternate charging path, and (4) the 3-inch normal charging path. All of the welds up to the first valve  ;

will be PT, and the 3-inch line will receive an UT as weII.  ;

i These exams will be conducted during cycle 3. "

The SONP PE shall prepare the report to licensing which in turn shall prepare the report to the NRC. (See memorandum 829 880906 008, L44 880824 802, 508 880830 843, and 825 880819 014.) - .

1 20.12 Examination of Row I and Row 2 of the Steam Generatqrs The following augmented examinations requirements are self [

imposed by TVA and therefore do not require a special report.  :

However they shall be included within the report to NRC specified i

in section 20.4. This augmented examination is being performed i to satisfy the requirements in the recurrence control of CAQR No.  !

j SOPA80312. [

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/ 0867e/COC4 [

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SQNP SI-114.2

, Page 82 of 83 '

Rev. 13 6

All non plugged and also non-stress relieved steam generator row 1

I and 2 tubing in all 4S/G's shall have the U-bend regions examined witn an eddy current examination quallfled by TVA for the detection of primary water stress corrosion cracking (PHSCC) in close radius U-bends.

The frequency of these examinations shall coincide with the Inservice Inspection exams specified in section 7.3.8 the results of the examination shall not be utilized in determining the

' Inservice Inspection sample category, sample size for second and third sample (section 7.3.8.2.c). All tubes which have degradations (PWSCC) detected as a result of these row I and 2 U-bend examinations shall be plugged.

21.0 REFERENCES

21.1 . Source Occuments 21.1.1 ASME Boller and Pressure Vessel Code,Section XI,1974 Edition, Summer 1975 Addenda,1977 Edition, Sumer 1978 r Addenda.

21.1.2 ASME Boller and Pressure Code,Section V. ,

21.1.3 Sequoyah Nuclear Plant Final Safety Analysis Report.

21.1.4 Nuclear Quality Assurance Manual, Part II, Sections 2.3, 3.2, 5.1, and 6.3, and Part I, Section 2.16.  ;.

I 21.1.5 Code of Federal Regulations, Title 10. Part 50.55A.

21.1.6 U.S. Nuclear Regulatory Comission Regulatory Guide 1.14,  ;

1.26,1.150, and 1.83.  ;

21.2 Other Documents l

• 21.2.1 Sequoyah Nuclear Plant Standard Practice 501.

I 21.2.2 Westinghouse Technical Manual - Pressurizer, TM 1440-C225 Contract No. 68C60-91934, N2M-2-6.  !

21.2.3 Westinghouse Technical Manual - Vertical Stean f

Generators, TM 1440-C224 Contract No. 68C31-91934,  !

l N2M-2-4  !

r 21.2.4 Westinghouse Instruction Manual - Ausillary Heat j Exchangers, Contract No. 68C60-91934, N2M-2-25. [

• E 21.2.5 Westinghouse Instruction Book - Reactor Coolant Pump, l Contract No. 6SC60-91934, N2H-2-05.

i

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i SQNP .

l SI-114.2 t Page 83 of 83 Rev. 13 l

- 21.2.6 Ingersoll-Rand Instruction Manual - Residual Heat Removal Pumps. Contract No. 68C60-91934, N2M-2-30.

21.2.7 Sequoyah Nuclear Plant Technical Instruction TI-51.

21.2.8 Sequoyah Nuclear Plant Technical Specifications Unit 2.  ;

21.2.9 Program Manual Procedure: PMP 0202.14, PHP N75C01, N76A10. SEQ 80M7, SEQ 82El, and SQ82M1, PMP 1502.07 (Formerly DPM N80E3).. .

21.2.10 Memorandum fr:wn D. W. Wilson to H. L. Abercromble dated i August 1, 1983, "Sequoyah Nuclear Plant Units 1 and 2 t indications in class I welds" (L18 860730 899).  !

21.2.11 Sequoyah Nuclear Plant M1-6.2.1. I 21.2.12 ASME Section XI Interpretations, PMP 1502.01 (Formerly i N83A3).

P 21.2.13 Memorandum from V. A. Blanco to C. R. Brimer dated January 10, 1987 (B25 870109 045).  ;

21.2.14 Memorandum from G. G. Zecit to S. A. White dated January 25, 1988 allowing the use of code cases M-341 and N-356. j 21.2.15 Memo from P. R. Wallace to W. T. Cottle and C. C. Mason 'l dated May 11, 1984 (L22 840501 803), "Nuclear Plant Operating Expertence Review - Westinghouse Letter i 84TV'-G-027. RCCA Cladding Wear Observations."

i 21.2.16 Program Procedures and Quality Methods Procedures:

l 0202.14 (or QMP 102.4), 1502.07 (or QMP 110.5), 1502.03, i l and 1402.02.

l l 21.2.17 Letter from R. L. Gridley to 8. J. Youngblood datea l January 30, 1987 (L44 870130 804). l l t 21.2.18 NRC Bulletin 88-09 and information Notice 87-44 i supplement 1. , ,

l 21.2.19 Memorandum from R. H. Fortemberry to S. J. Smith dated  !

l July 21,1988 (557 880721821) {

21.2.20 Memorandum from J. F. Murdock to J. B. Hosner dated i June 3, 1988 (L29 880531 914) l i

l ) 0967e/COC4 r {

i

898F SI-114.1 Page 1 of 1 Rev.,13 AFFENDIX A

, TABLE 1 ,

MINIMLM NUMBER OF STEAM CENERATORS TO BE INSFECTED DURING INSERVICE INSFECTION ONLY No. of Steam Cenerators per Unit y First Inservice Inspection Second and Subsequent Inservice Inspections  %

Table Notation:

Each of the other two steam generators not inspected during the first inservice inspections shall be inspected during the secono and third inspections.

E f The maximum allowable time between eddy-current inspections of an individual steam generator should not extend beyond 72 months (IVA coannitment to NRC L44 850617 801).

f O

C0C4/0070e

, . o SQNP SI-114.2 Page 1 of 1 Rev. 13 4 AFFENDIX A TABLE 2 STEAM CENERATOR TUBE INSPECTION First Sample Inspection Second Sample Inspection Sample Size Third Sample Inspection Result Action Required Result Action Required Result Action Required A minimum of S C-1 None N/A N/A tubes per S.C. N/A N/A C-2 Plug defective C-1 None N/A N/A tubes and inspect Flug defective tubes C-1 None additional 2S C-2 and inspect additional C-2 Flug defective

., tubes in this S.C. 4S tubes in this S.C. tubes e C-3 Perform action y Perform action for for C-3 result C-3 C-3 result of firsi. of first sample N/A N/A C-3 Inspect all tubes All other this S.C., plug S.C.s are None N/A N/A defective tubes C-1 and inspect 2S Some S.C.s Ferform action for tubes in each C-2 but no C-2 result of N/A N/A other S.C. additional second sample S.C. are C-3 Prompt notification to Additional Inspect all tubes NRC pursuant to tech- S.C. is C-3 in each S.C. and plug N/A N/A nical specification defective tubes. N/A N/A 6.9.1. Prompt notification to NRC pursuant to technical specification 6.9.1.

- - - 12%

3 n Where n is the na:mber of steam generators inspected during an inspection. -

CoC4/os h

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SQMF SI-114.2 Fage 1 of 14 APPENDIX A Rev. 13 TABLE A SEQUOYAE INSERVICE INSPECTION FROGRAM I CIASS 1 COMPONENTS Program Section XI Reference Fu==' Exam 1st Insp. Interval Component Inspection Periods Reference Section Method Category 43 Yr. Sample Sample 3 yrs. 7 yrs. 10 yrs. Dws. No.

A. Reactor Vessel

1. Circumferential 7.1.1.1 UT B-A 4/50 ft. 4/50 ft. 0 0 4 ISI-0298-B Shell Welds

2. Closure Head 7.1.1.3 UT B-A 41 ft. 41 ft. 13 ft. 14 ft. 14 ft. ISI-0301-A Ci c Weld

3. Iower Head 7.1.1.4 UT B-A 38 ft. 38 ft. 0 0 38 ft. ISI-0298-B Circ Weld ,

T 4. Lower Ucad 7.1.1.6 UT B-A 6 6 0 0 6 ISI-0298-B Meridional Welds

5. Shell-to-Flange 7.1.1.7 UT B-A 50 ft. 50 ft. O ft. O ft. 50 ft. ISI-0298-B Weld

6. Closure Head- 7.1.1.8 UT B-A 45 ft. 45 ft. 15 ft. 15 ft. 15 ft. ISI-0301-A to-Flange Wcid

7. Nozzle-to 7.1.2 UT B-D 8 8 4 0 4 Inlets ISI-Oi98-B vessel Welds Outlets (Inner & ISI-Oi97-A (Outer cuter CHM-2360-A Bore) bore) 4 Outlets (Inner Bore) 0869e/COC4

SI-114.2 Page 2 of la AFFENDIX A Rev. 13 TABLE A SEQUOYAE INSERVICE INSFECTION FROGRAM I CLASS 1 COMPONENTS Program Section XI Reference Exass' Fwamm ist Insp. Interval Inspection Feriods Reference Component Section Method Category 40 Yr. em le Sample 3 yrs. 7 yrs. 10 yrs. Dws. No.

A. Reettor Vesriel (Cont *d)

8. Inside Radius 7.1. 's UT B-D 8 8 4 0 4 Inlets ISI-0297-A Sec*.lons Outlets ISI-4XM8-B (includes integral CEM-23/i0-A extensions on the outlet nozzles)

9. Vessel Pene- 7.1.4 VT-2 3-E 141 37 12 12 13 15sI-0097-C trations and ISI-0319-C

& Attachments 7

10. Nozzle-to-Safe 7.1.5 UT. PT B-1 8 8 houtlet 0 4 inlet ISI-0008-5 End Welds

11. Closure Studs 7.1.6 UT. MT B-G-1 54 54 18 18 ISI-0304-B and Nuts ,

12. Ligaments 7.1.6 UT B-G-1 54 54 18 18 18 ISI-0304-B Between Threaded Stud Holes .

13. Closure Washers 7.1.6 '1T-1 B-C-1 54 54 18 18 18 ISI-0304-B

14. Vessel Interior 7.1.9 VT-3 B-N-1 1 1 1 1 1

13. Removal Core 7.1.10 VT-3 B-N-3 See Program Section 7.1.10 Support Structure ,

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W sI-114.2 Page 3 of 14 APPENDIX A Rev. 13

-TABLE A SEQUOYAH INSERVICE INSPECTION PROGRAM CLASS 1 COMPONENTS Program Section XI Reference Fw=E Exam 1st Insp. Interval Component Inspection Periods Reference Section Method Category 40 Yr. Sample e ele 3 yrs. 7 yrs. 10 yrs. Dwa, No.

A. Reactor Vessel (Cont'd)

16. Control Rod 7.1.11 UT B-O 20 2 0 Drive Housings 1 1 ISI 4097-C ISI-0300-A

17. Auxiliary Head 7.1.12 UT. PT B-F 4 4 2 1 1 ISI-0097-C ISI-0001-C ISI-0318-A

,B. g essurizer .

o>

? 1. Circumferenttal 7.2.1 UT B-B 2/24 ft. 2/24 ft.

Shell-to-Head 12 ft. 12 ft. 24 ft. ISI-0308-A Welds

2. Longitudinal 7.2.2 UT B-B 2/1 ft. 2/1 ft.

Shell-to-Head l' l' l' ISI-0308-A Welds .

3. No:.zle-to-Vessel 7.2.4 UT B-D 6 6 2 2 2 ISI-0308-A and Inside '

Radius Section 4 Heater 7.2.5 VT-2 B-E 78 20 6 7 7 ISI-0309-A Penetrations

5. Nozzle-to-Safe 7.2.6 UT. PT 3-F 6 6 2 2 2 ISI-0308-A End Welds r .

'The longitudinci ' weld selected for examination is that weld intersecting the circumferential shell-to-head weld examined.

0869e/C0C4 I

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,-,.___m _ _. . _ _ , . _ . , _ , , , _ _ , _____-_ , _ _ , ,

SqNP

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SI-114.2 Page 4 of 14 APPENDIX A Rev. 13 TARI.E A SEQUOYAR INSERVICE INSPECTION PROGRAM CLASS 1 COMFONENTS Program ,Section XI Reference Exam Exam ist Insp. Interval Component Inspection Periods Reference Section Method Catesory 40 Yr. Sample

• rle 3 yrs. 7 vre. 10 vre. Dwn. No.

B. Pressurizer (Cont'd)

6. Pressure 7.2.8 VT-1 B-C-2 1 mwy/16 bolts 16 bolts Retaining Bolting 16 0 0 ISI-0299-B

7. Integrally 7.2.9 MT B-H 23 ft. 23 ft. 7 ft.

Welded Vessel 8 ft. 8 ft. ISI-0323-A Supports -

C.~~

Steam Cenerators ,

1. Primary 7.3.2 UT B-B 4/36 ft. 4/36 ft. 1 2

' ISI-0320-5 I

Head-to-Tube Sheet Weld

2. Primary Nozzle- 7.3.3 See Program Section 7.3.3 (Request for Relief ISI-)

to-Vessel and Inside Radius .

Section

3. Primary Nozzle- 7.3.4 UT. PT B-F 8 8 2 3 3 to-Safe End Welds ISI-0008-5

4. Pressure 7. 3. f. VT-1 B-C-2 4 gens./2 mwy 8 mwy Retaining Bolting 2 2 4 ISI-0299-3

5. Tubing 7.3.8 ET & gens./31 B-Q 4 gens./31 2 1 1 76M1

. 0869e/COC4 .

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SQHP SI-114.2 Page 5 of 14 AFFENDIX A Rev. 13 TABLE A SEQUCYAN INSERVICE INSFECTION PROGRAM CLASS 1 COMPON'JfTS Program Section XI Reference Fn=, Exam 1st Insp. Interval Inspection Perioda Component Section Method Category 40 Yr. Sample Reference emle 3 yrs. 7 yrs. 10 yrs. Dwn. No.

D. Pressure Retaining Bolting

1. Reactor Cortrol 7.4.3.1 UT-1 B-C-2 13 Sets 13 Sets System 3 5 5 ISI-0013-C t

2. Chemical and 7.4.3.2 VT-1 B-C-2 4 Sets /4 Bolts 4 Sets 1 1 2 MSC-0008-C Volume Control System (SWI) .

3. Res* dual Heat 7.4.3.3 VT-1 3-C-2 N/A See Program Section 7.4.3.3 Removal System 4 Safety Injection 7.4.3.4 VT-1 B-C-2 System 4 Sets /4 Bolts 4 Sets 1 1 2 ISI-0002-C

5. Upper Head 7.4.3.5 VT-1 B-C-2 12 Sets /2 Bolts 12 Sets 4 4 4 ISI-0001-C Injection System E. Piping

1. Circumferential Welds A. Reactor 7.4.4.1 UT/FT B-J 62 16 Coolant System Accelerated FW Frograss Schedule

($ 5 6)' 1S1-0008-B 5 6 5 Main Loops Cires _)4" t .

' See Original RrR-14.

Schedule prior to implementing the accelerated FW program. Do not use these numbers for the first interval.

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S SI-114.2 Page 6 of 14 APPENDIX A Rev. 13 TABLE A  ; 9 SEQUOYAR INSERVICE INSPECTION PROGRAM CIASS 1 COMPONENTS '

Program .Section XI

• Reference Exam F== let Insp. Interval Inspection Perioda Component Section Method Category 40 Yr. e - le Reference Sample 3 rrs. 7 yrs. 10 yrs. Dwn. No.

E. Piping (Cont'd)

B. Reactor Coolant System j

Cires 14"

! Nom. Size 7.4.4.2 UT/PT B-J 62 15 5

' 5 5 ISI-0013-C Cires <4" I Nom. Size 7.4.4.2 PT B-J 110' 27' 8 9' 10' IFI-0013-C l

! . o_ C. N alesi and -

volume Control

'! System i

Cires 14" Nom. Size 7.4.4.3 N/A ISI-0009-C

} Cires <4" Nom. Size 7.4.4.3 PT B-J 60 15' 4 5 6' ISI-0009-C MSG-0008-C D. Residual Heat i Removs1 System Cires 14 "

l Nom. Size 7.4.4.4 UT/PT B-J 45 11 3 4 4 ISI-0003-C f

! 'The change in weld numbers during the second period was due to new code class boundaries.

}

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, 0869e/C0C4 4 *

- - - . - - - . . - . . _ . - . . . - - - - - - - - . . - - - , . _ , - - . , - - - - - - . - , - - - - _ - - - - , - - - - . - - - - - - - - - -e. ,- -, , .. --, - . , . - 1

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sI-114.2 Page 7 of 14 APPENDIX A Rev. 13 l TABLE A j SEQUOYAR INSERVICE INSPECTION PROGRAM i iI CIASS 1 COMPONENTS Program Section XI Reference Fw amm* Fu- 1st Insp. Interval Inapection Perioda Reference l Component Section Method Category 40 Yr. M le Sample 3 yrs. 7 yrs. 10 yrs. 3wn. No.

i Eo Piping (Cont'd) i E. Safety l Injection l System Cires t

24" Kom.

l Size 7.4.4.5 UT/PT B-J 72' 18' 6' 6' 6' ISI-0002-C Cires 44" Nom. Size 7.4.4.5 PT s-J 38 10 (3 3 4)* ISI-0002-C

, Accelerated W program schedule 3 4 3 7 F. Upper Head Injection System Cires p " 7.4.4.6 UT/PT B-J 120' 30 10 10 10 ISI-0001-C

3. Brsnch Pipe Connection Welds A. Reactor Coolant System - Main Loops Welds

>2" Ncm. Size 7.4.5.1 UT/PT B-J 1 1 0 1 0 ISI-0008-8 Welds 42" Nom. Sizw 7.4.5.1 PT B-J 13 48 1 1 2 ISI-0006-B

'The change in weld numbers during the second period was due to new code class bounderlea.

. ' Original schedule prior to implementing the accelerated W prograu. Do not =?? tl.see numbeirs for the first laterval.

See Rf2-14

) 'Ennch pipe corrections 42" have 1,een combined with the >2".

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sgst :

$1-114.2 Page 8 of 14 AFFENDIX A Rev. 13 l TABLE A SEQUOYAE INSERVICE INSFECTICK PROGRAM CIASS I COMPONENTS raogram Section XI

.aference Exam' Exam Ist Insp. Interval Inspection Periods Component Section Method Category 40 Yr.

• m le Reference Sample 3 yre. 7 yrs. 10 vrs. Dez. No.

E. Piping (Cont'd)

B. Reactor Coolant System Welds

>2" Nom. Size 7.4.5.1 UT/PT B-J 6 2 0 Welds <2" 1 1 ISI-0013-C Nom. Size 7.4.5.2 PT B-J 8 2 8

0 1 1 ISI-0013-C C. Chemical and Volume Control .

System Welds Y >2" Nom. Size 7.4.5.3 UT/PT B-J 3 1 0 0 Welds <2"

~

1 ISI-0009-C Nom S1re 7.4.5.3 N/A - - - - -

ISI-0009-C D. Residual Ecst Removal System Welds .

>2" Nom. Size 7.4.5.4 UT/PT B-J 3 1 0 0 1 ISI-0003-C Welds 12" Nom. Size 7.4.5.4 PT E-J 2 -

0 0 0 ISI-0003-C E. Safety Injection System Welds

>2" Nom. St.e 7.4.5.5 UT/PT B-J 5 1 0 1 0 Welds _<2" ISI-0002-C Nom. Size 7. & . S .,5 PT B-J 11 I' 1 ,1 0 ISI-0002-C

' Branch Pipe Connections i 2" have been combined with the > 2".

0869e/COC4 ,

1 5@8F SI-114.2 Page 9 of 14 AFFENDIX A Rev. 13 TABLE A SEQUOYAE INSERVICE INSPECTION FROGRAN I CLASS 1 COMPONENTS Program Section II Reference Exam' rv.= 1st Insp. Interval Inspection Periods Component Section Method catezory 40 Yr. Sample Reference

'mle 3 yrs. 7 yrs. 10 yrs. Dwa. No.

E. Pipiog (Cont *d)

F. Upper Head Injection System Welds >2" Nom. Size 7.4.5.6 N/A - - - - -

ISI-4001-C Welds c2 .

Nom. Size 7.4.5.6 PT B-J 2 l' 0 1 0 ISI-0001-C

. 'E Socket Welds

'!?

A. Reactor 7.4.6.1 PT B-J 238' 60' Coolant Accelerated N program schedule.

(20 20 20)*** ISI-0013-C 20 40 0 0 System B. Chemical and 7.4.6.2 PT B-J 240' 60' Volume Control (18 19 23)*** MSG-0008-C Accelerated FW program schedule. 18 42 0 ISI-0009-C System C. Residual Heat 7.4.6.3 PT B-J 18 5 (1 2 2)* ISI-0003-C Removal System Accelerated N program schedle 1 4 0 D. Safety 8 7.4.6.4 FT B-J 171 43 (14 14 15)* ISI-0002-C Injection Accelerated N program schedule. 14 29 0 System

' Branch pipe connections < 2" ,have been combined with > 2".

'The chsnge in weld numbers during the second period was due to new code class boundaries. ,

"Original schedule prior to feptementing the accelerated W program. Do not use these naambers for the first interval exama. See RFR-14 0869e/C0C4

4 sqNP SI-114.2 Fase 10 of 14 APPENDIX A Rev. 13 TABI.E A SEQUOYAE INSERVICE INSPECTION PROGRAM '

C1. ASS 1 COMPONENTS Program Section XI Reference Exam Exam 1et Insp. Inte.rval Inspection Periods Component Section Method Catemory 40 Yr. Sample Reference S-le 3 yrs. 7 yrs. 10 yrs. Dwn. No.

E. Pip h (Cont'd)

E. Upper Head 7.4.6.5 PT B-J 16 4 Injection (1 1 2)* ISI-0001-C Accelerated W program schedule. 1 3 0 System 4 Piping and Valve ytegrally-Welded Support

, Members e

Y 7.4. 7.1 A. Reactor PT B-K-1 9' 9' (3 3 3)*** MSC-0013-C Coolant Accelerated W program schedule 3 6 O System B. Chemical and 7.4.7.2 PT B-K-1 1 1 0 volume Control 1 0 MSG-0012-C System MSG-0015-C C. Residual Heat 7.4.7.3 PT B-K-1 5 5 (1 2 2)*

Removal System MSC-0010-C Accelerated W program schedule 1 4 0 D. Safety 7.4.7.4 PT B-K-1 6' 6' 3 2 3s.a.s ISI-0151-C Injection Accelerated W program schedule 3 5 0 System

'The change in support nus:bers during the second period was due to new code class boundaries. e

' Sample went from 9 to 6 welds on the second period. Of the three done in the first period 2 are no longer CC-1, therefore, we will do 2 welds on the second period and three welds in the third period.

' Original schedule prior to implementing the accelerated W program. Do not use these numbers for the first interval exams. See RFR-14 OS69e/COC4

SquP SI-114.2 Page 11 of 14 APPENDIX A Rev. 13 TABl.E A SEQUOYAE INSERVICE INSPECTION FROGRAN I CIASS 1 COMPONENTS Frogram Section XI Reference Exam Exam ist Insp. Interval Component Inspection Periods Reference Section Method Category 40 Yr. Sample Sample 3 yre. 7 yrs. 10 yrs. Dwn. No.

F. Piping (Cont *d)

E. Upper Head 7.4.7.5 PT B-K-1 1 1 0 1 0 MSC-0014-C Injection

5. Piping ard Valve,_

Component Supports A. Reactor 7.4.8.1 VT-3, B-K-2 138' 138' Coolant (45 46 47)'** MSG-0013-C VT-4 Accelerated W program schedule 45 93 0

& System

?

B. Chemical and 7.4.8.2 130' Volume Control VT-3, VT-4 B-K-2 130' (38 46 46) MSG-0012-C Accelerated W program schedule 38 92 0 MSG-0015-C System C. Residual Beat 7.4.8.3 VT-3, B-K-2 17 17 (5 6 6)* MSC-0010-C Removal System VT-4 Accelerated W program schedule 5 12 0 o

D. Safety 7.4.8.4 VT-3, B-K-2 91 8

91 8

(27 31 33)'**** ISI-0151-C Injection VT-4 Accelerated W program schedule 27 64 0 System E. Upper Head 7.4.8.5 VT-3, B-K-2 88 88 (29 29 30)' MSC-0014-C Injection VT-4 Accelerated W program schedule 29 59 0 System -

'Origir.a1 schedule prior to is~plementing the accelerated N program. Do not use these numbers for the first interval exasa. See RFR-14

'Tha change in support numbers during the second period was due to new code class bonandaries.

• Eight of the supports done in the first period as CC-1 are now CC-2.

0869e/COC4

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i SQNP SI-114.2 Page 12 of 14 i

APPENDIX A Rev. 13 TABLE A i f SEQUDYAE INSERVICE INSPECTION FROCRAM j CIASS 1 COMPONENTS i

i Program Section XI l Reference Fu- Fum 1st Insp. Interval Component ISepection Periods ReferimCe

]

Section Method catezory 40 Tr. Sample *mle 3 yrs. 7 yrs. 10 yrs.

$ Dwn. No.

) E. Pipina (Cont'd)

F. RCS Main 7.4.8.6 VT-3 B-K-2 7s. 7s.:

toop Piping VT-4 (0 4 3)'**

i 0 7 0 F. Reactor Coolant Pumps Press 2re- 7.5.1 UT B-C-1 96 96 l

.ining 24 24 48 ISI-0307-3

, ing o

..asure- 7.5.1 UT. R-C-1 96 96 24 24 taining 48 ISI-0307-5 PT or MT when removed j bolting Deferral to end of interval is permissible when bolts are removed i

j e. Pressure- VT-1 7.5.2 B-C-2 4RCP/1 Set

• 4 sets 1 set i Retaining I set 2 sets ISI-0307-8 Bolting .

4. Integrally- 7.5.3 PT B-K-1 3 pumps /3 fest 9 feet 3 3 3 8

Welded Supports per pump" ISI-0326-3

5. Component 7.5.4 VT-3 B-K-2 4 pumps /3 feet 12 feet 3 Supports VT-4 per pump *

'3 6 15I-0326-3

6. Casing 7.5.0 VT-1 3-Ic2 4 See Frogram Sectica 7.5.6 N/A .

7. Flywheel 7. 5. 7 , UT N/A 4 See Frogram Section 7.5.7, ISI-0306-3

' Original schedule prior to implementing the accelersted W program. Do not use these numbers for the first interval cr.ams . See RFR-14

'The change in support numberi in the second period was due to new code class boundaries.

"See Program Reference Section for explanation of inspection sample. ,

898F SI-114.2 AFFBIDIX A Fase 13 of 14 Rev. 13 TABLE A t

SEQUOYAE INSERVICE INSPECTION FROGRAM CIASS 1 COnroutxts Program Section KI Reference Fw== Exam ist Insp. Interval Component Inspection Feriods Reference Section Method catezory 40 Yr. Sample Sample 3 yrs. 7 yrs. 10 yrs. Dwn. No.

G. Valves *

1. Pressure t

Retaining bolting A. Reactor 7.6.2.1 VT-1 3-C-2 15 15 4 Coolant System 5 6 ISI-0013-C

, B. Chemical and 7.6.2.2 VT-1 5-C-2 3 3 y Volume Control 0 1 2 ISI-0009-C

• System MSG-0008-C C. Residual Heat 7.6.2.3 Yt-1 B-C-1 6 6 1 2 Removal System 3 ISI-0003-C D. Safety . 7.6.2.4 VT-1 B-i-2 15' 15' 6 Injection 6 5 ISI-0002-C System E. Upper Head 7.6.2.5 VT-1 B-G-2 8 8 Injection 2 3 3 ISI-0001-C System

2. Integrally- 7.6.3 UT/PT B-K-1 See Program Section 7.4.7 Welded Support

• Members s -

'In the second period 4 of the CC-1 valves became CC-2.

'All the valves pressure retainis- Two of which were examined in the first period.

bolted connectings have been combined for all the systems for category 5-G-2.

0869e/COC4 .

~

SQMP SI-114.2 Page 14 of 14 APPENDIX A Rev. 13 TABLE A SEQUOYAN INSERVICE INSPECTION PROGRAM ' '

CIASS 1 COMPONDrr5

.rogram Section XI Reference Exsm Exas let Insp. Interval Inspection Perioda Reference C xponent Section Method Catemory 40 Yr. Sample Sample 3 rre. 7 Frs. 10 vre. Dwn. No.

C. Univas (Cont *d)  !

3.

Component 7.6.4 VT-3 B-K-2 See Program Section 7.4.8 Supporta VT-4

4. Valve Bodies 7.6.6 VT-4 B-M-2 See Table D Part I of Appendix A

>4" N.P.S.

H. Sys*em 7.9 VT-2 B-P See Program Section 7.9 Pressure Teste E

y 1. Peactor Vessel - Pressure Retaining Boundary

2. Pressurizer - Pressure Retaining Roundary

3. Steam Generators - Pressure Retaining Boundary

4. Heat Exchangers - Pressure Retaining Boundary ~

,. Piping - Pressure Retaining Boundary

6. Pumps - Pressure Retaining Boundary

7. Valves - Pressure Retaining Boundary 0869e/CoC4 e

a

squF SI-114.2 Page 1 of 8 '

APPENDIX A TABLE B Rev. 13 i

SEQUDYAE INSERVICE INSFECTION FROCRAM CLASS 2 COMPONENTS Program Section XI Reference Exam Fu== let Imep. Interval Inspection Feriods Component Section Method Catefory 40 Yr. Sample Sample Reference 3 yre. 7 yre. 10 yrs. Dwn. No.

A. Steam Generators

1. Circumferential 8.1.1 UT C-A 4 Cens./3 Welds 3 1 1 1 I

1S1-0320-B Shell Wids (12)

2. Circumferential 8.1.2 UT C-A 4 Cens./1 Weld I wld/46 ft 15' 15' 16' 151-0320-B Head Welds (4)

3. Tubesheet-to- 8.1.3 UT C-A 4 Cens./1 Wald Shell Weld I wid/36 ft 12' 12' 12' ISI-4320-3 (4) h4 Nozzle-to-Vessel 8.1.4 Welds & Inner UT. MT C-B 4 Cens/2 Nos 8 1 3 4 ISI-0320-B (8)

Radius B. Heat Exchanaers

1. Residual Beat -

Removal Heat Exchanger (2)

RHRHX

a. RHRHX Circumferen- 8.2.1.1 UT C-A 2 Et. Ex./1 Weld I wid/113" tial tube-37" 38" 38" ISI-0289-A sheet to Shell Weld 1 *

'In the first period the UHI WA was examined (weld IT2WA-1) for category C-3 welds (3 welds in sample) nad category C-C (two welds in sample). But during the second period the tank was exempted under IWC-1220(a) of A$hE al;ection XI 77ES78A.

Aal the welds under category C-C e.nd all the welds under category C-B have combined.

C0C4/0870e

- . _ ~ _.__

i l

W SI-114.2 Fase 2 of S AFFENDIX A TASIE B Rev. 13 i SEQUOYAN INSERVICE INSFECTION FROCRAM l

CIASS 2 COMFONENTS '

Frogram Section XI Reference Exam Fne 1st Insp. Interval Inspectica Feriods Reference Cornponent Section Method Category 40 Yr. etaple Sample 3 yrs. 7 vrs. 10 yrs. Dwn. No.

B. Heat Exchangers (Cont'd)

b. RERHX Circumferen- 8.2.1.2 UT C-A 2 Et. Ex./1 Weld I wld/113" 37" 38" 38" --7 ? *9-A tial Shell to (2)

Head Weld

c. RRREX Nozzle-to- 8.2.2 UT. FT C-3 2 Et. Ex./2 nos. 4 1 8

1 2 ISI-0289-A i Vessel Weld (4) {

3* d. RHRHX Integrally- 8.2.3 FT C-C 2 Et. Ex./2 Wids 2 0' 1 1 ISI-0289-A Welded (4)

Supports

c. RHREX Component 8.2.4 VT-3 C-E 2 Et. Ex./ 4 1 1 2 ISI-0289-A Supports 2 Sprts. (4)

2. Regenerative Heat See Relief Request ISI-12 Exchanger (1) REX

3. Excess Leitdown See Relief Request ISI-12 l Heat Exchanger (1) ELHX .

I l

'In the first period the UHIWA was examined for category C-B welds (3 weld: in sample) and category C-C(two welds in sample). But during the second period the tank was exempted under IWC-1220(a) of ASPE Sectica XI 77ES78A. All the welds j undec cacegory C-C and all the welds under category C-B have combined. j C0C4/0870e

W SI-114.2 AFFENDIX A TABLE B Fase 3 of 8 Bev. 13 SEQUOYAS INSERVICE INSFECTION FROGRAM CLASS 2 COMFONENTS Frogram Section XI Reference Exam Exas 1st Insp. Interval Inspectica Ferioda Component Section Method category 40 Yr. Emle Reference Sample 3 yrs. 7 yrs. 10 yrs. Dwa.'No.

C. Tanka

1. Boron Injection Tank (1) BIT

a. BIT Circum- 8.5.1 UT C-A 1 Tank /2 Welds 2 1 0 ferential 1 ISI-0074-A Shell/ Bead Weld

b. BIT Nozzle 8.5.2 MT. UT C-B 1 Tank /2 Noz. 2 08 1 1 ISI-0074-A h

N to Vessel Welds

. BIT IW 8.5.3 FT C-C 1 Tank /4 IA's Supports 4 0'** 2 2 ISI-0074-A

d. BIT Component 8.5.4 VT-3 C-E 4 4 1 1 2 ISI-0074-A Supports

<. BIT Pressure 8.5.5 UT C-D 179wy/16 Stude 1 rewy 1 0 0 ISI-0074-A Retaining Bolting

>2" Dia.

2. Seal Water Injection Filter 2 (SWIF)

a. SWIF Circum- 8.8.1 UT C-A 2 Filters'/2 Wids 2 O l' l' ISI-0225-A ferential Flenge/ -

Shell Weld .

'The exam should lie done atter the f11ters are changed or flushed to reduce the radiation exposure.

In the first pericJ the UN!WA was examined for category C-B welds (3 welds in aample) and category C-C(two welds in cample).

But during the second period the tank was exempted under IWC-122O(a) of ADE Section XI 77ES78A. All the welda under category C-B and-all the welds under category C-C have been combined. s

'In the first period these were considered 3/8" therefore they were exempt. Now they are 5/8". '

W SI-114.2 Page 4 of 8 AFFENDIX A TAB 12 B Rev. 13 SEQUOYAE INSERVICE INSPECTION PROGRAN CIAss 2 ConroNurTS Frogram Section XI Reference Fems Eaan let lasp. Interval Inspection Periods Cneponent section Method Category 40 Yr. e--le Reference Sample 3 yre. 7 yre. 10 yrs. Dum. No.

D. Piping

1. Integrally-Welded Supports

a. Residual 8.9.1.1 N/A C-C See Frogram section MSG-0010-C Heat Removal 8.9.1.1 System

b. Safety 8.9.1.2 FT C-C 7 8

7' g

Injection (1 3' 3)* ISI-0151-C Accelerated N program schedule 1 6 0 MSC-0009-C y System l c. Main Steam 8.9.1.3 MI C-C 11 11 (1*

l System 5 5)* MSC-0017-C 1

Accelerated N program schedule. 1 7 3

d. Icedwater 8.9.1.4 MT C-C 5 5 0 3 2 MSC-0016-C System

c. Containment 8.9.1.5 Ff C-C Se Program Section Spray System MSG-0011-C 8.9.1.5

f. L'pper Head 8.9.1.6 PT C-C 4 4 Injection (1 1 2)* MSC-0014-C Accelersted N program schedule. 1 3 0 ,

System l

1 .

i l 'The change in support numbers diaring the second period was due to new code class boundaries. ~

'One of these supports, (2-MSH-312) became IC.CC during the second period.

' Original schedule prict to implementing the accelerated W program. Do act ease these numbers for the first laterval I exaes. See RFR-14

• i COC4/0870e

SQNF s1-114.2 Fase 5 of 8 AFFENDIX A TABI.E B Rev. 13

?

SEQUOYAI INSERVICE INSFECTION FROGRAM CIASS 2 COMPONEN25 Frogram Section XI Reference Fume Fuma let Insp. Interval Inspection rerio4s neferene.

Component Section Method Category 40 Tr. Sample Sample 3 yrs. 7 yrs. 10 yrs. Dws. No.

D. Piping (Cont'd)

2. Piping and Valve Creponent Supports

a. Residual 8.9.2.1 VT-3 C-E 83 83 (27 28 28)* MSG 4010-C Heat Removal VT-4 Accelerated W progam schedule 27 56 O System

b. Safety 4.9.2.2 VT-3 C-E 77' 77' (18 29' 30')* MSG-00J9-C

. Injection VT-4 Accelerated W program schedule 18 59 0

?. System a

c. Main Steam 8.9.2.3 VT-3 C-E 65' 65 8

(20'** 24' 24')* MSG-0017-C System VT-4 Accelerated W program schedule 20 48 0 ,

d. Feedwater 8.9.2.4 VT-3 C-E 30 33 (10 10 10)* MSG-0016-C System VT-4 Accelerated W program schedule. 10 20 0

c. Contairment 8.9.2.5 VT-3 C-E 5 5 (1 2 2)* MSG-0011-C Spray System VT-4 Accelerated W program schedule. 1 4 0 f, !!pper Head 8.9.2.6 VT-3 C-E 7 7 (2 2 3)* MSG-0014-C Injection VT-4 Accelerated W program schedule. 2 5 0 Systers

'ne change in component suppor'ts during the second period was due to * *w code class bou v aries.

' Support 2-MSH-312. 428 and 429 were CC-2 in the first period. They beca EsCC in ** e second period.

' Original schedule prior to irplementing the accelerated W program. Do ne use these numbers for the first interval.

Se2 kra-14 C0C4/0870e

~

SW SI-114.2 Page 6 of 8 APPENDIX A ".JLE B Rev. 13 SEQUCYAE INSERVICE INSFECTICII PROGRAM CLASS 2 COMP 00WrI5 Frogram Section XI Reference Exam Exam ist Insp. Interval Component Section Method Catemory 40 Yr.

• rle Inspection F;.'iode Refersace Sample 3 yre. 7 rre. 10 yre. Duia. No.

D. U ping (Cont *d)

3. Circumferentist' t and Longitudinal I

! A. Residual Beat Removal System

)

{ a. RER Cires 31/2" Nom. W11 Thickness #

8.9.4.1 UT. FT C-F. C-C 27' S 1 2 3

! ISI-0003-C k' i b. RER Long. >1/2" Nom. W 11 Thickness

} 3 8.9.4.1 UT FT C-?. C-C 6' 2' 1 0 l' ISI-0003-C

c. RER Cires :1/2" Nom. W11 Thickness ~

l 8. 9.7. 1 PT C-F. C-C 121' 30' S 11' 11'

. ISI-0003-C 5

d. RER "ong. 41/2" Nom. Wil Thickness

! ~ 8.9.4.1 FT C-F. C-C 49' 12' 2 8 5' 6' ISI-0C03-C I

B. Safety Inj.ction System

! a. SIS Cires >1/2" Nom. Wa1.1 Thickness

, 8 9.4.2 117. FT C-F. C-C 42' 11' 3 4' 4' 1SI-0002-C J

b. S15 Circa 11/2" Nom. Wall Thickness 8.9.h.? FT C-F. C-C 50' 12' 2 5' 5' ISI-0002-C .

i ISI-0074-A l 'The changes in weld numbers during the second period was due to new code cleaa boundaries.

i 0rigina" schedule prior to implementing the accelerated IV program. Do not use these numbers for the first interval er.aus. See RFR-14

' Weld RERS-7-LS was done as i 1/2". now we coesider it as > 1/2".

i 4 *All long seam

• elds under C-F/C-G and all circumferential welds sander C-F/C-C have been cashined.

' C0C4/0870e

-., E r SQNP S1-114.2 Page 7 of 8 APPENDIX A TABLE B Rev. 13 SEQUOYAH INSERVICE INSPECTION PROGRAM CLASS 2 COMPONENTS Program Section XI Reference Fram A a= 1st Insp. Interval Inspection Periods Reference Component Section Method Category 40 Yr. Sample Sample 3 yrs. 7 yrs. 10 yrs. Dws. No.

D. Pip'ng (Cont'd)

c. SIS Long. 11/2" Nom. Uall Thickness

8. 9. '- - 2 PT C-F. C-C 23' 5 0 2 3 ISI-0002-C C. Main Steam System

c. MS Cires >1/2" Nom. Wall Thickness 8.9.4.3 U-. MT C-F. C-C 13' 4' 0* 2 28 ISI-u015-C e

5 b. MS Long. >1/2" Nom. Wall Thicknaess i' 8.9.4.3 UT MT C-C. C-C 8' 2' O 1 l' ISI-0015-C D. Feedwater System

a. FW Cires >1/2" Nom. Wall Thickness 8.9.4.4 UT. MT C-F C-G 14' 4 0 2 2 CHM-2403-C

b. FJ Long. >1/2" Nom. Wall Thickness 8.9.4.4 UT. MT C-F. C-C 2' 1 1 0 0 CHM-2403-C E. Containment Spray System

a. (S Cires 11/2" Non. Wall Thickness ,

8.9.4.5 PT C-F. C-C 6 1 1 0 0 ISI-0007-C

b. CS Long. 11/2" Nom. Wall Thickness 8.9.4.5 PT C-F. C-C

^

_ 1 0 ,1 0 ISI-0007-C

'The changes in weld numbers during the.second period was due to new code class boundaries.

' Weld MSF-10 is now KNCC and it was done in the first period as CC-2.

COC4/0870e

• T

SQNP SI-114.2 Page 8 of 8 APPENDIX A TABLE B Rev. 13 SEQUOYAH INSERVICE INSPECTION PROGRAM CLASS 2 COMPONENTS Prog sa Section XI Reference Eram Exam let Insp. Interval Inspection Periods Component Section Method Category 40 Yr. Sample Reference Sample 3 yrs. 7 yrs. 10 yrs. Dwa. No.

D. Piping (Cont'd)

F. Upperhead Injection System

a. Cire. welds > 1/2" nominal wall thickness 8.9.4.6 UT, PT C-F, C-C 25' 7 2 2 3 ISI-0001-C E. Pumps

~

. 1. Residual Heat Removc1 Pu=ps (2) RHRP o

7 a. RERT Suppor* N ponents

1. 0,1.2 VT-3 C-C, C-E 2 2 0 1 1 ISI-0099-A F. Systeca Pressure Test 8.12 VT-2 C-H See Program Sectio 8.12

'The change in components nu=bers during the second period was due to new codes class boundaries.

l .

l l

• l COC4/0870e h i

SQNP SI-114.2 Page 1 of 2 APPENDIX A IABLE C Rev. 13 SEQUOYAH INSERVICE INSPECTION PROGRAM CLASS 3 COMPONENTS Program Section XI Reference Exam Fram ist Insp. Interval Inspection Periods Compoaent Section Method Category 40 Yr. Sample Re8 erence Sample 3 yrs. 7 yrs. 10 yrs. Dwa. No.

A. System Pressure Tests

1. All ASME 9.0, 9.1 VT-2 D-A, D-B N/A N/A 1001 100% 100% N/A code Class 3 D-C (Equivalent)

B. Piping Co=ponent Supoorte

1. Auxiliary 9.0.1.1 VT-3 D-A

, Feedwater System VT-4 39 3 9 ' ' *- 45 39 39* ISI-0146-C k$ 2. Cbemical and 9.0.1.2 VT-3 D-A 0' O' 7 0' 0' Volu.e Control Systeri VT-4

3. Component 9.O.1.3 VT-3 165 165

Cooling System D-A, D-B 208 165 165*** ISI-0154-C VT-4 4 Containment 9.0.1.4 UT-$ D-B O' 0' 26 0' Spray System C' VT-4

5. Essential Raw 9.0.1.5 VT-3 D-A, D-B 298

8 293 a3 222 298' 298*

Cooling Water System VT-4 ISI-0158-C

6. Fuel Pool 9.0.1.6 VT-3 D-C N/A ,

N/A See Program Section 9.0.1.6 Cooling Sy:ter VT-4

'The change in support numbers, during the second period was due to new code class barriers. ,

• Equipment supports are shown'on part C. ~

. 0873e/COC4

SQNP SI-114.2 Page 2 of 2 APPENDIX A TABLE C Rev. 13 SEQUOYAH INSERVICE INSPECTION PROGRAM I CI. ASS 3 COMPONE?TS Program Section XI Reference Em Fram lat Insp. Interval Inspection Patriods Reference Component Section Method Categnry 40 Yr. Sample Sample 3 yra. 7 yrs. 10 yrs. Dws. No.

B. Component Supporis (Cont'd)

7. Residual Heat 9.0.1.7 VT-3 D-B O' 0' / 0' 0' Removal System VT-4

8. Safety 9.0.1.8 VT-3 D-B O' 0' 28 0' 0' Injection VT-4 System

,C. Equipment g Co=ponent Supports 7

1. Equipment 9.2 VT-3 D-A.D-B 59 supports 59' 57' 59' 59' Component D-C 40 pieces of supports equipment

2. Equipment compo 9.2 VT-3 D-A, D-B 56 integrally 12' 12' 12' 12' .

nent supports D-C welded support integrally welded attachments in attachment. 12 pieces of J

equipment.

'The change in support number $ during the second interval was due to new code class barriers'.

- 0873e/COC4 t

e

1 SQNP-sI-114.2 Pcga 1 cf 2 Rev. 13

. APPENDIX A TABLE D, PART I VAI.VES SUBJECT TO TiiE REQUIREMENTS OF EXAMINATION CATECORY B-M-2 0F TABLE IWB-2500-1 OF SECTION XI .

Code Valve Piping Valve Valve Valve Croup TVA Dwg No. Vendor Material Valve Forging Valve Fo. C! ass Cat. System Size Type Act No. (Weld Map) Dwg No. Vendor Spec. Function Casting i

i c3-560 1 AC-Act SIS 10" Ck SA 2 ISI-0002-C 94-12892 Darling ASTM A516' PSIV i 63-561 1 AC-Act SIS 10" Ok SA 2 ISI-0002-C 94-12892 Darling ASTM A516' PSIV

,63-562 1 AC-Act SIS 10" Ck S.s 2 ISI-0002-C 94-12892 Darling- ASTM A516 8 PSIV 63-5L3 1 AC-Act SIS 10" Ci SA 2 ISI-0002-C 94-12892 Darling ASTM A516' PSIV 63-622 1 AC-Act SIS 10" Ck SA 2 ISI-0002-C 94-12892 Darling ASTM A516' PSIV 63-623 1 AC-Act SIS 10" Ck SA 2 ISI-0002-C 94-1289 Darling ASTM A516' PSIV 63-624 1 AC-Act SIS 10" Ck SA 2 ISI-0002-C 94-12892 Darling ASTM A516' PSIV 63-625 1 AC-Act SIS 10" Ck SA 2 ISI-0002-C 94-12892 Darling ASTM A516' ESIV 63-640 1 AC-Act SIS /RIIR 8" Ck SA 2 ISI-0003-C 94-12392 Darling ASTM A516' PSIV 63-643 1 AC-Act SIS /RilR 8" Ck SA 2 ISI-0003-C 9':-12'192 Darling ASTM A516' PSIV

.63-558 1 AC-Act SIS 6" Ck SA 3 ISI-0002-C 78704 Velan ASTM A182 PSIV Forging 63-559 1 AC-Act SIS 6" Ck SA 3 ISI-0002-C 78704 Velan ASTM A182 PSIV Forging

?63-632 1 AC-Act SIS 6" Ck SA 3 ISI-0002-C 78704 Velan ASTM A182 PSIV Forging 63-633 1 AC-Act SIS 6" Ck SA 3 ISI-0002-C 7S104 Velan ASTM A182 PSIV Forging 63-634 1 AC-Act SIS 6" Ck SA 3 ISI-0002-C 78704 Velan ASTM A182 PSIV Forging

63-635 1 AC-Act SIS 6" Ck SA 3 ISI-0002-C 78704 Velan ASTM A182 PSIV Forging 1 53-641 1 AC-Act SIS /Ri!R 6 Ck SA 3 ISI-0003-C 78704 Velan ASTM A182 PSIV Forging i 63-644 1 AC-Ac't SIS /R!!R 6" Ck- SA 3 ISI-0003-C 78704 Velan ASTM A182 PSIV Forging

.68-563 1 C RCS 6" Re1 SA 4 ISI-0013-C 1151688' Crosby ASTM A182/ See A351' Note

• 68-564 1 C RCS 6 Re1 SA 4 ISI-0013-C H51688 Crosby ASTM A182/ See A351* Note

• 68-565 1 C RCS 6" Re1 SA 4 ISI-0013-C II5168G Crosby ASTM A182/ See A351' Note' FCV 74-1 1 A-Act RIIR 14" Cate MO 5 ISI--0003-C E-1-144831 Copes-Vulcan ASTM A182 PSIV Forging FCV-74-2 1 A-Act RIIR 14" Cate MO 5 ISI-0303-C E-1-144831 Copes-Vulcan ASTM A182 PSIV Forging NOTES:

t ,

' Seal plate manufactured to ASTM A240 F304. Body to ASTM A351 grade CF-8.

tiozzle manufactured to ASTM A182 F316 - Forging Body manufactured to ASTM A351 CR8M - Casting COC4/0876e ,

2 -

SQNP SI-114.2 Page 2 of 2 Rev. 13 APPENDIX A TABLE D. PART I ,

VALVES SUBJECT TO T11E REQUIREMENTS OF EXAMINATION CATEGORY B-M-2 0F TABLE IWB-2500-10F SECTION XI Code Valve Piping Valve Valve Valve Croup TVA Dwg No. Vendor Material Valve Forging Valve No. Class Cat. System Size Type Acc No. (Weld Map) Dwg No. Vendor Spec. Function Castina 87-558 1 AC-Act UHI 8" Ck SA 6 ISI-0001-C 3-148885 Copes-Vulcan ASTM A182 E7-559 1 AC-Act UHI 8" PSI 1, Forging CY SA 6 ISI-0001-C B-148885 Copes-Vulcan ASTM A182 PSIV Forging 87-560 1 AC-Act UHI 8" Ck SA 6 ISI-0001-C B-148885 Copes-Vulcan ASTM AIC2 87-561 AC-Act UHI 8" PSIV Forging 1 Ck SA 6 ISI-0001-C B-148885 Copes-Vulcan ASTM A182 87-562 AC-Act UHI F3IV Forging 1 12" Ck SA 6 ISI-0001-C B-148885 Copes-Vulcan ASTM A182 87-563 PSIV Forging 1 AC-Act UHI 12" Ck SA 6 ISI-0001-C B-148284 Copes-Vulcan ASTM A182 PSIV Forging

~

I e

COC4/0876e -

O

J^

SQNP SI-114.2 APPENDIX A - TABLE D. PART II Page 1 of 4 VALVES SUBJECT TO THE EXAMINATION I Rev. 13 REQUIREMENTS OF EXAMINATION CATECORY B-C-2 SIZE VALVE BOLTING VLV BODY IW COMP SYS VLV NO (IN) TYPE ISI DWG NO VENDOR VENDCB DWG NO <= 2" >2" WELDS SUPPORTS SUPPORTS CVC 62-560 2 CKV MSG-0008-C SH1 EDWARD D-464529 R5 N/A NONE IATER IATER CVC 62-561 2 CKV MSG-0008-C SH2 EDWARD D-464529 R5 N/A NONE IATER IATER CVC 62-562 2 CKV MSG-0005-C SH5 EDWARD D-464529 R5 N/A' NONE IATER LATER CVC 62-563 2 CKV MSC-0008-C SH3 EDWARD D-464529 R5 N/A N/A NONE N/A CVC 62-564 2 CATE MSG-0008-C SH1 EDWARD D-464532 R5 N/A NONE LATER LATER CVC 62-565 2 CATE MSG-0008-C SH2 EDWARD D-464532 R5 N/A NONE IATER LATER CVC 62-566 2 CATE MSG-0008-C SH5 EDWARD D-464532 R5 N/A NONE IATER IATER CVC 62-567 2 CATE MSG-0008-C SH3 EDWARD D-464532 R5 N/A NONE N/A 2-CVCH-120 CVC 62-576 2 CKV MSG-0008-C SHI EDWARD D-464529 R5 N/A NONE IATER LATER CVC 62-577 2 CKV MSG-0008-C SH2 EDWARD D-464529 R5 N/A NONE LATER IATER CVC 62-578 2 CKV MSG-0008-C SH4 EDWARD D-464529 R5 N/A NONE N/A N/A CVC 62-579 2 CKV MSG-0008-C SH4 EDWARD D-464529 R5 N/A NONE IATER IATER CVC 62-659 3 CKV ISI-0009-C SH2 BORG-WARNER 80290 5/16" NONE N/A N/A

~~ CVC 62-660 3 CKV ISI--0009-C SE2 BORG-WARNER 80290 5/16" NONE N/A 2-CVCH-349

'/ CVC 62-661 2 CKV ISI-0009-C SH2 EDWARD C-464529 R5 N/A NONE N/A N/A CVC 62-716 3 CKV ISI-0009-C SH2 BORC-WARNER 80290 5/16" NONE N/A N/A CVC 62-717 3 CKV ISI-0009-C SH2 BORG-WARNER 80290 5/16" NONE N/A N/A RHR 63-543 2 CKV ISI-0003-C SH8 EDWARD C-464529 R5 N/A NONE N/A N/A FHR 63-545 2 ~ CKV ISI-0003-C SH8 EDWARD C-464529 R5 N/A NONE N/A N/A SIS63-547 2 CKV ISI-0002-C SH12 EDWARD C-464529 R5 N/A NONE N/A N/A SIS63-549 2 CKV ISI-0002-C SE12 EDWARD C-464529 R5 N/A NONE N/A N/A SIS63-551 2 CKY ISI-0002-C SH4 EDWARD C-464529 R$ N/A NONE N/A 2-SIE-9,31,3 SIS63-553 2 CKV ISI-0002-C SH6 EDWARD C-464529 R5 N/A NONE LATER 1ATER SIS63-555 2 CKV ISI-0002-C SH5 EDWARD C-464529 R5 N/A NONE LATER LATER SIS63-557 2 CKV ISI-0002-C S:14 EDWARD . C-464529 R5 N/A NONE N/A N/A SIS63-558 6 CKV ISI-0CO2-C SH7 VELAN 78704 1 1/4" NONE N/A N/A SIS63-559 6 CKV ISI-0002-C SH7 VEIAN 78704 1 1/4" NONE N/A N/A .

SIS63-560 10 CKY ISI-0002-C SH5 ANCHOR / DARLING 94-12892 1 3/8" NONE N/A N/A ALL CONTRACTS 68-91934 EXbEPTFORVLVSFCV-68-332,333->8182961&PCV-L8-334,?404->83-83630.

Contract for valves62-559. 716, 717, 660 and FCV-62-69, 70. later.

C0C4/0877e

f SQNP SI-114.2 APPENDIX A - TABLE D. PART II ,Page 2 of 4 VALVES SUBJECT TO THE EXAMINATION ^ Rev. 13 REQUIREMENTS OF EXAMINATION CATEGORY B-C-2 SIZE VALVE BOLTING VLV BODY IW COMP SYS VLV NO (IN) TYPE ISI DWG NO VENDOR VENDOR DWG NO <= 2" >2" WELDS SUPPORTS SUPPORTS SIS63-561 10 CKV ISI-0002-C SH6 ANCHOR / DARLING 94-12892 1 3/8" M. LATER MTER SIS63-562 10 CKV ISI-C002-C SH6 ANCHOR / DARLING 94-12892 1 3/8" NONE LATER MTER SIS63-563 10 CKV ISI-0002-C SH4 ANCHOR / DARLING 94-12892 1 3/8" NONE I.ATER MTER SIS63-581 3 CKV ISI-0002-C SH7 VELAN 78409 3/4" NONE N/A N/A SIS63-582 1 1/2 CATE ISI-0002-C SH8 ROCKWELL INTERNATIONAL D-478072 N/A NONE N/A 2-SIE-154 SIS63-583 1 1/2 CATE ISI-0002-C SH9 ROCKWELL INTERNATIONAL D-478072 N/A NONE N/A N/A SIS63-584 1 1/2 CATE ISI-0002-C SH10 ROCKWELL INTERNATIONAL D-478072 N/A NONE N/A 2-SIN-227 SIS63-585 1 1/2 CATE ISI-0002-C SH11 ROCKWELL INTERNATIONAL D-478072 N/A NONE N/A N/A SIS63-586 1 1/2 CKV ISI-0002-C SH8 EDWARD C-465341 R2 N/A HOME N/A N/A SIS63-587 1 1/2 CKV ISI-0002-C SH9 EDWARD C-465347 R2 N/A NONE N/A N/A SIS63-588 1 1/2 CKV ISI-0002-C SE10 EDWARD C-465347 R2 N/A NONE N/A N/A SIS63-589 11/2 CKV ISI-0002-C SH11 EDWARD C-465347 R2 N/A NONE N/A N/A 1 SIS63-622 10 CKV ISI-0002-C SHS ANCHOR / DARLING 94-12892 1 3/8" NONE N/is 2-SIH-3.4 3 SIS63-623 10 CKV ISI-0002-C SH6 ANCHOR / DARLING 94-12892 1 3/8" NONE MTER LATER e SIS63-624 10 CKV ISI-0002-C SH6 ANCHOR / DARLING 94-12892 1 3/8" NONE MTER LATER SIS63-625 10 CKV ISI-0002-C SH4. ANCHOR / DARLING 94-12892 1 3/8" NONE N/A N/A SIS63-632 6 CKV ISI-0002-C SH6 VELAN 78704 1 1/4" NONE MTER MTER SIS63-633 6 CKV ISI-0002-C SHS VELAN 78704 1 1/4" NONE N/A N/A SIS63-634 6 CKV ISI-0002-C SH6 VEMN 78704 1 1/4" NONE MTER MTER SIS63-635 6 CKV ISI-0002-C SH4 VELAN 78704 1 1/4" NONE N/A N/A RHR 63-640 8 CKV ISI-0003-C SHS ANCHOR / DARLING 94-12892 1 3/8" NONE N/A N/A RHR 63-641 6 CKV ISI-0003-C SHS VELAN 78704 1 1/4" NONE N/A N/A RHR 63-643 8 CEV ISI-0003-C SH6 ANCHOR / DARLING 94-12892 1 3/8" NONE N/A N/A RHR 63-644 6 CKV ISI-0003-C SH6 VELAN 78704 1 1/4" NONE N/A N/A dCS68-504 2 CATE ISI-0013-C SH6 EDWARD D-464532 N/A NONE LATER MTER RCS68-505 2 CATE ISI-0013-C SH6 EDWARD D-464532 N/A NONE MTER LATER ECS68-508 3 CATE ISI-0013-C SHS VELAN 88406 3/4" NONE N/A 2-RCH-145 RCS68-509 2 CATE ISI-0013-C SH6 EDWARD D-464532 N/A NONE N/A N/A

• RCS68-510 2 CATE ISI-0013-C SH6 EDWARD D-464532 N/A L.NE N/A N/A ALL CONTRACTS 68-91934 EXCEPT FOR VLVS FCV-68-332. 333 -> 8182961 & PCV-68-334, 340A -> 83-83630.

1 Contract for valves62-559, 716. 717. 660 and FCV-62-69. 70. later.

- COC4/0877e

SQNP SI-114.2 APPENDIX A - TABLE D. PART II Page 3 of 4 VALVES SUBJECT TO THE EXAMINATION , Rev. 13 REQUIREMENTS OF EXAMINATION CATEGORY B-C-2 SIZE VALVE BOLTING VLV BODY IW COMP i SYS VLV NO (IN) TYPE ISI DWC NO VENDOR __ , VENDOR DWC NO <= 2" >2" WELDS SUPPORTS SUPPORTS RCS68-513 2 CATE ISI-0013-C SH6 EDWARD D-464532 RCS68-514 3 N/A NONE N/A N/A CATE ISI-0013-C SHS VELAN 88406 3/4" NONE N/A 2-iJH-141,142 RCS68-515 2 CATE ISI-0013-C SH7 EDWARD D-464532 N/A NONE N/A 2-RCh-198,199 RCS68-516 2 CATE ISI-0013-3 SH7 EDWARD D-464532 N/A NONE N/A N/A RCS68-519 3 CATE ISI-0013-C SH4 VEIAN 88406 3/4" NONE N/A 2-RCH-194 RCS68-520 2 GATE ISI-0013-C SH7 EDWARD D-464532 RCS68-521 2 N/A NONE N/A N/A CATE ISI-0013-C SH7 EDWARD D-464532 N/A NONE N/A RCS68-524 2 N/A CATE ISI-0013-C SH7 EDWARD D-464532 N/A NONE N/A RCS68-525 3 N/A CATE ISI-0013-C SH4 VELAN 88406 3/4" NONE N/A 2-RCH-190,191 RCS68-526 2 CATE ISI-0013-C SHS EDWARD D-464532 N/A RCS68-527 2 NONE N/A N/A CATE ISI-0013-C SH8 EDWARD D-464532 N/A NONE N/A 2-RCH-248,249 RCS.68-530 3 CATE ISI-0013-C SH2 VEIAN 88406 3/4"

/.RCS68-531 2 NONE N/A 2-RCH-244 CATE ISI-0013-C SH8 EDWARD D-464532 N/A NONE N/A N/A ERCS68-532 2 CATE ISI-0013-C SH8 EDWARD D-464532 N/A

' RCS68-535 2 NONE N/A N/A CATE ISI-0013-C SB8 EDWARD D-464532 N/A NONE N/A 2-RCH-236 l RCS68-536 3 GATE ISI-0013-C SH2 VEIAN 88406 3/4" RCS68-537 2 NONE N/A 2-RCH-231,233 CATE ISI-0013-C SH9 EDWARD D-464532 N/A NONE N/A N/A RCS68-538 2 CATE ISI-0013-C SH9 EDWARD D-464532 N/A NONE N/A 2-RCH-298.299 ECS68-541 3 CATE ISI-0013-C SH4 VEIAN 88406 3/4" RCS68-542 2 NONE N/A N/A CATE ISI-0013-C SH9 EDWARD D-464532 N/A NONE N/A N/A 2CS68-543 2 CATE ISI-0013-C SH9 EDWARD D-464532 N/A RCS 6*-546 2 NONE N/A N/A CATE ISI-0013-C SH9 EDWARD D-464532 N/A NONE N/A h/A RCS M-647 3 CATE ISI-0013-C SH4 VEIAN 88406 RCS 66-JM 2 3/4" NONE N/A 2-RCH-290.291 CATE ISI-0013-C SH10 EDWARD D-464532 N/A NONE N/A N/A' RCS 68-55 2 CATE ISI-0013-C SH10 EDWARD D-464532 N/A RCS68-553 2 NONE N/A N/A 4

CATE ISI-0013-C SH10 EDWARD -

D-464532 N/A NONE N/A N/A i

RCS68-554 2 CATE ISI-0013-C SH10 EDWARD D-464532 N/A RCS 68-55) 2 NONE N/A N/A CATE ISI-0013-C S211 EDWARD D-464532 N/A NONE N/A N/A

• ALL CONTRACTS 68-91934 EXCEPT FOR VLVS FCV-68-332 333 -> 8182961 L PCV-68-334, 340A -> 83-83630.

Contract for vale s62-559, 716, 717, 660 and FCV-62-69, 70, later.

COC4/0877e

SQNP SI-114.2 APPENDIX A - TABLE D. PART II , Page 4 of 4 VALVES SUBJECT TO THE EXAMINATION Rev. 13 REQUIREMENTS OF EXAMINATION CATECORY B-C-2 SIZE VALVE BOLTING VLV BODY IW COMt SYS VLV NO (IN) TYPE ISI DWC NO VENDOR VENDOR DWC NO <= 2" 12" WELDS SUPPORTS SUPPORTS RCS68-558 2 CATE ISI-0013-C SH11 EDWARD D-464532 N/A RCS68-563 NONE N/A N/A 6 RELF ISI-0013-C SH3 CROSBY H-51688 1" NOME N/A 2-RCH-+5,63 RCS68-564 6 RELF ISI-0013-C SH3 CROSBY H-51688 1" RCS68-565 NONE N/A 2-RCE 41,72 6 RELF ISI-0013-C SH3 CROSBY H-51688 1" NONE N/A 2-RCH-80,83 CVC 68-580 3 CATE ISI-0009-C SIII VELAN 13920 N/A RCS68-581 NONE N/A N/A 2 CATE ISI-0013-C SH11 EDWARD D-464532 N/A NONE N/A N/A RCS68-582 2 CATE ISI-0013-C S1111 EDWARD D-464532 N/A UHI 63-558 NONE N/A N/A 8 CKV ISI-0001-C Stil COPES-VULCAN B-148885 1 1/4" NONE N/A N/A UHI 68-559 8 CKV ISI-0001-C SIII COPES-VULCAN B-148885 1 1/4" NONE N/A N/A UHI 68-560 8 CKV ISI-0001-C SH2 COPES-VULCAN B-148885 1 1/4" NONE N/A N/A UHI 68-561 8 CKV ISI-0001-C S!!2 COPES-VULCAN B-148885 1 1/4" NONE N/A N/A UHI 87-562 12 CEV ISI-0001-C Clil COPES-VULCAN B-148284 R7 1 1/2" Ud1 87-563 NONE N/A N/A 12 CKV ISI-0001-C 5112 COPES-VULCAN B-148284 R7 1 1/2" NONE N/A N/A 8 CVC FCV-62-69 3 CATE ISI-0009-C SI'i MASONEIIAN/WORTli!NCTON CPI-1855,A8425 7/8" NONE N/A 2-CVC-294 g CVC FCV-62-70 3 CATE ISI-0009-C SHL MASONEI1AN/WORTHINGTON CPI-1855,A84757 7/8" NONE N/A N/A

' CVC FCV-62-84 2 CATE ISI-0009-C SH2 MASONEIIAN A-8474,A-8475 7/8" NONE N/A 2-CVCH-327 RCS FCV-68-332 3 CATE ISI-0013-C SH3. VEIAN 02-405-0494-2 3/4" NONE N/A 2-RCH-fi,95,96 RCS FCV-68-331 3 CATE ISI-0013-C S113 VEIAN 02-405-0494-2 3/4" NONE N/A 2-RCH-88,89.90 RHR FCV-74-1 14 CATE ISI-0003-C Sil7 COPES-VULCAN E-1-144831 R4 1 3/4" NONE LATER LATER RHR FCV-74-2 14 CATE ISI-0003-C Sil7 COPES-VULCAN E-1-144831 R4 1 3/4" NONE Il.TER IATER UHI FCV-87-7 2 CATE ISI-0001-C SII2 COPES-VULCAN L-170203 R2 1 1/8" NONE N/A N/A UllI FCV-87-8 2 CATE ISI-0001-C'SH1 COPES-VULCAN L-170203 R2 1 1/8" NONE N/A N/A RCS PCV-68-340D 4 BALL ISI-0013-C SH1 FISHER 50A2159 7/3" NONE N/A N/A RCS PCV-68-340A 3 CATE ISI-0013-C SH3 TARCET ROCK 1052020-3 N/A NONE N/A N/A RCS PCV-68-340L 4 BALL ISI-0013-C SH1 FISHER 50A2159 7/8" NONE N/A N/A RCS PCV-68-334 3 CLB ISI-0013-C SH3 TARCET ROCK 1052020-3 N/A NONE N/A N/A ALL CONTRACTS 68-91934 EXCEPT FOR VLVS FCV-68-332, 333 -> 8182961 & PCV-68-334, 340A -> 83-83630.

Cor. tract for valves62-559, 716, 717, 660 and FCV-62-69, 70, later. .

. COC4/0877e

-r_ -,-- __ . _ -

i

' SQNP 1 SI-114.2 APPENDIX A - TABLE E Page 1 of 2 VALVES SUBJECT TO 1HE EXAMINATION Rev. 13 REQUIREMENTS OF EXAMINATION CATECORY C-D SIZE 1 i SYS VLV NO VALVE BOLTING VLV BODY IW COMP (IN) TYPE ISI DWC NO VENDOR VENDOR DWC NO <= 2" >2" WELDS SUPPORTS SUPPORTS 4

ts 1-619 6 CATE ISI-0015-C Stil WALWORTl! A-6609-M-128B 7/8" N/A NONE N/A N/A l MS 1-620 6 GATE ISI-0015-C SH2 WALWORTl! A-6609-M-128B 7/8" N/A NONE N/A N/A

. 53 1-621 6 GATE ISI-0015-C Stil WALWORTII A-6609-M-128B 7/8" N/A NONE N/A N/A ML 1-622 6 CATE ISI-0015-C SIII WALWORT!I A-6609-M-128B 7/8" N/A NONE N/A N/A F4 3-508 16 CKV CHM-2403-C SH2 WALWORTli A-11332-M-32A IV 3-509 16 CYV 1 3/4" N/A NONE LATER LATER CIIM-2403-C S!!2 WALWORTH A-11332-M-32A 1 3/4" N/A NONE FW 3-510 16 CKV LATER LATER C11M-2403-C SH1 WALWORTH A-11332-M-32A 1 3/4" N/A EW 3-511 16 CKV NONE LATER LATER CllM-2403-C S!!1 WALWORTil A-11332-M-32A 1 3/4" N/A NONE SIS63-502 12 CKV LATER LATER ISI-0002-C S!!6 ALOYC0 D48276 K74221C 1" N/A NONE N/A RER 74-514 8 CKV N/A ISI-0003-C Si!3 CRANE K-7422 7/8" N/A NONE N/A RHE 74-515 8 CKV N/A ISI-0003-C SII3 CRANE K-7422 7/8" N/A N/A RHR 74-520 8 CATE ISI-0003-C S!!2 ALOYC0 NONE I /A E-47381 3/4" N/A NONE N/A N/A Ri!R 74-521 8 CATE ISI-0003-C SII3 ALOYC0 E-47381

!* RHR 74-524 8 3/4" N/A NONE N/A N/A CATE ISI-0003-C SH2 ALOYC0 E-47381 3/4" N/A NONE N/A

[kEER74-525 8 N/A CATE ISI-0003-C SH3 ALOYC0 E-47381 3/4" N/A N/A O i P6 FCV-1-4 NONE N/A

' 32 CATE ISI-0015-C Stil ATWOOD & MORRILL CO 21245-H LATER N/A NONE N/A N/A MS FCV-1-11 32 CATE ISa-0015-C Sil2 ATWOOD & MORRILL CO 21245-11 LATER N/A NONE N/A N/A

?$ FCV-1-22 32 CATE ISI-1015-C S!!2 ATWOOD & MORRILL CO 21245-H F3 FCV-1-29 LATER N/A NONE N/A N/A 32 CATE ISI-0115-C SHi ATWOOD L MORRILL CO 21245-H LATER N/A NONE N/A N/A FW FCV-3-33 18 CATE CliM-2493-C SH1 WALWORTli 3 FW FCV-3-47 A-6614-M-15D 1 1/2" N/A NGNE LATER LATFR 18 CATE CHM-2403-C SH2 WALWORTli A-6614-M-15D 1 1/2" N/A

! FW FCV-3-87 NONE LATCR LATER IS CATE C51M-240 3-C SII2 WALWORTl! A-6614-M-15D 1 1/2" N/A NON';

FW FCV-2-100 18 CATE CIIM-240_'-C Slll WALWORT!! LATER LATER A-6614-M-15D 1 1/2" N/A NONE LATER LATER RHR FcV-63-72 18 CATE ISI-0003-C Stil ANCl!0R/ DARLING 94-13300 1 1/4" N/A NONE N/A N/A RIIR FCV-63-73 18 CATE ISI-0003-C S!ll ANCl!OR/ DARLING 94-13300 1 1/4" N/A NONE N/A N/A RHR FCV-63-172 12 CATE ISI-C003-C S!!5 VELAN 88907-2 1 7/8" N/A SIS FCV-63-1 NONE N/A N/A 16 CATE ISI-C002-C Sill CRANE K-7634-15.16 7/8" N/A NONE N/A SIS FCV-53-8 8 N/A CATE ISI-0002-C SII3 ANCIIOR/ DARLING '94-13295 7/8" N/A S S FCV-63-11 8 NONE N/A N/A CATE ISI-9002-C SH3 ANCif0R/ DARLING 94-13295 7/8" NONE SIS FCV-63-41 8 LATER LATE 1 CATE ISI-0002-C SII6 ALOYC0 E-48836 LATER N/A NONE N/A N/A ALL CCNTRACTS 68-91934

. 0885e/COC4 i

e

0885e/COC4 SQNP SI-114.2 APPENDIX A - TABLE E Page 2 of 2 "ALVES SUBJECT TO THE EXAMINATION Rev. 13 REQUIREMENTS OF EXAMINATION CATEGORY C-D SIZE VALVE EOLTING VLV BODY IW COMP SYS VLV NO (IN) TYPE IS1 om no VENDOR VENDOR DWC NO <= 2" >2" WELDS SUPPORTS SUPPORTS SIS FCV-63-67 10 CATE ISI-0002-C SH4 VELAN 88926 R.D1 1 3/8" NONE N/A N/A SIS FCV-63-80 10 CATE ISI-0002-C SH6 VELAN 88926 R.D1 1 3/8" NONE I.ATER LATER SIS FCV-63-93 8 CATE ISI-0002-C SH1 VELAN 8806-1 1 3/8" N/A NONE LATER LATER SIS FCV-63-98 10 CATE ISI-0002-C SH6 VELAN 88936 R.D1 1 3/8" NONE MTER MTER SIS FCV-63-118 10 CATE ISI-0002-C SHS VELAN 88926 R.D1 1 3/8" NONE N/A N/A SIS FCV-63-40 8 CATE ISI-0002-C SH6 ALOYC0 E-48836 MTER N/A NONE N/A N/A SIS FCV-63-94 8 GATE ISI-0002-C SH2 VELAN 88806-1 1 3/l," N/A NONE N/A 2-SIH-429 CS FCV-72-20 12 CATE ISI-0007-C SH1 ALOYCO E-48840 MTER N/A NONE N/A **

./*

CS FCV-72-23 12 CATE ISI-0007-C SH1 ALOYC0 E-48840 LATER N/A NONE N/A N/A RHR FCV-74-3 14 CATE ISI-0003-C SH4 ANCHOR / DARLING 94-13298 1 1/8" N/A NONE N/A N/A RER FCV-74-5 14 MTER ISI-0003-C SH4 LATER MTE;l MTER N/A LATER N/A N/A RHR FCV-74-16 8 BUTF ISI-0003-C SH2 FISHER COVERNOR CO F-41304 MTER N/A NONE N/A 2-RHR-508 RHR FCV-74-21 14 CATE ISI-0003-C SH4 ANCHOR / DARLING 94-13298 1 1/8" N/A NONE N/A N/A

RER FCV-74-28

~~

8 BUTF ISI-0003-C SH3 FISHER COVERNOR CO F-41304 LATER N/A NONE N/A 2-RHR-509 2HR FCV-74-32 8 EUTF ISI-0003-C SH2 FISHER COVERNOR CO F-41304 MTER N/A NONE N/A N/A 7 RHR FCV-74-33 8 CLOB ISI-0003-C SH2 ANCHOR / DARLING 93-13435 3/4" N/A NONE N/A N/A RHR FCV-74-35 8 CATE ISI-0003-C SH3 ANCHOR / DARLING 93-13435 3/4" N/A NONE N/A N/A UHI FCV-87-21 12 CATE ISI-0001-C SH3 ANCHOR / DARLING 93-13447 R.F. 2" N/A NONE LATER LATER-UHI FCV-87-22 . 12 CATE ISI-0001-C SH3 ANCHOR / DARLING 93-13471 R.F. 2" N/A NONE LATER MTER UHI FCV-87-23 12 CATE ISI-0001-C SH3 ANCHOR /DARLINC 93-13471 R.F. 2" N/A NONE MTER MTER UHI FCV-87-24 12 CATE ISI-0001-C SH3 ANCHOR / DARLING 93-13471 R.F. 2" N/A NONE LATER MTER l RHR HCV-74-34 8 CATE ISI-0003-C SH3 ANCHOR / DARLING 93-13435 3/4" N/A NONE N/A 2-RER-431 RHR HCV-74-36 8 CATE ISI-0003-C SH2 ANCHOR / DARLING 93-14074 3/4" N/A NONE N/A N/A RHR HCV-74-37 8 CATE ISI-0003-C SH3 ANCHOR / DARLING 93-13435 3/4" N/A NONE N/A N/A MS PCV-1-5 6 CATE ISI-0015-C SH2 COPES-VULCAN B-149093 R7 LATER N/A LATER N/A 2-MSH-321.-322 MS PC7-1-12 6 CATE ISI-0015-C SHL COPES-VULCAN B-149093 R7 MTER N/A MTER N/A 2-MSH-356, 357 MS PCV-1-23 6 CATE ISI-0015-C SHL COPES-VULCAN- B-149093 R7 LATER N/A NONE N/A 2-MSH-396,-397 MS PCV-1-30 6 CATE ISI-0015-C SH1 COPES-VULCAN B-149093 R7 LATER N/A NONE N/A 2-MSH-439.-440 ALL CONTRACTS 68-91934 i

, 4685e/COC4

o .

SQNP SI-114.2 Page 1 of 4 Rev.13

_ APPENDIX A TABLE F

, LIST OF ORANINGS - UNIT 2

, Reactor Vessel Appendix A

. Drawing No. Title Page No.

~

. CH-M-2360-A Reactor Vessel Inlet Nozzles 1 ISI-0097-C Closure Head Penetrations 47-48

~

ISI-0297-A Reactor Vessel Outlet Mozzles 107 ISI-0298-8 Reactor Vessel Scan Welds 108 ISI-0300-A Control Rod Drive Housing 110-111 ISI-0301-A Reactor Vessel Closure Head 112 ISI-0304-8 Reactor Vessel Stud Locations and Detalls 114-115 ISI-0318-A Auxillary Head Adapter 120 ISI-0319-A Reactor Vessel Botton Head Penetrations 121 Pressurizer Appendix A Drawing No. Tlt1e Page No.

ISI-0299-8 Pressurizer and Steam Generator Cladding Patches .

and Hanway Bolting 109 ISI-0308-A Pressurizer Seam Helds 118 IS!-0309-A Pressurizer Heater Penetations 119 ISI-0323-A Pressurizer Support Sk$rt Held 124 Steam Generators '

Appendix A Orawing No. Title Page No.

76H1 Vertical Steam Generators (Tube Sheet Arrangement) 4 ISI-0299-8 Fressurizer and Steam Generators Cladding Patches and Hanway Bolting 109 151-0320-8 Steam Generator 122., ,

ISI-0350-A Steam Generator /Feedwater Transition Spool Piece 126 o

.gi3 0875e/COC4

SQNP SI-114.2 Page 2 of 4 Rev. 13

~

APPENDIX A TABLE F (Continued)

Heat Exchangers Appendix A Drawing No. Title _Page No.

ISI-0226-8 Gas Stripper and Boric Acid Evaporator Package 81-84 ISI-0229-A Positive Displacement Pump 011 Cooler 86 ISI-0230-A Gross failed fuel Detector Heat Exchanger 8?

ISI-0231-8 Centrifugal Charging Pump 011 & Gear Cooler 88 ISI-0232-8 Waste Gas Compressor Heat Exchanger 89 1S1-0233-8 Centrifugal Charging Pump Mechanical Seal Heat Exchanger 90 ISI-0234 C RHR Pump Seal Water Heat Exchanger 91 ISI-0235-A Safety Injection Pump 011 Cooler 92 ISI-0236-A Safety Injection Pump Mechanical Seal Heat Exchanger 93 ISI-0257-A Non-Regenerative Letdown Heat Exchanger Evaporator Package 98 ISI-0258-A Seal Water Heat Exchanger 99 ISI-0259-A Containment Spray Heat Exchanger 100 15I-0261-8 Component Cooling Heat Exchanger Support Location 102 ISI-0289-A ' Residual Heat Removal Heat Exchanger 105 ISI-0291-8 RHR Heat Exchanger Secondary Side Support (CCS) 106 Piping and Valve Weld Maps Appendix A Drawing No. Title Page No, CH-M-2403-C Feedwater System 2-3 ISI-0001-C Upper Head Injection System 5-7 ISI-0002-C Safety Injection System 8-19 ISI-0003-C Residual Heat Removal System 20-27 ISI-0007-C Containment Spray System 28 ISI-0008-8 Reactor Coolant Piping (Hain Loops) 29-30 ISI-0009-C Chemical and Volume Control System 31-32 ISI-0013-C Reactor Coolant System 33-43 ISI-0015-C Main Steam System 44-45 MSG-0008-C Seal Water Injection (Chemical and Volume Control System) 127-131

-119- 08750/COC4

m

, SQNP.

SI-114.2 Page 3 of 4 Rev. 13'

-. APPEN0!X A TABLE F (Continued)

Cless 1 and 2 Piping and' Valve Scoport Orwings Appendix A Drawinq No.

Title _ Pace No.

MSG-0009-C Safety injection System 132-143 MSG-0010-C Residual Heat Removal Systen 144-l'50 MSG-0011-C Containment Spray System 151 MSG-0012-C Chemical and Volume Control System 152-153 MSG-0013-C Reactor Coolant System 154-165 MSG-0014-C Upper Head Injection System 166-169 MSG-0015-C Seal Water Injection (Chemical and Volume Control System) 170-174 mig-0016-C Feedwater System 175-176 MSG-0017-C Main Steam System 177-178 ISI-0151 C Safety injection System 52 ISI-0302-C Reactor Coolant System Support Locations (Main Loop) 113 ISI-0321-B Reactor Coolant System (Main Piping) Crossover Leg Restraint 123 C1gsts 3 Pipinq and Valve Support Orawings Appendix A Drawing No. Title Page No.

ISI-0146-C Aux 111ary feedwater System 50-51 ISI-0154-C Component Cooling System 53-59 ISI-0158-C Essential Raw Cooling Water System 60-79 ,,

Pumps Appendix A Drawing No. Title Page No.

ISI-0099-A Residual Heat Removal Pump Supports 49 ISI-0238-A Thermal Barrier Booster Pump 94, ,

151-0253-8 Turbine Driven Auxillary Feedwater Pump Support Locations 95 151-0260-8 CCS Water pumps 2A-A & 28-8 Support Locations 101 15!-0263-B Hotor Driven Auxillary feedwater Pumps Support Locations 103 151-0306-B Reactor Coolant Pump Hotor Flywheel Examination 116 151-0307-8 Reactor Coolant Pump Main Flange and Lower Seal House Bolt Pattern 117 151-0326-8 Reactor Coolant Pump Support Feet. 125

-120- 0875e/CN4

^

SQNP

. SI-114.2 Page 4 of 4

.' Rev. 13

_. APPEN0!X A-TABLE F (Continued)

Tanks Appendix A l' Ora',Ina No. Title Page No.

'SI-0074-A Boron Injection Tank (Unit 2) 46 '

. ISI-0225-A Seal Water Injection Filter 80, 151-0227-8 Component Cooling Surge Tank 85

, ISI-0268-A ERCN System Strainer Support Detail 104

. I

~

Pipino Support Details L Drawino No. Title Appendix A ,

Page No. >

ISI-0255-A ERCH System Support Detail 96-97 l

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-121- 08752/COC4 i i

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                                                                                        .                                                                               I MFERTNCE DRAWINGS BE-esso-scc SH. :120-2050 CONTRACT NO. 72C33-92692 F-6722-2               .

ASnt CC-3 (EQUIVALENT) b CCNxH-4-IA (2/2.2 1/2] - CootH-3-IA (2/2. 2 1/2) - - m l _v- 7, _ y _g_ _7 g NOTC PLATE IS MT SELDED TO VESSEL NO*w

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                                                                                                                        .                                 IMIT 2 an ,         e                                                                                                           COMOONENT COOLING HEAT EXCHA%ER 8 SLApp0RT L OCA TIOC
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17771-1 ASME CC-3 (EQUIVALENT) ERCWSH-11-IA (24 IA 'S. i " EACH) ERCWSH-12-IA (24 IA *S. 1." EACH) . O 24" INLET y24" OUTLET l 3 l

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• I# ESSENTIAL RAW COOLING WA TER SYSTEM tuaCWApc TExTRCNix 4129 STRAINER SUPPORT DETAIL SOFTWAPE TENNECAD 8.2 -

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IS'I-0268-A 00-

ASNE CC-2 ($0UIVALENT) NOTES FM LNIT I DWG SEE CIN-2404-A 2 IM ET IM.ET ~ RmW-16-Y-Z ~ RHRW- l 9- Y-IA -

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t LIST OF CONTROL ROD DRIVE HOUSINGS C.R.D. NO. N(JMBER B 01-09 9 9.05 10-13 4 9.57 64-17 4 12.20 18-21 4 13.07 22-29 8 14.02 , 30-37 38-41 8 4 16.81 19.69 L g[ 42-49 8 20.67  ?" o-z E , 50-53 4 21.69 G ' .* 54-6I 8 23. 74 $~ 62-65 4 27.17 66-73 8 28.3i FOR NOTES SEE SH. I 7f-78 5 Jf.50 TOTAL r 78 l FOR LOCATIONS SEE DRAWINGS ISI-OO97-C aEv. er care ocsaxerzcer cw olsts :Apr. TENESTE VALLEY AUTMMITY DIVISIOV W NX1 EAR ENGIhEERInC SEQUOYAH NUCLEAR PLANT UNIT 2 - CONTROL ROD DRIVE HOUSING nev- 0 wrwar 18" 50s5 wAm. arc suwstrev Apenosto scAtt urs sxrune con ytt,e-ar-se --care. .s-se

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N co 7 NOTES, I. TMSE ARE DISSIMILAR METAL WELDS CATEGORY B-F.

2. TMSE WELDS ARE ALSO SHOWN ON ISI-0001-C

3. FOR LNIT I DWG SEE ISI-0014-A REv- er o^rt wsorzprim wo s:n. Ape.

TEMESSEE VALLEY AUTMRITY

                                                                               * * * ' * * * ' ^ " ' * *  *

4. FOR PENETRATION WELDS SEE DWG ISI-0097-C. SEQUOYAH NUCLEAR PLANT WIT 2 AUXILIARY LEAD ADAPTER

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